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EXHIBIT 10.11
CONFIDENTIAL
CONTRACT FOR PURCHASE
between
TENASKA GEORGIA I, L.P.
and
GENERAL ELECTRIC COMPANY
An asterisk [*] indicates that confidential information has been omitted and
filed separately with the Securities and Exchange Commission as part of a
Confidential Treatment Request.
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TABLE OF CONTENTS
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<S> <C> <C>
ARTICLE 1. DEFINITIONS...................................................................................................1
Acceptance Testing.............................................................................................1
Applicable Laws................................................................................................1
Availability Test..............................................................................................1
Business Days..................................................................................................1
Buyer's Inspector(s)...........................................................................................1
Cancellation Charge............................................................................................1
Commercial Operation...........................................................................................1
Computer Programs..............................................................................................1
Contract.......................................................................................................2
Delay Notice...................................................................................................2
Delivery.......................................................................................................2
Delivery Point.................................................................................................2
Demonstration Tests............................................................................................2
Design Finalization Meeting....................................................................................2
Directed Order.................................................................................................2
Dispute Notice.................................................................................................2
Documentation..................................................................................................2
Emissions Test.................................................................................................2
EPC Agreement..................................................................................................2
EPC Contractor.................................................................................................2
Equipment......................................................................................................2
Excusable Delay................................................................................................2
Facility.......................................................................................................2
Guarantee Fuel.................................................................................................2
Initial Synchronization........................................................................................3
Liquidated Damage Performance Guarantees.......................................................................3
Month..........................................................................................................3
Normal Carriage................................................................................................3
Options........................................................................................................3
Performance Guarantees.........................................................................................3
Performance Minimums...........................................................................................3
Performance Tests..............................................................................................3
Power Purchase Agreement.......................................................................................4
Project........................................................................................................4
Project Coordinators...........................................................................................4
Projected Date of Commercial Operation.........................................................................4
Proposed Delivery Date.........................................................................................4
Punch List.....................................................................................................4
Requested Delivery Date........................................................................................4
Scheduled Delivery Date........................................................................................4
Section(s).....................................................................................................4
Services.......................................................................................................4
Site...........................................................................................................4
Spare Part.....................................................................................................4
Specifications.................................................................................................4
Subcontractor(s) or Supplier(s)................................................................................4
Substantial Completion.........................................................................................5
Total Contract Price...........................................................................................5
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Unit(s)........................................................................................................5
Unit Contract Price............................................................................................5
Utility Tests..................................................................................................5
Witness Tests..................................................................................................5
ARTICLE 2. SCOPE OF SUPPLY...............................................................................................6
2.1 Scope.....................................................................................................6
2.2 Directed Order............................................................................................6
2.3 Multiple Projects.........................................................................................6
2.4 Options...................................................................................................6
2.5 Pre-Assembly..............................................................................................6
ARTICLE 3. PRICE AND TERMS OF PAYMENT....................................................................................8
3.1 Total Contract Price......................................................................................8
3.2 Sales Tax.................................................................................................8
3.3 Progress Payment Schedule.................................................................................8
3.4 Changes in Total Contract Price...........................................................................8
3.5 Progress Payment Invoices.................................................................................9
ARTICLE 4. SHIPMENT AND DELIVERY........................................................................................11
4.1 Shipment of Equipment....................................................................................11
(a) Combustion Turbine Scheduled Delivery Date...................................................11
(b) Revised Total Contract Price and Payment Schedule............................................11
(c) Scheduled Delivery Date......................................................................12
(d) Delivery.....................................................................................12
4.2 Method of Shipment.......................................................................................13
4.3 Early Shipment...........................................................................................13
4.4 Inspection of Equipment..................................................................................13
ARTICLE 5. INSPECTION AND FACTORY TESTS.................................................................................14
5.1 Inspection Rights........................................................................................14
5.2 Witness Tests............................................................................................14
5.3 Notification of Testing..................................................................................14
5.4 Consequences of Inspection...............................................................................14
ARTICLE 6. DELIVERY, TITLE, AND RICK OF LOSS............................................................................15
6.1 Risk of Loss.............................................................................................15
6.2 Passage of Title.........................................................................................15
6.3 Computer Programs........................................................................................15
6.4 License of Computer Programs.............................................................................15
ARTICLE 7. EXCUSABLE DELAYS.............................................................................................17
7.1 Excusable Delay..........................................................................................17
ARTICLE 8. COMPLIANCE WITH LAWS, CODES AND STANDARDS....................................................................18
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8.1 Compliance with Applicable Laws..........................................................................18
8.2 Change in Applicable Laws................................................................................18
ARTICLE 9. CHANGES; ADDITIONAL EQUIPMENT................................................................................20
9.1 Changes..................................................................................................20
9.2 Options..................................................................................................20
ARTICLE 10. WARRANTY....................................................................................................21
10.1 Warranties and Representations..........................................................................21
10.2 Warranty Period.........................................................................................21
10.3 General Conditions of Warranty..........................................................................22
10.4 Warranty Obligations....................................................................................22
(i) Net Equipment Electric Output.......................................................24
(ii) Net Equipment Heat Rate............................................................24
(iii) Net Equipment Peak Electrical Output..............................................24
10.5 Extension of Warranty Period............................................................................24
10.6 Exclusive Warranties....................................................................................25
10.7 Warranty Exclusion......................................................................................25
ARTICLE 11. PROPRIETARY INFORMATION.....................................................................................26
11.1 Proprietary Information.................................................................................26
11.2 Exclusions from Confidentiality.........................................................................26
11.3 Buyer's Confidential Information........................................................................26
11.4 No Adequate Remedy......................................................................................27
11.5 Confidentiality of Contract.............................................................................27
ARTICLE 12. INTELLECTUAL PROPERTY.......................................................................................28
12.1 Intellectual Property Indemnification....................................................................28
12.2 Remedy for Infringement.................................................................................28
12.3 Exception to Indemnification............................................................................28
ARTICLE 13. LIMITATION OF LIABILITY.....................................................................................29
13.1 Limitation of Liability.................................................................................29
13.2 Consequential Damages Exclusion.........................................................................29
13.3 Retention of Remedies...................................................................................29
13.4 Further Limitations.....................................................................................30
ARTICLE 14. TERMINATION.................................................................................................31
14.1 Termination.............................................................................................31
14.2 Termination by Seller...................................................................................31
14.3 Termination by Buyer....................................................................................31
ARTICLE 15. INDEMNIFICATION.............................................................................................32
15.1 Indemnification.........................................................................................32
15.2 Indemnification.........................................................................................32
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ARTICLE 16. PERFORMANCE GUARANTEES......................................................................................33
16.1 Performance Guarantees..................................................................................33
(a) Liquidated Damage Performance Guarantees.....................................................33
(b) Performance Guarantees.......................................................................33
16.2 Satisfaction of Liquidated Damage Performance Guarantees and Performance Guarantees.....................34
(a) Satisfaction of Liquidated Damage Performance Guarantees.....................................34
(b) Satisfaction of Performance Guarantees.......................................................34
16.3 Demonstration Test Guarantees...........................................................................35
16.4 Availability Test Guarantee.............................................................................35
ARTICLE 17. LIQUIDATED DAMAGES AND ACCEPTANCE TESTING...................................................................37
17.1 Schedule Liquidated Damages.............................................................................37
(a) Delivery.....................................................................................37
(b) Commercial Operation.........................................................................37
(c) Accrual of Liquidated Damages under Section 17.1.............................................40
(d) Aggregation of Liquidated Damages............................................................40
(e) Limitation...................................................................................41
17.2 Performance.............................................................................................41
(a) Performance Guarantees.......................................................................41
(b) Performance Liquidated Damages...............................................................41
(i) Net Equipment Electric Output.......................................................41
(ii) Net Equipment Heat Rate............................................................41
(iii) Net Equipment Peak Electrical Output..............................................41
(c) Acceptance Testing...........................................................................41
(i) Testing Procedures..................................................................41
(ii) Diagnostic Testing and Remedy......................................................42
(iii) Retesting.........................................................................43
(d) Seller's Election to Reduce Liquidated Damages for Commercial Operation......................43
(e) Modified Liquidated Damages..................................................................45
(f) Failure of Performance Tests.................................................................45
(g) Limitation...................................................................................47
17.3 Documentation Liquidated Damages........................................................................47
17.4 Limitation of Liquidated Damages........................................................................47
17.5 Exclusive Remedy........................................................................................47
17.6 Application of Total Contract Price Reductions..........................................................48
ARTICLE 18. PROJECT MANAGEMENT..........................................................................................49
18.1 Project Coordinators....................................................................................49
18.2 Continuity of Seller's Employees........................................................................49
18.3 Status Reports..........................................................................................49
ARTICLE 19. TECHNICAL SERVICES..........................................................................................50
19.1 Technical Services......................................................................................50
ARTICLE 20. TRAINING AND DOCUMENTATION..................................................................................51
20.1 Documentation...........................................................................................51
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20.2 Reproduction of Documentation...........................................................................51
20.3 Training................................................................................................51
ARTICLE 21. INSURANCE...................................................................................................52
21.1 Insurance Requirements..................................................................................52
21.2 Additional Requirements.................................................................................52
ARTICLE 22. GENERAL CLAUSES.............................................................................................53
22.1 Assignment..............................................................................................53
22.2 Third Party Beneficiaries...............................................................................54
22.3 Entire Agreement........................................................................................54
22.4 Severability............................................................................................54
22.5 Independent Contractor..................................................................................54
22.6 Governing Law...........................................................................................54
22.7 Notice..................................................................................................54
22.8 Construction............................................................................................55
22.9 Nuclear Waiver..........................................................................................55
22.10 Dispute Resolution.....................................................................................56
22.11 Disclosure of Information..............................................................................56
INDEX TO APPENDICES......................................................................................................58
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CONTRACT FOR PURCHASE
This Contract, effective this 27th day of August, 1999, is between
Tenaska Georgia I, L.P., a Delaware limited partnership ("Buyer") and General
Electric Company, a New York corporation ("Seller"). Buyer and Seller may be
referred to individually as a "Party" and collectively as "Parties".
ARTICLE 1. DEFINITIONS
The following defined terms used in this Contract have the meanings specified in
this Section.
ACCEPTANCE TESTING for a Unit means the performance of one or more of the
Performance Tests, Demonstrations Tests, the Emission Test, the Availability
Test or the Utility Tests for such Unit in accordance with the general
requirements of Section 3.0 of Appendix C and the particular requirements of the
individual tests.
APPLICABLE LAWS means all laws, ordinances, rules, regulations, orders,
interpretations, requirements, standards, codes, resolutions, licenses, permits,
judgments, decrees, injunctions, writs and orders of any court, arbitrator, or
governmental (federal, national, state, municipal, local or other, having
jurisdiction over a Party and the location where a particular element of the
Services is performed or where any part of the Equipment is situated) agency,
body, instrumentality or authority that are applicable to either or both of the
Parties, the Facility, the Site, the Services or the terms of this Agreement,
including the Codes and Standards described in Section 8 of Appendix A and all
environmental and hazardous materials laws which are applicable to a Site or the
Equipment and which are at any time applicable to performing the Services.
AVAILABILITY TEST means the test conducted by Buyer or on Buyer's behalf to
demonstrate that each Unit satisfies the requirements of Section 7.0 of Appendix
C.
BUSINESS DAYS mean all calendar days except Saturdays, Sundays and all legal
holidays of the United States or the State of New York.
BUYER'S INSPECTOR(S) has the meaning set forth in Section 5.1.
CANCELLATION CHARGE has the meaning set forth in Section 14.1.
COMMERCIAL OPERATION has the meaning set forth in Section 17.1(b).
COMPUTER PROGRAMS means the software programs provided by Seller to Buyer under
this Contract.
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CONTRACT means this contract, including Appendices A through M.
DEFERRED TESTS has the meaning set forth in Section 10.2.
DELIVERY has the meaning set forth in Section 4.1(d)(ii).
DELIVERY POINT means (i) the location selected by Buyer for Delivery of a Unit
in accordance with Section 4.1 when shipped by highway transport, or (ii) the
accessible rail siding nearest the location selected by Buyer in accordance with
Section 4.1 when shipped by rail transport.
DEMONSTRATION TESTS means tests conducted by Buyer or on Buyer's behalf to
demonstrate that a Unit satisfies the requirements of Section 6.0 of Appendix C.
DESIGN FINALIZATION MEETING has the meaning set forth in Section 18.3.
DIRECTED ORDER has the meaning set forth in Section 2.2.
DISPUTE NOTICE has the meaning set forth in Section 22.10.
DOCUMENTATION has the meaning set forth in Section 20.1.
EMISSIONS TEST means a test conducted by Buyer or on Buyer's behalf to
demonstrate that a Unit satisfies the Performance Guarantee set forth in Section
4.1 of Appendix C.
EPC AGREEMENT means the Engineering, Procurement and Construction Agreement of
Buyer for the Project, when executed.
EPC CONTRACTOR means the entity or entities which execute an EPC Agreement with
Buyer for the Project.
EQUIPMENT means: all items as described in Appendix A; all items included in any
Appendix D option exercised in accordance with such Appendix; and, all other
items, parts, components and materials necessary for the manufacture and supply
of the Units.
EXCUSABLE DELAY has the meaning set forth in Section 7.1.
FACILITY means the power generation facility at the Project Site together with
all Equipment located at such Site.
GUARANTEED DATE has the meaning set forth in Section 4.1(a).
GUARANTEE FUEL means the operating fuel, in accordance with fuel specifications,
which are specifically identified in Section 2.1 of Appendix C.
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INITIAL SYNCHRONIZATION means, for each Unit, the date on which the generator
breaker for such Unit is first closed and the Unit is connected to the electric
grid.
INTERIM PERFORMANCE REQUIREMENTS means the Interim Performance Requirement for
Net Equipment Electrical Output set forth in Section 1.1 of Appendix C and the
Interim Performance Requirement for Net Equipment Heat Rate set forth in Section
1.2 of Appendix C
LIQUIDATED DAMAGE PERFORMANCE GUARANTEES has the meaning set forth in Section
16.1(a).
MECHANICALLY COMPLETE means that installation of a Unit is complete and such
Unit and all necessary auxiliary systems (including any balance of plant issues
such as gas supply) are ready for first fire.
MONTH means a period of time beginning on a certain day of the month and ending
on the day before the same date in the following calendar month, provided that
when determining periods of one or more Months if the calendar month which
should contain the end date does not have a date corresponding to the end date
then the end of the period shall be the last day of such calendar month.
NORMAL CARRIAGE means carriage by either highway transport or by rail transport,
as selected by Seller, on normal routing from the factory to the Delivery Point.
OPTIONS has the meaning set forth in Section 9.2.
PERFORMANCE GUARANTEES has the meaning set forth in Section 16.1(b).
PERFORMANCE MINIMUMS means the Performance Minimum for Net Equipment Electrical
Output set forth in Section 1.1 of Appendix C and the Performance Minimum for
Net Equipment Heat Rate set forth in Section 1.2 of Appendix C.
PERFORMANCE TESTS means tests conducted by Buyer or on Buyer's behalf in
accordance with Section 5.0 of Appendix C to determine if a Unit or Units have
satisfied certain of the Liquidated Damage Performance Guarantees, Performance
Minimums and Performance Guarantees.
PHASE means either Phase I or Phase II of the Project.
PHASE I means the installation of Units #1, #2 and #3 and shall be completed
upon the achievement of Substantial Completion of all of Units #1, #2 and #3 and
the satisfactory completion of the tests set forth in Section 8.0 of Appendix C
with respect to such Units.
PHASE II means the installation of Units #4, #5 and #6 and shall be completed
upon achievement of Substantial Completion for all of the Units #1 through #6
and the satisfactory completion of the tests set forth in Section 8.0 of
Appendix C with respect to Units #1 through #6.
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POTENTIAL LIQUIDATED DAMAGES has the meaning set forth in Section 17.2(d).
POWER PURCHASE AGREEMENT means an agreement for the sale of power from the
Project.
PROJECT means the construction of a power generation facility for Buyer in Heard
County, Georgia, or such other location as designated by Buyer in accordance
with Section 4.1, at which the Units are to be installed, including related and
associated Equipment.
PROJECT COORDINATORS has the meaning set forth in Section 18.1.
PUNCH LIST means unfinished items which in the reasonable opinion of Buyer do
not affect the operation, safety or integrity of a Unit at a certain Facility
and do not impact the performance or life of the Unit, but are included in the
scope of Seller's obligations under the Contract.
SCHEDULED DATE OF COMMERCIAL OPERATION means, for each Unit, the "Scheduled Date
of Commercial Operation" for such Unit as such term is defined in the EPC
Agreement and, for each Phase, means the latest Scheduled Date of Commercial
Operation for any Unit in such Phase.
SCHEDULED DELIVERY DATE has the meaning set forth in Section 4.1(c).
SCHEDULED SHIPMENT DATE has the meaning set forth in Section 4.1(c).
SECTION(S) means sections of this Contract, not including Appendices, unless
otherwise stated.
SERVICES means all work or services to be performed by Seller in accordance with
this Contract.
SHIPMENT has the meaning set forth in Section 4.1(d)(i).
SITE means the location of the Project as set forth in the legal description
attached as Appendix K, or such other legal description as Buyer may substitute
upon designation of a Delivery Point other than a location at or near Heard
County, Georgia.
SPARE PART means any component of a Unit purchased by Buyer under this Contract
which is intended to be placed into Buyer's inventory and not used or installed
into the Unit at the time of Initial Synchronization.
SPECIFICATIONS means: Appendices A, C, D and G and, all other obligations of
Seller as described in Articles 1 through 22 of this Contract.
SUBCONTRACTOR(S) OR SUPPLIER(S) shall mean any licensor, subcontractor or
supplier of any tier supplying material, equipment, documentation, labor, goods
or services to Seller in connection with the obligations of Seller under the
Contract.
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SUBSTANTIAL COMPLETION has the meaning set forth in Section 10.2.
TOTAL CONTRACT PRICE has the meaning set forth in Section 3.1.
UNIT means each of the six (6) General Electric Frame PG7241 (FA) heavy-duty,
single shaft combustion turbine-generator units to be supplied to Buyer pursuant
to this Contract.
UNIT CONTRACT PRICE means that portion of the Total Contract Price allocable to
a specific individual Unit.
UNIT PERFORMANCE LIQUIDATED DAMAGES means liquidated damages which become due to
Buyer under this Contract at the rates set forth in Section 17.2(b) based upon
the performance testing of an individual Unit, the aggregate amount of which
shall be subject to adjustment based upon aggregate test results in accordance
with the provisions of Section 17.2(f).
UTILITY TESTS means tests conducted on all of the Units in Phase I and at a
later date, on all of the Units in Phase I and Phase II, by Buyer or on Buyer's
behalf in accordance with Section 8.0 of Appendix C.
WITNESS TESTS has the meaning set forth in Section 5.2.
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ARTICLE 2. SCOPE OF SUPPLY
2.1 SCOPE. Seller shall supply the Documentation, Equipment and Services
in accordance with the Specifications and shall meet the performance
requirements and guarantees set forth in this Contract in accordance
with the Specifications.
2.2 DIRECTED ORDER. If Buyer determines that Documentation, Equipment or
Services to be provided by Seller under this Contract do not comply
with Applicable Laws and Seller disagrees as to the Documentation,
Equipment or Services to be provided by Seller under this Contract,
Buyer may issue a Directed Order to Seller covering such Documentation,
Equipment or Services so long as such Directed Order is reasonably
capable of being performed by Seller and is intended solely to cause
such Documentation, Equipment or Services to comply with Applicable
Laws. If Owner issues a Directed Order, Seller shall proceed without
undue delay to provide the Documentation, Equipment or Service which
Buyer has directed, as set out in such order. Within ten (10) days
after Buyer's issuance of a Directed Order, if Seller disagrees with
such order, Seller shall submit a Dispute Notice to Buyer setting out
the reasons for Seller's disagreement with Buyer's position and the
Parties shall resolve such disagreement in accordance with the
procedures of Section 22.10.
2.3 RESERVED.
2.4 OPTIONS. If Buyer elects to exercise any of the Options described in
Section 9.2 and Appendix D, prior to or on August 31, 1999, then Seller
shall provide such Options to Buyer at the prices listed on and in
accordance with Section 9.2 and Appendix D, as applicable, and subject
to all terms and conditions of this Contract. If Buyer elects to
exercise any of the Options described in Section 9.2 and Appendix D
after August 31, 1999, Seller shall be entitled to a Change Order for
an applicable change in price or schedule, provided that Seller shall,
in good faith, attempt to mitigate any effects upon price and schedule.
2.5 PRE-ASSEMBLY. All Units, including the auxiliary equipment and the
following Major Components (to the extent included in the scope of
supply), shall be shipped pre-fabricated and pre-assembled as
described in Appendix A, according to Seller's standard practice.
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Major Components
Combustion Turbine Unit(s): - combustion turbine
- generator
- gas valve module
- packaged electrical and electronic control cabinet
- fuel forwarding skid
- cooling water module
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- turbine enclosure
- accessory module
- water injection skid
- turbine inlet air & exhaust systems
- compressor water wash skid
- generator auxiliary compartment
- special installation tools
- interconnecting pipe and cables (to the extent included
in Seller's scope in Appendix A)
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Any and all changes shall be updated by Seller in a conformed
technical specification based on review and agreement by Buyer and
Seller prior to August 31, 1999.
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ARTICLE 3. PRICE AND TERMS OF PAYMENT
3.1 TOTAL CONTRACT PRICE. The total price for the Equipment, Documentation
and Services is [*] (the "Total Contract Price").
3.2 SALES TAX. The Total Contract Price does not include any federal, state
or local sales, use, excise, value added, or similar taxes, provided
that Buyer shall not be responsible for any foreign taxes of any kind
including excise taxes, value added taxes, sales or use taxes, customs
fees or duties which may arise as a result of the foreign manufacture
or import of any of the Equipment. Consequently, in addition to the
Total Contract Price, the amount of any present or future sales, use,
excise, value added, or other similar tax applicable to the sale or use
of the Equipment, Documentation or Services hereunder (exclusive of
taxes based on the income of Seller) shall be paid by Buyer, or in lieu
thereof Buyer shall provide Seller with a tax-exemption certificate (or
similar documentation) acceptable to the taxing authorities. Seller
agrees to cooperate within reason with Buyer in connection with any
proceeding or other action undertaken by Buyer for the purpose of
eliminating, reducing or deferring the payment of any such taxes.
Seller will cooperate with Buyer to provide such information to Buyer
or applicable taxing authorities so as to appropriately mitigate
Buyer's taxes, however, Seller will not be obligated to provide
proprietary cost information to taxing authorities, or to provide audit
information to taxing authorities beyond that which Seller determines
to be reasonable.
3.3 PROGRESS PAYMENT SCHEDULE. Seller acknowledges timely receipt from
Buyer of the payments shown on Appendix B as due to Seller through
August, 1999. Buyer shall make all additional progress payments to
Seller in accordance with the payment schedule attached as Appendix B.
Prior to Shipment of the first Major Component of a Unit, Buyer shall
provide to Seller written evidence, in a form reasonably acceptable to
Seller, that Buyer has the financial ability to satisfy Buyer's
remaining obligations under this Contract for such Units. Seller shall
be entitled to invoice Buyer on or before the fifteenth (15th) calendar
day of each calendar month for the progress payment due for the
following calendar month. All progress payments shall be made to Seller
upon submission of invoices by Seller in accordance with Section 3.5,
provided that each invoice submitted by Seller pursuant to the
applicable Appendix shall include charges only for those applicable
events or durations as described in Appendix B. All payments to be made
under this Section 3.3 shall be in accordance with Sections 3.1 and 3.4
of this Contract.
3.4 CHANGES IN TOTAL CONTRACT PRICE. In the event that a change in the
Contract scope pursuant to Section 9.1 results in a change in the Unit
Contract Price for one or more Units and in the Total Contract Price,
all payments shall be adjusted accordingly. However, if the change
results in a decrease in the Total Contract Price, then the payments
previously made shall be retained by Seller and the credit shall be
applied fully
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to the extent of the next payment and each subsequent payment as it
becomes due.
3.5 PROGRESS PAYMENT INVOICES. Invoices shall be received by Buyer not
later than the fifteenth (15th) calendar day of the month preceding the
month in which payment is due, and such invoices shall be due and
payable on the twenty-fifth (25th) calendar day of the month following
the month in which such invoice is received by Buyer, except that the
Shipment Payments (as described in Appendix B) and the Final Payments
(as described in Appendix B), shall each be due within three (3)
Business Days respectively after receipt of proper invoices documenting
the events or dates shown in Appendix B. In the event payment is not
received by the due date, interest shall accrue on such amount at an
annual rate of interest equal to the prime rate of The Chase Manhattan
Bank, N.A. in effect on the due date plus one percent (1%). Buyer may
withhold payment of the disputed portion of any invoice until such
dispute is resolved to the reasonable satisfaction of Buyer. If it is
determined that Buyer was justified in withholding payment or if the
dispute is settled in favor of Buyer, Buyer shall not pay interest on
the amounts withheld. If it is determined that Buyer was not justified
in withholding such amounts or if the dispute is settled in favor of
Seller, Buyer shall pay interest at the rate provided above, from the
time the withheld amount was due. Buyer may retain the Final Payment
for each Unit in Phase I in the amount of five percent (5%) per Unit
("Retainage") as security for any liquidated damages which may become
due under this Contract until Substantial Completion is achieved for
all Units in Phase I or until payment is made of Unit Performance
Liquidated Damages with respect to all of the Units in Phase I;
provided that if an election is made by Seller pursuant to Section
17.2(d) with respect to one or more Units in Phase I, then the
Potential Liquidated Damages calculated as set forth in Section 17.2(d)
shall be aggregated for all Units in Phase I and to the extent that the
aggregate Potential Liquidated Damages for such Units is less than the
Retainage for all of the Units in Phase I, Buyer shall pay to Seller
the amount by which the Retainage exceeds such aggregate Potential
Liquidated Damages; provided that as a condition to such payment each
Unit in Phase I which is not subject to an election under Section
17.2(d) shall have achieved Substantial Completion. Buyer may retain
the Final Payment for each Unit in Phase II in the amount of five
percent (5%) per Unit ("Retainage") as security for any liquidated
damages which may become due under this Contract until (i) the Deferred
Tests are completed for Units #2 and #3 and (ii) Substantial Completion
is achieved for all Units or until payment is made of final liquidated
damages with respect to all of the Units; provided that if an election
is made by Seller pursuant to Section 17.2(d) with respect to one or
more Units in Phase II, then the Potential Liquidated Damages
calculated as set forth in Section 17.2(d) shall be aggregated for all
Units in Phase II and to the extent that the aggregate Potential
Liquidated Damages for such Units is less than the Retainage for all of
the Units in Phase II, Buyer shall pay to Seller the amount by which
the Retainage exceeds such aggregate Potential Liquidated Damages;
provided that as a condition to such payment each Unit in Phase II
which is not subject to an election under Section 17.2(d) shall have
achieved Substantial Completion. Notwithstanding the achievement of
Substantial Completion for a Unit, Buyer may continue to hold a portion
of the Retainage for such Unit equal to Twenty Five Thousand Dollars
($25,000) until the satisfactory completion of tests with respect to
the
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Combustion Turbine Evaporative Cooler for such Unit plus an amount
equal to twice the value of any Punch List items for such Unit. Buyer
and Seller shall mutually agree upon an estimated cost for each item
included by Buyer on the Punch List, and Buyer shall, on a monthly
basis, release such amounts from such Retainage as correspond to twice
the value of those items on the Punch List which Seller has completed
and when all remaining Punch List items are complete and approved by
Buyer, Buyer shall release the entire Retainage. In the event that,
following timely Delivery of all of the Units in a Phase in accordance
with the provisions of this Contract, all of the Units in a Phase have
not achieved Substantial Completion by the date ("Delayed Final Payment
Date") which is the earlier of (i) six (6) months after the Scheduled
Date of Commercial Operation for such Phase, as such date is determined
at the time of execution of the EPC Agreement or (ii) June 1, 2002 for
Phase I and June 1, 2003 for Phase II, as applicable, through no cause
of Seller (including any claim of Excusable Delay by Seller under this
Contract), then Buyer shall pay to Seller all of the Retainage for the
Units in such Phase (if, with respect to Phase II only, less than [*]
of Technical Services have been used at such time with respect to all
of the Units, Buyer shall receive a credit against any Retainage to be
paid equal to the difference between [*] and the number of man-weeks
actually used multiplied by [*]) within three (3) Business Days after
the Delayed Final Payment Date for such Phase, provided that payment of
such Retainage shall not release Seller from any liability or
obligation due or which may become due under this Contract, except
that Seller will no longer be obligated to provide additional Technical
Services as set forth in Section 19.1. Payment of Retainage to Seller
pursuant to the immediately preceding sentence shall be accompanied by
interest on the amount of such payment at the annual rate of interest
equal to the prime rate of The Chase Manhattan Bank, in effect on the
Scheduled Date of Commercial Operation for the applicable Phase, as
such date is determined at the time of execution of the EPC Agreement,
plus onepercent (1%), until the date of payment to Seller.
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ARTICLE 4. SHIPMENT AND DELIVERY
4.1 SHIPMENT OF EQUIPMENT. Approximately ninety (90) days prior to the
first anticipated shipment of any Major Components for a Unit, Seller
shall notify Buyer of the anticipated date for Shipment of such Unit.
Upon receipt of notification from Seller of the anticipated date for
Shipment for a Unit, Buyer shall immediately designate a Delivery Point
for such Unit, provided that if Buyer fails to designate a Delivery
Point for a Unit within sixty (60) days of such notification, the Unit
shall be stored by Seller until Buyer designates a Delivery Point. In
the event of such storage, Buyer shall reimburse Seller's additional
expenses thereby incurred, including but not limited to preparation
for, placement into, and removal from storage. Each Unit shall be
shipped by Seller so that the Unit will be delivered by Normal
Carriage, in accordance with Section 4.2, to the Delivery Point. If
Buyer directs Seller to deliver the Unit to a Delivery Point other than
a location at or near Heard County, Georgia then (i) Buyer shall pay to
Seller any additional delivery costs incurred by Seller for such
delivery of the Unit to such other location, or (ii) Buyer shall be
entitled to a credit from Seller against the Total Contract Price for
any delivery costs saved by Seller for such delivery of the Unit to
such other location. In the event that Seller places a Unit in storage
in accordance with the provisions of this Section 4.1, Seller shall be
deemed to have accomplished Shipment or Delivery, as applicable, for
the purposes of Section 17.1 upon placing such Unit in storage,
provided that upon designation of a Delivery Point by Buyer such Unit
shall be delivered to the Delivery Point within four (4) weeks of such
designation.
(A) COMBUSTION TURBINE SCHEDULED DELIVERY DATE. Subject to the
provisions of Section 4.1(d), Scheduled Shipment Dates and
Scheduled Delivery Dates of the Units shall be as follows:
<TABLE>
<CAPTION>
SCHEDULED SHIPMENT DATE SCHEDULED DELIVERY DATE
----------------------- -----------------------
<S> <C> <C>
Gas Turbine-Generator Unit #1 August 30, 2000 September 30, 2000
Gas Turbine-Generator Unit #2 [*] [*]
Gas Turbine-Generator Unit #3 [*] [*]
Gas Turbine-Generator Unit #4 [*] [*]
Gas Turbine-Generator Unit #5 [*] [*]
Gas Turbine-Generator Unit #6 November 15, 2001 December 15, 20001
</TABLE>
"Guaranteed Date" means for each of Units #1 and #4 the Scheduled
Delivery Date for such Unit and for each of Units #2, #3, #5 and
#6 the Scheduled Shipment Date for such Unit, which dates, if not
met by Seller will, in accordance with Section 17.1, subject
Seller to the payment of liquidated damages.
(B) RESERVED.
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(C) SCHEDULED SHIPMENT DATE AND SCHEDULED DELIVERY DATE. Unless the
context requires otherwise, the term "Scheduled Shipment Date" as
used in this Contract shall mean, for each Unit, the date, as set
forth in Section 4.1(a), that Shipment of such Unit is to be
accomplished pursuant to the terms of this Contract. Unless the
context requires otherwise, the term "Scheduled Delivery Date" as
used in this Contract shall mean, for each Unit, the date, as set
forth in Section 4.1(a), that Delivery of such Unit is to be made
to the Delivery Point pursuant to the terms of this Contract.
(D) SHIPMENT AND DELIVERY.
(I) SHIPMENT. For the purposes of this Contract, "Shipment" of a
Unit shall be deemed to have occurred when the last of the
Major Components of such Unit as set forth in Section 2.5
(provided such Major Components substantially conform to the
Specifications and requirements of this Contract) has been
placed in the carrier's custody for shipment to the Delivery
Point in accordance with this Contract, as evidenced by a
bill of lading signed by the carrier; provided that for
purposes of any Unit or Major Component of a Unit
manufactured or procured from outside the United States,
"Shipment" of such Unit or Major Component shall be deemed
to have occurred when such Unit or Major Component clears
United States Customs at its port of entry into the United
States; and further provided that solely for the purposes of
determining liquidated damages pursuant to Section 17.1(a),
Shipment of a Unit shall be deemed not to have occurred if
any Equipment related to such Unit remains undelivered more
than ninety (90) days after the Scheduled Shipment Date for
such Unit and such undelivered Equipment delays the
installation and safe operation of such Unit.
Notwithstanding the provision of the immediately preceding
sentence, liquidated damages shall not begin to accrue for
late Shipment of a Unit under Section 17.1(a) because of any
undelivered Equipment related to such Unit until ten (10)
days after delivery to Seller of written notice that such
Equipment is undelivered and may delay the installation and
safe operation of such Unit.
(II) DELIVERY. For the purposes of this Contract, "Delivery" of a
Unit shall be deemed to have occurred when the last of the
Major Components of such Unit as set forth in Section 2.5
(provided such Major Components substantially conform to the
Specifications and requirements of this Contract) has been
delivered to the Delivery Point as evidenced by a bill of
lading signed by the carrier; provided that solely for the
purposes of determining liquidated damages pursuant to
Section 17.1(a), Delivery of a Unit shall be deemed not to
have occurred if any Equipment related to such Unit (other
than such Major Components) remains undelivered more than
sixty (60) days after the Scheduled Delivery Date for such
Unit and such undelivered Equipment delays the installation
and safe operation of such
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Unit. Notwithstanding the provision of the immediately
preceding sentence, liquidated damages shall not begin to
accrue for late Delivery of a Unit under Section 17.1(a)
because of any undelivered Equipment related to such Unit
(other than such Major Components) until ten (10) days after
delivery to Seller of written notice that such Equipment is
undelivered and may delay the installation and safe
operation of such Unit.
4.2 METHOD OF SHIPMENT. Shipment will be made F.O.B. carrier, at the point
of delivery to the carrier. Seller shall, at Seller's expense, arrange
for Shipment of the Equipment by Normal Carriage to the Delivery
Point.
4.3 EARLY SHIPMENT. Seller plans to deliver the generators and the
following additional Equipment (PEECC, Isophase Bus, Sole Plates,
Generator Terminal Enclosure, Bus Accessory Compartment, Isolation
Transformer, DC Link Reactor, LCI Module, Inlet Duct and Inlet Filter)
associated with Combustion Turbine-Generator Units #2 and #3 by
[*], respectively. Seller makes no guarantee of any early Shipment or
early Delivery of Combustion Turbine- Generator Units #2 and #3. The
only Guaranteed Dates for such Units are as designated in Section
4.1(a). Except with respect to the generators and additional Equipment
for Combustion Turbine-Generator Units #2 and #3 itemized above, or as
otherwise specifically agreed upon by Buyer in writing, Buyer shall
not be required to accept early Shipment of any Unit if such Shipment
would result in delivery of any portion of such Unit earlier than one
(1) Month prior to the Scheduled Delivery Date for such Unit.
4.3 INSPECTION OF EQUIPMENT. Payment for Equipment provided hereunder, or
inspection or testing thereof by Buyer, shall not constitute acceptance
or relieve Seller of its obligations under this Contract. Buyer may
inspect the Equipment delivered and reject upon prompt notification to
Seller any and all such Equipment which does not conform to the
Specifications or the requirements of this Contract. Equipment which is
rejected shall be corrected, repaired, or replaced by Seller in
accordance with Seller's warranty obligations under Article 10, such
that the Equipment conforms to the Specifications and requirements of
this Contract. If Buyer receives Equipment with a defect or
nonconformity not reasonably apparent on inspection, then Buyer
reserves the right to require prompt correction, repair, or replacement
by Seller in accordance with Seller's warranty obligations under
Article 10 following the discovery of such defect or nonconformity.
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ARTICLE 5. INSPECTION AND FACTORY TESTS
5.1 INSPECTION RIGHTS. Buyer, its agents (including but not limited to
Buyer's engineering and construction contractors and employees and
consultants of Tenaska, Inc.), as well as the employees and agents for
the purchasers of the electrical output of the Project and Buyer's
lenders (collectively, "Buyer's Inspector(s)") will be provided access
to Seller's facilities and production records for purposes of obtaining
information on production progress, quality control, determining
status, and observing tests and inspections. Seller shall have the
right of approval, which approval shall not be unreasonably withheld,
with respect to all Buyer's Inspectors who are not employees of
Tenaska, Inc. Such access may be conditioned upon the execution by such
inspectors of confidentiality agreements acceptable to Seller, in its
reasonable discretion, and limited to areas concerned with the
Equipment where work of a non-proprietary nature is performed.
5.2 WITNESS TESTS. All "non-optional" factory testing described in Appendix
L shall be successfully completed by Seller prior to Shipment of a
Unit. Seller and Buyer shall mutually agree upon a specific list of
factory tests ("Witness Tests") which Buyer's Inspectors shall witness,
provided that such list may be supplemented at Buyer's request to
permit Buyer to witness additional factory tests which Seller intends
to conduct, upon reasonable advance notice to Seller. Such Witness
Tests shall be initially identified as such in Appendix A.
5.3 NOTIFICATION OF TESTING. Seller shall advise Buyer as to the schedule
for testing and Buyer's Inspectors will be given an opportunity to
observe work during regular working hours. Neither completion of
production work nor shipment of any part of the Equipment will be
delayed to accommodate Buyer's Inspectors. The conditions of any tests
shall be as set forth in the Specifications and Buyer shall be notified
at least ten (10) Business Days prior to the commencement of all
Witness Tests. Buyer will be informed of Seller's methods of reporting
production progress. Appropriate office facilities will be provided
where Buyer's Inspectors may conduct their work in connection with the
above. Subject to the conditions set forth in this Article 5, Seller
will make reasonable efforts to obtain for Buyer access to Seller's
Suppliers' facilities for the purposes described in this Article.
5.4 CONSEQUENCES OF INSPECTION. Buyer's inspection of the work or Buyer's
failure to inspect any work in no way relieves Seller of its
obligation to fulfill the requirements of this Contract nor is it to
be construed as acceptance by Buyer.
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ARTICLE 6. DELIVERY, TITLE, AND RISK OF LOSS
6.1 RISK OF LOSS. Seller shall retain all risk of loss for damage to the
Equipment until the Equipment is delivered to the Delivery Point. Risk
of loss or damage to the Equipment, except for Computer Programs,
shall pass to and vest in Buyer upon arrival of the Equipment at the
Delivery Point.
6.2 PASSAGE OF TITLE. Title to the Equipment shipped from within the United
States shall vest in Buyer when the Equipment is placed in the
carrier's custody for shipment, and title to Equipment shipped from a
country other than the United States shall vest in Buyer at the port of
export immediately after the Equipment has been cleared for export.
Upon transfer of title to Equipment to Buyer, Seller shall promptly
execute and deliver to Buyer written documentation which shall be
effective to confirm in Buyer good and marketable title to the
Equipment being purchased, free and clear of all obligations,
mortgages, liens, pledges, custodianship, security interests, or any
other encumbrances, claims, or charges of any kind whatsoever, except
those relating to any payments remaining due Seller under this
Contract. Upon written request of Buyer, Seller shall execute and
deliver such documents as are reasonably required by Buyer to
subordinate the lien, security interest, or claim of Seller relating to
any payments remaining due under this Contract, to the interests
(including any lien and/or security interests) of the lenders for the
Project. It is expressly understood that Seller has the right to
utilize all resources within its global manufacturing and supplier
network to supply the requirements of this Contract. In the event that
Major Components are manufactured in a country other than the United
States, such Major Components will be scheduled by Seller to arrive in
the United States for delivery to the Delivery Point no later than the
applicable date(s) set forth in Section 4.1(a), or any other date(s)
mutually agreed upon by Buyer and Seller, in writing. Seller shall
indemnify Buyer and hold Buyer harmless with respect to any foreign
taxes of any kind including excise taxes, value added taxes, sales or
use taxes, customs, fees or duties which may arise as a result of the
foreign manufacture or import of any of the Equipment.
6.3 COMPUTER PROGRAMS. Title to and right of possession of any Computer
Programs licensed hereunder shall remain with Seller, or its licensor,
except that Buyer shall have the right of possession and use of the
Computer Programs provided hereunder at no cost for the term of the
license set forth in Section 6.4. Nothing in this Contract shall be
construed as limiting Seller, or its licensors, from using and
licensing the Computer Programs to any third party.
6.4 LICENSE OF COMPUTER PROGRAMS. Seller grants to Buyer, and any party
under contract with Buyer to operate the Units of Equipment, a
nontransferable, nonexclusive license (the "License"), without
sublicensing rights, to use the computer programs provided to Buyer
under this Contract (the "Computer Programs") solely in connection with
the Unit for which such Computer Programs are supplied, subject to the
conditions and restrictions contained in this Contract. The term of the
License shall extend until the
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decommissioning of the Unit for which such Computer Programs are
licensed. The License does not grant any right to the background
technology from which the Computer Programs were generated or to the
source code underlying the Computer Programs, except to the extent
specifically identified in this Contract. Except as specifically set
forth in this Contract, Buyer is granted no right to modify the
Computer Programs or merge the computer programs with other computer
programs, provided that the use of the Computer Programs with other
programs or the sharing of data between the Computer Programs and
other programs is not prohibited. Notwithstanding the foregoing
provisions of this Section 6.4, in the event of the sale or transfer
of any Unit of the Equipment or the sale or transfer of the Project,
such License will automatically transfer to the transferee, subject to
the terms of this Section 6.4. In the event that Seller updates,
revises or enhances the Computer Programs governed by the License,
Seller shall make all such updates, revisions or enhancements to the
Computer Programs available to Buyer on reasonable terms.
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ARTICLE 7. EXCUSABLE DELAYS
7.1 EXCUSABLE DELAY. Seller shall not be liable for delays in delivery
or other failures to perform the terms of this Contract caused by
events beyond its reasonable control which Seller is unable to
overcome by the exercise of reasonable diligence, including acts
of God, acts (or failure to act) of Buyer, acts of civil or
military authority, governmental priorities, fires, floods,
epidemics, strike or labor disturbance, war, or riot, (collectively,
"Excusable Delay"); provided, however, that such Excusable Delay must
directly, adversely, and materially affect a specific portion of the
manufacture of a Unit or Units or Seller's obligations under this
Contract with respect to such Unit or Units and Seller shall establish
that such Excusable Delay will cause a delay in Delivery as set forth
in Article 4 or a required performance date in this Contract. In the
event of an Excusable Delay, the Party claiming Excusable Delay will
use commercially reasonable efforts to mitigate the effects of the
Excusable Delay on its performance of the Contract, including, if
applicable, Seller making available replacement Equipment at the
earliest possible date. In the event of any such Excusable Delay
with respect to any Unit, the Scheduled Delivery Date, and any
performance requirement or other date of required performance,
shall be extended only by that amount of delay demonstrated by
Seller to have been caused by such Excusable Delay, Seller shall
give Buyer written notice of the occurrence of any such event
within seven (7) days after Seller becomes aware or reasonably
should have become aware of an Excusable Delay which notice shall
include a good faith estimate of the expected impact that such
event will have on Delivery or the performance of Seller under
this Contract.
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ARTICLE 8. COMPLIANCE WITH LAWS, CODES AND STANDARDS
8.1 COMPLIANCE WITH APPLICABLE LAWS. Seller warrants and represents that
the Equipment, Documentation and Services under this Contract shall
comply, at the time of Delivery and in the case of Services at the time
of performance, with all Applicable Laws, except to the extent that
such Applicable Laws (i) pertain to conditions within the control of
Buyer or (ii) pertain to sound level emissions and gas emissions of the
Units, in which case Seller's obligations shall be as set forth in this
Contract. Buyer shall advise Seller of any local laws, codes, standards
and regulations ("local laws") materially affecting the Equipment.
Seller's representation and warranty as to compliance with local laws
is subject to and limited by the preceding sentence.
In the event that Seller fails to conform to the above warranty, Buyer
shall, promptly after discovery, advise Seller thereof in writing and
Seller, at its option and expense, shall repair, replace or modify the
nonconforming Equipment or Documentation or reperform the nonconforming
portion of Services in accordance with Seller's warranty obligations
under Article 10. In the event of any unreasonable delay by Buyer in
advising Seller of a breach of the warranty set forth in Section 8.1,
Seller shall be relieved of its warranty obligations hereunder only to
the extent of any additional loss or expense directly resulting from
such delay.
8.2 CHANGE IN APPLICABLE LAWS. In the event that compliance under Section
8.1 with respect to any applicable local laws requires any
modifications to the scope set forth in Appendix A or any changes in
Seller's design, manufacturing processes and procedures, or quality
assurance program, then the Total Contract Price will be adjusted by
change order to equitably reflect the added costs and expense to Seller
of such change and, if necessary, the schedule for Seller's performance
under the Contract will be revised for the reasonable period necessary
to comply with such modification, change or revision. Any other
provisions of this Contract will be modified as is required by such
change or revision in Applicable Laws. In the event Buyer elects to
have one or more of the Units delivered to any location other than a
location at or near Heard County, Georgia, and any modifications to the
scope set forth in Appendix A or any changes in Sellers design,
manufacturing processes and procedures, or quality assurance program
are required as a result of such change of location, including changes
required for compliance under Section 8.1, then the Unit Contract Price
for such Unit(s) and the Total Contract Price will be adjusted by
change order to equitably reflect the added or reduced costs and
expenses to Seller of such change and, if necessary, the schedule for
Seller's performance under the Contract will be revised for the
reasonable period necessary to comply with such modification, change or
revision, and any other provisions of this Contract will be modified as
is required by any changes in the Applicable Laws. Notwithstanding the
foregoing, no modification in the Total Contract Price, schedule or
other provisions of this Contract shall be made as a result of any
general change in the manufacturing facilities of Seller or a change in
Seller's work force not specifically limited to the
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Equipment, Documentation or Services for this Project, resulting from
any change of Applicable Laws.
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ARTICLE 9. CHANGES; ADDITIONAL EQUIPMENT
9.1 CHANGES. Buyer may, by written change order, make mutually agreed to
changes to the Equipment, Documentation and/or Services. If any such
change results in an increase or decrease in the cost or time required
for the performance of the Services or changes to any other pertinent
provisions under this Contract, then there shall be an equitable
adjustment to the Total Contract Price and any applicable Unit Contract
Prices and time of delivery and any other pertinent provisions of the
Contract. Any such change in the Equipment, Documentation and/or
Services and in the Total Contract Price and any Unit Contract Price or
the Scheduled Delivery Date or any other pertinent provisions of the
Contract, shall be indicated on the change order. If Buyer and Seller
do not agree upon the price of such change or its effect on the
Scheduled Delivery Date or its effect on any other pertinent provisions
of the Contract, Buyer may issue a Directed Change Order, so long as
such Directed Change Order is reasonably capable of being performed by
Seller and is intended solely to cause the Documentation, Equipment or
Services to comply with Applicable Laws, and Seller shall proceed
without undue delay to perform the change described in the Directed
Change Order, as set out in such order and consistent with this Section
9.1. Within ten (10) days after Buyer's submission of a Directed Change
Order, Seller shall submit a Dispute Notice to Buyer setting out the
reasons for Seller's disagreement with the price of such change or its
effect on the Scheduled Delivery Date or its effect on any other
pertinent provisions of Seller, and the Parties shall resolve such
disagreement in accordance with the procedures of Section 22.10.
9.2 OPTIONS. Attached to this Contract as Appendix D is a listing of
certain options (the "Options") that are available in connection with
the Equipment. The Parties agree that the prices listed on Appendix D
with respect to the Options are firm prices in accordance with Article
3. In the event Buyer elects to purchase any such Option(s), the
Contract Price and any other pertinent provisions of the Contract shall
be adjusted accordingly. Seller agrees that the Scheduled Delivery Date
shall not be impacted in the event Buyer selects such Options set forth
in Appendix D on or prior August 31, 1999.
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ARTICLE 10. WARRANTY
10.1 WARRANTIES AND REPRESENTATIONS.
(a) Seller warrants and represents to Buyer that the Equipment to
be delivered hereunder shall be as described in the
Specifications; shall be designed and fit for the purpose of
generating electric power in accordance with the
Specifications; shall be new; and shall be free from defects
in material, workmanship, and title; and that the Services
shall be performed in a competent, diligent, workmanlike
manner in accordance with generally accepted industry
standards. Seller further warrants and represents to Buyer
that the Documentation, Specifications, and other materials
which are to be provided to Buyer under this Contract, will
faithfully and accurately reflect the Equipment provided under
this Contract.
(b) Seller warrants and represents to Buyer that Seller will have
good and indefeasible title, and will at the time of transfer
of title under this Contract, convey to Buyer good and
indefeasible title to the Equipment, free and clear of any and
all liens and security interests which may arise by or through
Seller or any subcontractor of Seller.
10.2 WARRANTY PERIOD. The warranties set forth in Section 10.1(a) for each
Unit shall apply to defects which appear prior to Substantial
Completion and during a period of either (i) twelve (12) Months
following the earlier of (1) the date on which Seller makes a valid
election with respect to such Unit under Section 17.2(d) or (2) the
date such Unit achieves Substantial Completion; or (ii) thirty (30)
Months from the actual date of Delivery of such Unit to Buyer,
whichever period expires first ("Warranty Period"). Where any item of
Equipment is used with more than one Unit, the warranty on such item
shall be for the same period as the warranty on the Unit with which it
is first used. The Warranty Period for a Unit shall be extended on a
day-for-day basis for any period of time in excess of ten (10) days
that the Unit is not capable of operating due solely to a warranty
claim attributable to Seller. For the purposes of this paragraph, the
number of days of Warranty Period extension shall be counted as those
days in excess of ten (10) between:
(i) the date the Unit is removed from service, or unable to return
to service, solely due to a warranty nonconformity for which Seller is
responsible; and
(ii) the date the corrective work is complete and Seller advises that
the Unit is available for return to service.
"Substantial Completion" of a Unit shall mean the satisfaction by such
Unit of each of the Liquidated Damage Performance Guarantees,
Performance Guarantees, Demonstration Test Requirements and the
Availability Test Requirements under Article 16; provided that with
respect to Units #2 and #3, certain tests as indicated in Section 3.15
of Exhibit C
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("Deferred Tests") shall be deferred and the performance requirements
of such Deferred Tests shall not be a condition of Substantial
Completion of such Units. The Warranty Period for the warranties set
forth in Section 10.1(b) shall extend for a period of five (5) years
from the date of this Contract.
10.3 GENERAL CONDITIONS OF WARRANTY. The warranties and remedies set forth
herein are conditioned upon the following:
(a) The proper receipt, handling, storage, installation, use,
inspection, operation and maintenance of the Equipment by
Buyer in accordance with the Specifications and written
service manuals and written advisories (to the extent such
service manuals and advisories are not inconsistent with the
terms of this Contract including the Specifications) provided
by Seller pursuant to the Contract, and, in the absence
thereof, Buyer following generally accepted industry practices
in regard to the above activities.
(b) The Equipment not being subjected to accident, alteration,
abuse or misuse by Buyer, which directly causes a defect in
the Equipment.
(c) Buyer shall allow Seller the reasonable opportunity to review
operating and maintenance records relating to the Facility at
which the warranted Equipment is located and shall provide
Seller's representatives reasonable access to the Site for the
purpose of observing the Equipment and the operation and
maintenance thereof.
10.4 WARRANTY OBLIGATIONS.
(a) Except with respect to the warranties set forth in Section
10.1(b), if during the applicable Warranty Period, the
Equipment or Documentation delivered and/or Services
performed under this Contract do not meet the above
warranties, then Buyer shall promptly notify Seller, not later
than thirty (30) days after the expiration of the Warranty
Period, and make the Equipment or Documentation available
promptly for correction; provided that Buyer may elect to
defer the correction for a reasonable period of time to permit
Buyer's continued use of the Equipment, but Buyer assumes the
risk of any additional damage which may arise from the
deferral of such correction. Seller, at its expense, shall
thereupon correct any defect, at its option, by (i)
re-performing the defective Service, (ii) modifying or
repairing any Equipment or Documentation not in compliance
with Section 8.1, and/or (iii) repairing, replacing, or
modifying any defective Equipment, or any defects in the
Documentation (including repairing, replacing, or modifying
any parts of the Equipment damaged ("Collateral Damage") as a
result of the defective Service, defective parts, or defective
Documentation, except that Seller shall be entitled to be
reimbursed by Buyer for the costs incurred by Seller with
respect to repairing the Collateral Damage, but only to the
extent of any insurance proceeds
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received by Buyer to cover the expense of repairing such
Collateral Damage); provided that in repairing, replacing,
or modifying any Equipment, Buyer shall not materially
change the functionality or performance of the Equipment to
the detriment of Buyer. Seller shall provide technical
advisory services reasonably necessary for any such repair
or replacement. If required to avoid or mitigate a forced
outage, warranty work and services by Seller shall be
performed on a twenty-four (24) hours a day, seven (7) days
a week basis. Such warranty work and services are limited to
the Equipment supplied and do not include removal and
replacement of structures or other parts of the facility
reasonably necessary to conduct the warranty work. In the
event Seller shall fail to undertake and perform its
warranty obligations within a reasonable time, Buyer may,
with prior written notice to Seller, perform or retain a
third party contractor to perform such warranty work and
Seller shall be liable for the reasonable costs thereof. In
such event, Seller's ongoing warranty obligations on the
portion of work on which Buyer or a third party contractor
are performing such warranty work shall only continue if
Seller gives written approval, which shall not be
unreasonably withheld, to the remedial work performed by
Buyer or third party contractor.
(b) Seller shall perform its warranty obligations under this
Contract without materially changing the performance
of the Equipment to the detriment of Buyer. In the
event that following the performance of warranty
obligations by Seller, Buyer believes that the
performance of the Equipment with respect to Net
Equipment Electrical Output or Net Equipment Heat
Rate may have materially changed to the detriment of
Buyer because of the work done under the warranty
obligation. Buyer shall conduct retests of the
Equipment to determine any such changes in Net
Equipment Electrical Output or Net Equipment Heat
Rate (adjusted in accordance with the degradation
curves attached in Appendix C). Seller shall be
notified of such tests and shall be permitted to
witnesses such tests. If the tests performed by
Buyer indicated that the Net Equipment Electrical
Output or Net Equipment Heat Rate of the Equipment
has materially changed to the detriment of Buyer
(after adjusting for degradation in accordance with
the degradation curves attached in Appendix C),
Seller may attempt to remedy and retest the
Equipment (all retesting to be conducted by Buyer
under Seller's technical guidance) for a period not
to exceed 60 days, provided that Seller's remedy and
testing will not unreasonably interfere with the
normal and continuous operation of the Equipment
and that all changes, adjustments and retesting
shall be at Seller's expense, excluding fuel and
operating expenses. In the event that at the end of
such period, despite the best efforts of Seller to
remedy the defect in a manner which does not
materially change the Net Equipment Electric Output
or Net Equipment Heat Rate of the Equipment to the
detriment of Buyer, the Net Equipment Electrical
Output or Net Equipment Heat Rate of the Equipment,
as measured by the final test performed, has
materially changed to the detriment of Buyer because
of the work done under the warranty obligation.
Seller shall pay to Buyer liquidated damages as a
predetermined reasonable and exclusive remedy for
such reduced performance and not as a penalty for
any such change, based upon the following items:
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(i) NET EQUIPMENT ELECTRICAL OUTPUT - [*] for each
kilowatt that the Net Equipment Electrical Output
(using an aggregated number for all reworked Units
based upon the testing of all reworked Unit(s) at
the Project) measured after such warranty work is
less than the Final Test Value for Net Equipment
Electrical Output of such Unit(s) measured during
Acceptance Testing, adjusted in accordance with
the degradation curve attached in Appendix C.
(ii) NET EQUIPMENT HEAT RATE - [*] for each BTU per
kilowatt hour per Unit that the Net Equipment Heat
Rate (determined as an average for all reworked
Unit(s) based upon the testing of all reworked
Unit(s) at the Project) measured after such
warranty work and when operated on natural gas is
greater than the Final Test Value for Net
Equipment Heat Rate (determined as an average for
all Unit(s)) measured during Acceptance Testing
when operated on natural gas, adjusted in
accordance with the degradation curve attached in
Appendix C, plus [*] for each BTU per kilowatt
hour per Unit that the Net Equipment Heat Rate
(determined as an average for all reworked
Unit(s) based upon the testing of all reworked
Unit (s) at the Project) measured after such
warranty work and when operated on fuel oil is
greater than the Final Test Value for Net
Equipment Heat Rate (determined as an average for
all Unit(s)) measured during Acceptance Testing
when operated on fuel oil, adjusted in accordance
with the degradation curve attached in Appendix C.
Seller's total aggregate liability for liquidated damages
under this Section 10.4 shall not exceed [*] of the
Contract Price. Payment of liquidated damages under
this Section 10.4 shall relieve Seller from all further
liability with respect to the change in Net Equipment
Electrical Output or Net Equipment Heat Rate of the Equipment
but shall not relieve Seller in any way from any warranty
obligations under this Contract.
10.5 EXTENSION OF WARRANTY PERIOD. Any modified, repaired or replaced part
of the Equipment, revised Documentation and/or service furnished in
connection therewith and any Service re-performed under the aforesaid
warranty shall carry warranties on the same terms as set forth above
except that the warranty period shall be for a period of one (1) year
from the date of such modification, repair or replacement, revision, or
reperformance. Seller's warranty obligations with respect to any Unit,
if not terminated earlier pursuant to this Article 10, shall terminate
on and shall be subject to the overall warranty limit of, the lesser of
four (4) years after Substantial Completion of the Unit, or five (5)
years after Delivery of the Unit.
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10.6 EXCLUSIVE WARRANTIES. The warranties set forth in this Article 10 and
the warranty contained in Section 8.1, are exclusive and in lieu of all
other warranties, whether written, oral, implied or statutory. NO
IMPLIED OR STATUTORY WARRANTY OF EITHER MERCHANTABILITY OR FITNESS FOR
PARTICULAR PURPOSE, OR ANY WARRANTIES ARISING FROM COURSE OF DEALING OR
USAGE OF TRADE SHALL APPLY. The remedies set forth in this Article 10,
Article 17, Section 8.1 and Section 13.3 are the only remedies of Buyer
for claims based on defect in or failure of Equipment or Services,
whether said claims are designated as arising in contract, warranty
(other than with respect to infringement which shall be governed by
Article 12), tort (including negligence), strict liability, indemnity
(other than with respect to those situations governed by Article 15),
or otherwise, whether arising before or after Delivery, and however
instituted.
10.7 WARRANTY EXCLUSION. Seller does not warrant the Equipment or any
repaired or replaced part against normal wear and tear due to operation
or environment.
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ARTICLE 11. PROPRIETARY INFORMATION
11.1 PROPRIETARY INFORMATION. Performance of the Contract by Seller may
involve the use or furnishing of drawings, procedures, equipment, or
the like, which Seller considers to be proprietary. At the time of
furnishing such information to Buyer, Seller will expressly designate
by label, stamp, or other written communication that the information or
documentation furnished is proprietary and confidential. Buyer, its
employees, and agents (including any architect/engineer or contractor)
agree (a) to treat such information as confidential and to use all
reasonable care not to divulge such information to any third party
other than (i) employees and consultants of Tenaska, Inc., (ii) the
purchasers of the electrical output generated by the Project, (iii)
Buyer's lenders, investors, contractors, partners, insurers,
consultants and affiliates, (iv) Buyer's Project operator, (v)
governmental regulators, (vi) affiliates of partners in Buyer and (vii)
permitted assignees under Section 22.1, (b) to restrict the use of such
information to matters relating to (i) Seller's performance of the
Contract and (ii) Buyer's performance of its obligations to regulators,
investors, lenders, contractors, Project operator, and purchasers of
the electrical output generated by such Facility, and (c) in all cases
to restrict such access to those individuals or entities whose access
is necessary in the implementation of the Contract, the development,
construction and operation of such Project, and the purchasers of the
electrical output generated by the Project, subject to the
confidentiality provisions of this Article 11. Except for such
purposes, confidential information will not be reproduced without
Seller's prior written consent.
11.2 EXCLUSIONS FROM CONFIDENTIALITY. The foregoing restrictions do not
apply to information which: (i) is contained in a printed publication
which was released to the public by Seller prior to the date of this
Contract or is disclosed by Seller without restriction either prior to
or subsequent to the receipt by Buyer of such information; (ii) is, or
becomes, publicly known otherwise than through a wrongful act of Buyer,
its employees, or agents; (iii) is in the possession of Buyer, its
employees, or agents prior to receipt from Seller, provided that the
person or persons providing the same have not had access to the
information from Seller; (iv) is developed independently by Buyer, its
agents or employees without use of Seller's confidential information;
(v) is required to be disclosed by a court, governmental or regulatory
body; or (vi) is approved in writing by Seller for disclosure by Buyer,
its agents or employees to a third party not bound by the
confidentiality obligations afforded to Seller under Section 11.1
above.
11.3 BUYER'S CONFIDENTIAL INFORMATION. Confidential information shall also
include any Project information obtained by Seller from, or disclosed
to Seller by, Buyer, its agents or employees, which is considered by
Buyer to be proprietary, and is designated by label, stamp, or other
written communication by Buyer to Seller that the information or
documentation furnished is proprietary and confidential, except such
information as was (i) previously known by Seller, free from any
obligation to keep it confidential, (ii) publicly disclosed or
disclosed without restriction by Buyer to parties other than Buyer's
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partners, affiliates of partners or lenders or potential lenders for
the Project, either prior to or subsequent to the receipt by Seller of
such information, or (iii) is developed independently by Seller, its
agents or employees without use of Buyer's confidential information.
Except as may be authorized by Buyer in writing, Seller shall not
disclose to any person, firm, or enterprise, or use for its own benefit
other than in the performance of its obligations under this Contract or
if required to do so by a court, governmental or regulatory body, any
such confidential information of Buyer.
11.4 NO ADEQUATE REMEDY. Each Party acknowledges and agrees that, in the
event of a breach or threatened breach by it of the provisions of
Sections 11.1 or 11.3, the aggrieved Party will have no adequate remedy
in money or damages and, accordingly, shall be entitled to an
injunction against such breach. However, no specification in this
Section 11.4 of any specific legal or equitable remedy shall be
construed as a waiver or prohibition against any other legal or
equitable remedies in the event of a breach of a provision of this
Article 11.
11.5 CONFIDENTIALITY OF CONTRACT. Seller and Buyer deem this Contract, and
information concerning price, warranty, performance guarantees, and
delivery cycles exchanged by the Parties during the negotiations of
this Contract, to be confidential information and subject to the
provisions of this Article 11. Notwithstanding the foregoing, the terms
and provisions of Article 3 shall not be disclosed to any third party,
including any potential prime contractor, (but excepting any investors,
partners in Buyer and their affiliates, any financial lender, insuror
or consultant of Buyer and the employees and consultants of Tenaska,
Inc.) without the prior written consent of Seller, which consent shall
not be unreasonably withheld. The Parties' respective obligations with
respect to confidential information hereunder shall terminate on the
tenth (10th) anniversary date of this Contract.
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ARTICLE 12. INTELLECTUAL PROPERTY
12.1 INTELLECTUAL PROPERTY INDEMNIFICATION. Seller agrees to defend and to
handle at its own cost and expense any claim or action against Buyer
for actual or alleged infringement of any patent or copyright, or
similar proprietary right, including but not limited to
misappropriation of trade secrets, based upon the Equipment,
Documentation, or other materials and/or Services furnished to Buyer by
Seller, or the use thereof by Buyer. Seller shall, at Seller's sole
expense, conduct the defense of any such claim or action and all
negotiations for the settlement or compromise, unless otherwise
mutually agreed to, in writing, by Buyer and Seller; provided that if
such claim or action seeks an injunction or other equitable relief
against Buyer, counsel retained by Buyer at the expense of Buyer shall
be permitted to participate in such defense. Seller agrees to further
indemnify and hold Buyer harmless from and against any and all
liabilities, losses, settlements, judgments, reasonable costs and
expenses (including but not limited to reasonable legal fees and
expenses and costs of settlement) incurred by Buyer associated with any
such claim or action. Seller will not be responsible for any settlement
of such suit or proceeding made without its prior written consent,
subject to Seller's compliance with the foregoing provisions of this
Section 12.1.
12.2 REMEDY FOR INFRINGEMENT. If any Equipment, Documentation, materials
and/or Services furnished hereunder are held to constitute
infringement, and the use thereof is temporarily or permanently
enjoined, then Seller shall, at its own expense, in such manner as to
minimize the disturbance to Buyer's business activities, either: (i)
obtain for Buyer the right to continue using such Equipment,
Documentation, materials and/or Services or (ii) modify such Equipment,
Documentation, materials and/or Services to become non-infringing
(provided that such modification does not affect Buyer's intended use
of the same as contemplated hereunder); or (iii) replace such
Equipment, Documentation, materials and/or Services with equally
suitable, non-infringing Equipment, Documentation, materials and/or
Services, provided such replacement Equipment does not degrade the
operation of the Equipment or affect Seller's warranty. Sections 12.1
and 12.2 state the entire liability of Seller for infringement of any
patent, copyright or similar proprietary right with respect to any
Equipment, Documentation, materials and/or Services.
12.3 EXCEPTION TO INDEMNIFICATION. Sections 12.1 and 12.2 shall not apply to
the extent that a claim is caused by any Equipment (i) which is
manufactured to Buyer's unique design requirements for Buyer's sole and
exclusive use, (ii) modified by Buyer or its contractors after Delivery
and by reason of said design, use or modification a suit is brought
against Buyer or (iii) furnished under this Contract and used by Buyer
in conjunction with any other apparatus or material not reasonably
anticipated or specified by Seller. To the extent of a claim described
in the preceding sentence, Seller assumes no liability whatsoever for
infringement.
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ARTICLE 13. LIMITATION OF LIABILITY
13.1 LIMITATION OF LIABILITY. Except for liabilities arising under Article
11, or Sections 12.1 and 15.1, the total liability of Seller on all
claims, whether in contract, warranty, tort (including negligence),
strict liability, indemnity, or otherwise, arising out of the
performance of this Contract or from the manufacture, sale, delivery,
resale, repair, installation, technical direction of installation,
replacement, or use of any Equipment shall not exceed the Total
Contract Price. All liability of Seller with respect to any Unit shall
terminate upon the first to occur of: (a) the Unit completing two
thousand four hundred (2,400) starts, (b) four (4) years after
Substantial Completion of the Unit, or (c) six (6) years after
Delivery of the Unit.
13.2 CONSEQUENTIAL DAMAGES EXCLUSION. Except for the payment of liquidated
damages as specified in Articles 10 and 17, in no event, whether as a
result of breach of contract, warranty, tort (including negligence),
strict liability, indemnity, or otherwise, shall Seller or its
subcontractors or suppliers be liable for any special, consequential,
incidental, indirect, or exemplary damages; provided that the
immediately foregoing exclusion of liability for any special,
consequential, incidental, indirect, or exemplary damages shall not
limit the obligations of Seller to provide indemnification for (a)
injury (including death) to persons in accordance with Section 15.1 or
(b) damage to tangible property of a third party in accordance with
Section 15.1 but only if Seller is held to be directly liable to the
third party for all or a portion of such tangible property damage by a
court of competent jurisdiction. In no event, (c) shall Buyer be liable
to Seller for any special, consequential, incidental, indirect or
exemplary damages and (d) the total liability of Buyer on all claims,
whether in contract, tort (including negligence), strict liability,
indemnity or otherwise arising out of this Contract shall not exceed
the Total Contract Price, provided that the limitations set forth in
clause (d) shall not apply to Buyer's obligations (including any breach
thereof) under Article 3, Article 11 or Section 15.2. Nothing in clause
(c) of the preceding sentence of this Section 13.2 shall limit the
obligations of Buyer to provide indemnification for (e) injury
(including death) to persons in accordance with Section 15.2 or (f)
damage to tangible property of a third party in accordance with Section
15.2 but only if Buyer is held to be directly liable to the third party
for all or a portion of such tangible property damage by a court of
competent jurisdiction. This section shall not limit Seller's
obligation to provide the express remedies for breach of warranty set
forth in Article 10 of this Contract.
13.3 RETENTION OF REMEDIES. Subject to the limitations in Section 8.1,
Article 10, Sections 13.1 and 13.2, and the limitations of Buyer's
remedies in Articles 16 and 17, Buyer retains all of its rights and
remedies at law or in equity, for Seller's failure to comply with any
provision of this Contract, including failure of Seller to satisfy any
of the Performance Guarantees, Demonstration Test Requirements and
Availability Test Requirements.
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13.4 FURTHER LIMITATIONS. For the purpose of this Article 13, the term
"Seller" shall mean Seller, its affiliates, subcontractors and
suppliers of any tier, and their respective agents and employees,
whether individually or collectively. Buyer will obtain from any third
party to which this Contract may be assigned and from the initial owner
of any Project and from the owner of the Project Site, a specific
acknowledgement that the protections afforded Seller by this Article 13
will be binding on such parties.
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ARTICLE 14. TERMINATION
14.1 TERMINATION. Buyer may terminate this Contract at any time upon written
notice to Seller and payment of the Cancellation Charge in accordance
with Appendix B, provided that Buyer shall have the option of
terminating this Contract as to specific Units and retaining the right
to purchase less than all of the Units (to be delivered to Buyer in
accordance with the terms of this Contract) by making the payments to
Seller as shown in Appendix B.
14.2 TERMINATION BY SELLER. In the event that Buyer fails to timely pay to
Seller any undisputed amounts due pursuant to the terms of this
Contract, Buyer shall be in default under this Contract and Buyer shall
be allowed thirty (30) days from receipt of a written notice of such
default from Seller in which to cure such default, after which Seller
may immediately terminate this Contract by written notice to Buyer. Any
amount disputed by Buyer to be due under this Contract must be disputed
in good faith.
14.3 TERMINATION BY BUYER. In the event that Seller breaches a material
provision of this Contract, Seller shall be in default under this
Contract and Seller shall be allowed thirty (30) days from receipt of a
written notice of such default from Buyer in which to cure such
default, or initiate and diligently pursue to completion a cure, after
which Buyer shall immediately have the right to terminate this Contract
by written notice to Seller. In the event the Contract sets forth a
specific remedy for any breach, Buyer shall not have the right to
terminate the Contract.
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ARTICLE 15. INDEMNIFICATION
15.1 INDEMNIFICATION. Seller shall indemnify and hold harmless Buyer,
partners in Buyer, their respective affiliates, a Section 22.1 third
party assignee and the officers and directors of such partners,
affiliates and assignee ("Buyer Indemnified Parties"), from any losses,
liabilities, judgments or damages arising from third party claims
(excluding claims of third parties due to electric service interruption
or frequency fluctuation) for damage to tangible property, or for
injury (including death) to persons (including employees of Seller and
the Buyer Indemnified Parties) to the extent that such claim is based
upon or attributable to (i) the negligence or willful misconduct of
Seller or its servants, agents, or employees, or (ii) the breach of
Seller's obligations under this Contract. In the event any damage or
injury is caused jointly or concurrently by the negligence of Buyer and
Seller, such loss shall be borne proportionately by the Parties to
their degree of negligence. Seller shall not be liable in any event for
loss or injury to persons or property (including the Equipment supplied
hereunder) to the extent caused (a) solely by Buyer, its agents,
employees, contractors, or their employees, agents, or subcontractors,
or (b) solely by the failure or malfunctioning of any tools, equipment,
facilities, or devices furnished by Buyer. For purposes of this Section
15.1, "third party" shall not include Buyer, or its partners,
subsidiaries, affiliates, parents, successors or assigns, or any party
with (x) an equity or partnership interest in the foregoing, or (y) a
security interest of any nature in the foregoing's assets or property,
if such party also claims or seeks to claim any of the rights, powers,
or privileges of Buyer under this Contract.
15.2 INDEMNIFICATION. Buyer shall indemnify and hold harmless Seller and
affiliates of Seller, and the officers and directors of such affiliates
("Seller Indemnified Parties"), from any losses, liabilities, judgments
or damages arising from third party claims for damage to tangible
property, or for injury (including death) to persons (including
employees of Buyer and the Seller Indemnified Parties) to the extent
that such claim is based upon or attributable to (i) the negligence or
willful misconduct of Buyer or its servants, agents, or employees, or
(ii) the breach of Buyer's obligations under this Contract. In the
event any damage or injury is caused jointly or concurrently by the
negligence of Buyer and Seller, such loss shall be borne
proportionately by the Parties to their degree of negligence. Buyer
shall not be liable in any event for loss or injury to persons or
property (including the Equipment supplied hereunder) to the extent
caused (a) solely by Seller, its agents, employees, contractors, or
their employees, agents, or subcontractors, or (b) solely by the
failure or malfunctioning of any tools, equipment, facilities, or
devices furnished by Seller. For purposes of this Section 15.2, "third
party" shall not include Seller, or its subsidiaries, affiliates,
parents, successors or assigns, or any party with (x) an equity or
partnership interest in the foregoing, or (y) a security interest of
any nature in the foregoing's assets or property, if such party also
claims or seeks to claim any of the rights, powers, or privileges of
Seller under this Contract.
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ARTICLE 16. PERFORMANCE GUARANTEES
16.1 Performance Guarantees.
(a) LIQUIDATED DAMAGE PERFORMANCE GUARANTEES Each individual
guaranteed performance specified in subsections (i) and (ii)
of this Section 16.1(a) is herein referred to as a "Liquidated
Damage Performance Guarantee". The respective guaranteed
values referenced below, and the contract conditions which
apply to such guaranteed values, are identified in Section 1.0
of Appendix C.
Seller guarantees that:
(i) the "Final Test Value" for the Net Equipment
Electrical Output as defined in Sections 1.0, 2.0
and 3.0 of Appendix C shall not be less than the
guaranteed output set forth in Section 1.1 of
Appendix C; and
(ii) the "Final Test Value" for the Net Equipment Heat
Rate as defined in Sections 1.0, 2.0 and 3.0 of
Appendix C shall not be greater than the guaranteed
heat rate set forth in Section 1.2 of Appendix C;
when, in each case (i) and (ii) above, such actual values are
measured and corrected to the contract conditions as specified
in Appendix C all in accordance with the test procedures
(hereinafter "Final Test Value(s)").
(b) PERFORMANCE GUARANTEES. (Exhaust and Noise Emissions) Each
individual guaranteed performance specified in subsections (i)
and (ii) of this Section 16.1(b) is herein referred to as a
"Performance Guarantee". The respective guaranteed values
referenced below, and the contract conditions which apply to
such guaranteed values, are identified in Section 4.0 of
Appendix C.
Seller guarantees that:
(i) the "Final Test Values" for the exhaust emissions
from the combustion turbine Units shall not exceed
the guaranteed limits set forth in Section 4.1 of
Appendix C when the actual values for such emissions
are measured as specified in Section 4.1 of Appendix
C all in accordance with the test procedures; and
(ii) the "Final Test Values" for the noise emissions from
the combustion turbine Unit(s) shall not exceed the
guaranteed limits set forth in Section 4.2 of
Appendix C when the actual value for such emissions
is measured as specified in Section 4.2 of Appendix C
in accordance with the test procedures.
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16.2 SATISFACTION OF LIQUIDATED DAMAGE PERFORMANCE GUARANTEES AND
PERFORMANCE GUARANTEES.
(a) SATISFACTION OF LIQUIDATED DAMAGE PERFORMANCE GUARANTEES. The
Liquidated Damage Performance Guarantees set forth in
subsections (i) and (ii) of Section 16.1(a) shall be
conclusively deemed satisfied and Seller shall be relieved of
any and all obligations with respect to such Liquidated Damage
Performance Guarantees after the condition(s) of the
applicable subsection of each of (i) and (ii) below has
occurred:
(i) (A) the Final Test Value of the Net Equipment Electrical
Output is equal to or greater than the guaranteed
electrical output set forth in Section 1.1 of
Appendix C, or
(B) Seller has exercised all reasonable efforts and
diligently taken appropriate corrective actions to
achieve the guaranteed electrical output set forth in
Section 1.1 of Appendix C during any testing and
retesting conducted by Buyer or on Buyer's behalf and
having achieved the Performance Minimum for
electrical output set forth in Section 1.1 of
Appendix C but having failed to achieve the
guaranteed electrical output, Seller has paid
liquidated damages to Buyer pursuant to Section
17.2(b), or
(C) Buyer provides written notice to Seller that it has
satisfied this portion of the Liquidated Damage
Performance Guarantee; and
(ii) (A) the Final Test Value of the Net Equipment Heat Rate
is equal to or less than the guaranteed heat rate set
forth in Section 1.2 of Appendix C, or
(B) Seller has exercised all reasonable efforts and
diligently taken appropriate corrective actions to
achieve the guaranteed heat rate set forth in Section
1.2 of Appendix C during any testing and retesting
conducted by Buyer or on Buyer's behalf and having
achieved the Performance Minimum for heat rate set
forth in Section 1.2 of Appendix C but having failed
to achieve the guaranteed heat rate, Seller has paid
liquidated damages to Buyer pursuant to Section
17.2(b), or
(C Buyer provides written notice to Seller that it has
satisfied this portion of the Liquidated Damage
Performance Guarantee.
(b) SATISFACTION OF PERFORMANCE GUARANTEES. The Performance
Guarantees set forth in subsections (i) and (ii) of Section
16.1(b) shall be conclusively deemed satisfied and Seller
shall be relieved of any and all obligations with respect to
such Performance Guarantees after the condition(s) of the
applicable subsection of each of (i) and (ii) below has
occurred:
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(i) (A) the Final Test Values for the exhaust emissions
from the combustion turbine Unit are each equal to
or less than the guaranteed limits set forth in
Section 4.1 of Appendix C, or
(B) Buyer provides written notice to Seller that it has
satisfied such Performance Guarantee; and
(ii) (A) the Final Test Values for the noise emissions from
the combustion turbine Unit(s) is equal to or less
than the guaranteed limits set forth in Section 4.2
of Appendix C, or
(B) Buyer provides written notice to Seller that it has
satisfied such Performance Guarantee;
provided that the Emissions Test for such Project may be delayed by
Buyer for a period not to exceed six (6) months after Commercial
Operation.
16.3 DEMONSTRATION TEST GUARANTEES. Seller guarantees that the Equipment
shall satisfy the Demonstration Test requirements set forth in Section
6.0 of Appendix C (the "Demonstration Test Requirements") when such
tests are performed in accordance with the test procedures.
Each Demonstration Test Requirement set forth in Section 6.0 of
Appendix C shall be conclusively deemed satisfied and Seller shall be
relieved of any and all obligations with respect to such Demonstration
Test Requirement upon the occurrence of the following:
(i) the performance of the Equipment in such
Demonstration Test equals or exceeds the requirement
guaranteed for such test in Section 6.0 of Appendix
C, or
(ii) Buyer provides written notice to Seller that it has
satisfied such Demonstration Test Requirement;
provided that the test of the Combustion Turbine Evaporative Cooler may
be delayed by Buyer for a period not to exceed six (6) months after
Commercial Operation.
16.4 AVAILABILITY TEST GUARANTEE. Seller guarantees that the Equipment
shall satisfy the Availability Test requirements set forth in Section
7.0 of Appendix C (the "Availability Test Requirements") when such
test is performed in accordance with the test procedures.
Each Availability Test Requirement set forth in Section 7.0 of Appendix
C shall be conclusively deemed satisfied and Seller shall be relieved
of any and all obligations with respect to such Availability Test
Requirement upon the occurrence of the following:
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(i) the performance of the Equipment in such Availability Test
equals or exceeds the requirement guaranteed for such test in
Section 7.0 of Appendix C, or
(ii) Buyer provides written notice to Seller that it has satisfied
such Availability Test Requirement.
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ARTICLE 17. LIQUIDATED DAMAGES AND ACCEPTANCE TESTING
17.1 SCHEDULE LIQUIDATED DAMAGES. In the event of a delay in Shipment or
Delivery (as applicable, depending upon which of such events has an
applicable Guaranteed Date in Section 4.1(a)) of a Unit or if Seller's
failure to comply with the requirements of this Contract with respect
to Equipment and Services causes a delay in the achievement of
Commercial Operation of one or more Units, the Parties agree that
Buyer's loss would be difficult to determine. Each Party acknowledges
and agrees, after taking into account the terms of this Contract and
all relevant circumstances at the date hereof, that the liquidated
damages payable under this Section 17.1 represent a reasonable and
genuine pre-estimate of the damages which would be suffered by Buyer in
the event of a delay in the Delivery or Shipment (as applicable) of one
or more Units or a delay in the achievement of Commercial Operation of
one or more Units and does not constitute a penalty. Accordingly,
Seller and Buyer agree, as a predetermined reasonable and exclusive
remedy for any such loss to the following liquidated damages:
(a) SHIPMENT OR DELIVERY.
Except for Spare Parts, in the event that Shipment or Delivery
(as applicable depending upon the Guaranteed Date) of a Unit
(as defined in Section 4.1(d)) is not made on or before the
applicable Guaranteed Date for such Unit as set forth in
Section 4.1(a) due to causes not excused by the provisions of
this Contract, daily liquidated damages shall accrue (subject
to the notice requirements of Section 4.1(d)(i) and (ii) in
the event that certain Equipment is missing) at the following
rates for each full day that Shipment or Delivery (as
applicable) of such Unit occurs after the Guaranteed Date:
for days one (1) through fourteen (14), the sum of
Twenty Thousand Dollars ($20,000) per day, per
Unit; and for days beyond the fourteenth (14th) day,
the sum of Forty Thousand Dollars ($40,000) per day,
per Unit.
(b) COMMERCIAL OPERATION. To the extent that Seller's failure to
comply with the requirements of this Contract with respect to
a Unit is the primary cause of one or more days that the Unit
does not achieve Commercial Operation by the Scheduled Date of
Commercial Operation for such Unit and such cause of delay is
not excused by the provisions of this Contract, Seller agrees
to pay liquidated damages in accordance with the following
schedule: for days one (1) through fourteen (14), the sum of
Thirty Thousand Dollars ($30,000) per day, per Unit; and for
days beyond the fourteenth (14th) day, the sum of Fifty
Thousand Dollars ($50,000) per day, per Unit.
(i) If, despite the efforts of the EPC Contractor to
mitigate the effects of late Shipment or Delivery
under Section 17.1(a), such late Shipment or
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Delivery of a Unit is the primary cause of a delay of
any day the Unit does not achieve Commercial Operation
by the Scheduled Date of Commercial Operation for such
Unit (excluding the first thirty (30) days of late
Shipment or Delivery under Section 17.1(a) which shall
be deemed to have no effect on the achievement of
Commercial Operation), Seller shall pay liquidated
damages to Buyer in accordance with the schedule set
forth in Section 17.1(b) above, provided that in
determining the amount of any liquidated damages under
this Section 17.1(b)(i) for delay after the first
thirty (30) days, the liquidated damages paid by
Seller under Section 17.1(a) with respect to each day
of delay shall reduce the amount of liquidated damages
due under this Section 17.1(b)(1) for such
corresponding day of delay. FOR EXAMPLE, if Commercial
Operation of a Unit is fifty (50) days late, all of
which was caused by late delivery of such Unit, the
first thirty (30) days of late Commercial
Operation are disregarded. Liquidated damages under
this Section 17.1(b)(1) will be $10,000 per day for
each day thereafter through the fiftieth day,
calculated by using $50,000 for the thirty first day
of delay in achieving Commercial Operation as shown in
the schedule at the beginning of this Section 17.1(b)
minus $40,000 of liquidated damages paid for such gas
turbine Unit which was delivered thirty-one days late,
and continuing similarly with such calculation for
each of the days through the fiftieth day.
(ii) If, excluding any and all effects of any late
Shipment or Delivery under Section 17.1(a), the
actions or inactions of Seller are the primary cause
of a delay of any day a Unit does not achieve
Commercial Operation by the Scheduled Date of
Commercial Operation for such Unit and such cause of
delay is not excused by the provisions of this
Contract, Seller shall pay liquidated damages to Buyer
in accordance with the schedule set forth in Section
17.1(b) above, provided that (i) Seller shall have a
minimum time period (the "Minimum Period") of
thirty-one (31) days after each of Units #1, #4, #5
and #6 is Mechanically Complete and twenty-seven (27)
days after each of Units #2 and #3 is Mechanically
Complete, as shown in the EPC Project Schedule
attached to this Contract as Appendix H (commissioning
of Units #2 and #3 on fuel oil to be delayed until
after Commercial Operation) for inspecting the Unit
and its installation, the performance of pre-testing,
startup, commissioning, correction of discovered
problems, tuning, verification that the Unit is in
proper adjustment and condition to begin Acceptance
Testing and the performance of Acceptance Testing by
Buyer's EPC Contractor (extended for any time periods
during such Minimum Period when Seller reasonably
needs to perform services or tests on such Unit and
does not have such access and availability to such
Unit, consistent with the EPC Project Schedule),
prior to the expiration of which no liquidated damages
shall accrue under this Section 17.1(b). Seller shall
notify Buyer's EPC Contractor, in writing, in the
event that, as provided in the immediately
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preceding sentence, Seller believes that it has not
had the access to such Unit which it reasonably needs
and Buyer's EPC Contractor shall have 24 hours in
which to cure such problem by providing such access to
Seller. Buyer shall cause the EPC Contractor to
provide Seller with written notice when each Unit is
Mechanically Complete, and the Minimum Period shall
not commence until Seller has received such notice.
Any modifications to the EPC Project Schedule made by
the EPC Contractor shall provide Seller with durations
for the performance of Seller's activities during the
Minimum Period, which are comparable to or greater
than the durations available under the original EPC
Project Schedule attached as Appendix H. If, prior to
Commercial Operation of a Unit, Seller recommends
repair activities for a Unit which Buyer's EPC
Contractor has the responsibility to perform, Seller
shall not be charged for liquidated damages for delay
in achieving Commercial Operation of such Unit for any
period of time which is longer than the normal period
of time which would be required to accomplish such
repairs or for any period of time after such repairs
are completed which is longer than reasonably
necessary to prepare such Unit for testing or
retesting. In connection with Seller's performance of
Services under this Contract, including work performed
by Seller during the Minimum Period, Seller shall work
in conjunction with Buyer's EPC Contractor to
coordinate all activities in order to minimize the
total time required for the achievement of Commercial
Operation. Any liquidated damages which accrue under
this Section 17.1(b)(ii) shall be in addition to any
liquidated damages which may accrue under Section
17.1(a) or Section 17.1(b)(i).
In the event that liquidated damages are to be paid to Buyer
pursuant to this Section 17.1(b), such liquidated damages
shall continue to accrue for a Unit for each day until the
earlier of (1) Commercial Operation for such Unit is achieved
or (2) Seller, having (i) achieved the Interim Performance
Requirements for such Unit, (ii) satisfied the exhaust
emission requirements as measured by CEMS in accordance with
the requirements of Appendix C (compliance testing not
required prior to this date), (iii) satisfied the
Demonstration Test Requirements (excluding an Evaporation
Cooler Test), and (iv) successfully completed a ten (10) hour
availability test requirement for such Unit, as described in
Section 7.0 of Appendix C, elects to stop the accrual of
liquidated damages under this Section 17.1(b) by making an
election under Section 17.2(d). "Commercial Operation" means
the satisfaction of all requirements of applicable tests
required under the EPC Agreement for Commercial Operation of a
Unit, as determined under the EPC Agreement. Buyer shall cause
the contractor under the EPC Agreement to cooperate with
Seller to provide timely information, including an Acceptance
Testing schedule during the Minimum Period, to Seller
concerning the Scheduled Commercial Operation Date for each
Unit under the EPC Agreement, including any changes to such
dates within a reasonable time after such changes. In the
event that the aggregate amount of liquidated damages charged
to Seller under
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Section 17.1(b) exceeds the aggregate amount of liquidated
damages paid by the EPC Contractor under the EPC Agreement
for failing to timely achieve Commercial Operation, as
defined in the EPC Agreement, the amount of liquidated
damages charged to Seller under Section 17.1(b) shall be
reduced to such amount paid by the EPC Contractor, and Buyer
shall, if necessary, refund any excess payments to Seller.
In the event that Seller is the primary cause of delay in
the achievement of Commercial Operation of a Unit and the
maximum liquidated damages for delay in achieving Commercial
Operation under this Section 17.1 have accrued, or the delay
in the achievement of Commercial Operation of a Unit caused
by Seller exceeds one (1) year, for whatever reasons,
including delay in Shipment or Delivery of the Unit, Seller
shall be in material breach for substantial nonperformance
of this Contract. Upon a material breach for substantial
nonperformance pursuant to this Section 17.1, Buyer may
pursue any and all remedies available to Buyer, at law or in
equity, including termination of this Contract with respect
to such Unit at any time thereafter without payment of any
Cancellation Charge, and the filing of an action for damages
in addition to any previously accrued liquidated damages
relating to such Unit, caused by such material breach,
subject only to the limitation of liability set forth in
Section 13.1 and the exclusion of damages set forth in
Section 13.2, provided that Section 13.2 shall not restrict
Buyer from the recovery of damages for any additional direct
costs arising from the completion of the performance
required under this Contract, whether by another party or by
Buyer.
(c) ACCRUAL OF LIQUIDATED DAMAGES UNDER SECTIONS 17.1. Liquidated
damages shall accrue pursuant to Section 17.1(a) beginning on
the Scheduled Shipment Date or the Scheduled Delivery Date for
each Unit, as applicable. Liquidated damages, if any,
applicable pursuant to Section 17.1(b) shall be determined by
Buyer within thirty (30) days after Commercial Operation of a
Unit and shall be deemed to have accrued upon the notification
to Seller, in accordance with Section 22.7, of the amount of
such liquidated damages and the basis for such determination;
provided that in the event that Commercial Operation of a Unit
is delayed beyond ninety (90) days after the Scheduled Date of
Commercial Operation for such Unit as a result of delays
caused by Seller or Commercial Operation of a Unit fails to
occur within twelve (12) months of the date of the Delivery of
a Unit, Buyer may, at any time thereafter, notify Seller of
the amount of liquidated damages, if any, applicable to Seller
under Section 17.1(b) and such liquidated damages shall be
deemed to have accrued on such date of notification.
(d) AGGREGATION OF LIQUIDATED DAMAGES. The amounts specified in
the schedule set forth in Section 17.1(a), when aggregated for
all days of late Shipment or Delivery, as applicable, plus the
amounts specified in the schedule set forth in Section 17.1(b)
when aggregated for all Units and all days of delay in
Commercial Operation for all Units represent the aggregate
maximum liability of Seller for late Shipment or Delivery, as
applicable, under Section 17.1(a) and for delay in Commercial
Operation under Section 17.1(b).
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(e) LIMITATION. Seller's total aggregate liability for
liquidated damages under this Section 17.1 for all Units,
together with any payments made pursuant to Section 17.2(e),
shall not exceed thirty percent (30%) of the Total
Contract Price.
17.2 PERFORMANCE.
(a) PERFORMANCE GUARANTEES. If Buyer elects to conduct Acceptance
Testing, then each of the Units shall satisfy the Liquidated
Damage Performance Guarantees set forth in Section 1.0 of
Appendix C, the Performance Guarantees set forth in Section
4.0 of Appendix C, the Demonstration Test Requirements set
forth in Section 6.0 of Appendix C, and the Availability Test
Requirements set forth in Section 7.0 of Appendix C. Seller
may observe any preliminary tests including standard start-up
tests made by Buyer, for the purpose of verifying that the
Unit is in proper adjustment and condition to undergo
Acceptance Testing.
(b) PERFORMANCE LIQUIDATED DAMAGES. With respect to the Liquidated
Damage Performance Guarantees, it is agreed that Buyer's loss
would be difficult to determine in the event that one or more
of the Units fails to satisfy the Liquidated Damage
Performance Guarantees. Accordingly, Seller and Buyer agree as
a predetermined reasonable and exclusive remedy (provided that
with respect to Net Equipment Electrical Output and Net
Equipment Heat Rate, the Units must achieve the Performance
Minimums before liquidated damages become the exclusive
remedy) for any such loss, Seller shall pay to Buyer for
liquidated damages and not as a penalty, sums based upon the
following items:
(i) NET EQUIPMENT ELECTRICAL OUTPUT - [*] for each
kilowatt that the actual Net Equipment Electrical
Output (using an aggregated number for all Units
based upon testing of all Units located at the
Project) is less than the guaranteed Net Equipment
Electrical Output set forth in Section 1.1 of
Appendix C.
(ii) NET EQUIPMENT HEAT RATE - [*] for each BTU per
kilowatt hour per Unit that the actual Net Equipment
Heat Rate (using an average number based upon testing
of all Units located at the Project Site), when
tested on natural gas, is greater than the guaranteed
Net Equipment Heat Rate set forth in Section 1.2 of
Appendix C, plus [*] for each BTU per kilowatt hour
per Unit that the actual Net Equipment Heat Rate
(using an average number based upon testing of all
Units located at the Project Site), when tested on
fuel oil, is greater than the guaranteed Net
Equipment Heat Rate set forth in Section 1.2 of
Appendix C.
(c) ACCEPTANCE TESTING.
(i) TESTING PROCEDURES. Buyer may conduct Acceptance
Testing in order to
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determine whether the Liquidated Damage Performance
Guarantees, the Performance Guarantees, the
Demonstration Test Requirements, and the Availability
Test Requirements have been satisfied. Such testing
shall be conducted by Buyer or on Buyer's behalf and
may be witnessed by Seller. Seller shall develop the
detailed test procedures for initial testing and
potential retesting and obtain Buyer's review,
comment, and approval not later than October 31,
2000; provided that test procedures for the Utility
Tests shall be developed on Buyer's behalf by the EPC
Contractor as set forth in Section 8.0 of Appendix C.
For all Acceptance Testing performed under this
Contract, Buyer (or, as applicable, the EPC
Contractor on Buyer's behalf) shall at no cost to
Seller: (i) make the Units available at the times,
loads and conditions necessary for proper testing,
(ii) provide all instrumentation, labor, operators,
technicians, fuel and consumables required to perform
Acceptance Testing and to read and record the test
data, (iii) provide fuel and consumables in
accordance with the Specifications and (iv) conduct
the Performance Tests, Demonstration Tests, Emissions
Test, Availability Test and Utility Tests in
accordance with test procedures approved by Buyer and
calculate the test results. Seller, based upon
project information provided by Buyer, estimates that
[*] of fuel will be consumed during operation of the
Units in connection with the installation, start up,
commissioning, Acceptance Testing, diagnostic
testing, and retesting of the Units and Seller will
perform the Services under this Contract so as to
minimize the potential use of fuel in excess of such
estimated amounts. Seller shall have no liability for
fuel costs associated with the Project. Seller shall
(i) have the right of representation at all
Acceptance Testing, (ii) have access to all data
resulting from the Acceptance Testing, and (iii) be
promptly furnished with a copy of the test data and
have the right to review and comment on the
calculations used to determine the test results.
(ii) DIAGNOSTIC TESTING AND REMEDY If results of any
Acceptance Testing indicate that any of the
Liquidated Damage Performance Guarantees, the
Performance Guarantees, the Demonstration Test
Requirements, or the Availability Test Requirements
have not been satisfied, Buyer (or the EPC Contractor
on Buyer's behalf) will, at Seller's request, conduct
diagnostic tests (which may include tests to
determine the efficiency of the groups of blading in
each turbine element) to determine the cause(s) of
the failure and the expedient remedial action. With
respect to such diagnostic tests, Seller will at its
expense (i) provide test instrumentation for the
period of the tests, (ii) provide engineering
direction and labor for installation of the test
instrumentation and for conducting the tests, and
(iii) analyze the test data from such tests. With
respect to such diagnostic tests, Buyer (or the EPC
Contractor on Buyer's behalf) will at its expense (i)
provide fuel for the tests, (ii) provide sufficient
load during the tests, (iii) operate the Units during
the tests, and (iv) read and record the test data.
Seller shall, at its
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expense, using all reasonable efforts, attempt to
remedy the failure by repair, adjustment or
replacement of the Equipment as Seller deems
necessary to correct such failure.
(iii) RETESTING. If Seller has completed its attempt to
remedy the failure of the Equipment to satisfy the
Liquidated Damage Performance Guarantees, the
Performance Guarantees, the Demonstration Test
Requirements, or the Availability Test Requirements,
the Parties shall as soon as practicable after the
date of re-synchronization following completion of
Seller's remedy, reperform Acceptance Testing.
Reperformance of Acceptance Testing shall occur as
soon as reasonably possible following notice from
Seller during the Retest Period that a Unit is again
ready for Acceptance Testing. With respect to such
Acceptance Testing, Seller will (i) provide test
instrumentation for the period of the tests, (ii)
provide technical guidance and assistance during the
tests, and (iii) calculate the tests results.
Following any failure of the Equipment to satisfy any
of the Liquidated Damage Performance Guarantees, the
Performance Guarantees, the Demonstration Test
Requirements, or the Availability Test Requirements,
Seller shall continue to use all reasonable efforts
to satisfy the Liquidated Damage Performance
Guarantees, the Performance Guarantees, the
Demonstration Test Requirements, and the Availability
Test Requirements in accordance with the preceding
procedures of this Section 17.2(c), provided that
upon satisfying all of the Performance Guarantees
(other than the Emissions Test, if delayed),
the Demonstration Test Requirements (other than the
Combustion Turbine Evaporative Cooler portion, if
delayed), and the Availability Test Requirements and
achieving all of the Interim Performance
Requirements, Seller may elect to proceed in
accordance with Section 17.2(d). Notwithstanding any
provision in this Contract to the contrary, Buyer
reserves the right to require Seller to reconduct any
Acceptance Testing which Buyer reasonably
deems necessary after any changes, adjustments or
modifications are made to the Equipment by Seller, in
order to confirm or establish the final test results.
Subject to the right of Seller to elect pursuant to
Section 17.2(d), and Buyer's right to terminate this
Contract pursuant to Section 17.2(f), Seller shall be
required to continue diagnostic testing, remedy and
retesting of the Units until all of the Performance
Guarantees, the Demonstration Test Requirements, the
Availability Test Requirements, and the Performance
Minimums have been satisfied.
(d) SELLER'S ELECTION TO REDUCE LIQUIDATED DAMAGES FOR COMMERCIAL
OPERATION. In the event that after completion of Acceptance
Testing, a Unit has (i) achieved the Interim Performance
Requirements, (ii) satisfied the exhaust emission requirements
as measured by CEMS in accordance with the requirements of
Appendix C (compliance testing not required prior to this
date), (iii) satisfied the Demonstration Test Requirements
(excluding an Evaporation Cooler Test), and
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(iv) successfully completed an ten (10) hour availability test
requirement, as described in Section 7.0 of Appendix C, but
has failed to satisfy all of the Liquidated Damage Performance
Guarantees, Seller may elect to stop the accrual of liquidated
damages under Section 17.1(b) by delivering written notice to
Buyer under this Section 17.2(d) of such election, which
notice shall include a statement that the Unit has achieved
the Interim Performance Requirements based upon the results
of the most recent Performance Tests and setting forth the
values for Net Equipment Heat Rate and Net Equipment
Electrical Output achieved by such Unit. For purposes of a
Unit satisfying the Interim Performance Requirements for Net
Equipment Heat Rate and Net Equipment Electrical Output in
order to stop the accrual of liquidated damages under Section
17.1(b), such Unit will be tested individually and must
satisfy each of the Net Equipment Heat Rate Interim
Performance Requirement and the Net Equipment Electrical
Output Interim Performance Requirement individually, and Buyer
shall calculate the performance liquidated damages which would
otherwise be due with respect to such Unit based upon such
values for Net Equipment Heat Rate and Net Equipment
Electrical Output ("Potential Liquidated Damages"), but such
liquidated damages shall not be deemed to have accrued as a
result of such election. Notwithstanding the immediately
preceding sentence, for purposes of finally calculating
liquidated damages under this Contract, Net Equipment Heat
Rate will be determined as an average of all Units and Net
Equipment Electrical Output will be determined as an aggregate
of all Units. After making an election under this Section
17.2(d), Seller shall use all reasonable efforts to cause such
Unit to satisfy all of the Liquidated Damage Performance
Guarantees making such changes and adjustments to the Unit as
Seller deems necessary and diligently retesting until all of
the Liquidated Damage Performance Guarantees for such Unit
have been satisfied or until one hundred eighty (180) days
have expired from the date of the notification, whichever
occurs first ("Retest Period"). As a condition to proceeding
under this Section 17.2(d), Seller agrees that Seller's remedy
and testing will not unreasonably interfere with the normal
and continuous operation of the Unit during the Retest Period
and that the cost of all changes, adjustments and retesting,
excluding fuel and operating expenses, shall be at Seller's
expense. If the Retest Period has elapsed and the Unit has
failed to satisfy all of the Liquidated Damage Performance
Guarantees, Buyer may terminate Seller's remedy and retesting
activities or require Seller to continue remedy and testing
activities for an additional period of up to one hundred
twenty (120) days under the same provisions and procedures
which governed the Retest Period. If Buyer terminates Seller's
remedy and retesting activities, liquidated damages relating
to the Liquidated Damage Performance Guarantees shall be
finally determined in accordance with Section 17.2(f). If
Buyer extends the time for remedy and retesting, Seller shall
make changes and adjustments to the Unit as Seller deems
necessary to satisfy the Liquidated Damage Performance
Guarantees and shall use all reasonable efforts and shall
diligently remedy and retest until all of the Liquidated
Damage Performance Guarantees are satisfied or until such
extension has expired, whichever comes first ("Extended Retest
Period"). The cost of any
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such changes, adjustments and retesting, excluding fuel and
operating expenses, shall be at Seller's expense. If at the
end of such Extended Retest Period, the Equipment has failed
to satisfy all of the Liquidated Damage Performance
Guarantees, Buyer shall terminate retesting and liquidated
damages relating to the Liquidated Damage Performance
Guarantees shall be finally determined in accordance with
Section 17.2(f). If during the Retest Period or the Extended
Retest Period, Buyer operates a Unit more than a total of two
hundred fifty (250) hours to satisfy the requirements of the
Power Purchase Agreement, the Liquidated Damage Performance
Guarantee values will be adjusted in accordance with a
degradation schedule provided in the Acceptance Test
procedures pursuant to Appendix C of this Contract.
(e) MODIFIED LIQUIDATED DAMAGES. During any Retest Period and
Extended Retest Period pursuant to Section 17.2(d),
Buyer and Seller shall, in good faith, coordinate
the availability of Unit(s) for diagnostic testing,
remedy or retesting, so as to permit Seller to
perform such diagnostic testing, remedy or retesting
at times when Buyer would not otherwise operate such
Units under the Power Purchase Agreement. Seller
shall be required to pay modified liquidated damages
only if diagnostic testing, remedy or retesting
during the Retest Period and any Extend Retest
Period causes a Unit to be unavailable to Buyer for
generation of power under the Power Purchase
Agreement for periods in excess of the periods
described in the immediately preceding sentence.
Liquidated damages, if applicable, shall be
calculated on a daily basis with respect to each day
or part thereof that such Unit was unavailable to
Buyer because of diagnostic testing, remedy or
retesting, during the entire period, using the
following formula (this value shall not be less than
zero):
$/Day x (Hours Not Available/24)
The $/Day in the above formula is the full daily
amount of liquidated damages as stipulated in
Section 17.1(b) and considering the number of days,
if any, previously used in such schedule. Hours Not
Available are the actual hours during which Buyer
was prevented from earning revenue from such Unit
during such Day becuase of Seller's activities.
(f) FAILURE OF PERFORMANCE TESTS. If Seller has achieved the
Performance Minimums but failed to satisfy all of the
Liquidated Damage Performance Guarantees with respect to a
Unit, Unit Performance Liquidated Damages shall be
calculated by Buyer in accordance with Section 17.2(b) based
upon the test results from the most recent Performance
Tests, provided that if Seller has not elected to proceed in
accordance with Section 17.2(d), Seller shall use reasonable
commercial efforts to satisfy the Liquidated Damage
Performance Guarantees for a period of at least thirty (30)
days. Unit Performance Liquidated Damages for each Unit
(based upon the most recent performance tests) for failure
to satisfy any Liquidated Damage Performance Guarantees, if
not previously satisfied, shall
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accrue under this Contract on the earlier of (i) such time
as Seller, having satisfied the Performance Minimums and
having used reasonable commercial efforts to satisfy the
Liquidated Damage Performance Guarantees for a period of at
least thirty (30) days, has notified Buyer that it accepts
the results of the most recent Performance Test for such
Unit as the Final Test Values, (ii) if written notice is
delivered to Buyer pursuant to Section 17.2(d), at the end
of any period for remedy and testing of a Unit allowed
pursuant to Section 17.2(d), or (iii) ninety (90) days
having passed since the beginning of initial Acceptance
Testing for a Unit and Seller, having satisfied the Interim
Performance Requirements but failed to achieve the
Liquidated Damage Performance Guarantees for such Unit, has
not elected to proceed pursuant to Section 17.2(d). In the
event that Seller, having been permitted the opportunity to
exercise all reasonable efforts to achieve the Performance
Minimums and satisfy the Performance Guarantees, the
Demonstration Test Requirements, and the Availability Test
Requirements for a Unit for a period not to exceed one
hundred sixty (160) days after the beginning of initial
Acceptance Testing, is unable to achieve all of the
Performance Minimums and to satisfy each Performance
Guarantee, each Demonstration Test Requirement, and each
Availability Test Requirement for a Unit, Buyer may declare
that there has been a material breach and substantial
nonperformance of this Contract with respect to such Unit
and Buyer may thereafter pursue any and all remedies
available to Buyer, at law or in equity (including
termination of this Contract with respect to such Unit
without payment of any Cancellation Charge and the filing of
an action for damages, in addition to any previously accrued
Unit Performance Liquidated Damages, caused by such material
breach and substantial nonperformance), subject only to the
limitation of liability set forth in Section 13.1 and the
exclusion of damages set forth in Section 13.2, provided
that Section 13.2 shall not restrict Buyer from the recovery
of damages for any additional direct costs arising from the
completion of the performance required under this Contract,
whether by another party or by Buyer. In any event, Seller
shall be deemed to have satisfied its obligations under this
Section 17.2 with respect to any Unit upon such Unit
satisfying or achieving the Liquidated Damage Performance
Guarantees, the Performance Guarantees, the Demonstration
Test Requirements, and the Availability Test Requirements
for such Unit. At such time as all of the Units have
accomplished one of the following:
(i) achieved Substantial Completion, or
(ii) completed testing and retesting under a Section
17.2(d) election, or
(iii) satisfied the Performance Minimums and all other
requirements of Acceptance Testing but Seller, in the
absence of a 17.2(d) election, having tried for at
least thirty (30) days after completion of initial
Acceptance Testing to achieve the Liquidated Damage
Performance Guarantees and having not achieved the
Liquidated Damage Performance Guarantees has elected
to accept Unit Performance Liquidated Damages at the
current
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performance level,
final liquidated damages shall be finally determined for all
of the Units based upon Net Equipment Heat Rate determined as
an average of all Units and Net Equipment Electrical Output
determined as an aggregate of all Units and final liquidated
damages shall be adjusted on an equitable basis and paid in
accordance with Section 17.6. Unit Performance Liquidated
Damages for each Unit shall be calculated based upon
performance tests performed on each Unit as a condition to
achieving Substantial Completion of such Unit and the results
of such tests shall be used for all aggregate calculations of
final liquidated damages (without any requirement to repeat
such performance tests), except that Unit Performance
Liquidated Damages for Units #2 and #3 shall be initially
calculated without the Deferred Tests for such Units and Unit
Liquidated Damages for Units #2 and #3 shall be recalculated
as such time as the Deferred Tests are completed for such
Units.
(g) LIMITATION. Seller's total aggregate liability for liquidated
damages under this Section 17.2, excluding any payments made
pursuant to Section 17.2(e), shall not exceed thirty percent
(30%) of the Total Contract Price.
17.3 DOCUMENTATION LIQUIDATED DAMAGES. In the event that the Project
specific documentation, in reasonable form and substance for the power
industry, identified by the initials L.D. in the left margin next to
the documents listed in Appendix G is not provided by the applicable
dates set forth in Appendix G due to causes not excused by the
provisions of this Contract, Seller shall pay to Buyer daily liquidated
damages in the amount of [*] per day for each late document until such
documentation is provided; not to exceed in the aggregate an amount of
[*] per day, regardless of the number of late documents. Seller's
liability for liquidated damages pursuant to this Section 17.3 shall
not exceed [*]. Daily liquidated damages shall accrue under this
Section 17.3 beginning upon the applicable dates set forth in Appendix
G.
17.4 LIMITATION OF LIQUIDATED DAMAGES. Seller's total aggregate
liability for liquidated damages under this Contract shall not exceed
thirty five percent (35%) of the Total Contract Price.
17.5 EXCLUSIVE REMEDY. If the Units achieve all of the Performance Minimums,
Seller's liability for liquidated damages with respect to such Units
shall be the exclusive remedy of Buyer and the sole liability of Seller
for an unexcused failure of the Seller to comply with the Liquidated
Damage Performance Guarantees and the requirements of this Contract in
Section 17.3 with respect to such Units which result in liquidated
damages, whether based in contract, in tort (including negligence and
strict liability), or otherwise. In the event liquidated damages for
failure to meet all of the Liquidated Damage Performance Guarantees or
the requirements of Section 17.3 with respect to the Units are paid by
Seller or by refund in accordance with Section 17.6, Seller's
Liquidated Damage
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Performance Guarantees or the requirements of Section 17.3, as
applicable, shall be deemed met at the level of performance actually
achieved by such Units and Seller's obligations with respect to such
Liquidated Damage Performance Guarantees and Section 17.3 shall
terminate with respect to such Units. Payment of liquidated damages
shall not relieve Seller of its obligations to repair or replace as
provided in Section 10.4 and Seller's obligations arising under
Section 13.3 except, after testing by Seller is completed, with
respect to those specific defects or deficiencies in a Unit for which
such liquidated damages have been paid.
17.6 APPLICATION OF TOTAL CONTRACT PRICE REDUCTIONS As any liquidated
damages accrue pursuant to Article 17, Buyer may invoice Seller for the
amount of such liquidated damages and Seller shall pay to Buyer the
amount invoiced within thirty (30) days of the date invoiced by Buyer,
provided that Buyer, upon written notice to Seller of the amount of
liquidated damages which have accrued, may withhold or cause to be
withheld, such amount of liquidated damages from any payments remaining
due to Seller under this Contract. If the aggregate Unit Performance
Liquidated Damages paid by Seller exceeds the final liquidated damages
determined as set forth in Section 17.2(f), Buyer shall pay to Seller
such excess amount within thirty (30) days of the final determination.
Any amount of liquidated damages which is not paid when due shall
accrue interest at an annual rate of interest equal to the prime rate
of The Chase Manhattan Bank, in effect on the due date plus one percent
(1%). The term Total Contract Price, for the purposes of determining
all limitations on liquidated damages or liability as provided in this
Contract, shall mean the sum of [*] unless the Total Contract Price is
modified pursuant to Section 3.5 or Article 9. The amount set forth in
the preceding sentence shall not be changed by reason of any liquidated
damages which may be withheld from payments due to Seller pursuant to
this Article 17.
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ARTICLE 18. PROJECT MANAGEMENT
18.1 PROJECT COORDINATORS. Seller and Buyer each agree to appoint a
qualified staff member or members, at no additional charge, to function
as overall Project Coordinator(s). The Seller and Buyer Project
Coordinators will act as the principal points of interface between the
Parties.
18.2 CONTINUITY OF SELLER'S EMPLOYEES. Seller agrees to use its reasonable
efforts to insure the continuity of all Seller employees assigned to
perform services hereunder. All persons furnished by Seller to perform
services at Buyer's premises shall be deemed solely Seller's employees
or agents and Seller shall have sole responsibility for them. Seller
shall use its best efforts to notify Buyer at least fourteen (14) days
prior to the reassignment of any such personnel. In the event Seller
reassigns any such personnel, Seller will use its best efforts to
provide a qualified replacement as soon as reasonably possible. In the
event that any Seller employee performing services contemplated by this
Contract is found to be unacceptable to Buyer, based upon Buyer's
reasonable judgment, Buyer shall notify Seller and Seller shall
immediately take appropriate corrective action to remove the
objectionable employee and to provide a qualified replacement.
18.3 STATUS REPORTS. Seller shall submit to Buyer's Project Coordinator(s),
commencing four (4) weeks after the date of the Design Finalization
Meeting with respect to the combustion turbine Units, and thereafter
every four (4) weeks during the term of the work effort contemplated by
this Contract, written status reports fully describing the activities
and accomplishments of Seller during the preceding four (4) week
period, in order to timely report Seller's continuous progress so that
timely corrective action can be taken as necessary. The status reports
will include, but not be limited to, the following: (a) current status
of Seller's activities, together with an explanatory narrative where
appropriate; (b) indication of the progress on the work being performed
by Seller; and (c) identification of actual and anticipated problem
areas, their impact on the work effort of Seller and on the delivery
schedule, and present action being taken (or suggested alternative
action to be taken) in order to reduce the impact of such problems. If
Buyer requests, Seller shall hold status meetings with Buyer management
in order to review the status of Seller's activities. Such meetings
will be conducted at such locations as are mutually agreed to by Buyer
and Seller. Any participation by Buyer or it's permitted assignee for a
certain Project, or an affiliate of Buyer, in the Vendor Coordination
Meeting is for the purpose of being advised of scheduling dates and
such entities shall have no responsibility with respect to the
coordination of Seller's work and any participation by Buyer or it's
permitted assignee, or an affiliate of Buyer in the Design Finalization
Meeting is for the purpose of generally advising Buyer concerning
design matters and such entities shall have no responsibility for the
adequacy of Seller's design and/or engineering.
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ARTICLE 19. TECHNICAL SERVICES
19.1 TECHNICAL SERVICES. Seller shall provide technical services to
Buyer, at no additional cost, in accordance with Appendix I for up to
six hundred (600) man-weeks for the combustion turbine Units (based on
a total purchase of six (6) Units). Any technical services provided by
Seller as a result of any defects in the Equipment or Services provided
by Seller shall not be charged against such allowance. A man-week shall
mean forty (40) hours of technical services, provided that there shall
be no use of equivalent hours for overtime or coverage during double
shifts, it being the obligation of Seller to provide a sufficient
number of technicians to satisfy the construction schedule and avoid
overtime charges. In the event that Buyer uses more than the total
number of six hundred (600) man-weeks of technical services, the Total
Contract Price shall be increased to reflect such actual usage based
upon a rate of $8,000 per man-week. In the event that Buyer uses less
than six hundred (600) man-weeks of technical services, the Total
Contract Price shall be decreased by an amount equal to $8,000 for each
man-week less than five hundred five man-weeks. The provision of such
services shall be scheduled to correspond to the construction schedule
for the Project.
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ARTICLE 20. TRAINING AND DOCUMENTATION
20.1 DOCUMENTATION. Seller agrees to provide, at no charge to Buyer, copies
of all documentation for the Equipment (the "Documentation") described
in Appendix G by no later than the applicable dates set forth in
Appendix G and such other written materials, including manuals, which
are to be provided to Buyer by Seller in accordance with any other
Sections of this Contract and the Appendices. Such Documentation shall
be in accordance with Seller's standard format and include, but not be
limited to, the following: user, operator/attendant and supervisory
reference manuals and guides, operational and technical bulletins,
Equipment schematics, parts listings, and other documentation and
operating instructions sufficient to enable Buyer to use, operate, and
maintain the Equipment.
20.2 REPRODUCTION OF DOCUMENTATION. Buyer may copy the Documentation
provided hereunder in order to satisfy its own internal requirements
subject to the confidentiality requirements of Article 11. If Buyer
requests Seller to furnish additional copies of any such Documentation,
Seller shall furnish the same at its standard published prices.
20.3 TRAINING. Seller shall provide a familiarization training program in
the use, operation, technical, and maintenance aspects of the Equipment
sufficient for personnel of Buyer or it's permitted assignee, or an
affiliate of Buyer, to use, operate, and maintain the Equipment. The
extent and timing of such familiarization training is described in
Appendix E.
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ARTICLE 21. INSURANCE
21.1 INSURANCE REQUIREMENTS. Seller shall procure and at all times prior to
completion of the obligations of Seller under this Contract shall
maintain with insurers reasonably acceptable to Buyer, the following
insurance protecting Seller against liability from damages because of
injuries, including death, suffered by persons, including employees of
Seller, and from damages to property arising from or resulting out of
Seller's negligence in performance, including its subcontractors and
suppliers, of Services. Buyer, Buyer's lender and their consultants
shall be included as an additional insured under the policies listed in
subsections (b) and (c) below, and the insurer shall waive all rights
of subrogation against Buyer, Buyer's lender and their consultants.
(a) Workers' Compensation Insurance in accordance with statutory
requirements and Employer's Liability Insurance with limits of
not less than $1,000,000 each accident.
(b) Commercial General Liability Insurance with bodily injury and
property damage limits of not less than $1,000,000 combined
single limit each occurrence/aggregate.
(c) Automobile Liability Insurance with bodily injury and property
damage limits of not less than $1,000,000 combined single limit
each accident.
21.2 ADDITIONAL REQUIREMENTS. All insurance required to be maintained by
Seller shall be primary to any insurance carried by Buyer that might
apply on the same basis. Prior to the performance of any Services,
Seller shall furnish Buyer with a certificate of insurance evidencing
the coverages set forth in Section 21.1. The certificate shall indicate
that such insurance shall not be canceled or materially changed without
at least thirty (30) days written notice to Buyer. Nothing contained in
this Article 21 shall be construed as a limitation of the liability of
Seller for damage or injury, including death, which arises out of
Seller's obligations under this Contract.
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ARTICLE 22. GENERAL CLAUSES
22.1 ASSIGNMENT.
(A) ASSIGNMENT TO PROJECT DEVELOPER OR OWNER. Buyer may assign any or
all of its rights or obligations under this Contract to an
affiliate of Buyer, provided such assignee has adequate resources
(as determined by Seller in the exercise of its reasonable
judgment) to fulfill those obligations of Buyer which are
assigned, and further provided such assignee agrees to be bound
by all of the protections and limitations afforded Seller under
this Contract and any defaults of Buyer existing at such time are
cured. Upon completion of such assignment and the delivery of an
assumption agreement (in a form reasonably satisfactory to
Seller) executed by such assignee to Seller, Buyer shall be
released from any and all obligations and liabilities therefor
under this Contract which are assumed by the assignee, provided,
however, Buyer shall not be released from those obligations, if
any, which Buyer elects to reserve from such assignment.
Notwithstanding any provision of this Contract to the contrary,
Buyer and Buyer's assignee, if applicable, shall have the
absolute right, without the consent of Seller, to assign this
Contract, or any rights reserved by Buyer after assignment,
including any licenses granted hereunder pursuant to Section 6.4,
to the Project lenders for collateral security purposes. Seller
will have the right to assign any part of its obligations under
this Contract to any of its subsidiaries or affiliates, in which
case Seller will guarantee the performance of such assignee.
(b) ASSIGNMENT TO CONTRACTOR. In addition to the rights of assignment
under Section 22.1(a), Buyer or Buyer's assignee under Section
22.1(a) may assign this Contract to a third party contractor that
has entered into an agreement with Buyer or such assignee for the
construction of the Project ("Contractor Assignee"), provided
such Contractor Assignee has adequate resources (as determined by
Seller in the exercise of its reasonable judgment) to fulfill
those duties or rights of Buyer or Buyer's assignee under Section
22.1(a) which are assigned and provided such Contractor Assignee
agrees to be bound by all of the protections and limitations
afforded Seller under this Contract and any defaults of Buyer or
Buyer's assignee under Section 22.1(a) existing at such time are
cured. Those rights which are reserved to Buyer or Buyer's
assignee under Section 22.1(a) pursuant to the terms of this
Contract and Appendix M are not assigned to such Contractor
Assignee. Upon the delivery of an assumption agreement (in a form
reasonably satisfactory to Seller) executed by such Contractor
Assignee to Seller, Buyer or Buyer's Assignee under Section
22.1(a), as the case may be, shall be released from any and all
obligations and liabilities therefor under this Contract which
are assumed by the Contractor Assignee, provided, however, Buyer
or Buyer's assignee under Section 22.1(a) is not released from
those obligations which are identified in this
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Contract and in Appendix M as obligations retained by Buyer. In
the event of the delay or cancellation of the Project after this
Contract is assigned to a Contractor Assignee, Seller consents to
the reassignment of this Contract to Buyer, or an affiliate of
Buyer to which this Contract was previously assigned in
accordance with Section 22.1(a), by such Contractor Assignee.
22.2 THIRD PARTY BENEFICIARIES. The provisions of this Contract are for the
benefit of the Parties hereto and are not for any other third party,
except as provided in Article 15 and Section 22.1.
22.3 ENTIRE AGREEMENT. This Contract represents the entire agreement between
the Parties and no modification, amendment, rescission, waiver or other
change shall be binding on either Party unless assented to in writing
by such Party's authorized representative. Any oral or written
representation or warranty not contained or referenced herein shall not
be binding on either Party. Each Party agrees that it has not relied
on, or been induced by, any representations of the other Party not
contained in this Contract or the attachments hereto. A failure or
delay of either Party to this Contract to enforce any of the provisions
hereof, or to exercise any option which is herein provided, or to
require at any time performance of any of the provisions hereof shall
in no way be construed to be a waiver of such provision. This Contract
supercedes all provisions of the Memorandum of Global Agreement, dated
July 2, 1999, entered into between Buyer and Seller, which relate to
the six (6) PG7241FA gas turbine-generator units for the Georgia
Project.
22.4 SEVERABILITY. In the event any one or more provisions of this Contract
shall for any reason be held to be invalid, illegal or unenforceable,
the remaining provisions of this Contract shall be unimpaired, and the
invalid, illegal or unenforceable provision shall be replaced by a
mutually acceptable provision, which, being valid, legal and
enforceable, reflects the intention of the Parties regarding the
invalid, illegal or unenforceable provision.
22.5 INDEPENDENT CONTRACTOR. In performing services pursuant to this
Contract, Seller is acting as an independent contractor and except as
specified in this Contract, neither Party has any authority to bind or
otherwise obligate the other Party in any manner whatsoever. Buyer
shall not be responsible for payment of workers' compensation,
disability or other similar benefits, unemployment or other similar
insurance, or for the withholding of income taxes or other taxes and
social security for any Seller employees, and such responsibility shall
be that of Seller.
22.6 GOVERNING LAW. The validity, performance and all matters relating to
the interpretation and effect of this Contract and any amendment
thereto shall be governed by the laws of the State of New York,
excluding their conflict of laws provisions.
22.7 NOTICE. All notices or other communications shall be in writing and
shall be sufficient if delivered personally, dispatched by overnight
courier service, mailed by registered or
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CONFIDENTIAL
certified mail, return receipt requested, proper postage prepaid, or
sent by facsimile machine to the following addresses:
<TABLE>
<S> <C>
If to Buyer: Tenaska Georgia I, L.P.
1044 North 115th Street
Omaha, Nebraska 68154
Attention: Michael C. Lebens
Facsimile Number: (402) 691-9530
If to Seller: Dave Stender
Project Manager
Global Power Plant Systems Department
General Electric International, Inc.
1 River Road, Bldg. 2-309, Schenectady, NY 12345
Facsimile Number: (518) 385-7326
</TABLE>
or such other address or addresses as either Party may from time to
time designate to the other by written notice. Any such notice or other
official communication shall be deemed to have been delivered as of the
date it is personally delivered, when received if placed in the mails
in the manner specified or sent by overnight courier or when sent if by
facsimile.
22.8 CONSTRUCTION. The headings and captions in this Contract are inserted
for convenient reference only and shall not limit or construe the
articles, paragraphs or sections to which they apply. Where the context
requires, all singular words in this Contract shall be construed to
include their plural and all words of neuter gender shall be construed
to include the masculine and feminine forms of such words. The terms
"include," "including" and similar terms shall be construed as if
followed by the phrase "without limitation." Notwithstanding the fact
that this Contract has been prepared by one of the Parties, all of the
Parties confirm that they and their respective counsel have reviewed,
negotiated and adopted this Contract as the joint agreement and
understanding of the Parties. Accordingly, this Contract is to be
construed as a whole and any presumption that ambiguities are to be
resolved against the primary drafting Party shall not apply. In the
event any conflict exists between provisions of this Contract and the
provisions of any Appendix or attachment to this Contract, the
provisions of the Contract, excluding the Appendices and any
attachments hereto, shall control.
22.9 NUCLEAR WAIVER. The Equipment sold hereunder is not intended for
application (and shall not be used) in connection with the use or
handling of nuclear material or the construction or operation of a
nuclear installation. Buyer warrants that it shall not use such
Equipment for such purposes, or permit others to use such Equipment for
such purposes unless such use is agreed to in writing by Seller. If, in
breach of the foregoing, any such use occurs, Seller disclaims all
liability for any nuclear or other damage, injury, or contamination,
and Buyer shall indemnify Seller against any such liability, whether
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arising as a result of breach of contract, warranty, tort (including
negligence), strict liability, indemnity, or otherwise.
22.10 DISPUTE RESOLUTION. The Parties agree to use good faith attempts to
resolve any disputes which may arise between the Parties regarding the
application or interpretation of any provision of this Contract. In
case of a dispute, the aggrieved Party shall promptly notify the other
Party of the existence of a dispute subject to resolution pursuant to
Section 22.10 of the Contract and shall describe the nature of the
dispute in reasonable detail ("Dispute Notice"). If the Parties shall
have failed to resolve the dispute within ten (10) days after delivery
of the Dispute Notice, each Party shall nominate a senior member of its
management to attempt to resolve the dispute. Should the Parties still
be unable to resolve the dispute to their mutual satisfaction within
thirty (30) days after delivery of the Dispute Notice, each Party shall
have the right to pursue any and all remedies available at law or in
equity. Pending final resolution of any dispute, the Parties shall
continue to fulfill their respective obligations hereunder.
22.11 DISCLOSURE OF INFORMATION. Seller covenants to Buyer that as of the
date of this Contract, all technical information letters issued by
Seller relative to maintenance or reliability issues with the Equipment
have been provided to Buyer and Seller has disclosed to Buyer all
material maintenance and reliability issues with the Equipment which
Seller has learned through user groups or directly from users and which
have not yet been addressed by Seller by the release of technical
information letters. From the date of this Contract until Substantial
Completion, Seller shall promptly disclose to Buyer (a) technical
information letters issued by Seller relative to maintenance or
reliability issues with the Equipment and (b) shall use it best efforts
to promptly disclose all material maintenance and reliability issues
with the Equipment which Seller learns through user groups or directly
from users and which have not yet been addressed by Seller by the
release of technical information letters. In the event that Buyer
notifies Seller that Seller has failed to provide Buyer with the
information required by this Section, Seller shall within ten (10) days
of receipt of such notice provide Buyer with copies of the relevant
technical information letters previously issued by Seller or summaries
of maintenance and reliability issues identified and shall schedule a
conference call and/or meeting between representatives of Buyer and
Seller to review the technical findings and recommendations cited in
such technical information, letters and summaries.
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IN WITNESS WHEREOF, the Parties have executed this Contract by their
duly authorized representatives as of the date first above written.
GENERAL ELECTRIC COMPANY
By: /S/
-------------------------------
Title: GM-Commercial Operations
TENASKA GEORGIA I, L.P.,
a Delaware limited partnership
By: TENASKA GEORGIA, INC.
Managing General Partner
By: /S/
-------------------------------
Title: Vice President
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INDEX TO APPENDICES
<TABLE>
<S> <C>
Appendix A Description of Equipment
Appendix B Payment\Cancellation Charge Schedule with Engineering Release Notice
Appendix C Guaranteed Performance Criteria and Test Provisions
Appendix D Options
Appendix E Training
Appendix F Not Used
Appendix G Documentation
Appendix H EPC Project Schedule
Appendix I Technical Direction of Installation and
Commissioning Assistance
Appendix J Not Used
Appendix K Site Legal Description
Appendix L Customer Witness Plan
Appendix M Rights and Obligations retained by Buyer
</TABLE>
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TurbineContract
59
<PAGE>
GE POWER SYSTEMS
1. GENERAL EQUIPMENT DESCRIPTION
--------------------------------------------------------------------------------
1.1 EQUIPMENT PROPOSAL OVERVIEW
1.1.1 DESIGN CONDITIONS
<TABLE>
<S> <C>
Nominal Net Equipment Rating (Refer to the Performance
Specifications for Equipment Performance
Requirements
Site Conditions
Site Ambient Temp./Relative Humidity 94oF/39.4%RH
(Guarantee Conditions)
Site Pressure 14.289psia
Elevation 785 feet
Location Inland
Seismic Criteria 1997 UBC, Zone 2A
Wind Design 1997 UBC; Exposure C,
Importance Factor = 1.00
Basic Wind Speed = 100 mph
Fuel
Primary Natural Gas
Backup Distillate Fuel Oil
Gas Fuel Preheating Not Included.
Liquid Fuel Preheating Not Included
Treatment Not Included
Gas Fuel Booster Compressor Not Included. Minimum required gas
pressure is 415 psig at customer
connection to gas feed module. Maximum
operating pressure is 475 psig.
<PAGE>
1.1.2 EQUIPMENT/SYSTEM DEFINITION
Gas Turbine Six (6) PG7241FA Units
Exhaust System No stack included
Starting Means Shared static (1 for 2 units)
Air Filtration Two-Stage High Efficiency
Inlet Air Cooling Evap Coolers (Effectiveness 85%)
Compressor/Turbine Cleaning Off-Line / On-Line
Compressor Water Wash Only
Combustion System DLN 2.6
Emissions Control
Natural Gas Dry Low NOx: 15 ppm
Distillate Oil Water Injection:42 ppm
Generators Six (6) Gas Turbine Units
Gas Turbine Generators
Model Six (6) 7FH2 Packaged Generators
Cooling Hydrogen
Terminal Voltage 7F H2 = 18.0 kV
Frequency 60 Hz
Power Factor (pf)
Gas Turbine 0.85 Lagging/0.95 Leading
Generator Excitation EX2000 - Static Bus Fed
Generator Seal Oil System Scavenging Design
<PAGE>
Enclosures/Location
Gas Turbine-Generator Outdoor
Cooling Systems
Gas Turbine/Generator/Auxiliaries Closed H2O to Air
Control Systems
Gas Turbine-Generators SPEEDTRONIC-TM- Mark V / Local Control
Packages
Continuous Emissions Monitoring (CEMs) Not Included
Black Start Capability Not Included
High Voltage Switchyard Not Included
Transmission System Not Included
Generator Breaker Not Included
Auxiliary Boiler Not Included
Freeze Protection Not Included
</TABLE>
TURBINECONTRACTAPPENDIXA-1
--------
-TM- A TRADEMARK OF GENERAL ELECTRIC COMPANY
<PAGE>
GE POWER SYSTEMS
2. GAS TURBINE-GENERATOR
--------------------------------------------------------------------------------
2.1 GAS TURBINE MAJOR EQUIPMENT AND SERVICES LIST
Six (6) General Electric Frame PG7241 (FA) heavy-duty,
single-shaft combustion turbine-generator units, each
comprising an air compressor, dual fuel combustion system,
power turbine, and a 60 Hz, 18.0 kV generator, all enclosed
in environmentally acceptable enclosures will be provided.
The Combustion Turbines will meet the performance emissions
and noise requirements as described in Appendix C.
This presents a listing of the gas turbine major equipment
and services which GE proposes to provide. The list is only
a quick reference to the scope of supply. Please refer to
the Table of Contents to locate more detailed descriptions
of the items listed here.
2.1.1 MAJOR EQUIPMENT
Six (6) base-mounted PG7241(FA) 60 Hz gas turbines
including:
2.1.1.1 COMBUSTION SYSTEMS
- Dry low NOx combustion system
-- With inlet heating
- Water injection for NOx control to 42 ppmvd @ 15% O2
when burning oil fuel
-- On base equipment
- Supply manifold and piping
- Spray nozzles
- Controls
-- Off base skid with water forwarding pump,
enclosure, space heater
- Compressor inlet humidity sensor
- Compressor inlet temperature thermocouple
<PAGE>
2.1.1.2 SPECIAL SYSTEMS
- Modulating IGV with position feedback control
- Exhaust frame blowers on turbine compartment roof
2.1.2 INLET SYSTEM
- Inlet system arrangement
-- Up and forward inlet system arrangement
- Inlet filtration
-- Two-stage standard pad-type media filter
-- Moisture resistant filter media (high humidity
environments)
-- Weather protection on inlet filter compartment
-- Inlet system differential pressure indicator
-- Inlet system differential pressure alarm
-- Inlet filter compartment support steel (Seismic
Zone 2A, -GREATER THAN OR EQUAL TO- 100 mph wind
speed)
- Inlet heating
-- Inlet heating control valves
-- Combined 8 ft silencer and in-duct inlet heating
module
- Inlet ducting
-- Inlet silencing to meet a guaranteed individual
turbine near field sound level guarantee of 90 dB
A. at 3 feet
-- Inlet expansion joint
-- Inlet 90 degree elbow
-- Inlet transition piece
-- Inlet ducting support steel (Seismic Zone 2A, =
100 mph wind speed)
- Inlet cooling
-- Evaporative cooler
-- 90% design effectiveness evaporative cooler
(Standard GE procurement practice)
-- 85% guaranteed effectiveness evaporative cooler
(Per Appendix C)
<PAGE>
- Inlet system hardware
-- Walkway for inlet filter compartment
-- Stairway access to inlet filter compartment house
-- Right hand access to inlet filter compartment
-- Electric hoist with 500 lb lift capacity
-- Inlet filter compartment interior lighting
- Inlet system atmospheric protection
-- Zinc rich paint inside and outside of inlet filter
compartment
-- Zinc rich painted inlet support steel
-- Zinc rich paint inside and outside of inlet
ducting with epoxy top coat inside ducting
-- Stainless steel inlet silencing perforated sheet
2.1.3 EXHAUST SYSTEM
2.1.3.1 ARRANGEMENT
- Exhaust diffuser with an axial exit
- Exhaust expansion joint
2.1.4 GAS TURBINE ACCESSORY COMPARTMENT
2.1.4.1 STARTING SYSTEMS
- LCI static start ( 1 per 2 units )
-- 6 Disconnect switches
-- Generator start with inverter/regulator
-- Static start isolation transformer
-- 12-pulse water cooled LCI
- Rotor turning systems
-- Turning gear and motor for rotor cooldown
-- Rotor indexing (borescope inspection)
<PAGE>
2.1.4.2 LUBRICATING AND HYDRAULIC SYSTEMS
- Oil reservoir
- Pumps
-- AC motor driven main lube oil pump
-- Motor driven main hydraulic pump
-- AC motor driven, auxiliary lube oil and hydraulic
pumps
-- DC motor driven, emergency lube oil pump
-- Pressure lift journal bearings
- Turbine
- Load
- Dual Combined Hydralic/Lift Oil Pump
-- Generator seal oil pump
- AC/DC auxiliary pump
- Industrial, off-base cooling water system
-- Aluminum fin material
-- Modular 100% capacity coolant-to-air heat
exchanger mounted off-base, with motor driven fans
to force air over finned tube heat exchangers. The
fan motor power is supplied from the unit motor
control center.
-- Automatic temperature controller which regulates
coolant flow to control lube oil temperature
during operation
-- Dual full-flow AC motor-driven coolant circulating
pumps (one running, one standby)
-- Make-up and expansion tank
-- Instruments for the system as follows:
- Tank low level alarm and indicator
- Panel mounted water header pressure gage,
pressure switch and temperature switch.
- Coolant header temperature gage
- Inlet and outlet thermometers
-
-- Dual lube oil system filters
<PAGE>
-- Dual hydraulic oil filters
-- Dual lube oil coolers
- Plate/frame type with stainless steel plates
-- ASME code stamp
- Lube oil coolers
- Lube oil filters
- Lube oil piping
-- 304L stainless steel lube oil feed pipe
-- Carbon steel lube oil drain pipe
-- Lube system valve stainless steel trim
-- Lube vent demister
- Compartment vent fan
2.1.4.3 FIRE PROTECTION SYSTEM
- Fire detection system
-- Turbine and accessory compartments
-- Liquid fuel and atomizing air skid
- Compartment warning signs
- FM-200 Fire Protection for the PEECC
- CO(2) supply system
-- One low pressure CO(2) tank per unit
- Hazardous atmosphere detectors in turbine and fuel gas
compartments
- Hazardous atmosphere detector readout in Mark V panels
2.1.5 FUEL SYSTEMS
- Gas fuel
-- Stainless steel gas piping
-- Orifice type gas flow measurement system
-- Gas fuel valves on accessory base
<PAGE>
-- Gas fuel temperature -LESS THAN- 400DEG.F
-- Gas fuel scrubber
- Liquid fuel
-- Stainless steel fuel oil piping
-- Single, motor driven, atomizing air compressor
-- Motor driven, 1x100% capacity, main liquid fuel
pump
-- Fuel oil flow divider
- Fuel treatment/processing
-- Duplex, low pressure fuel filters
2.1.6 WATER WASH SYSTEM
- On-base piping and nozzles for offline and online
compressor water wash system
- Off base water wash skid, 2 skids for 6 units
2.1.7 GAS TURBINE PACKAGING
2.1.7.1 ENCLOSURES AND BASES
- Lagging and enclosures
-- Turbine and accessory compartment lagging
-- Load coupling compartment lagging
-- On-base accessory compartment lagging
-- Off-base acoustic enclosure for turbine only
- Compartment ac ventilation system
-- Dual accessory compartment vent fans
-- Dual turbine compartment vent fans
-- Single vent fan for liquid fuel and atomizing air
skid
- Heated turbine and accessory compartments for humidity
control
- Plant arrangement
-- Right hand accessory module
<PAGE>
-- Unit walkways by GE
- Turbine and accessory base painting
-- Standard primer
- Seismic Zone
-- UBC zone #4 (inlet and exhaust are 2A,
-LESS THAN OR EQUAL TO- 100 mph)
- Hazardous area classification
-- NEC Class I, Group D, Division 2 (turbine and gas
compartments only)
- Special features
-- Dual (metric-English) indicators and gauges
2.1.7.2 COUPLINGS
- Rigid load coupling
- Load coupling guard
2.1.8 GENERATOR
2.1.8.1 GENERAL INFORMATION
- Hydrogen cooled generator with conventionally cooled
armature
- Short circuit ratio = .58
- Outdoor installation
- Class F armature and rotor insulation
- Class B temperature rise, armature and rotor winding
- Capability to 0.85 power factor (leading)
- 60 Hz generator frequency
- Generator voltage 18.0 kV
- Generator bearings
-- End shield bearing support
-- Elliptical journal bearings
<PAGE>
-- Roll out bearing capability without removing rotor
-- Insulated collector end bearing
-- Online bearing insulation check
-- Offline bearing insulation check with isolated
rotor
- Monitoring Devices and sensors
-- Bently Nevada Series 3300
- Generator Field
-- Direct cooled field
-- Two-pole field
-- Finger type amortissuers
-- Full amortissuers
2.1.8.2 GENERATOR GAS COOLERS
- Coolers shipped installed
- Generator gas cooler configuration
-- Five (5) horizontally mounted simplex coolers
-- Coolers located in generator base
-- Cooler piping connections on left side as viewed
from collector end
-- ASME code stamp
-- Single wall cooler tubes
-- Victaulic cooler couplings
-- Plate fins
-- Cooling water manifold and isolation valves
- Generator gas cooling system characteristics
-- Coolant temperature 117DEG.F at 100DEG.F ambient
day
-- Generator capacity with one section out of service
80% with class "F" rise
-- Maximum cooler pressure capability - 125 psi
-- Coolant 66% water, 33% glycol
-- Fouling factor 0.0005
- Generator gas cooler construction materials
<PAGE>
-- 90-10 copper-nickel tubes
-- Carbon steel tube sheets
-- Carbon steel waterbox and coupling flanges with
epoxy coating
-- Aluminum cooler tube fins
2.1.8.3 GENERATOR LUBE OIL SYSTEMS AND EQUIPMENT
- Bearing lube oil system
-- Generator lube oil system integral with turbine
- Bearing lift oil system
-- Stainless steel lift oil piping and tubing
-- Lift oil supplied from turbine oil system
- Lube oil system piping materials
-- Stainless steel lube oil feed pipe
-- Carbon steel lube oil drain pipe
-- Welded oil piping
-- Flexible pipe as permitted by ANSI B31.3
2.1.8.4 GENERATOR GROUNDING EQUIPMENT
- Neutral grounding equipment
-- Neutral ground transformer and secondary resistor
-- Mounted in terminal enclosure
2.1.8.5 GENERATOR TEMPERATURE DEVICES
- Stator winding temperature devices
-- 100 ohm platinum RTDs (Resistance temperature
detector)
-- Single element RTDs
-- Grounded RTDs
-- Nine (9) stator slot RTDs
- Gas path temperature devices
-- 100 ohm platinum gas path RTDs
-- Single element RTDs
<PAGE>
- Bearing temperature devices
-- Chromel alumel (type K) thermocouples
-- Dual element temperature sensors
-- Two (2) bearing metal temperature sensors per
bearing
- Collector temperature devices
-- 100 ohm platinum RTDs
-- Single element temperature sensors
-- Collector air inlet temperature sensor
-- Collector air outlet temperature sensor
- Lube oil system temperature devices
-- Chromel alumel (type K) thermocouples
-- Dual element bearing temperature sensors per
bearing
-- One (1) bearing drain temperature sensor per drain
2.1.8.6 PACKAGING, ENCLOSURES, AND COMPARTMENTS
- Paint and preservation
-- Standard primer
- Line-side terminal enclosure
-- Terminal enclosure shipped separate
-- High voltage bushings shipped installed
-- Top mounted
-- Non-segregated phase internal bus
-- Phase sequence R-C-L when looking at enclosure
terminals
-- Outgoing power connection on left side when viewed
from collector end
-- Isolated phase bus duct connection
-- Lightning arrestors
-- Pull out PTs
- Neutral terminal enclosure
-- Top mounted
-- Integral with line side terminal enclosure
<PAGE>
-- Neutral tie
- Collector compartment
-- Collector compartment shipped separate
-- Outdoor
- Load coupling compartment
-- Dual load compartment vent fans
- Foundation hardware
-- Generator shims
-- Generator alignment key(s) - collector end
-- Generator alignment key(s) - turbine end
-- Generator alignment key(s) - axial
-- Jacking provisions
- Generator enclosure suitable for outdoor installation
2.1.8.7 HYDROGEN SYSTEMS AND ACCESSORIES
- Hydrogen control assembly
-- NEMA 1 assembly in collector compartment
- Hydrogen cooled generator gas manifolds
-- Hydrogen bottle manifold
-- CO2 bottle manifold
-- Auto purge gas purge control manifold
-- Hydrogen control manifold
- Seal oil system
-- Control unit mounted in collector compartment
-- Stainless steel seal oil feed pipe
-- Carbon steel seal oil drain pipe
2.1.8.8 ELECTRICAL EQUIPMENT
- Motors
-- TEFC motors
<PAGE>
-- Coated with antifungal material for protection in
tropical areas
- Six (6) ambient air cooled, high voltage bushings
- Heaters
-- Generator stator heaters
-- Generator collector heaters
- Compartment lighting and outlets
-- AC lighting
- Collector compartment
- Current transformers
-- Relaying class C400
-- Neutral CTs
- CT1, CT2, CT3 (metering CT's)
- CT4, CT5, CT6 (separate relaying CT's)
- CT7, CT8, CT9 (relaying)
- CT10, CT11, CT12 (generator differential) -
C800
-- Line CTs
- CT16, CT17, CT18 (relaying)
- CT19A, CT19C (Excitation CTs)
- CT21, CT22, CT23 (generator protection)
2.1.8.9 GENERATOR EXCITATION SYSTEMS, STATIC COMPONENTS
- Busfed static, with hot backup
2.1.8.9.1 EXCITATION MODULE FEATURES
- Control/monitor/display through TCP
-- Voltage matching
-- VAR/PF Controller
-- Selection of automatic or manual regulator
-- Raise-lower of the active regulator setpoint
<PAGE>
-- Enter setpoint command
-- Display field amps
-- Display field volts
-- Display transfer volts
-- Display field temperature
- Built-in diagnostic display panel
-- Automatic voltage regulator (AVR)
-- Manual voltage regulator (FVR)
-- Automatic and manual bi-directional tracking
-- Reactive current compensation (RCC)
-- Volts per hertz limiter (V/Hz LIM)
-- Over excitation limiter (OEL)
-- Under excitation limiter (UEL)
-- Generator field ground detector (64F)
-- VT failure detector (PTFD) (60EX)
- Dual source internal bulk power supply
- Millivolt shunt for field
- Surge protection
-- VT disconnect and CT shorting switches
-- Two phase current sensing (CT,s A,C)
-- Three phase voltage sensing
-- Single pole dc field contactor
- Thyristor bridge circuit filtering
- Shaft voltage suppresser circuit (mounted in panel)
-- Field de-excitation circuit (with field discharge
inductor)
-- 125 Vdc field flashing circuit (when required)
-- Bridge disconnect; ac no load
- Protection Module
-- Volts/hertz protection (24EX)
<PAGE>
-- Generator overvoltage protection (59EX)
-- Off/on-line overexcitation protection (76EX)
-- Loss of excitation (40EX)
-- Bridge ac phase unbalance (47EX)
- Power system stabilizer
2.1.8.9.2 PERFORMANCE
- 2.0 response ratio and 160% VFFL (100DEG.C) ceiling @
Vt = 1.0pu
2.1.8.9.3 ENCLOSURE LOCATION
- Installed in LCI compartment or GEC
2.1.8.9.4 ENCLOSURE CONSTRUCTION
- NEMA-I enclosure
- Standard paint ANSI-70 light gray, interior and
exterior
2.1.9 CONTROLS AND ELECTRICAL AUXILIARIES
2.1.9.1 CONTROL CAB/PACKAGED ELECTRIC AND ELECTRONIC CONTROL
COMPARTMENT (PEECC)
- Access doors
- Air conditioning and heating
- Control panels mounted on a common skid
- Lighting and power outlets
- FM200 fire protection system (including supply of
FM200)
2.1.9.2 MARK V SPEEDTRONIC-TM- TURBINE CONTROL PANEL FEATURES
- Triple modular redundant (TMR)
- Auto/manual synchronizing module with synchronizing
check function
-----------------
-TM- A Trademark of General Electric Company
<PAGE>
- Generator stator over-temperature alarm (49)
- Droop control
- Load limiter
- Customer alarm/trip contact for CRT display
- Additional customer input contacts
- Additional customer output contacts
- Provision for 8 selectable analog inputs from customer
- Provision for 8 selectable analog output to customer
- Wet low NOx data for EPA compliance
- Vibration alarm readout and trip
- Electrical overspeed protection
- Constant settable droop
- Power factor calculation and display
- Manual set point preselected load
2.1.9.3 GENERATOR CONTROL PANEL
2.1.9.3.1 GENERATOR CONTROL PANEL LOCATION
- PEECC
2.1.9.3.2 GENERATOR CONTROL PANEL FEATURES
2.1.9.3.2.1 GENERATOR BREAKER TRIP SWITCH (52G/CS) WITH RED AND GREEN
INDICATOR LIGHTS
2.1.9.3.2.2 DIGITAL GENERATOR PROTECTION SYSTEM (DGP) MODEL NO. DGP54
AACA
- Generator differential (87G)
- Current unbalance (46)
- Loss of excitation (40)
<PAGE>
- Reverse power (32)
- Stator ground detection (64G)/(59GN)
- Overexcitation (24)
- Overvoltage (59)
- Over frequency (81O)
- Under frequency (81U)
- System phase fault relay (51V)
- Generator differential lockout relay (86G-1)
-- One circuit coil monitor (74) in each 86 lockout
- Voltage transformer fuse failure (VTFF)
2.1.9.3.3 GENERATOR CONTROL PANEL DISCRETE RELAYS
- Synchronizing Undervoltage relay (27BS-1,2)
- DC tripping bus, blown fuse protection (74)
- Voltage balance relay (60)
- Distance relay (21)
- Breaker or lockout trip coil monitor (74)
- Reverse/Inadvertent energization protection (50RE/86RE)
- Bus Ground detection relay (59BN)-3 PT's & resist
2.1.9.3.4 GENERATOR CONTROL PANEL INSTRUMENTATION
- Generator digital multimeter
-- VM - Generator Volts:
-- AM - Generator Amps: Phase 1,2,3 and Neutral
-- MWATTS - Generator MegaWatts
-- MVAR - Generator MegaVArs
-- FM - Generator frequency
<PAGE>
-- MVA - Generator MVA
-- PF - Generator Power Factor
-- MWH - Generator MegaWatt-Hours
-- MWVAH - Generator MVA Hours
-- Generator transducers (watts, watt/var)
2.1.9.3.5 INTEGRATED INTO MARK V
- Mark V with speed matching, synch & check
- Manual sync displayed on Mark V [I]
- Load control in Mark V
- Temp indication-for generator RTD's
- Auto/manual synchronizing module displayed on
Mark V [I]
2.1.9.4 GENERATOR PROTECTION
- Generator electrical protection equipment
-- Ground brush rigging
2.1.9.5 LOCAL OPERATOR MULTIUNIT INTERFACE [I]
- Table top 15 in. color monitor
- Trackball cursor control
- Table top AT 101 spillproof keyboard
- 24 pin dot matrix printer
- 50 ft of Arcnet cable between Mark V panel and local
operator interface [I] for indoor use
- Display in English language
2.1.9.6 REMOTE CONTROL AND MONITORING SYSTEMS
- GSM-TCP/IP Ethernet via [I/G]
<PAGE>
2.1.9.7 BATTERIES AND ACCESSORIES
- Lead acid battery
- Single phase battery charger
- Battery and charger mounted in the PEECC
2.1.9.8 MOTOR CONTROL CENTER
- MCC mounted in control cab/PEECC
- Tin-plated copper bus-work
- 42 kA bracing
- 480V 60 Hz auxiliary power
2.1.9.9 MOTOR FEATURES
- Service factor on all motors 1.15
- Coated with antifungal material for protection in
tropical areas
- TEFC motors -LESS THAN- 200 hp
- Extra severe duty motors
- Cast iron motor housings o All redundant motors to be
lead/lag
- Motor heaters
- WP motors -GREATER THAN- 200 hp
2.1.9.10 ROTOR, BEARING AND PERFORMANCE MONITORING SYSTEMS
- Performance monitoring systems (RTD for compressor
inlet temperature)
-- Sensors wired to Mark V
- Vibration sensors
-- Seismic Velocity vibration sensors, Two per each
bearing for protection
<PAGE>
-- Bently Nevada proximity probes and proximeters.
Two probes on each bearing for readout
- Boroscope access holes
- Thermocouples for measuring critical turbine
temperatures including bearing metal and drains
- Redundant sensors for critical functions with
applicable third party certification on devices
2.1.10 POWER SYSTEM STUDIES
- Provided by owner
2.1.11 SERVICES
- Coordinate drafting, manufacturing and shipping
schedules to meet contractual requirements
- Containerize shipments of miscellaneous parts
- Technical advisory services
- Transportation to nearest rail siding
-- Heard County, Georgia
- Truck shipments to site (MSD)
- Provide design drawings and final drawings
- Documentation
-- Up to 10 sets of English language service manuals
per station, including Operation, Maintenance and
Parts volumes
- Turbine maintenance tools
-- Guide pins (for removal or replacement of bearing
caps, compressor casing and exhaust frame)
-- Fuel nozzle wrenches
-- Fuel nozzle test fixture
-- Spark plug electrode tool
<PAGE>
-- Clearance tools
-- Fuel nozzle staking tool
-- Combustion liner tool
-- Bearing and coupling disassembly fixture
- Generator maintenance tools
-- Rotor lifting slings
-- Rotor removal equipment including shoes, pans,
pulling devices
-- Rotor jacking bolts
- Installation Equipment
-- Trunions for generator
- On loan basis only
-- Jacking bolts for generator
--------------------------------------------------------------------------------
2.2 GAS TURBINE MECHANICAL DESCRIPTION
The gas turbine output flange is located at the compressor
end of the rotor assembly to provide "cold end" drive. This
feature substantially improves alignment control and
provides an axial exhaust to optimize the plant arrangement
for combined cycle or waste heat recovery applications. The
generator is connected to the gas turbine through a solid
coupling. The direction of rotation is counter-clockwise
when facing the direction of airflow through the gas
turbine.
<PAGE>
[GRAPHIC OMITTED]
The gas turbine has an eighteen stage axial flow compressor
with modulated inlet guide vanes. Interstage extraction is
used for turbine nozzle and wheelspace cooling.
A reverse flow, fourteen chamber combustion system is
utilized with multiple fuel nozzles per chamber. Redundant
spark plugs and flame detectors are a standard part of the
combustion system with crossfire tubes connecting each
combustion chamber to adjacent chambers. If required, water
injection can be introduced for NOx emissions control.
Transition pieces are effectively cooled by air impingement.
Thermal barrier coatings are applied to the inner walls of
the combustion liners for smoother temperature gradients.
The gas turbine has three turbine stages with the first and
second stage nozzles and buckets being air cooled. The
buckets are designed with long shanks to isolate the turbine
wheel rim from the hot gas path. Precision cast buckets are
used for each turbine stage with the second and third stages
incorporating an integral tip shroud for better gas path
leakage control. All turbine buckets are
<PAGE>
coated to provide corrosion resistance. The turbine section
is coupled to an axial diffuser with optimum pressure
recovery for higher thermal efficiency.
The rotor is a two bearing single shaft design with high
torque capability. It incorporates internal cooling and
thermal response control in the turbine section. Both the
compressor and turbine sections are constructed of
individually rabbeted discs held with through bolts. For
field changeout, the unit rotor is handled as one piece.
The turbine and compressor casings are horizontally split
for ease of inspection and maintenance. For each combustion
chamber, the liners and transition pieces can be
individually changed out. Borescope holes are located in the
compressor, combustion and turbine sections to facilitate
visual inspection.
2.2.1 COMPRESSOR CLEANING
2.2.1.1 ON-LINE/OFF-LINE COMPRESSOR WATER WASH
Compressor water washing is used to remove fouling deposits
and to restore performance. Fouled compressors result in
reduced air flow, lower compressor efficiency, and lower
compressor pressure ratio. Compressor cleaning may also slow
the progress of corrosion, thereby increasing blade life and
reducing the contribution of corrosion products to the
formation of fouling deposits. On-line cleaning is the
process of injecting cleaning solution into the compressor
while running at full speed and some percentage of load.
Off-line cleaning is the process of injecting cleaning
solution into the compressor while it is being turned at
cranking speed. The advantage of on-line cleaning is that
washing can be done without having to shut down the machine.
On-line washing, however is not as effective as off-line
washing: therefore on-line washing is used to supplement
off-line washing, not replace it.
The on-base compressor washing feature consists of piping,
nozzles, solenoid valves and software in the turbine control
panel. A compressor water wash can be initiated while the
turbine is either on-line or off-line.
The off-base detergent pumping skid consists of detergent
storage tank, mixing venturi, forwarding pump, enclosure and
freeze protection. One skid is provided for the site
(approximate plan dimensions of 9' x 8').
<PAGE>
2.2.1.1.1 ON-LINE MANIFOLD AND NOZZLES
The on-line washing components consist of two piping
manifolds, and spray nozzles (one in the forward bellmouth
and one in the aft bellmouth) and a motor-operated valve
which is also controlled by the turbine control panel. The
turbine control system is equipped with software to perform
an automatic on-line wash by simply initiating the wash from
the turbine control panel.
2.2.1.1.2 OFF-LINE MANIFOLD AND NOZZLES
The off-line washing components consist of a piping
manifold, and spray nozzles in the forward bellmouth, and a
motor-operated valve controlled by the turbine control
panel. Off-line washing is a manual operation because of the
large number of manual valves on the turbine which need to
be manipulated in order to perform an off-line wash.
[GRAPHIC OMITTED]
2.2.1.2 COMBUSTION
A reverse flow, multi chamber (can annular) combustion
system is utilized. Combustion chambers are arranged around
the periphery of the compressor discharge casing. This
system also includes the fuel nozzles, spark plug ignition
system, flame detectors, and crossfire tubes.
Crossfire tubes connect each combustion chamber to adjacent
chambers on both sides. Transition pieces connect the
combustion liners to the turbine nozzles Each liner, fuel
nozzle, and transition piece can be individually replaced.
<PAGE>
[GRAPHIC OMITTED]
2.2.1.2.1 COMBUSTION CHAMBERS
The combustion liners are cylindrical. Discharge air from
the axial-flow compressor flows forward along the outside of
the combustion liner, as guided by the flow sleeve. Liner
cooling is achieved via film cooling with annular slots
distributed along the length of the combustion liner.
Backside only cooling is utilized on some DLN combustors.
Thermal barrier coatings are applied to the inner walls of
the combustion liners for longer inspection intervals.
Air enters the combustor through a variety of holes in the
liner. The air, depending on its injection location is
utilized in the actual combustion process, for cooling, or
as dilution to tailor the exhaust gas profile.
2.2.1.2.2 TRANSITION PIECES
Transition pieces direct the hot gases from the liners to
the turbine nozzles. The transition pieces have a circular
inlet for the combustion liners transitioning to an annular
segment at the exit for the turbine nozzle. Seals are
utilized at both connection locations to control leakage
flows.
2.2.1.2.3 SPARK PLUGS
Combustion is initiated by discharge from two electrode
spark plugs each in a different combustion chamber. At the
time of firing, a spark at one or both of these plugs
ignites a chamber.
<PAGE>
No LP gas torch ignitor system is required with this design.
2.2.1.2.4 CROSSFIRE TUBES
The combustion chambers are interconnected by means of
crossfire tubes. These tubes enable flame from the fired
chambers containing spark plugs to propagate to the unfired
chambers.
2.2.1.2.5 ULTRAVIOLET FLAME DETECTORS
The control system continuously monitors for presence or
absence of flame. Cooled flame detectors are installed in
several combustors. The detector consists of a small gas
filled tube with two closely spread electrodes. An
electronic package containing a power supply applies a high
DC voltage across the electrodes. When ultraviolet (UV)
radiation is present, it causes a discharge within the tube,
which results in a current pulse and discharge of the power
supply.
The power supply recharges and the discharge process
continues to repeat as long as the UV radiation is present.
The presence of flame is determined by the electronic
package which measures the pulse frequency, and relays the
flame condition to the gas turbine control system. The
"FAILURE TO FIRE" or "LOSS OF FLAME" is indicated on the
control panel.
2.2.1.2.6 DRY LOW NOx COMBUSTION SYSTEM
The Dry Low NOx (DLN) combustor is a single stage multi-mode
combustor capable of operation with either gaseous or liquid
fuel. The burning zone is formed by the combustion liner and
the face of the cap. The majority of the combustion air is
introduced through annular passages (premix chambers)
surrounding each of the six fuel nozzles.
<PAGE>
[GRAPHIC OMITTED]
The DLN 2.6 fuel system operation is fully automated,
sequencing the combustion system through a number of staging
modes prior to reaching full load. The primary controlling
parameter for fuel staging is the calculated combustion
reference temperature. Other DLN 2.6 operation influencing
parameters available to the operator are inlet guide vane
(IGV) temperature control "ON" or "OFF" and inlet bleed heat
"ON" or "OFF". To achieve maximum exhaust temperature, as
well as an expanded load range for optimal emissions, both
IGV temperature control and inlet bleed heat should be
selected "ON".
<PAGE>
[GRAPHIC OMITTED]
Liquid fuel injection is injected at the tip of the fuel
nozzle only. Operation is thus in diffusion mode, with
emissions comparable to a standard GE multi-nozzle
combustor. A water injection passage is integral to the fuel
nozzle and is used for NOx abatement while operating on
liquid fuel.
2.2.1.2.7 CONTINUOUS DYNAMICS MONITORING SYSTEM
A continuous dynamics monitoring system will be provided for
tuning the combustion system on a rental basis, and will be
returned after unit commissioning. The system shall consist
of the following (optional):
o Probes
o Multiplex junction box
o NT computer
<PAGE>
2.2.2 ACCESSORY MODULE
2.2.2.1 LUBRICATION AND HYDRAULIC CONTROL OIL SYSTEM
The lubricating provisions for the turbine and
generator are incorporated in a common system
located on the accessory module.
[GRAPHIC OMITTED]
The module is vented to atmosphere and includes the
following equipment:
o Lubricating oil reservoir with the following devices:
-- Redundant full flow AC motor-driven lubricating oil
pumps
-- AC/DC auxiliary generator seal oil pump
-- Partial flow DC motor-driven emergency lubricating oil
pump
-- Redundant full flow AC motor-driven hydraulic oil pumps
-- (Stainless steel) dual plate frame oil-to-coolant heat
exchanger with transfer valve
<PAGE>
-- Dual lube oil system filters
-- Pressure lift bearings for the
- Turbine
- Load
-- Dual filters and transfer valve for hydraulic oil
systems
The mist eliminator is an air-exhaust filtration unit used
to remove lube oil-mist particles which are entrained in the
lubricating system vent lines by the sealing air returns of
the gas turbine lubricating system. The mist eliminator
assembly consists of a holding tank with filter elements,
motor-driven blower, and check-relief valve. One assembly is
provided for the vent line from the lube oil reservoir and
one is provided in the exciter end of the generator for the
generator bearings. Collected oil drains back to the lube
oil reservoir.
-- Temperature indicating gauge for bearing header
temperature
-- Thermocouples in turbine and generator bearing drains
-- Bearing metal thermocouples
-- Permissive-start temperature switch
-- Bearing header high temperature alarm and shutdown
switches
-- Bearing header low pressure alarm and trip switches
-- Oil filter delta pressure alarm switches
-- Lubricating oil pump stop and start switches
-- Tank mounted level indicator, with low and high level
alarm switch
-- Lube oil heater for -20F
-- Panel mounted bearing header pressure gauge
-- Panel mounted main, auxiliary, emergency and seal oil
pump discharge pressure gauges
-- Panel mounted lubrication and hydraulic oil filter
differential pressure gauges
2.2.3 DUAL FUEL SYSTEM
2.2.3.1 FUEL TRANSFER
Fuel is to be in accordance with GE fuel specifications as
indicated in the Reference Specification section of the
proposal.
<PAGE>
The gas turbine may be started on either fuel, and transfers
from one fuel to the other may be initiated by the operator
prior to start up or at any time after completion of the
starting sequence. Since gas is usually the primary fuel,
with distillate as a backup, transfers from gas to
distillate can be automatically initiated on low gas supply
pressure, provided that liquid fuel is available, and that
there is adequate time to start the fuel forwarding pump.
Transfer back to the primary fuel is by operator initiation
only, in order to ensure the integrity of the supply and
prevent oscillatory operation if the gas supply pressure is
marginal at the transfer initiation pressure. If liquid fuel
is the primary fuel, this automatic sequence can be switched
to accommodate this.
A typical gas/distillate transfer is illustrated below. The
energy equivalent of the fuel flow as the function of fuel
command is matched between the two fuels, so that equal gas
and liquid commands will result in equal energy release in
the gas turbine combustors. The fuel signal divider then
splits the signal to each fuel system in a manner that
maintains the sum of the two signals equal to the total
required fuel demand.
[GRAPHIC OMITTED]
The transfer sequence is divided into two parts, a line
filling period and the actual transfer. During the first
period, the incoming fuel command is raised to
<PAGE>
a level that will allow filling of the system in about
thirty seconds, and the outgoing fuel command is lowered by
an equivalent amount. After fuel has reached the fuel
nozzles, the incoming fuel is ramped up to equal the total
fuel demand, and the outgoing fuel is ramped down to zero.
Since total energy to the gas turbine is held reasonably
constant, load variations for a properly matched and tuned
system are minimal, and generally are less than five percent
of nameplate rating.
The next step in the process involves initiation of the
inactive fuel system purge, if purging is required, and
automatic verification of proper operation. Since purging
results in additional, although limited, fuel being injected
into the turbine to clear the inactive fuel system, there is
potential for a load disturbance at this time if the purge
is initiated too abruptly. Once the system is cleared, the
potential for a load spike disappears. Purge system
sequencing is designed to minimize this effect, and in the
case of liquid fuel nozzle purging, is initiated during the
transfer. This results in random opening of purge check
valves, which has been shown to substantially reduce the
load spikes. The final step in the transfer process is
resetting the NOx control system to meet the needs of the
new fuel.
2.2.3.2 NATURAL GAS FUEL SYSTEM
[GRAPHIC OMITTED]
<PAGE>
2.2.3.2.1 RESERVED
2.2.3.3 LIQUID FUEL SYSTEM
[GRAPHIC OMITTED]
The liquid fuel equipment located on the liquid
fuel/atomizing air module consists of:
o Single 5 micron low pressure fuel oil filter, ahead of
fuel pump
o Fuel oil filter differential pressure gages
o One 100% capacity AC motor driven fuel pump
o Electro-hydraulically controlled bypass valve
o Fuel oil stop valve
o Fuel flow divider
o Fuel oil pressure gauges-- after low pressure filter and
before flow divider
<PAGE>
o On-base piping and manifold
o Off base skid - forwarding pump, enclosure and space
heater
o Water quality per GEK101944
2.2.3.4 ATOMIZING AIR SYSTEM
The motor-driven atomizing air equipment located on the
liquid fuel/atomizing air module provides high-pressure air
to atomize the liquid fuel for combustion, to purge the
liquid fuel combustor nozzle passages, and to provide the
purge control valve operating air. The equipment consists
of:
o Single air to water U-tube heat exchanger for cooling
cycle air for entry to the atomizing air compressor and
purge compressor
o Full flow one micron filter
o Throttling valve to reduce atomizing air compressor outlet
pressure for purging
o Motor driven atomizing air compressor
o Gauge/switch panel
o Module enclosure
o Piping; flexible fuel nozzle pigtails
2.2.3.5 WATER INJECTION SYSTEM FOR NOX REDUCTION (DISTILLATE FUEL)
o On-base manifold and supply piping
o Off-base water injection skid
Water forwarding pumps, AC motor driven
2.2.4 PACKAGE ENCLOSURES
Gas turbine enclosures consist of several connected sections
forming an all weather protective housing. Enclosures
provide thermal insulation, acoustical attenuation and fire
extinguishing media containment. The enclosures allow access
to equipment for routine inspections and maintenance.
Enclosures are also heated, cooled and lighted, as described
below, for convenience and optimum performance of installed
equipment.
<PAGE>
2.2.4.1 HEATING AND VENTILATION SYSTEM
The following heaters are provided to maintain start-up
temperatures and humidity protection during shutdown and
standby periods at ambient temperatures down to
-20DEG.F(-28.9DEG.C):
o Electric (ac) heaters in the generator, generator
termination, and generator auxiliary compartments for
humidity control
o Electric (ac) heaters in the control compartment to
50 DEG. F minimum
o Electric (ac) heaters in the turbine, accessory, and
liquid fuel/atomizing air compartments for humidity control
Ventilation of compartments during operation is provided for
as follows:
o Control compartment (by wall-mounted air conditioner)
90 DEG. F maximum
o Dual AC accessory compartment vent fans 150 DEG. F
maximum
o Dual AC turbine compartment vent fans 350 DEG. F maximum
o Single vent fan liquid fuel/atomizing air skid
150 DEG. F maximum
2.2.4.2 FIRE PROTECTION SYSTEM
Fixed temperature sensing fire detectors are provided in the
gas turbine and liquid fuel/atomizing air compartments and
#2 bearing tunnel. The detectors provide signals to actuate
the low pressure carbon dioxide (CO(SUB2)) automatic
multi-zone fire protection system. Nozzles in the protected
zones direct the CO(SUB2) to the compartments at a
concentration sufficient for extinguishing flame. This
concentration is maintained by gradual addition of CO(SUB2)
for an extended period. Wiring to the detectors will be
single conductor with high temperature insulation.
The fire protection system is capable of achieving a
non-combustible atmosphere in less than one minute, which
meets the requirements of the United States National Fire
Protection Association (NFPA) #12.
The supply system is composed of a low pressure CO2 tank,
mounted off-base, a manifold and a release mechanism.
Initiation of the system will trip the unit, provide an
alarm on the annunciator, turn-off ventilation fans and
close ventilation openings.
<PAGE>
2.2.4.3 LIGHTING
AC lighting on an automatic circuit is provided in the
turbine compartment, accessory compartment and control
compartment. When ac power is not available, a dc
battery-operated circuit supplies a lower level of light
automatically.
2.2.4.4 WALKWAYS
Unit walkways, platforms and stairway access by GE.
2.2.5 INLET SYSTEM
2.2.5.1 GENERAL
Gas turbine performance and reliability are a function of
the quality and cleanliness of the inlet air entering the
turbine. Therefore, for most efficient operation, it is
necessary to treat the ambient air entering the turbine and
filter out contaminants. It is the function of the air inlet
system with its specially designed equipment and ducting to
modify the quality of the air under various temperature,
humidity, and contamination situations and make it more
suitable for use. The inlet system consists of the equipment
and materials defined in the Scope of Supply chapter of this
proposal. The following paragraphs provide a brief
description of the major components of the inlet system.
2.2.5.2 INLET FILTRATION
2.2.5.2.1 INLET FILTER COMPARTMENT
The inlet filter compartment sits on a steel support
structure upstream of the gas turbine. The elevated
arrangement provides a compact system and minimizes pickup
of dust concentration near the ground.
The two stage inlet filter is comprised of a prefilter and a
high-efficiency filter. The media-type prefilters provide an
inexpensive, disposable stage of filtration. The prefilters
usually extend the life of high-efficiency filters by a
factor of about three.
The high-efficiency filters use filter medium appropriate
for the site environmental conditions to achieve good
collection efficiency for all particles, including those as
small as 1 micron. Because the collection
<PAGE>
efficiency is very high, the air quality downstream is also
high, even when the ambient air is badly contaminated.
The filter elements are contained within a fabricated steel
enclosure which has been specially designed for proper air
flow management and weather protection.
As the outside of the filter elements become laden with
dust, increasing differential pressure is sensed by a
pressure switch in the plenum.
2.2.5.2.2 EVAPORATIVE COOLER
The evaporative cooler is used in applications where
significant operation occurs in the hot months and where low
relative humidities are common. With evaporative cooling,
water is added to the inlet air and, as the water
evaporates, the air is cooled. The amount of water required
for evaporative cooling depends upon the airflow through the
turbine, the temperature and humidity of the ambient air and
the amount of hardness in the water. The exact increase in
power available from the gas turbine is dependent upon the
same site conditions.
The cooler consists of a water distribution system and media
packed blocks made of corrugated layers of fibrous material.
Water is distributed over the blocks through one set of
channels and the air passes over alternate channels. The air
side is wetted by the wicking action of the media. This
system minimizes water carryover.
Water is to be provided per GEK 101944, "Requirements for
Water/Steam Purity in Gas Turbines."
2.2.5.3 INLET SYSTEM INSTRUMENTATION
2.2.5.3.1 INLET SYSTEM DIFFERENTIAL PRESSURE INDICATOR
Standard pressure drop indicator (gauge) displays the
pressure differential across the inlet filters in inches of
water.
2.2.5.3.2 INLET SYSTEM DIFFERENTIAL PRESSURE ALARM
When the pressure differential across the inlet filters
reaches a preset value , an alarm is initiated. This alarm
may signify a need to change the filter elements.
<PAGE>
2.2.5.4 INLET DUCTING AND SILENCING
2.2.5.4.1 INLET DUCTING
The inlet ductwork system connects the inlet filter
compartment with the gas turbine compressor inlet plenum.
The ducting is designed to deliver the required air flow to
the compressor while minimizing the pressure drop of the
incoming air stream. There is a stationary trash screen
within the ducting system to prevent the remote possibility
of ingestion of foreign objects. The trash screen can be
accessed for cleaning and inspection through a removable
access panel. The inlet ducting makes use of materials and
coatings in their construction which are designed to
minimize maintenance requirements.
2.2.5.4.2 INLET SILENCING
The noise generated during gas turbine operation is
attenuated by means of absorptive silencing material and
devices built into the inlet system which dissipate or
reduce the acoustical energy to an expected level of 58 dBA
at normal operation and 65 dBA during filter cleaning at 400
feet. The silencer is specifically designed to eliminate the
fundamental compressor tone, and to attenuate the noise at
other frequencies also. The inlet silencer consists of an
acoustically lined duct containing 8 feet of silencing
baffles constructed of a low-density insulating material
which is encapsulated by perforated sheet steel. The
acoustic lining in the walls of the silencer duct and the
walls of the ducting downstream of the silencer have a
similar construction.
2.2.5.4.3 INLET SYSTEM ANTI-ICING PROTECTION
This system features an inlet bleed heat injection manifold
integrated with the inlet silencer.
2.2.6 EXHAUST SYSTEM
The exhaust system arrangement includes the exhaust
diffuser. After exiting the last turbine stage, the exhaust
gases enter the exhaust diffuser section in which a portion
of the dynamic pressure is recovered as the gas expands. The
gas then flows axially into the exhaust system which is not
in GE's scope of supply.
GE is providing an inconel flex-joint expansion joint at the
outlet flange of the exhaust frame which is designed to
interface with internally insulated exhaust diffuser.
<PAGE>
2.2.7 ACOUSTICS
Measuring procedures will be in accordance with ASME PTC 36
(near field) and/or ANSI B133.8 (far field).
2.2.8 PAINTING
The exteriors of the turbine compartment, accessory and
liquid fuel/atomizing air modules, generator compartment,
control cab (if supplied), BAC/LCI and accessory base and
other equipment are painted with two coats of alkyd primer
prior to shipment.
The turbine compartment interior is painted with
high-temperature paint. Interiors of all other compartments
are painted.
2.2.9 WIRING
The gas turbine electrical interconnection system includes
on-base wiring, terminal boards, junction boxes, etc. as
well as compartment interconnecting cables. Junction boxes
are selected to meet the environmental requirement of the
Purchaser but are, in general, of steel or cast aluminum
construction. Special environments such as corrosive or
hazardous can be accommodated. Terminal boards within
junction boxes are of the heavy duty industrial type
selected for the particular environment in which the
junction box is located. On-base gas turbine wire
termination uses spring tongue crimped type terminals.
Generator wire terminations are ring type. Control panel
wiring is General Electric type SIS Vulkene insulated
switchboard wire, AWG #14-41 Strand SI-57275. Ribbon cables
are used as appropriate.
With the exception of cables pre-connected with specific
equipment, the Purchaser or his Installer is responsible for
interconnecting cable purchase, installation, and
connection. GE will supply appropriate connection diagrams
and recommended cable installation procedures for the
turbine and GE furnished off-base equipment. On-base gas
turbine wire installation and termination is performed in
the factory.
2.2.10 MISCELLANEOUS PARTS
As a service to the customer and to facilitate an efficient
installation of the gas turbine, GE provides for shipment of
miscellaneous parts needed during field installation.
<PAGE>
Shipment is in a single 96" x 96" x 192" (2438 mm x 2438 mm
x 4877 mm) weather-tight cargo container. The plywood
container, which can be opened from one end, is outfitted
with shelves and bins for parts storage. The container
comprises what amounts to a "mobile stockroom" and is
designed for transport by truck or rail.
Within the container, each part is packed, identified with
its own label or tag, and stowed in an assigned bin or
shelf. A master inventory list furnished with the container
provides the location of each part for ease in locating the
item.
An additional box approximately 60" x 60" x 216" (1524 mm x
1524 mm x 5486 mm) is furnished for the interconnecting
piping.
2.2.10.1 OFF-BASE COOLANT-TO-AIR INDUSTRIAL TYPE COOLING SYSTEM
A self contained, off-base industrial type, closed-loop
pressurized coolant system is supplied to dissipate the heat
from the lubrication oil and turbine support legs. It also
cools the flame detectors, atomizing air system and
generator. The following major components are included:
o Modular 100% capacity coolant-to-air heat exchanger
mounted off-base, with motor driven fans to force air over
finned tube heat exchangers. The fan motor power is
supplied from the unit motor control center.
o Automatic temperature controller which regulates coolant
flow to control lube oil temperature during operation.
o Dual full-flow AC motor-driven coolant circulating pumps
(one running, one standby).
o Make-up and expansion tank.
o Instruments for the system as follows:
-- Tank low level alarm and indicator
-- Panel mounted water header pressure gauge, pressure
switch and temperature switch.
-- Coolant header temperature gauge
-- Inlet and outlet thermometers.
<PAGE>
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2.3 GAS TURBINE ELECTRICAL DESCRIPTION
2.3.1 GENERATOR SYSTEM
2.3.1.1 ELECTRICAL RATING
The generator is designed to operate within Class "B"
temperature rise limits, per ANSI standards, throughout the
allowable operating range. The insulation systems utilized
throughout the machine are proven class "F" materials.
The generator is designed to exceed the gas turbine
capability at all ambient conditions between 0 and
120DEG.F.
2.3.1.2 PACKAGING
The 7FH2 generator is designed for compactness and ease of
service and maintenance. Location permitting, the unit will
ship with the rotor, gas shields and end shields factory
assembled. The high voltage bushings, bearings, oil
deflectors hydrogen seals and coolers will also be factory
assembled. The clearances of the bearings, rub rings, fans,
hydrogen seals and deflectors will be factory fitted and
will only require a minimum amount of field inspection of
these components.
All generator wiring, including winding and gas RTD's,
bearing metal and drain TC's, and vibration detection
systems will all be terminated on the main unit with level
separation provided. The standard arrangement will be hard
wired.
Prior to full assembly, the generator stator will receive a
150% pressure test. Following full assembly, a 45 psig seal
oil test will be performed to ensure the seals are seated
properly.
Feed piping between the bearings will be stainless steel and
mounted on the units in the factory to a common header. All
connections to the end shields will be assembled. All
assembled piping will be welded without backing rings and a
first pass TIG weld. A full oil flush will be performed
prior to shipping.
Some amount of field assembly will be required but should be
limited to the following:
<PAGE>
o Factory fitted bearing drain piping and bearing drain
enlargement (BDE)
-- Matched, marked, and shipped separate
-- Loop seal between BDE and drain tank will be stainless
steel and will ship loose
o Water manifolds will be factory fitted and shipped
separate
o Collector compartment
-- Interconnecting wiring and piping
-- Alignment of collector housing and brush rigging to
collector ring
2.3.1.3 FRAME FABRICATION
The frame is a stiff structure, constructed to be a hydrogen
vessel and to be able to withstand in excess of 200PSI. It
is a hard frame design with its four-nodal frequency
significantly above l20Hz. The ventilation system is
completely self contained, including the gas coolers within
the structure. The gastight structure is constructed of
welded steel plate, reinforced internally by radial web
plates and axially by heavy wall pipes, bars and axial
braces.
A series of floating support rings and core rings are welded
to keybars which in turn will support the core. This allows
the entire core to be spring mounted at twenty locations.
This arrangement isolates the core vibration, resulting from
the radial and tangential magnetic forces of the rotor, by
damping the amplitude and reducing the transmissibility by
20:1 Excessive movement of the core, as may result from out
of phase synchronization, is limited by the use of stop
collars at certain locations circumferential around the
frame. The clearance is designed to allow the spring action
of the bar to be unrestricted during normal operation but to
transmit the load of excessive movement through the
structure prior to yielding of any of the components. This
entire arrangement is in keeping with long standard
practices and experience with similar frame designs which
have proven to be very effective and reliable.
The stator frame is supported on four welded-on feet
attached at the lower portion of the fabrication. All the
weight of the unit and the operating loads are carried
through the structure by the web plates and the wrapper to
the feet. The machined portion of the feet are located 85"
below the centerline of the unit.
<PAGE>
2.3.1.4 CORE
The core is laminated from grain oriented silicon steel to
provide maximum flux density with minimum losses, thereby
providing a compact electrical design. The laminations are
coated on both sides to ensure electrical insulation and
reduce the possibility of localized heating resulting from
circulation currents.
The overall core is designed to have a natural frequency in
excess of 170 hertz, well above the critical two-per-rev
electromagnetic stimulus from the rotor. The axial length of
the core is made up of many individual segments separated by
radial ventilation ducts. The ducts at the core ends are
made of stainless steel to reduce heating from end fringing
flux. The flanges are made of cast iron to minimize losses.
The unit will receive periodic pressing during stacking to
ensure compactness, and after stacking the core will receive
a final press in excess of 700 tons.
2.3.1.5 ROTOR
The rotor is machined from a single high alloy steel
forging. The two pole design has 24 axial slots machined
radially in the main body of the shaft. The axial vent slots
machined directly into the main coil slot are narrower then
the main slots and provide the direct radial cooling of the
field copper.
The two retaining rings are of the body mounted design. The
rings will be made of 18 Mn - 18 Cr forged material which
offers excellent protection against stress corrosion
cracking.
The coil wedges are segmented stainless steel. Radial holes
are drilled in the wedges for ventilation passages.
The shaft at the collector is designed to transmit the
torque of an optional starting motor. A shrunk-on coupling
is assembled after the collector rings are on, and it
provides the interface point to the flex-coupling connection
to the motor. The same arrangement and coupling are used
with a static start system when the turning gear is replaced
by a torque converter and starting motor.
2.3.1.6 FIELD ASSEMBLY
The field consists of coils made from high conductivity
copper. Each turn will have slots punched in the slot
portion of the winding to provide direct cooling of the
field. The end turns are of the same cross section as the
slot portion and the entire coil will be pre-assembled with
overlapping brazed joints.
<PAGE>
The slot armor used in the slots is a Class "F" rigid epoxy
glass design. An insulated cover is positioned on the bottom
of each slot armor and on top of the subslot vent. The cover
will provide the required creepage between the lower turn
and the shaft. Epoxy glass insulation strips are used
between each coil turn. A pre-molded polyester glass
retaining ring insulation is utilized over the end windings
and a partial amortisseur is assembled under the rings to
form a low resistance circuit for eddy currents to flow. The
rotor is designed to accommodate static start hardware
utilizing full length slot amortisseurs.
The collector assembly incorporates all the features of GE
proven generator packages with slip on insulation over the
shaft and under the rings. The collector rings use a radial
stud design to provide electrical contact between the rings
and the field leads. The rings are designed to handle the
excitation requirements of the design (approximately 2200
amps on cold day operation and 1900 amps at rated
conditions).
The entire rotor assembly, weighing 76,000 pounds is
balanced up to 10% over operating speed.
[GRAPHIC OMITTED]
<PAGE>
2.3.1.7 END SHIELD/BEARING
The unit is equipped with end shields on each end designed
to support the rotor bearings, prevent gas from escaping and
to be able to withstand a hydrogen explosion in the unlikely
event of such a mishap. The end shield is constructed from
steel plate and it is reinforced to provide the required
strength and stiffness. The split at the horizontal joint
allows for ease of assembly and removal. The horizontal
joints, as well as the vertical face which bolts to the end
structure, are machined to provide a gas tight joint.
Sealing grooves are machined into these joints. These steps
are taken to prevent gas leakage between all the structural
components for pressures up to 45 psig.
The center section of the end shields contain the bearings,
oil deflectors and hydrogen seals.. The lower halves of the
bearings are equipped with dual element thermocouples. The
leads are connected through a quick disconnect through the
end shield to allow ease of bearing removal.
A three section inner and a two section outer oil deflector
are bolted into the end shield and provide sealing of the
oil along the shaft. The deflectors are either fabricated or
cast aluminum. All faces of the deflectors have "O" ring
grooves to provide additional protection from oil leaks. All
annular areas formed between the set of teeth are designed
to provide minimum pressure drops and have oil gutters
machined in to prevent oil from backdripping on the shaft.
The hydrogen seal casing and seals, which prevent hydrogen
gas from escaping along the shaft utilize steel babbitted
rings. Pressurized oil for the seals is supplied from the
main oil system header to the seal oil control unit, where
it is regulated. The seal oil control unit is factory
assembled packaged system and is located in the collector
end compartment and includes the following components:
o Differential pressure regulator valve with bypass
o Differential pressure gage (seal oil pressure vs casing
gas pressure) and two differential pressure switches: one
for alarm and one for actuating the DC emergency seal oil
pump
o Shut-off and isolation valves for operation and
maintenance
The connection end bearing and hydrogen seals are insulated
from the rotor to prevent direct electrical contact between
the rotor and the end shield. Both end shields will have
proximity type vibration probes. These are located axially
<PAGE>
outboard of the bearing. Mounting for velocity type
vibration sensors is also provided on the surface of the
bearing caps.
All exiting wiring from the temperature indication devices
and the insulating test leads are brought out of the unit
through gas tight conex type seals to prevent any chance of
a hydrogen leak.
2.3.1.8 WINDING
The armature winding consists of "Class F" insulated bars.
The winding is a three phase, two circuit design. The bar
ground insulation is protected with a semi-conducting armor
in the slot and our well proven grading system on the end
arms.
The ends of the bars are pre-cut and solidified prior to
insulation to allow strap brazing connections on each end
after the bars are assembled. A resin impregnated insulation
cap is used to insulate the end turn connections.
The bars are secured in the slot with side ripple springs
(SRS) to provide circumferential force and with a top ripple
spring (TRS) for additional mechanical restraint in the
radial direction. The SRS's, TRS's and the wedging system
are well-proven reliable designs. The end winding support
structure consists of glass binding bands, radial rings and
the conformable resin-impregnated felt pads and glass roving
to provide the rigid structure required for system
electrical transients.
<PAGE>
[GRAPHIC OMITTED]
2.3.1.9 LEAD CONNECTIONS
All the lead connection rings terminate at the top of the
structure at the excitation end of the unit. Each of the
circuits are connected to the high voltage bushings. The
bushings, which provide a compact design for factory
assembly and shipment, are positioned in the top of the
frame and are offset to allow proper clearances to be
maintained. This configuration also allows connections to
the leads to be staggered and provides ease of bolting and
insulation.
The six high voltage bushings exit the frame at the top.
These bushings are made up of a porcelain insulators
containing silver plated, copper conductors which form a
hydrogen tight seal. The bushings are assembled to
non-magnetic terminal plates to minimize losses. Copper bus
is assemble to the bushings within an enclosure. Customer
connections are made beyond the terminal enclosure and the
specific mating arrangements will be provided within the
enclosure, not inside the generator.
2.3.1.10 LUBRICATION
Lubrication for the generator is supplied from a system in
common with the turbine lubrication system which is
contained in the lubrication module. Lubricant feed and
drain lines are provided as an integral part of the
generator
<PAGE>
package. Flanged connections are provided for connection to
piping from the lubrication module.
2.3.1.11 DETRAINING SYSTEM
The air-side seal oil and the generator bearing oil drain to
a bearing drain enlargement mounted under the generator
casing. This bearing drain enlargement is a detraining
chamber and provides a large surface area for detraining the
oil before it is returned to the main oil tank.
Two seal drain enlargements are provided for removing
entrained hydrogen from the oil which drains from the
hydrogen-side seal rings. They are drained through a common
line to a float trap which then drains to the bearing drain
enlargement for further detraining. A high liquid level
alarm switch is provided to detect abnormal oil level in the
seal drain enlargement.
Piping is all factory fitted and the system is well-proven
to assure that no hydrogen can enter into the oil system.
2.3.1.12 HYDROGEN CONTROL CABINET
To maintain hydrogen purity in the generator casing at
approximately 98 percent, a small quantity of hydrogen is
continuously scavenged from the seal drain enlargements and
discharged to atmosphere. The function of the hydrogen
control cabinet is to control the rate of scavenging and to
analyze the purity of the hydrogen gas. The cabinet is
divided into two compartments, the gas compartment and the
electrical compartment, which are separated by a gas-tight
partition.
2.3.1.13 GAS COMPARTMENT
The following instrumentation is included:
o Hydrogen pressure gage with electronic transmitter for
remote receiver
o Differential fan pressure gage
o Flowmeters for gas analyzer and for total scavenging rate
o A gas purifier with filter for removing oil, water and
particles as small as 12 microns
o Moisture indicator to indicate the presence of moisture in
the gas line
<PAGE>
o Gas tight wiring seal into hydrogen electrical compartment
2.3.1.14 ELECTRICAL COMPARTMENT
The following instrumentation is included:
o One gas purity analyzer with 0-105 mv output for panel and
remote indicators, with high and low purity alarm contacts
o Generator gas temperature indicator with high temperature
alarm contact
2.3.1.15 HYDROGEN MANIFOLD
Hydrogen, is admitted to the generator casing through the
use of the hydrogen gas manifold. The following
instrumentation is provided and is located in the collector
compartment:
o Generator gas pressure gage
o High and low generator gas pressure switches
2.3.1.16 CARBON DIOXIDE MANIFOLD
A carbon dioxide system is used for purging the generator
casing of air before admitting hydrogen, and also to purge
hydrogen before admitting air. The following instrumentation
is provided and is located in the collector compartment.
o Purging control valve assembly
o Relief valve
2.3.1.17 MOTOR CONTROL CENTER
The MCC is manufactured and tested in accordance with NEMA
ICS-2 & UL Standard No. 845. It is designed for 480V, 3 PH,
60 HZ, with a short circuit capacity of 42,000 amps RMS
symmetrical at the incoming 480VAC line terminals. The main
protective device will be a Tri break 600 amp, type TB4,
200,000 amp interrupting, 125-400 amp trip, bolt -in
connection.
2.3.1.18 COOLING SYSTEM
The generator is cooled by a recirculating gas stream cooled
by gas-to-water heat exchangers. Cold gas is forced by the
generator fans into the gas gap, and
<PAGE>
also around the stator core. The stator is divided axially
into sections by the web plates and outer wrapper so that in
the center section cold gas is forced from the outside of
the core toward the gap through the radial gas ducts, and in
the end section it passes from the gas gap toward the
outside of the core through the radial ducts. This
arrangement results in substantially uniform cooling of the
windings and core.
The rotor is cooled externally by the gas flowing along the
gap over the rotor surface, and internally by the gas which
passes over the rotor and windings, through the rotor
ventilating slots, and radially outward to the gap through
holes in the ventilating slot wedges.
After the gas has passed through the generator, it is
directed to five horizontally mounted gas-to-water heat
exchangers. After the heat is removed, cold gas is returned
to the rotor fans and recirculated.
2.3.2 GENERATOR COLLECTOR COMPARTMENT
An exciter-end, enclosure will be provided shipped separate
from the generator. It will contain the following
assemblies:
o Hydrogen control cabinet
o Seal oil control unit, regulator & flowmeter
o Seal oil drain system, float trap & liquid level detector
o H2 & CO2 feed & purge system, valves & gauges
o Switch & gauge, block & porting system
o Collector housing & brush rigging assembly
o Collector filters & silencers
o Level-separated electrical junction boxes
o Turning gear
The above items will be packaged in the enclosure and
shipped separate from the generator. All internal piping and
wiring will be completed and terminated at convenient
locations in the housing. A minimum fit of field wiring and
piping will be required to assemble the collector cabinet to
the generator. The end wall of the enclosure will have
provisions for the flex coupling between the generator and
the starting motor or torque converter to pass through. The
<PAGE>
generator end of the enclosure will interface with the
generator and be sealed against the elements.
The enclosure is designed with a removable end wall section
& roof to allow ease of rotor removal without moving the
housing. Position of all the above hardware will be spaced
to allow easy access for maintenance and to prevent any
unnecessary disassembly during rotor removal. Two doors are
provided on the end wall to allow access from either side.
Safety latches are provided on the inside of the doors to
provide easy exit from the enclosure. AC lighting is
standard. One DC light fixture is optional. Fire detectors
in the enclosure are optional.
2.3.3 GENERATOR TERMINAL COMPARTMENT
The generator terminal compartment is a roof mounted
enclosure located above the generator having estimated
weight of 15000 lbs. Design of the enclosure will
accommodate ISO phase bus on centers up to 40 inches with
bus exit either from the left or right side. Devices
included in the enclosure are as follows:
o Outgoing power connections to station transformer
contained in individual isolated phase ducts
o Neutral grounding transformer rated 25 KVA, 12 KV-240 V,
95 kV BIL
o Neutral grounding resistor rated 1.45 ohms, 160A for one
(1) minute
o Three (3) 18 KV lightning arrestors for generator
protection
o Current transformers:
-- 3 sets of 3 8,000/5 with C/400 accuracy in the neutral
connection
-- 1 set of 3 8,000/5 with C/800 in the neutral connection
-- 2 sets of 3 8,000/5 and 1 set of 2 for the excitation
with C400 accuracy on the line side
2.3.4 PACKAGED ELECTRONIC AND ELECTRICAL CONTROL COMPARTMENT (PEECC)
The PEECC is a completely enclosed compartment suitable for
outdoor installation. Heating, air conditioning, compartment
lighting and power outlets are provided for convenience and
protection of the equipment in the PEECC. Electrical
monitoring and control of the unit are accomplished by the
<PAGE>
turbine Mark V SPEEDTRONIC-TM- control panel and the
generator control panel, which are mounted on a common skid
and located in the PEECC. In addition to the control
systems, the PEECC also houses the gas turbine motor control
centers and 125Vdc battery and charger. The arrangement of
the equipment is shown in the typical compartment layout
below.
Description of the FM-200 system in the PEECC is as follows:
o Smoke detectors for fire detection only
o Heat detectors for fire detection and signal discharge
FM-200
o Strobe/horn local alarm system
o On-base discharge piping and nozzles
PACKAGED ELECTRONIC AND ELECTRICAL CONTROL COMPARTMENT (PEECC)
(Typical)
[GRAPHIC OMITTED]
<PAGE>
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2.4 GAS TURBINE CONTROL DESCRIPTION
2.4.1 MARK V SPEEDTRONIC CONTROL SYSTEM
2.4.1.1 CONTROL SYSTEM
The gas turbine control system, SPEEDTRONIC Mark V, is a
state-of-the-art Triple Modular Redundant (TMR)
microprocessor control system with a heritage of over 40
years of successful turbine automation. The core of this
system is the three separate but identical controllers
called [R], [S], and [T]. All critical control algorithms,
protective functions, and sequencing are performed by these
processors. In so doing, they also acquire the data needed
to generate outputs to the turbine. Protective outputs are
routed through the [P] module consisting of triple redundant
processors [X], [Y], and [Z], which also provide independent
protection for certain critical functions such as overspeed.
The three control processors, [R], [S], and [T], acquire
data from triple-redundant sensors as well as from dual or
single sensors. The actual number of sensors will depend on
the turbine type. All critical sensors for continuous
controls, as well as protection, are triple-redundant. Other
sensors are dual or single devices fanned out to all three
control processors. The extremely high reliability achieved
by TMR control systems is due in considerable measure to the
use of triple sensors for all critical parameters.
2.4.1.1.1 MARK V ELECTRONICS
All of the microprocessor-based controls have a modular
design for ease of maintenance. Each module or controller
contains up to five cards, including a power supply.
Multiple microprocessors reside in each controller which
distribute the processing for maximum performance.
Individual microprocessors are dedicated to specific I/O
assignments, application software communications, etc., and
the processing is performed in a real-time, multi-tasking
operating system. Communications between the controller's
five cards is accomplished with ribbon cables and gas-tight
connectors. Communication between individual controllers is
performed on high-speed Arcnet links.
2.4.1.1.2 SHARED VOTING
Software Implemented Fault Tolerance (SIFT) and hardware
voting are utilized by the Mark V TMR control system. At the
beginning of each computing time frame, each controller
independently reads its sensors and
<PAGE>
exchanges this data with the data from the other two
controllers. The median value of each analog input is
calculated in each controller and then used as the resultant
control parameter for that controller. Diagnostic algorithms
monitor a predefined deadband for each analog input to each
controller, and if one of the analog inputs deviates from
this deadband, a diagnostic alarm is initiated to advise
maintenance personnel.
Contact inputs are voted in a similar manner. Each contact
input connects to a single terminal point and is parallel
wired to three contact input cards. Each card optically
isolates the 125 or 24 V dc input, and then a dedicated
80196 processor in each card time stamps the input to within
1 ms resolution. These signals are then transmitted to the
[R], [S], and [T] controllers for voting and execution of
the application software. This technique eliminates any
single point failure in the software voting system.
Redundant contact inputs for certain functions such as low
lube oil pressure are connected to three separate terminal
points and then individually voted. With this SIFT
technique, multiple failures of contact or analog inputs can
be accepted by the control system without causing an
erroneous trip command from any of the three controllers as
long as the failures are not from the same circuit.
Another form of voting is accomplished through hardware
voting of analog outputs. Three coil servos on the valve
actuators are separately driven from each controller, and
the position feedback is provided by three LVDTs. The normal
position of each valve is the average of the three commands
from [R], [S], and [T]. The resultant averaging circuit has
sufficient gain to override a gross failure of any
controller, such as a controller output being driven to
saturation. Diagnostics monitor the servo coil currents and
the D/A converters in addition to the LVDTs.
2.4.1.1.3 PC BASED OPERATOR INTERFACE
The operator interface, [I], consists of a PC, color
monitor, cursor positioning device, keyboard, and printer.
It can be used as the sole operator interface or as a local
maintenance work station with all operator control and
monitoring coming from communication links with a plant
distributed control system (DCS). Operators use the monitor,
cursor positioning device, and keyboard. The keyboard is not
necessary. However, the keyboard is convenient for accessing
displays with dedicated function keys and adjusting
setpoints by entering a numeric value such as 100 mw rather
than issuing a manual raise/lower command. The keyboard is
primarily used for maintenance such as editing application
software or alarm messages. Setpoint and logic commands
require an initial selection, such as the command to engage
the
<PAGE>
turning gear, which is followed by a confirming execute
command. The monitor is available in various sizes and
types, and it can be used for desktop mounting, packaged as
a drop-in insert for a control room console, or mounted in a
separate free-standing cabinet.
2.4.1.1.4 DIRECT SENSOR INTERFACE
Mark V input/output (I/O) is designed for direct interface
to turbine and generator devices such as thermocouples,
RTD's , vibration sensors and flame sensors. Direct
monitoring of these sensors eliminates the cost and
potential reliability factors associated with interposing
transducers and instrumentation. In addition, all of the
resultant data visible to the operator from the Mark V
operator interface and Distributed Control System (DCS)
system via a communication link if desired.
2.4.1.1.5 BUILT-IN DIAGNOSTICS
The Mark V control system has extensive built-in diagnostics
and includes "power-up", background and manually initiated
diagnostic routines capable of identifying both control
panel, sensor, and output device faults. These faults are
identified down to the board level for the panel, and to the
circuit level for the sensor or actuator component. On-line
replacement of boards is made possible by the Mark V's
triply redundant design and is also available for those
sensors where physical access and system isolation are
feasible.
2.4.1.1.6 GENERATOR INTERFACE AND CONTROL
The primary point of control for the generator is though the
Mark V operator interface. However, the Mark V is integrated
with the EX2000 excitation system over an Arcnet local area
network (LAN). Therefore the Mark V is used to control
megawatt output and the EX2000 is used to control megavar
output. The generator protection panel (GPP) is used to
provide primary protection for the generator. This
protection is further augmented by protection features
located in the EX2000 and the Mark V.
2.4.1.1.7 SYNCHRONIZING CONTROL AND MONITORING
Automatic synchronization is performed by the [X], [Y], and
[Z] cards in conjunction with the [R], [S], and [T]
controllers. The controllers match speed and voltage and
issue a command to close the breaker based on a predefined
breaker closure time. Diagnostics monitor the actual breaker
closure time and self-correct each command. Another feature
is the ability to
<PAGE>
synchronize manually via the Mark V operator interface
instead of using the traditional synchroscope on the
generator protective panel. Operators can choose one
additional mode of operation by selecting the monitor mode,
which automatically matches speed and voltage, but waits for
the operator to review all pertinent data on the CRT display
before issuing a breaker close command.
2.4.1.1.8 ARCHITECTURE
The Mark V control configuration diagram depicts several
advantages for increased reliability and ease of interface.
For example:
o Multiple unit control from a single [I] which allows any
turbine to be controlled from any [I]
o Back-up display wired directly to [R], [S], and [T]
controllers
o PC interface to plant DCS system
o Hard wire protective signal from [R] [S] [T] controllers
o Additional protective processors [X], [Y], [Z]
The protective block diagram shows the built in
redundancy/reliability of the Mark V control system. For
example, if there is an overspeed condition requiring a trip
of the unit, the first line of defense would be the primary
overspeed protection via the [R], [S], and [T] controllers.
All three trip signals then pass to the [P] trip card where
two out of three voting occurs prior to sending the
automatic fuel supply trip signal. The secondary overspeed
protection is via the [X], [Y], and [Z] cards which
similarly send their independent trip signals to the [P]
trip card for voting.
<PAGE>
[GRAPHIC OMITTED]
<PAGE>
[GRAPHIC OMITTED]
<PAGE>
2.4.1.2 SCOPE OF CONTROL
The Mark V control system provides complete monitoring
control and protection for Gas Turbine-Generator and
Auxiliary systems. The scope of control is broken down into
three (3) sections: Control, Sequencing and Protection.
-- Control
-- Start-up control
-- Speed/load setpoint and governor
-- Temperature Control
-- Guide vane control
-- Fuel control
-- Generator excitation setpoints
-- Synchronizing control (speed/voltage matching)
-- Emissions control by one of the following:
- Diluent injection (water)
- Combustion staging for Dry Low NOx (DLN)
-- Droop control
-- Preselected load control
-- Base control
The Mark V will be capable of accepting raise and lower
pulses from the plant DCS system for load control.
-- Sequencing
-- GT auxiliary systems (MCC starters)
-- Start-up, running and shutdown
-- Purge and ignition
-- Fuel changeover
-- Alarm management
-- Synchronizing
-- H(2) sequencing (if applicable)
-- Maintain starts, trips and hours counters
-- Event counters
<PAGE>
- Manually initiated starts
- Fired starts
- Fast load starts
- Emergency trips
-- Time meters
-- Fired time
-- DCS interface (if applicable)
-- Protection
-- Overspeed, redundant electronic
-- Overtemperature (including generator)
-- Vibration
-- Loss of flame
-- Combustion monitor
-- Redundant sensor CO(2) fire protection
-- Low lube oil pressure, high lube oil temperature,
etc.
2.4.1.3 GAS TURBINE PLANT OPERATING MODES
2.4.1.3.1 STARTING/LOADING
All starting is done automatically, with the operator given
the opportunity to hold the start-up sequence at either the
crank (pre-ignition) or fire (post-ignition, pre-accelerate)
points of the start-up. An "Auto" mode selection results in
a start without any holds.
Either before issuing a start command, or during the start,
the operator may make the following selections:
1. Select or disable the automatic synchronization
capability of the Mark V control. Auto synch utilizes
the proven microsynchronizer first introduced in the
Mark II generation of SPEEDTRONIC. The
microsynchronizer provides extremely accurate and
repeatable breaker closures based on phase angle, slip,
the rate of change of slip and the response time of the
breaker which is in the system memory.
2. Select Preselected Load or Base Load. If a selection is
made the unit will automatically load to the selected
point and control there. If no selection is made the
unit will load to a low load referred to as "Spinning
Reserve"
<PAGE>
automatically upon synchronization; be it automatic or
manual. The turbine governor is automatically regulated
to maintain the megawatt setting assigned to "Spinning
Reserve".
2.4.1.3.2 OPERATING
Once the unit is on line, it may be controlled either
manually or automatically from the Mark V control Operator
Interface.
Manual control is provided by the governor raise/lower
control displayed on the operator interface screen.
Automatic operation is switched on when the operator selects
one of three load points (preselect or base) from the
turbine control interface.
For a fully automatic start with automatic loading to base
load, the operator selects the "Auto" operating mode,
enables auto synchronization and selects "Base" load. Given
a "Start" signal, the unit will then start, synchronize and
load to Base load with no further input on the part of the
operator.
2.4.1.3.3 SHUTDOWN
On shutdown, the system will automatically unload and return
to turning gear motor operation. The unit will stay on
turning gear until an operator turns it off. Note: the
operator must insure the unit is sufficiently cool before
shutting off turning gear to avoid temporary rotor bow due
to heat.
2.4.1.4 COMMUNICATIONS
The open architecture of the [I] processor facilitates a
wide range of external communication links. The Mark V's
internal Arcnet communication link is isolated from external
communication links at the [I] processor.
The External communication link utilizes Ethernet with
TCP-IP protocol to facilitate transmitting of data with
local time tags for alarms and events to the plant level.
Ethernet provides high speed 10 mega baud transmission rates
combined with TCP-IP which is widely used throughout the
world. GE supplies an application layer protocol call GSM
(i.e. GEDS Standard Messages) which supports four classes of
application level messages.
Time synchronization between Mark Vs, and/or between Mark Vs
and a DCS enable all time tags to be referenced to a common
source. The [I] operator interface is the common reference
point within the Mark V control system, and it sends the
time synchronization commands to the Mark V controllers
<PAGE>
where the individual time tags are assigned. Sites with
multiple Mark Vs can have a master [I] for time
synchronization with the other [I]s acting as slaves. A
failure of the master [I] will initiate an automatic default
to one of the slaves as the new master.
The [I] operator interface is supplied with 50 ft (15 m) of
cable to facilitate convenient location near the Mark V
panel. However, the communications link provided allows for
remote location of a single interface using up to 1500 ft
(457 m) of cable without repeaters or 9600 ft (2926 m) using
a fiber optic link without repeaters. Multiple operator
interfaces may be used to communicate to a Mark V. This
capability changes the maximum allowable distance of a
remote operator interface. Cable routing between buildings
of this stage link cable requires adequate lightning
protection (i.e., fiber optics).
2.4.1.5 OPERATOR DISPLAYS
Two (2) out of the typical forty (40) available displays are
shown on the following pages. The first screen is the main
menu display. From the main menu all operation/maintenance
and user defined screens can be reached. The main menu
screen is made up of three (3) major areas:
-- List of available displays
-- Alarm field shows the three (3) latest unacknowledged
alarms (Black band near bottom of screen in the
example. Blue is the actual color.)
-- Function control keys (bottom of screen)
<PAGE>
[GRAPHIC OMITTED]
The second screen shown is a typical operating screen. Note
that the alarm list and function control key fields are also
shown below the primary display field on this screen.
Control target values are shown in the primary display
field. Selecting and executing commands is very simple. For
example, to go to baseload, you would move the cursor to the
"Baseload" target and click on it. Then before the control
times out, you would move the cursor to the "Execute
Command" target and click on it. The "Execute Command" step
protects against accidental activation of the wrong command
that might occur with a one step (point/click) command.
Signals that require an Execute command in order to be
activated are:
-- Start -- Stop
-- Operation Selection
-- Off
-- Crank
-- Fire
-- Auto
-- Remote
<PAGE>
-- Fuel Selection
-- Gas
-- Distillate (Dist)
-- Load Selection
-- Preselected Load
-- Base
-- Guide Vane Control
-- Temp Control Off
-- Temp Control On
-- Governor Type Selection
-- Droop (nominal 4%)
<PAGE>
[GRAPHIC OMITTED]
Interface displays can be in either English or Metric units.
Standard operator display language is English.
2.4.1.6 BACKUP INTERFACE
In the unusual event that the operator interface becomes
unavailable, a small backup interface is provided on the
Mark V cabinet door. It uses a liquid crystal display with
two (2) lines of forty (40) characters per line to display
key control parameters and alarms. The Mark V accepts
operator commands from this backup interface.
2.4.1.7 PRINTER
The standard Mark V operator interface printer is a 240 cps,
dot matrix type with these convenient features:
<PAGE>
-- Alarm logging
-- Event logging
-- Historical trip display printing capability
-- User defined display printing capability
-- Periodic log display printing capability
-- CRT screen copy
Each alarm and event is logged with a high resolution time
tag. Contact inputs are logged to 1 millisecond. Separate
alarm queues are maintained for turbine/generator system
alarms and for Mark V internal self-diagnostic alarms.
System alarms can be silenced, acknowledged and reset
locally or from a DCS via a two-way communication link, if
desired. Any intermittent alarms can be locked out with a
permanent lockout message residing in the alarm queue.
If a trip occurs, the historical trip display automatically
captures in memory all key control parameters and alarm
messages at the time of the trip and at several time
intervals preceding the trip. The operator can print the
historical trip display when required. A start signal
triggers the display to start collecting new data and all
previous data is deleted from the current log. Display logs
can be saved at any time to a memory buffer.
A user-defined display allows selection of any desired data
for viewing or printing. The periodic log allows a user to
define points to be collected and printed periodically to a
printer. The period of each list is defined in minutes, from
1 to 10,080 (one week).
2.4.1.8 DOCUMENTATION
Documentation for the Mark V turbine control system consists
of two types: unit-specific drawings and instruction books.
A unique set of requisition-specific documentation is
supplied with each control system and three instruction
books are available for the specific needs of each user.
2.4.1.8.1 REQUISITION SPECIFIC DRAWINGS
-- I/O REPORT contains the unit-specific assignment of I/O
terminations in the Mark V control panel. This report
also has I/O related information such as the signal
names.
<PAGE>
-- CONTROL SEQUENCE PROGRAM PRINTOUT is a unit-specific
printout that shows a functional representation the Big
Blocks and sequencing of a particular requisition.
Software on the operator interface allows editing and
printing of this document from any location.
-- OUTLINE DRAWINGS provide an external view of the
control panel and primary operator interface. The
drawings furnish information needed for handling and
installing the equipment.
-- CASE LAYOUT DRAWING supplies an internal view of the
control panel. The primary purpose of this drawing is
to furnish information needed to route interconnect
cables.
-- CASE WIRING DRAWING defines the factory cabling
internal to the control panel case. The drawing's
primary purpose is to document the internal wiring for
maintenance use.
-- CORE DRAWINGS provide an isometric drawing of the core
depicting the cards and their respective locations
within the core. For each card, the physical location
and identification of removable parts, such as
connectors and hardware jumpers, are highlighted. The
core drawing is placed in a pocket on the inside of the
core door.
Instruction Books:
Three (3) instruction books are provided for the Mark V
turbine control system that are designed to meet the special
needs of the operators, maintenance personnel, and
application engineer.
-- For the operator, Mark V User's Manual
-- For the maintenance technician, Mark V Maintenance
Manual
-- For the application engineer, Mark V Application Manual
<PAGE>
2.4.1.9 SPEEDTRONIC MARK V REDUNDANCY LIST AND I/O
2.4.1.9.1 REDUNDANT OR MULTIPLE SENSORS
<TABLE>
<CAPTION>
DEVICE PARAMETER FUNCTION DEVICE TYPE QTY REDUNDANCY
------ --------- -------- ----------- --- ----------
<S> <C> <C> <C> <C> <C>
26QA/T Lube oil temp high A/P temp switch 3 S
28FD Flame detector A/P UV scanner 4 S
33FL Liquid fuel stop valve M limit switch 2 S
39VX Vibration sensor A/P velocity pick-up 2 S
45FX Fire detector A/P temp switch 2 # S
63HG Gas fuel trip oil press A/P press switch 3 D
63HL Liquid fuel trip oil press A/P press switch 3 D
63QA/T Lube oil hyd press A/P press switch 3 S
63TF Inlet filter press C/P press switch 3 D
65FP Liquid fuel pump servo C 3 coil servo 1 D
65GC Gas cont valve servo C 3 coil servo 1 D
77FD Liquid fuel flow C/P mag. pick-up 3 D
77NH Speed magnetic pick-up C mag. pick-up 3 D
77NT Speed magnetic pick-up A/P mag. pick-up 3 D
77WN Water flow mag pick-up C mag pick-up 4 S
90SR Gas ratio valve servo C 3 coil servo 1 D
90TV Inlet guide vane servo C 3 coil servo 1 D
96FG-2 Gas fuel cont press C transducer 3 D
96GC Gas control valve C LVDT 2 S
96SR Gas ratio valve C LVDT 2 S
96TV Inlet Guide Vane C LVDT 2 S
CTDA Compressor discharge temp M TC 2 S
CTIF Compressor inlet temp M TC 2 S
FTGI-x Fuel gas supply temp C TC 3 D
TTWS-x GT Wheelspace temp A/P TC 2/W S
TTXD-x GT Exhaust temp C/P TC 18 ## D/S
-------------------------------
Notes: # All channels/locations except 1 are redundant by means of two sensors per
location. The non-redundant location has one sensor.
## The number of exhaust TC's varies with the GT model from 13 to 27. Each
control processor reads 1/3 of the TC's directly and then all TC data is
shared by all processors.
Legend: S = Shared D = Dedicated A = Alarm
</TABLE>
<PAGE>
2.4.1.9.2 NONREDUNDANT (PARTIAL LISTING)
<TABLE>
<CAPTION>
DEVICE PARAMETER FUNCTION SENSOR QTY
------ --------- -------- ------ ---
<S> <C> <C> <C> <C>
20FG Gas fuel trip oil C solenoid valve 1
20FL Liquid fuel trip oil C solenoid valve 1
26FD Liquid fuel temp C temp switch 1
26QL/M Lube oil temp low/moderate C temp switch 1 ea
26QN Lube oil temp normal P temp switch 1
63AD Atomizing air differential press A press switch 1
63FD Liquid fuel press A * press switch 1
63FG Gas fuel press A * press switch 1
63LF1 Liquid fuel filter press A press switch 1
63QA Lube oil press P press switch 1
63QL Lube oil press P press switch 1
63TK Exh frame cooling press A/P press switch 1/fan
63WC Cooling water press low A press switch 1
71QH Lube tank high level A level switch 1
71QL Lube tank low level A level switch 1
71WL Water tank low level A level switch 1
96FF-1 Gas fuel low flow press C transducer 1
96FG-1 Gas fuel supply press C transducer 1
* Can be used to initiate a transfer from primary to backup fuel.
</TABLE>
<PAGE>
2.4.1.9.3 I/O CAPACITY
<TABLE>
<CAPTION>
I/O TYPE STD COMMENTS
-------- --- --------
<S> <C> <C>
Contact inputs 192 96 paralleled to [R][S][T] & 96 [C]
Paralleled to [R][S][T] (TMR only)
125 / 24V dc, optical isolation
Contact outputs 120 60 from [R][S][T] & 60 from [C]
From [R][S][T] (TMR only)
Pulse rate inputs 19 Mag pu: 6 to each of [R][S][T], 1 parallel
4 TTL
6 Mag pu: 2 to each of [X][Y][Z] in P
LVDT/R position inputs 16 7vrms, 3kHz, 70mA excitation
Servo valve outputs 8 3 coil, +/-10,20,40mA (4 channels)
3 coil, +/-10,20,40,80,120,240mA (4ch)
Vibration seismic 12 Paralleled to [R][S][T]
acceler. Paralleled to [R][S][T]
Proximitor vibration Requires special packaging on Simplex
position Requires special packaging on Simplex
key phas. Requires special packaging on Simplex
Thermocouple input 87 15 to each of [R][S][T] & 42 to [C]
RTD inputs 30 to [C]
4-20 mA inputs 29 15 paralleled to [R][S][T] & others [C]
4-20 / 0-1 mA inputs 1 1 paralleled to [R][S][T] & 8 to [C]
4-20 mA outputs 16 For monitoring from [C]
4-20 / 0-200 mA outputs 2 Valve positioners from [R][S][T]
+/- 10V dc inputs 8 2 to each of [R][S][T] & 2 parallel
0 to 5V dc inputs 6 2 to each of [R][S][T]
Flame scanners 8 335V dc excitation
Shaft voltage & currency 1 1 to [C]
PT inputs 120vac open delta
CT inputs 5 amps ac
</TABLE>
<PAGE>
2.4.1.10 HARDWARE AND SPECIFICATIONS
2.4.1.10.1 MARK V TURBINE CONTROL PANEL
<TABLE>
<S> <C>
Dimensions 54" (1.37 m) wide x 90" (2.29 m) high x 20" (0.51 m) deep
Weight 1200 lbs (544 kg)
Type NEMA 1, convection cooled
Power 1100W maximum for the Mark V enclosure
Provisions for one (1) dc and one (1) ac source or two (2) ac sources
Voltage ranges 100 to 140 V dc
105 to 132 V ac, 47 to 63 Hz
210 to 264 V ac, 47 to 63 Hz
[I] Operator Interface -- nominal load is 7.5 A for the 120 V source.
Type NEMA 1, convection cooled
Access Front only
Cable entrance Top or bottom
Temperature Operating: 32 DEG.F to +113 DEG.F (0 DEG.C to +45 DEG.C
Storage: -40 DEG.F to + 158 DEG.F (-40DEG.C to +70DEG.C)
Humidity: 5 to 95%, noncondensing
Reactive sulfur 10 ppb max
Reactive chlorine 10 ppb max
Equivalent Static Vertical 0.67G; Horizontal 1.0G
Levels:
Seismic Ground Levels Vertical 0.5G; Horizontal 0.5G
Cabinet meets Uniform Building Code (UBC) Zone 4 requirements
Clarification: The ground seismic accelerations will be amplified by
the intervening structure; thus, the difference above between seismic levels and
static equivalent levels provide for this amplification. These are relatively
conservative; however could be exceeded in a "flexible" installation. All seismic
installations should be reviewed by someone familiar with the dynamics
involved with the final installation.
Surge per ANSI C37.90A
</TABLE>
<PAGE>
<TABLE>
<S> <C>
EMI Mobile radio, 5 watt using 27, 150 and 480MHz at 3 ft (1 m), with
doors closed
Terminations Pressure pad type Phoenix terminal boards.
Accepts one (1) #12 AWG or two (2) #14 AWG per point for control I/O. 300 volt,
10 amp rating.
Designed to meet UL, CSA and VDE. Captive screws, dead front for safety, 85%
copper alloy with nickel plating.
Grounding Cabinet ground bar, must be connected to the plant ground grid with a minimum
of #4 AWG.
Cabinet steel 0.105" thick (12 gauge), B8A3A sheet, hot roll, low carbon, ATSI 1010.
Codes Cabinet carries CSA, CE/EMCD and UL labels.
Paint Exterior and Interior, electrocoat (E-Coat) plating process, color ANSI-70
light gray. E-coat contains no zinc, lead or chrome. Thickness is
approximately 1.5 to 2.0 mils.
</TABLE>
2.4.2 MOTOR CONTROL CENTERS
The motor control center contains circuit protective devices
and power distribution equipment to supply electrical power
to all packaged power plant devices as defined on the
electrical one line diagram. The motor control center is
manufactured and tested in accordance with NEMA ICS-2 and UL
Standard No. 845. Vertical sections and individual units
will be UL (CSA) Labeled where possible. The motor control
center is located in the PEECC.
2.4.3 GENERATOR PROTECTION
2.4.3.1 GENERATOR PROTECTION PANEL
The current generator protection panel is the result of
years of research to best meet our customers needs and to
upgrade the generator protection panel to incorporate the
latest in digital technology. The heart of the generator
protection panel is the digital multifunction relay
integration with the Mark V turbine control panel.
The standard generator protection panel incorporates this
features along with generator metering, Watt and Var
transducers for turbine control, and bus ground detection.
Pre-engineered protective modules such as generator step-up
transformer protection and auxiliary transformer protection
are not
<PAGE>
included in the generator protection panels design. The
generator protective panel can also be customized to
incorporate protective and monitoring features as required.
A simple one-line diagram of the standard generator
protection panel is presented on the following page. This
one-line is for illustration purposes only. For job specific
details see the one-line diagram in the Equipment Drawings
chapter of this proposal.
<PAGE>
[GRAPHIC OMITTED]
<PAGE>
2.4.3.2 GENERATOR PROTECTION
The Digital Generator Protection is a compact, digital,
multiprocessor, space saving, multifunction protection
system. It's modular construction allows for easy
maintenance. The Digital Generator Protection module
provides a wide range of protection, monitoring, control and
recording functions for ac generators. It can be used on
generators driven by steam, gas and hydraulic turbines. Any
size of generator can be protected with the Digital
Generator Protection. A high degree of dependability and
security is achieved by extensive self diagnostic routines
and redundant power supplies.
The Digital Generator Protection provides the commonly used
protective functions in one package, including 100% stator
ground fault detection using 3rd harmonic voltage
monitoring. It has adaptive sampling frequency for better
protection during startup. The Digital Generator Protection
has eight configurable output relays, four trip and four
alarm relays.
The Digital Generator Protection can record the last 100
sequence of events, 120 cycles of oscillography fault
recording and the last 3 fault reports. These records and
fault reports require connection to a local (customer
supplied) PC for displaying of reports.
IRIG-B time synchronization capability is available within
the Digital Generator Protection Module. To take advantage
of this feature, the customer must supply all external
equipment.
A Man Machine Interface (MMI) with integral keypad, 16
character displays, and target LEDs allow easy local user
interface for entering settings, display present values,
view fault target information and access stored data. Some
of the present values that can be displayed are amps, volts,
Watts, Vars, power factor, negative sequence, third harmonic
level.
A front 9 pin RS232 serial ports allow both local and remote
computer access. Available options include, serial printer
port supplied on the rear, and Sequential trip such as the
33ST function for steam turbines. It can be specified to
operate with wye-wye or open-delta connected VTs and any
phase rotation.
2.4.3.2.1 GENERATOR LOCKOUT RELAY (86G-1)
Trips the generator breaker, the turbine, and the excitation
system. This lockout is normally tripped by either one of
the three functions 40, 87G or
<PAGE>
59GN ( 64G1 ). The reasoning behind this is that if a loss
of excitation, or differential, or stator ground fault
occurs the structural integrity of the generator may have
been compromised and continued operation will potentially
lead to more devastating results. The turbine Mark V logic
monitors this lockout.
2.4.3.2.2 BREAKER OR LOCKOUT TRIP COIL MONITOR (74)
Monitoring of trip coil circuit integrity is of sufficient
concern to warrant the installation of an auxiliary relay
and indicating lights for the lockout relays and generator
breaker. A high impedance relay 74 is placed in series with
the trip coil to be monitored. This relay drops out if
either the power source fails (i.e. a fuse blows) or circuit
integrity to the trip coil is interrupted. A visual
indication is also supplied via a white indication light
mounted on the front of the generator protection panel. The
contacts from the monitoring relay can go to either the
Turbine control panel or customer DCS for alarm
2.4.3.2.3 GENERATOR BREAKER CONTROL SWITCH WITH STATUS LIGHTS (52G/CS)
The generator breaker control is through the Mark V [I]. The
52G/CS function provides a way to manually open the
generator breaker from the generator protection panel. This
breaker control switch is for TRIPPING ONLY, the breaker
can't be closed with it.
2.4.3.2.4 BREAKER DUAL COIL CROSS TRIPPING (94BG)
The standard panel has the capability to take full advantage
of redundant breaker trip coils when supplied on the
breaker. To take full advantage of the redundant breaker
coils (if supplied with the breaker) two separate dc sources
feed the trip coil circuits. The separation of sources is
normally via separate fusing. A high speed, low pickup
voltage auxiliary relay 94GB is placed in parallel with each
trip coil. Contacts from the relay in trip coil "A" circuit
are used to cross trip coil "B" and vice versa.
2.4.3.2.5 SYNCHRONIZING UNDERVOLTAGE RELAYS (27BS-1,2)
Undervoltage conditions can be present in a system due to
faults to ground, sudden energization of a considerable load
onto a loaded system, primary and backup regulator failure,
and when running up or coasting to a stop. The 27BS-1, and 2
are used with the Mark V synchronizing scheme to provide
additional inputs to help determine whether the generator
can be synchronized
<PAGE>
to a live or dead station bus. The Mark V logic alarms when
undervoltage conditions are present after the breaker has
closed.
2.4.3.2.6 GENERATOR DIGITAL METER (DMM)
This single meter provides the following functions:
1. VM - Generator Volts: 1-2, 2-3, 3-1
2. AM - Generator Amps: Phases 1,2,3 and Neutral
3. MWATTS - Generator MegaWatts
4. MVAR - Generator MegaVARs
5. FM - Generator frequency
6. MVA - Generator MVA
7. PF - Generator Power Factor
8. MWH - Generator MegaWatt-Hours
9. MVAH - Generator MVA Hours
2.4.3.2.7 BUS GROUND FAULT (59BN)
This protection scheme is designed to protect the system
(station bus) from faults to ground. The synchronous
generator is connected through a breaker to a step-up
transformer. The low voltage side of this transformer is
usually connected in a delta configuration. If one phase of
the system should go to ground, virtually no fault current
would flow. However, voltage reference in the delta
connection will be fixed at the ground fault location
causing the voltage vectors to be shifted. One set of PT's
connected in a Wye - Broken Delta configuration, in
conjunction with an overvoltage 59BN relay, are used to
detect such a fault.
2.4.3.2.8 DC BLOWN FUSE PROTECTION (74)
Each lockout tripping circuit is fused independently in the
generator protection panel. If the fuse of a particular
tripping bus is blown, the associated protective relays
cannot trip the lockout relay. The intent of this function
is to alert the operator when the dc voltage to the tripping
bus is lost. This loss of dc can be a result of either a
blown fuse or incoming dc source failure/low level.
<PAGE>
2.4.3.2.9 TRANSDUCERS (96GW1, GG1)
The main purpose of these transducers is to provide power
feedback to speed governing control in place of the
conventional fuel command feedback. The cases when this
function is required are:.
-- Constant Settable Droop (Gas Turbine of "Load
reference")
2.4.3.3 MARK V INTEGRATION
In addition to the relaying mounted in the generator
protection panel, the Mark V handles protection such as
generator temperature protection (49), synchronizing check
(25A), backup frequency and reverse power. Generator control
and monitoring is primarily accomplished via the Mark V
operator interface. The Mark V handles manual and
auto-synchronizing, speed raise/lower, voltage raise/lower,
and generator breaker control. The Mark V operator interface
also displays frequency and voltage for the generator and
bus, breaker status, field current and voltage, along with
the status of permissive. For the gas turbines connected to
a generator breaker, the Mark V auto/manual synchronizing
module will be capable of synchronizing across the generator
breaker and line breaker.
2.4.3.4 OPTIONAL PROTECTIVE FEATURES
The following additional protective features are
incorporated into a customized Generator Protective Panel.
This panel will be larger than the standard standard
generator panel.
2.4.3.4.1 SYSTEM BACKUP DISTANCE PROTECTION (21)
The distance relays are typically used instead of
overcurrent with voltage restraint when the lines leaving
the station bus have distance or pilot relay protection
schemes and the generator ties the station bus through a
step-up transformer.
This protection scheme is designed to protect the generator
from faults in the adjacent system which are not cleared by
the first line relays. It is used in lieu of 51V (system
phase fault over current relays with voltage restraint).
2.4.3.4.2 REVERSE/INADVERTENT ENERGIZATION PROTECTION (50RE/86RE)
This is also sometimes called: Accidental Energization, Back
Energization. Prior to the generator achieving rated speed,
the Mark V arms/enables the trip
<PAGE>
circuit ( using 14HS, i.e. 95% speed ) of the overcurrent
relay. A normally closed TMR contact is utilized in the Mark
V for maximum reliability both during normal operation and
during shutdowns ( i.e. Mark V powered down ). When the
turbine is above 95% speed the Mark V disarms the
overcurrent relay trip circuit, allowing the unit to be
synchronized.
An additional independent lockout 86RE is included to allow
the 86G fuses to be removed while the unit is shut down. The
trip contacts from the 86RE should trip customer upstream
breakers since the generator breaker trip coil may be
disabled (i.e. fuses removed during maintenance).
This protection scheme protects against inadvertent breaker
closure while the unit is at standstill, running up or down
in speed. One (1) three phase instantaneous overcurrent
relay 50RE is supervised by frequency/turbine speed
controlled outputs from the Mark V.
2.4.3.4.3 VOLTAGE BALANCE PROTECTION (60)
The 60 relay is used in this protection scheme is designed
to prevent the misoperation of protective relays and/or
regulator in the event of PT signal loss. In the event a
potential transformer fuse is blown or the PT voltage is
lost for any reason, the excitation ac regulator and certain
relays may operate incorrectly. (See Note below.) The relay
is operational only when the generator breaker is closed.
Both set of contacts ("a" and "b") are monitored by the
turbine control panel. If the 60 relay indicates a blown
fuse, the turbine panel will alarm and appropriate relay's
trips are blocked.
NOTE: The EX2000 has its own internal logic to transfer from
auto regulator to manual regulator in the event of a loss of
its PT feedback signal. So the "b" contact from the 60 relay
would not be required in that application. Also the DGP
relay has a VTFF ( voltage transformer fuse failure )
function that may be used for transfer or blocking functions
if it is connected to the appropriate PT's. Finally, several
of the functions that the 60 relay is normally used for
(e.g. blocking the 40, 51V and 32 ) are functions that are
in the DGP. The DGP software automatically disables these
functions if it detects a loss of its PT input signal.
2.4.3.5 ELECTRICAL SYSTEM INTEGRATION STUDY
All necessary studies and calculations required to integrate
the generator panel into the electrical system, including
short circuit, load flow, installation and protective device
coordination studies are by Owner.
<PAGE>
2.4.4 EX2000 DIGITAL EXCITATION SYSTEM
2.4.4.1 EX2000P DIGITAL, STATIC VOLTAGE REGULATOR FOR BUS FED
EXCITATION
The EX2000P is a digital, static, potential source
excitation system, utilizing the latest hardware and
software technology. To meet customer and operational
requirements, a full range of control and protection
functions are available for the product. A simplified
one-line diagram of the EX2000P with Hot Backup is shown
below.
[GRAPHIC OMITTED]
The EX2000P system comes equipped with a full-wave,
inverting, thyristor bridge which supplies excitation power
to the rotating field winding of the main AC generator. In
addition, all control and protective functions are
<PAGE>
implemented in the system software. Digital technology
coupled allows the EX2000P to maintain 99.98% availability.
The EX2000P is comprised of four basic components: 1) Power
Conversion Module; 2) Digital Controller; 3) Excitation
Transformer; and 4) Communication (ARCNET) Interface. The
following briefly describe these basic components.
2.4.4.1.1 POWER CONVERSION MODULE
A three phase, full-wave, inverting thyristor bridge is the
standard power conversion module for EX2000P digital
exciters. The inverting bridge provides both positive and
negative field forcing voltage for optimum performance.
Negative forcing provides fast response for load rejection
and de-excitation. Software changes of the firing circuits
can be made to suppress negative forcing if it is not
required for the system application. The standard current
capability of the bridge is 6% above the calculated rated
full load field current of the generator.
The thyristor bridge assembly is forced air cooled. These
blower assemblies are all energized during normal operation.
Thermostats are used to monitor the power conversion module
temperature. An alarm is provided for a high temperature
level and a trip at an even higher temperature level.
2.4.4.1.2 EXCITATION TRANSFORMER
The excitation transformer is more commonly referred to as
the input Power Potential Transformer (PPT). It is in a
separate enclosure from the exciter. The power to the
transformer can be obtained a station auxiliary bus. The
purpose of this transformer is to step the voltage down to
the required level for the excitation system.
With the use of a regulator in the static exciter, it is not
necessary to specify transformer full capacity taps, above
and below normal, on the primary winding. The transformer
rating is chosen so that the transformer can deliver the
excitation required for the application at 105% rated
generator terminal voltage on a continuous basis
2.4.4.1.3 DIGITAL CONTROLLER
The Digital Controller consists of five printed wire boards
mounted on the front door of the Power Conversion Module.
The cards included are the Main
<PAGE>
Processor Card, Microprocessor Application Card, Power
Supply and Instrumentation Card, Power Connect Card and LAN
Communications Card
2.4.4.1.4 COMMUNICATION (ARCNET) INTERFACE
For communications to the EX2000P, GE uses an ARCNET (local
area network) controller with modified ARCNET drivers. The
ARCNET controller adheres to standard ARCNET protocol
2.4.4.1.5 FEATURES AND FUNCTIONS
The exciter is enclosed in a NEMA-I stand alone enclosure
and contains the SCR power conversion module and regulator
with all standard control and protection functions, and
auxiliary functions such as de-excitation module, DC field
flashing module, and shaft voltage suppression circuit.
Standard features and functions and features included with
the EX2000P are listed below.
2.4.4.1.5.1 INTERFACE WITH THE GE SPEEDTRONIC MARK V TURBINE CONTROL
SYSTEM
The connection between the EX2000 and Mark V is accomplished
through a coaxial cable on the ARCNET LAN. Therefore, the
Mark V provides a digital window into the EX2000 through
which all pertinent variables can be monitored and
controlled (See Typical Mark V display - EX2000 variables).
Any or all of the following functions can be provided:
-- Voltage matching
-- VAR/PF controller
-- Selection of automatic or manual regulator
-- Raise/lower of the active regulator set-point
-- Enter set-point command
-- Start/stop
-- Field volts, amps and transfer volts
-- Status and alarms
-- Field temperature
<PAGE>
[GRAPHIC OMITTED]
2.4.4.1.5.2 DE-EXCITATION MODULE
Consisting of a thyristor and inductor for discharge of
stored field energy during unit shutdown or overvoltage
conditions
2.4.4.1.5.3 AC DISCONNECT
No load break disconnect switch to disconnect the EX2000
rectifier from the PPT.
2.4.4.1.5.4 SURGE PROTECTION
Including AC line-to-line RC filters sized to limit
commutation overshoot voltage on the thyristors.
<PAGE>
2.4.4.1.5.5 THYRISTOR BRIDGE CONDUCTION MONITOR
Detects loss of thyristor current conduction due to a blown
fuse, open or shorted thyristor, or faulty firing circuits.
2.4.4.1.5.6 BUILT-IN DIAGNOSTIC DISPLAY PANELS
If a problem occurs, a fault code appears in the programmer
displays. A 10 character alphanumeric diagnostic display
with keypad is provided in each exciter bridge/control core
of the exciter.
2.4.4.1.5.7 AUTOMATIC VOLTAGE REGULATOR (AVR)
Provides automatic control of generator terminal from no
load to full rated load.
2.4.4.1.5.8 MANUAL VOLTAGE REGULATOR (FVR)
Provides manual control of generator field excitation.
2.4.4.1.5.9 SOLID STATE AUTOMATIC AND MANUAL REGULATOR REFERENCE
ADJUSTERS
Allow each regulator reference set-point to increase or
decrease in response to "Raise" and Lower" signals from the
operator. The settings of the upper and lower limits and
up/down ramp times are adjustable.
2.4.4.1.5.10 AUTOMATIC AND MANUAL REFERENCE FOLLOWERS
Adjust the non-active regulator output to automatically
track the active regulator.
2.4.4.1.5.11 VOLTS/HERTZ PROTECTION (24EX)
This function serves as backup to the Volts/Hertz Limiter.
2.4.4.1.5.12 GENERATOR TIME OVERVOLTAGE (59EX)
This function monitors the generator armature voltage and
will initiate an alarm and or a trip signal upon detecting
an acceptably high voltage.
<PAGE>
2.4.4.1.5.13 BRIDGE AC VOLTAGE INPUT PHASE VOLTAGE UNBALANCE ALARM
This function will initiate an alarm if the bridge AC input
phase has excessive line dip or imbalance which persists to
long.
2.4.4.1.5.14 BRIDGE AC INPUT PHASE UNBALANCE (47EX)
This function will initiate a trip if the bridge AC input
phase has excessive line dip or imbalance persists to long.
2.4.4.1.5.15 REACTIVE CURRENT COMPENSATION (RCC)
Voltage droop for sharing reactive current between
paralleled machines or "line drop" compensation for
regulating voltage at some point remote from the generator
terminals.
2.4.4.1.5.16 SHAFT VOLTAGE SUPPRESSOR
Limits shaft voltage caused by thyristor commutation to aid
in protecting generator journals and bearings against shaft
currents caused by the excitation system..
2.4.4.1.5.17 DUAL SOURCE INTERNAL POWER SUPPLY
The 125 VDC battery supply and an internal ac supply fed
from the PPT are applied to this power supply. Should loss
occur in either of these sources, the power supply will
utilize the available source without interrupting exciter
operation.
2.4.4.1.5.18 GENERATOR FIELD FLASHING
Application circuit - utilizing station battery supply to
flash the field.
2.4.4.1.5.19 GENERATOR FIELD GROUND DETECTOR (64F)
Utilizing square wave modulation, this detector sweeps over
the entire field windings so that there are no dead bands,
detecting field leakage current between any point in the
field windings and ground.
2.4.4.1.5.20 SOFT STARTUP
Automatic startup sequencing provides a soft start when
flashing under AVR control with negligible terminal voltage
overshoot during startup.
<PAGE>
2.4.4.1.5.21 GLOBAL ALARM (30EX)
Contact output indicating exciter trouble.
2.4.4.1.5.22 EXCITER TRIP (94EX)
Contact output simultaneous trip request indicating exciter
failure. Typically used to trip 86G.
2.4.4.1.5.23 VT DISCONNECT AND CT SHORTING BLOCKS
Used to isolate the VT and CT feedback signals from the
voltage regulator.
2.4.4.1.5.24 GENERATOR VOLTAGE SENSING
All three phases of the generator VT are monitored and used
in regulating generator volts.
2.4.4.1.5.25 GENERATOR CURRENT SENSING
Phase A and C of the generator CT's are used for regulating
and monitoring generator current.
2.4.4.1.5.26 GENERATOR SIMULATOR FOR EXCITER OPERATOR TRAINING AND
PROTECTION SETUP
For use when the generator is not operating.
2.4.4.1.5.27 POWER SYSTEM STABILIZER (PSS)
This function is incorporated into the exciter system
software. A signal representing the integral of accelerating
power is introduced into the automatic voltage regulator
algorithm to increase the generators ability to produce and
transmit large power levels in a stable manner by reducing
low frequency rotor oscillations
2.4.4.1.5.28 PROTECTION MODULE
This module is separate from the main controller and serves
as a backup to the limiters located within the controller.
The protection module allows the separation of control and
protection into two separate systems. The output of the
protection package drives contacts that are used for
transfer to backup (hot backup) and alarm (30EX), or trip
purposes (94EX). The protection features provided are as
follows:
<PAGE>
-- Volts/Hertz, Dual Level (24EX)
-- Generator Overvoltage (59EX)
-- Off/On-Line Overexcitation (76EX)
-- Bridge AC Phase Unbalance (47EX)
-- Loss of Excitation (40EX)
2.4.4.1.5.29 LOSS OF EXCITATION (40EX)
Loss of excitation (or loss of field) results in loss of
synchronism and operation of the generator as an inductive
machine
2.4.4.1.5.30 SPARE POWER CONVERSION MODULE TO SERVE AS HOT BACKUP
For those applications where the customer requires
redundancy, the "Hot Backup" option is provided. This
feature utilizes a complete digital controller and rectifier
bridge as a backup to the primary controller and bridge.
During normal operation, the Hot Backup module receives the
same input as the primary module, but its output feeds a
small dummy load as opposed to the generator field.
If the protection module senses a condition that would
normally initiate a trip signal, it will force a transfer to
the Hot Backup module before the trip contact is necessary.
The transfer to Hot Backup is "on-the-fly" in the sense that
the transfer occurs with the generator on-line and does not
affect generator output
2.4.4.1.5.31 SECOND DC FIELD CONTACTOR
Field interrupting dc contactor in the hot backup rectifier
bridge output dc-positive line.
2.4.4.1.6 PERFORMANCE
The EX2000P bus fed excitation system is a High Initial
Response (HIR) potential source exciter based on IEEE std
421.5 (will reach 95% ceiling generator field voltage in
less than 100ms.)
2.4.4.1.7 ELECTRICAL SYSTEM INTEGRATION
All necessary studies and calculations required to integrate
the EX2000 into the Owners electrical system, including
short circuit, load flow, insulation,
<PAGE>
protective device coordination studies, and power system
stabilizer studies are by Owner.
--------------------------------------------------------------------------------
2.5 OTHER GAS TURBINE FEATURES
2.5.1 GAS TURBINE PERFORMANCE MONITORING INSTRUMENTATION
-- Compressor bellmouth static and differential pressure
transmitters
-- Compressor inlet RTDs
2.5.2 GENERATOR LINE-SIDE COMPARTMENT DRAWOUT PTS
-- Excitation (1 set)
-- Relaying (1 set)
2.5.3 STATIC START SYSTEM
2.5.3.1 OPERATION
Using existing ac drive technology, GE will furnish a
Load-Commutating Inverter(LCI) adjustable frequency drive as
the starting means for the gas turbine.
The static starting system can accelerate the gas
turbine-generator without imposing high inrush currents with
resulting voltage disturbance on the A.C. station service
line. This system will provide variable frequency power
directly to the generator terminals, using the generator as
a synchronous motor to start the gas turbine. The generator
will be turning at approximately 4 RPM, via a low speed
turning gear, prior to starting. With signals from the
turbine control, the LCI will accelerate or decelerate the
generator to a self sustaining speed required for purge,
light-off , waterwash etc. Deceleration is a coast-down
function.
Starting excitation is provided by GE's EX2000 excitation
system
Conventional, 3-phase , 12-pulse bridge circuits are used
for the rectifier and inverter and are connected through a
dc link inductor. A transformer provides 3-phase power,
impedance for fault protection, and electrical isolation
from system disturbances to ground.
<PAGE>
The drive system protective strategy is to provide a high
level of fault protection for the major equipment. The
protective relaying includes phase overcurrent, ground fault
and motor protection. The rectifier inverter will include
voltage surge protection and full fault suppression
capability for internal faults or malfunctions. A drive
system monitor and diagnostic fault indications continuously
monitor the condition and operation of the LCI.
The following equipment is provided as part of the static
start system:
2.5.3.2 LOW SPEED TURNING GEAR
The gear assembly is located on the collector end of the
generator and is used for slow speed operation (approx. 4
RPM), cooldown and standby turning and rotor breakaway
during startup.
2.5.3.3 POWER CONVERSION EQUIPMENT
The LCI power conversion equipment is mounted in a NEMA 4
ventilated enclosure and consists of the following:
-- One (1) 12-pulse converter with series redundant
thyristor cells to rectify ac line power to controlled
voltage dc power.
-- One (1) inverter with series redundant cells to convert
dc link power to controlled frequency ac power.
-- Cooling Fan and Electrical Filter Compartment: Two (2)
ventilation fans are provided to cool the inverter
section. The dc filters provide protection from voltage
spikes as well as providing sufficient latching current
to turn on the SCR's.
-- Control Panel
The control panel is located in a NEMA 1 enclosure. It
contains the microprocessor system control logic for firing,
drive sequencing, diagnostics and protective functions,
acceleration (ramping function), excitation system interface
and input/output signal interfacing. Door mounted panel
meters and operator devices are also provided.
2.5.3.4 DC LINK REACTOR
The dc link is a dry-type air-core reactor, convection
cooled, located in an outdoor protective enclosure.
<PAGE>
It is electrically connected between the converter and the
inverter. The inductor helps smooth the dc current to
eliminate coupling between the frequencies of the converter
and inverter. The dc link also provides protection during
system faults by limiting the current.
Reactor rating is as follows:
-- 890 amps dc continuous,
-- Inductance - 20 millineries
-- 5000v to ground
-- Momentary fault capacity of 13,000 amperes and braced
to withstand 30,000 amperes peak asymmetrical fault
for 1/2 Hz
-- Class H insulation
2.5.3.5 FUSED CONTACTOR (4160 VOLT)
Contains 4160 volt fused contactor for circuit isolation
under normal conditions. The fuse is rated to interrupt the
current if a fault occurred in the inverter section during
startup.
2.5.3.6 ISOLATION TRANSFORMER
The isolation transformer is an oil-filled type and is
located in an outdoor weather-protected enclosure. It
provides electrical isolation and impedance for system
protection against notching and harmonic distortion. The
transformer is designed for service with a three phase,
twelve pulse power converter connected to the secondary
winding.
One transformer is provided for each two gas turbine-
generators.
Transformer rating as follows:
-- 5500 KVA, 4160V pri-4160 / dual 480VAC sec
-- 1250 KVA exciter winding- 515v, 3 phase, 60 hz
-- Impedance 6%
-- Ambient 30DEG.C average, 50DEG.C maximum
-- Altitude 3300 ft above sea level
<PAGE>
-- Delta connected primary, BIL 95 KV
-- Wye connected secondary
-- Delta connected exciter winding
-- BIL 60 KV
-- Continuous voltage to ground
-- 5.2 KV
2.5.3.7 MOTORIZED DISCONNECT SWITCH
Each static start motor-operated generator three pole
disconnect switch is rated at 18 KV, 1250 A continuous, 80
KA momentary, no load break. They are separately mounted and
is electrically connected between the inverter and the feed
for the generator stator.
TURBINE CONTRACT APPENDIX A-2
<PAGE>
4. COMPONENT PERFORMANCE
------------------------------------------------------------------------------
4.1 ESTIMATED GAS TURBINE PERFORMANCE
<PAGE>
TURBINECONTRACT APPENDIX A-4 COVER
<PAGE>
TURBINE CONTRACT APPENDIX A-4
[*] The following four (4) pages have been omitted and filed separately with
the Securities and Exchange Commission as part of a Confidential Treatment
Request.
<PAGE>
6. PERFORMANCE CURVES
-------------------------------------------------------------------------------
6.1 TURBINE AND GENERATOR PERFORMANCE CURVES
6.1.1 GAS TURBINE CURVES
<TABLE>
<CAPTION>
CURVE NUMBER DATE
<S> <C> <C>
Estimated Single Unit Performance, Base (gas fuel) 522HA851 4/17/98
Compressor Inlet Temperature Corrections, Base (gas fuel) 522HA852 4/17/98
Modulated Inlet Guide Vane Effect (gas fuel) 522HA853 4/17/98
Estimated Single Unit Performance, Base (oil fuel) 544HA223 5/26/99
Compressor Inlet Temperature Corrections, Base (oil fuel) 544HA225 5/26/99
Modulated Inlet Guide Vane Effect (oil fuel) 544HA224 5/26/99
Altitude Correction Factor for Turbine 4l6HA662A 4/24/90
Humidity Effects Curve 498HA697B 10/10/89
</TABLE>
6.1.2 GAS TURBINE HYDROGEN COOLED GENERATOR PERFORMANCE CURVES
<TABLE>
<CAPTION>
CURVE NUMBER
<S> <C>
Estimated Saturation and Synchronous Impedance Curve 80203G1-1
Estimated Generator Reactive Capability Curve 80203G1-2
</TABLE>
<PAGE>
<TABLE>
<S> <C>
Estimated Excitation V Curve 80203G1-3
Generator Output as a Function of Cold Gas Temperature 80203G1-7A
Generator Output as a Function of Cold Liquid Temperature 80203G1-7B
Voltage - Frequency Capability Curve 80203G1-VF
</TABLE>
6.1.3 GAS TURBINE STARTUP CURVES AND DURATION CURVE
<TABLE>
<CAPTION>
CURVE NUMBER
<S> <C>
Typical 7FA Gas Turbine Startup Curve
LCI Start
DLN 2.6
</TABLE>
6.1.4 GAS TURBINE ALLOWABLE LOAD CHANGE RATES
During normal load, the unit can be loaded from FSNL to base load
in 12 minutes. During fast load, the unit can be loaded from FSNL
to base load in 4 minutes.
<PAGE>
The following is a description of information which cannot be submitted
electronically:
APPENDIX 6 - PERFORMANCE CURVES
GENERAL ELECTRIC MODEL PG7241(FA) GAS TURBINE
Page 4.2 Estimated Performance - Configuration: DLN Combustor
Compressor 59 F (15 C), 60% Relative Humidity Atmospheric Pressure
14.7 psia (1.013 bar)
Page 4.3 Effect of Compressor Inlet Temperature on Output, Heat Rate, Heat
Consumption, Exhaust Flow and Exhaust Temperature at Baseload
Page 4.4 Effect of Inlet Guide Vane on Exhaust Flow and Temperature As a
Function of Output and Compressor Inlet Temperature
GENERAL ELECTRIC GAS TURBINE ALTITUDE CORRECTION FACTOR
Page 4.5 Altitude Vs Atmospheric Pressure And Altitude Vs Correction Factor
For Gas Turbine Output and Fuel Consumption
GENERAL ELECTRIC MS6001, MS7001 AND MS9001 GAS TURBINES
Page 4.6 Corrections to Output and Heat Rate For Non-Iso Specific Humidity
Conditions For Operation At Base Load On Exhaust Temperature
Control Curve
ESTIMATED SATURATION AND SYNCHRONOUS IMPEDANCE CURVES
Page 4.7 198900 KVA - 3600 RPM - 18000 VOLTS - 0.90 PF
335 FLD VOLTS - 45 C COLD GAS - 30 PSIG H2
ESTIMATED REACTIVE CAPABILITY CURVES
Page 4.8 198900 KVA - 3600 RPM - 18000 VOLTS - 0.90 PF
335 FLD VOLTS - 45 C COLD GAS - 30 PSIG H2
ESTIMATED EXCITATION V CURVES
Page 4.9 198900 KVA - 3600 RPM - 18000 VOLTS - 0.90 PF
335 FLD VOLTS - 45 C COLD GAS - 30 PSIG H2
GENERATOR OUTPUT AS A FUNCTION OF COLD GAS TEMPERATURE
Page 4.10 198900 KVA - 3600 RPM - 18000 VOLTS - 0.90 PF
335 FLD VOLTS - 45 C COLD GAS - 30 PSIG H2
GENERATOR OUTPUT AS A FUNCTION OF COLD LIQUID TEMPERATURE
Page 4.11 198900 KVA - 3600 RPM - 18000 VOLTS - 0.90 PF
335 FLD VOLTS - 45 C COLD GAS - 30 PSIG H2
PG7241FA GAS TURBINE TYPICAL STARTUP CHARACTERISTICS (@ISO CONDITIONS; NG FUEL)
TURBINECONTRACTAPPENDIXA-6
<PAGE>
7. DIVISION OF RESPONSIBILITY/SUPPLY BY OTHERS
To provide a complete operational installation, additional equipment and
services not included in this proposal must be provided by the customer
or the installer. These include, but are not limited to, the following:
7.1 CIVIL
- Foundation design and construction with all embedments including
sub-sole plates, anchor bolts, and conduit
- Grounding grid and connections
- Necessary drainage, including sumps and piping
7.2 MECHANICAL
- Gas fuel in accordance with GEI-41040, Process Specification Fuel
Gases for Combustion in Heavy-Duty Gas Turbines (see Reference
Documents chapter)
- Gas fuel heated to 50 o F above its dew point.
- Gas supply shutoff valve located remotely from the unit
7.2.1 CUSTOMER GAS FUEL SYSTEM SUPPLY REQUIREMENTS
1. The gas fuel pressures specified in this document are
referenced to FG1. This point identifies the purchaser
connection as shown on the Purchaser Connection Drawing.
2. The fuel gas delivered to the turbine is to meet the most
recent revision of the Process Specification Fuel Gases For
Combustion in Heavy-Duty Gas Turbines - GEI-41040.
3. Maximum supply pressure excursions are limited to either 1%
per second ramp or 5% step. The 1% per second ramp is
applicable over the range of minimum pressure requirement
to maximum operating pressure. The 5% step is applicable
over the range of minimum
<PAGE>
pressure requirement to 95% of maximum operating pressure
and with a maximum of one 5% step change in 5 seconds.
4. Provide over-pressure protection, (including safety valve
accumulation), such that the maximum mechanical design
pressure is not exceeded at FG1.
- FUEL SUPPLY PRESSURE REQUIREMENTS
<TABLE>
<CAPTION>
MEASUREMENT VALUE
<S> <C>
Model Series PG7241
Combustor DLN 2.6
Maximum Mechanical Design Pressure psig (kPa) 575
Maximum Operating Pressure psig (kPa) 475
Minimum required pressure psig (kPa) 415
Maximum temperature at minimum pressureDEG.F(DEG.C) 120
Customer fuel modified Wobbe Index LATER
</TABLE>
NOTES:
1. The minimum pressure is specified at FG1 with respect to the model
series, fuel temp, ambient conditions, combustor, and customer design
fuel.
2. Maximum mechanical design pressure is specified to provide over-pressure
protection, (including safety valve accumulation), such that the maximum
mechanical design pressure value is not exceeded at FG1.
3. Maximum operating pressure refers to the maximum turndown capability of
the speed ratio valve.
4. Minimum pressure required is referenced to the coldest ambient
temperature and the maximum fuel temperature. This value is applicable
across the range of operation.
5. Minimum fuel temp required superheat above the hydrocarbon dewpoint at
FG1 is quoted in GEI41040.
6. The Modified Wobbe Index allowable variation from that quoted in the
table is +/- 5%.
<PAGE>
[GRAPHIC]
- Liquid fuel in accordance with GEI-41047, Gas Turbine Liquid Fuel
Specifications (see Reference Documents chapter)
- Storage tank(s), fuel forwarding and piping to the liquid
fuel atomizing air skid inlet
- Piping from the skid outlet to the turbine inlet connection
Note: Customer shall provide fuel analyses of actual operating
fuel(s) 30 days prior to the first fire of the gas turbine
- Distillate fuel forwarding skid
- Mineral lube oil in accordance with GE Lube Oil Recommendations
(see Reference Documents chapter)
- Inlet System
- Inlet heating interconnecting piping
- Exhaust System
- Exhaust duct/stack
<PAGE>
- External exhaust system finish paint including any tie
coats
- Demineralized water for the water injection system in accordance
with the following:
<TABLE>
<S> <C>
Total solids 5 ppm max
Total trace metals: sodium + potassium + 0.5 ppm max
lithium + vanadium + lead)
pH 6.5 - 7.5
</TABLE>
- Where contaminants are present in the water, the total limits in
the fuel, water and air should be controlled such that the total
concentration equivalent in the fuel (from all sources) conforms
to the following limits:
<TABLE>
<CAPTION>
CONTAMINANT MAX. EQUIVALENT
CONCENTRATION (PPM-WEIGHT)
<S> <C>
Sodium plus Potassium plus lithium 1.0
Lead 1.0
Vanadium 0.5
Calcium 2.0
</TABLE>
- The water quality requirement can generally be satisfied by
demineralized water.
- Coolant in accordance with GE cooling system specifications for gas
turbine lubrication, turbine supports, atomizing air and generator
cooling systems (see Reference Documents chapter)
- Vent and drain piping or ducting, as needed
- Unit walkways by GE
- Water for compressor cleaning system in accordance with GEK-103623, Gas
Turbine Compressor Washing--Liquid Washing Recommendations (see Reference
Documents chapter)
- Starting System
- LCI heat exchanger piping
- LCI system cables
<PAGE>
- LCI isolation transformer breaker and protection
- Start-up PPT overcurrent relays
- Miscellaneous Systems
- Station instrument air
- Station instrument air for start-up
- Interconnecting piping between the accessory compartment and
liquid fuel/atomizing air skid
-
7.3 ELECTRICAL
- AC electric power for gas turbine auxiliaries
- Electric power for station auxiliaries
- Line side current and potential transformers
- Generator circuit breaker
- ISO phase bus duct
- Interconnecting cables
7.4 INSTALLATION/ERECTION
- Transportation from the nearest rail siding, unloading, placement
on foundation and installation of the equipment offered in this
Proposal
- Construction services including electric power, lighting,
temporary heaters, test equipment, compressed air, crane(s) and
all required standard tools
- Storage and security for equipment received
- Finish paint including any special external finish paints required
for corrosion protection with any required tie coats
<PAGE>
- Interconnecting piping between the turbine-generator equipment and
/ or auxiliary skids, such as cooling water, water wash, exhaust
frame blowers, and fire protection systems, as applicable
- Perform necessary preoperational work
- Cables and bus duct as follows:
-- Control cables between controls equipment (or control cab
if supplied), fuel forwarding system, remote control
panels, customer devices, other off-base devices and
auxiliary skids
-- Power cables between the generating units, controls
equipment (or control cab), fuel forwarding system, remote
panels, customer devices, other off-base devices and
auxiliary skids
- Access, necessary authorizations, and office facilities for GE
personnel required during installation and start-up
7.5 START-UP/TEST
- Operating personnel for starting, preliminary runs and tests
- Lubricating fluid, greases, CO2, and supplies for starting,
preliminary runs, tests and normal operation thereafter
- Fuel and load for tests
- All field performance tests will be as described in Appendix C.
TURBINECONTRACTAPPENDIXA-7
<PAGE>
8. CODES AND STANDARDS
8.1 GAS TURBINE-GENERATOR
GE considers the applicable sections of the
following US and ISO codes and standards to be
the most relevant for the gas turbine equipment.
Our designs and procedures are generally
compliant with the applicable section for the
following:
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
ANSI/ASCE 7-1993 Minimum Design Loads for Buildings and Other Structures
(Used for snow loads)
---------------------------------------------------------------------------------------------
ANSI/ASME B1.1-1989 Unified Inch Screw Threads (GE complies at the
customer's connection)
---------------------------------------------------------------------------------------------
ANSI/ASME B1.20.1-1983 (R1992) General Purpose (Inch) Pipe Threads
---------------------------------------------------------------------------------------------
ANSI/ASME B16.5-1996 Pipe Flanges and Flanged Fittings
---------------------------------------------------------------------------------------------
ANSI/ASME B16.9-1993 Factory-Made Wrought Steel Butt Welding Fittings
---------------------------------------------------------------------------------------------
ANSI/ASME B16.21-1992 Nonmetallic Flat Gaskets for Pipe
Flanges (Spiral-wound gaskets per API 601 may be
used, particularly in turbine compartment piping.)
---------------------------------------------------------------------------------------------
ANSI/ASME B31.3-1996 Chemical Plant and Petroleum Refinery Piping Gas
turbine piping systems comply, with the exceptions
to the following paragraphs:
6.6.1 The standard factory performance
test serves as the leak test for
all gas turbine piping systems on
units and peripheral skids/hardware
except as noted on 6.6.2.
6.6.2 Fuel gas steam injection systems
are tested as individual
fabrications at 1.5 times their
design operating pressures.
---------------------------------------------------------------------------------------------
ANSI/ASME PTC-36-1985 Measurement of Industrial Sound (Used for Near-field
Measurements Only)
---------------------------------------------------------------------------------------------
ANSI B133.2-1997 Basic Gas Turbine. GE complies, with the following
exception to paragraph 8.5:
Loose items such as jackscrews and eyebolts are not
furnished. Provisions for use of such items are not
included in the design.
---------------------------------------------------------------------------------------------
ANSI B133.3-1981 (R1994) Gas Turbine-Procurement Standard-Auxiliary Equipment
(GE complies fully with design portions only.
GE uses its own lube oil flushing procedure.
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
Atomizing air receiver is not applicable.)
---------------------------------------------------------------------------------------------
ANSI B133.4-1978 (R1997) Gas Turbine Control and Protection Systems
---------------------------------------------------------------------------------------------
ANSI B133.5-1978 (R1990) Gas Turbine Electrical Equipment
---------------------------------------------------------------------------------------------
ANSI B133.8-1977 (R1989) Gas Turbine Installation Sound Emission (Used for
Far-field Measurements Only)
---------------------------------------------------------------------------------------------
ANSI/NFPA 12-1998 Carbon Dioxide Extinguishing Systems
---------------------------------------------------------------------------------------------
ANSI/NFPA 70-1999 National Electrical Code (Electrical components are
designed to meet the intent of this Code for Class
1, Group D, Div. 2, Hazardous area classification,
where appropriate.)
---------------------------------------------------------------------------------------------
ANSI/IEEE C37-1995 Guides and Standards for Circuit Breakers, Switchgear,
Substations and Fuses
---------------------------------------------------------------------------------------------
ANSI/IEEE C37.1-1994 Definition, Specification and Analysis of Systems Used
for Supervisory Control, Data Acquisition and Automatic
Control
---------------------------------------------------------------------------------------------
ANSI/IEEE C37.2-1996 Electrical Power System Device Function Numbers (GE
complies with respect to device designations except
that, in a few cases, device numbers were modified
or added to fit GE's needs.)
---------------------------------------------------------------------------------------------
ANSI/IEEE C37.90.1-1989 (R 1994) Surge Withstand Capability (SWC) Tests for Protective
Relays and Relay Systems (Salem Controls)
---------------------------------------------------------------------------------------------
ANSI/IEEE C57-1995 Compilation of all C57 Standards
---------------------------------------------------------------------------------------------
ANSI C50.10-1990 Rotating Electrical Machinery - Synchronous Machines
---------------------------------------------------------------------------------------------
ANSI C50.13-1989 Rotating Electrical Machinery - Cylindrical Rotor
Synchronous Generators
---------------------------------------------------------------------------------------------
ANSI C50.14-1977 (R1989) Requirements for Combustion Gas Turbine-Driven
Cylindrical Rotor Synchronous Generators (GE does
not provide a peak reserverating. Not all of the
prototype tests indicated in Table 2 have
necessarily been conducted.)
---------------------------------------------------------------------------------------------
ANSI/IEEE 100-1996 Dictionary of Electrical and Electronics Terms
---------------------------------------------------------------------------------------------
NEMA MG1-1993 Motors and Generators
---------------------------------------------------------------------------------------------
NEMA MG2-1989 Safety Standard for Construction and Guide for
Selection, Installation and Use of Electric Motors and
Generators
---------------------------------------------------------------------------------------------
NEMA TR1-1993 Transformers, Regulators and Reactors
---------------------------------------------------------------------------------------------
ANSI S1.4-1983 Specification for Sound Level Meters
---------------------------------------------------------------------------------------------
ANSI S1.13-1971 (R1986) Methods for the Measurement of Sound Pressure Levels
---------------------------------------------------------------------------------------------
ANSI/SAE/J184-Feb. 87 Qualifying a Sound Data Acquisition System
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
AGMA 6011-G92 Specification for High-Speed Helical Gear Units
(Used for accessory gear and load gear except for
service factor.)
---------------------------------------------------------------------------------------------
UBC-1994 Uniform Building Code (Used for wind loads and seismic
design)
---------------------------------------------------------------------------------------------
ANSI/IEEE 421.1-1986 Definitions for Excitation Systems for Synchronous
Machines
---------------------------------------------------------------------------------------------
EIA/TIA RS-232E-1991 Interface between Data Terminal Equipment and Data
Circuit Terminating Equipment Employing Serial Binary
Interchange
---------------------------------------------------------------------------------------------
</TABLE>
The GE Gas Turbine Drafting Standards are
based on the following as appropriate to the
gas turbine. Please note that in several
instances (symbols, etc.) have been devised
for GE's special needs (such as flow divider
and manifolds):
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
ANSI/ASME B46.1-1985 Surface Texture
---------------------------------------------------------------------------------------------
ANSI Y14.5M-1982 (R1988) Dimensioning and Tolerancing
---------------------------------------------------------------------------------------------
ANSI Y14.15-1966 (R1988) Electrical and Electronics Diagrams (On-base gas
turbine and accessory base equipment)
---------------------------------------------------------------------------------------------
ANSI Y14.17-1966 Fluid Power Diagrams
---------------------------------------------------------------------------------------------
ANSI Y14.36-1978 Surface Texture Symbols
---------------------------------------------------------------------------------------------
ANSI/IEEE 315-1975 (R1994) Graphic Symbols for Electrical and Electronics Diagrams
---------------------------------------------------------------------------------------------
ANSI Y32.10-1967 (R1987) Graphical Symbols for Fluid Power Diagrams
---------------------------------------------------------------------------------------------
ANSI Y32.11-1961 (R1993) Graphic Symbols for Process Flow Diagrams in the
Petroleum and Chemical Industries
---------------------------------------------------------------------------------------------
ANSI/ASME Y32.2.3-1949 (R1988) Graphical Symbols for Pipe Fittings, Valves and Piping
---------------------------------------------------------------------------------------------
ANSI/AWS A2.4-1993 Symbols for Welding, Brazing and Nondestructive
Examination
---------------------------------------------------------------------------------------------
ASME Section VIII, Division 1 - Boiler and Pressure Vessel Code--Pressure Vessels (for
1990 Stator Frame Welds)
---------------------------------------------------------------------------------------------
ISO 7919-1-1986 Mechanical Vibrations - Measurements on Rotating Shafts
and Evaluation
---------------------------------------------------------------------------------------------
ISO 10816 (Draft) Mechanical Vibrations - Evaluation of Machine Vibration
by Measurements of Non-rotating Parts
---------------------------------------------------------------------------------------------
TEMA C, 7th Edition Mechanical Standards for Class C Heat Exchangers (for
Commercial Coolers)
---------------------------------------------------------------------------------------------
OSHA Regulation No. 1910-179-1995 Crane Lifts; Factor of Safety
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
8.2 RESERVED
8.3 OTHER CODES AND STANDARDS OF PRACTICE
In the event conflicts arise between the codes and standards of
practice described herein and codes, laws, rules, decrees,
regulation, standards, etc., of the Owner and/or country where
the equipment is to be installed, the codes and standards of
practice described herein will govern. If the Owner desires
other codes and standards of practice to be utilized by GE or
its Suppliers, they will be subject to negotiation and mutual
agreement between the Owner and GE.
---------------------------------------------------------------
WARNING
MANUFACTURED WITH 1.1.1-TRICHLOROCTHANE, CFC-113 AND TCA, AND
CONTAINS HALON-1301, HCFC-22 AND FREON-113, SUBSTANCES WHICH
HARM PUBLIC HEALTH AND ENVIRONMENT BY DESTROYING OZONE IN THE
UPPER ATMOSPHERE.
---------------------------------------------------------------
8.4 CODES AND STANDARDS ORGANIZATION LISTING
Below is a list of the organizations with the
addresses and phone numbers where codes and
standards or related information can be
purchased:
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
AGMA American Gear Manufacturer's Association
1500 King Street, Suite 201
Alexandria, Virginia 22314 703-684-0211
---------------------------------------------------------------------------------------------
ANSI American National Standards Institute (Sales)
11 West 42nd Street, 13th Floor
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
New York, New York 10036 212-642-4900 Phone 212-302-1286 Fax
---------------------------------------------------------------------------------------------
ASCE American Society of Civil Engineers
345 East 47th Street
New York, New York 10017-2398 800-548-2723
---------------------------------------------------------------------------------------------
ASME The American Society of Mechanical Engineers
22 Law Drive, Box 2900
Fairfield, NJ 07007-2900 201-882-1167
---------------------------------------------------------------------------------------------
AWS American Welding Society
550 N. Lejeune Road
Miami, Florida 33126 305-443-9353
---------------------------------------------------------------------------------------------
EIA Electronic Industries Association
Global Engineering Documents (Distributor)
1990 M Street, Suite 400
Washington, D.C. 20036 800-854-7179
---------------------------------------------------------------------------------------------
IEEE Institute of Electrical and Electronic Engineers, Inc.
345 East 47th Street
New York, New York 10017 212-705-7900
---------------------------------------------------------------------------------------------
ISO International Organization for Standardization
Case Postal 56
CH-1211
Geneva 20, Switzerland
Contact ANSI - (212-642-4900)
---------------------------------------------------------------------------------------------
NEMA National Electrical Manufacturer's Association (Publications)
2101 L Street, N.W.
Washington, D.C. 20037 202-457-8400 Phone 202-457-8473 Fax
---------------------------------------------------------------------------------------------
NFPA National Fire Protection Association
1 Batterymarch Park
P.O. Box 9146
Quincy, MA 02269-9146 1-800-344-3555
---------------------------------------------------------------------------------------------
OSHA Office of Safety & Health Standards
U.S. Department Of Labor
200 Constitution Avenue, NW - Room N3101
Washington, D.C. 20210 202-219-4667
---------------------------------------------------------------------------------------------
TEMA Tubular Exchanger Manufacturers Association
25 North Broadway
Tarrytown, NY 10591
914-332-0040
---------------------------------------------------------------------------------------------
UBC Uniform Building Code
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
International Conference of Building Officials
5360 South Workman Mill Road
Whittier, CA 90601
310-699-0541
---------------------------------------------------------------------------------------------
</TABLE>
TURBINECONTRACTAPPENDIXA-9
<PAGE>
9. DATA SHEETS
9.1 TECHNICAL DATA
The following technical data is typical for the size and type
of unit proposed and except for that information specifically
identified as being guaranteed, this data is preliminary in
nature and subject to change based on final equipment design
and component selection.
9.1.1 GAS TURBINE
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Type Heavy duty
---------------------------------------------------------------------------------------------
Stages 3
---------------------------------------------------------------------------------------------
Configuration Single shaft, 2 bearing
---------------------------------------------------------------------------------------------
Operating speed 3600 rpm
---------------------------------------------------------------------------------------------
Critical speeds
---------------------------------------------------------------------------------------------
First rpm
---------------------------------------------------------------------------------------------
Laterial 1154
---------------------------------------------------------------------------------------------
Torsional 1309
---------------------------------------------------------------------------------------------
Second rpm
---------------------------------------------------------------------------------------------
Laterial 1212
---------------------------------------------------------------------------------------------
Torsional 7403
---------------------------------------------------------------------------------------------
Third rpm
---------------------------------------------------------------------------------------------
Laterial 2066
---------------------------------------------------------------------------------------------
Torsional 10305
---------------------------------------------------------------------------------------------
Fourth rpm (laterial) 3044
---------------------------------------------------------------------------------------------
Fifth rpm (laterial) 3162
---------------------------------------------------------------------------------------------
Maximum tip speed 1615 fps
---------------------------------------------------------------------------------------------
Trip speed
---------------------------------------------------------------------------------------------
Electrical 3960 rpm
---------------------------------------------------------------------------------------------
Maximum temperature 2420DEG.F
---------------------------------------------------------------------------------------------
First stage rotor bucket material
---------------------------------------------------------------------------------------------
Metal *DS-GTD-111
---------------------------------------------------------------------------------------------
Coating GE proprietary coating
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
Second stage rotor bucket material
---------------------------------------------------------------------------------------------
Metal DS-GTD-111
---------------------------------------------------------------------------------------------
Coating GE proprietary coating
---------------------------------------------------------------------------------------------
Third stage rotor bucket material
---------------------------------------------------------------------------------------------
Metal GTD-111
---------------------------------------------------------------------------------------------
Coating GE proprietary coating
---------------------------------------------------------------------------------------------
Stator nozzle material
---------------------------------------------------------------------------------------------
First FSX-414
---------------------------------------------------------------------------------------------
Second and third GTD-222
---------------------------------------------------------------------------------------------
Rotor wheel material In-706
---------------------------------------------------------------------------------------------
</TABLE>
* Directionally solidified casting with
serpentine cooling passages
9.1.2 COMPRESSOR
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Type Axial flow
---------------------------------------------------------------------------------------------
Stages 18
---------------------------------------------------------------------------------------------
Rati- 15.3 (ISO)
---------------------------------------------------------------------------------------------
Maximum tip speed 1269 fps
---------------------------------------------------------------------------------------------
Inlet guide vanes Variable-modulating
---------------------------------------------------------------------------------------------
Rotor blade material
---------------------------------------------------------------------------------------------
Stages 0 through 8 C-450
---------------------------------------------------------------------------------------------
Stages 9 through 17 AISI-403
---------------------------------------------------------------------------------------------
Stator blade material
---------------------------------------------------------------------------------------------
Stages 0 through 8 C-450
---------------------------------------------------------------------------------------------
Stages 9 through 17 AISI-403
---------------------------------------------------------------------------------------------
Rotor material
---------------------------------------------------------------------------------------------
Stages 0 through 14 Ni Cr MoV
---------------------------------------------------------------------------------------------
Stages 15 through 17 Cr Mo V
---------------------------------------------------------------------------------------------
Inlet guide vane material C-450
---------------------------------------------------------------------------------------------
</TABLE>
9.1.3 BEARINGS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Radial type (2) Tilt Pad
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
---------------------------------------------------------------------------------------------
Thrust type (1) Tilt pad
---------------------------------------------------------------------------------------------
</TABLE>
9.1.4 COMBUSTION
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Type Can annular reverse flow
---------------------------------------------------------------------------------------------
Number of chambers 14
---------------------------------------------------------------------------------------------
Materials
---------------------------------------------------------------------------------------------
Liners Nimonic 263
---------------------------------------------------------------------------------------------
Transition pieces Nimonic 263
---------------------------------------------------------------------------------------------
Igniters (quantity) 2
---------------------------------------------------------------------------------------------
Flame detectors
---------------------------------------------------------------------------------------------
Quantity 4
---------------------------------------------------------------------------------------------
</TABLE>
9.1.5 WATER INJECTION
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Required inlet pressure 0-20 psig
---------------------------------------------------------------------------------------------
Maximum inlet temperature 110DEG.F
---------------------------------------------------------------------------------------------
Minimum inlet temperature 35DEG.F
---------------------------------------------------------------------------------------------
</TABLE>
9.1.6 NATURAL GAS FUEL
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Pressure required
---------------------------------------------------------------------------------------------
* Maximum 475 psig
---------------------------------------------------------------------------------------------
* Minimum 415 psig
---------------------------------------------------------------------------------------------
Fuel gas temperature (minimum) 50DEG.F of superheat
---------------------------------------------------------------------------------------------
</TABLE>
* Fuel gas supply pressure is measured at the
inlet connection to the gas fuel valve module,
and the pressure value at this point is
referenced to site conditions. For typical gas
fuel quality information, refer to GEI-41040,
Process Specification Fuel Gases for
Combustion in Heavy-Duty Gas Turbines in the
Reference Document Chapter.
9.1.7 LIQUID FUEL
For typical liquid fuel quality information, refer to GEI
41047, Gas Turbine Liquid Fuel Specifications in the Reference
Document Chapter.
<PAGE>
9.1.8 LUBRICATION AND HYDRAULIC CONTROL OIL
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Configuration (turbine and generator) Common supply
---------------------------------------------------------------------------------------------
Oil type Mineral oil
Reference GEK-32568
---------------------------------------------------------------------------------------------
Retention time 5 minutes
---------------------------------------------------------------------------------------------
Bearing supply pressure nominal 25 psig
---------------------------------------------------------------------------------------------
Bearing supply temperature (nominal) 130DEG.F
---------------------------------------------------------------------------------------------
Main oil pump
---------------------------------------------------------------------------------------------
Type Centrifugal
---------------------------------------------------------------------------------------------
Driver AC motor
---------------------------------------------------------------------------------------------
Auxiliary oil pump
---------------------------------------------------------------------------------------------
Type Centrifugal
---------------------------------------------------------------------------------------------
Driver AC motor
---------------------------------------------------------------------------------------------
Emergency oil pump
---------------------------------------------------------------------------------------------
Type Centrifugal
---------------------------------------------------------------------------------------------
Driver DC motor
---------------------------------------------------------------------------------------------
Lube filters Duplex, 17 u nominal
---------------------------------------------------------------------------------------------
Lube cooler Plate and frame (stainless) water
cooled
---------------------------------------------------------------------------------------------
</TABLE>
9.1.9 INLET AIR
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Air filter
---------------------------------------------------------------------------------------------
Normal pressure loss 2.0 in. H2O
---------------------------------------------------------------------------------------------
Maximum pressure loss (dirty) 4.0 in. H2O
---------------------------------------------------------------------------------------------
</TABLE>
9.1.10 EXHAUST SYSTEM
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
External duct shell and stiffeners A36 carbon steel
---------------------------------------------------------------------------------------------
Internal flow liner Duct walls: 409 stainless steel
Silencer panels (if provided): ASTM/A176 TY 409
stainless steel perforated sheet
---------------------------------------------------------------------------------------------
External duct primer Inorganic zinc
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
9.1.11 ACOUSTICS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
OCTIVE BAND 31.5 63 125 250 500 1000 2000 4000 8000
(HZ)
---------------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
DB 131 142 146 145 137 139 132 115 98
---------------------------------------------------------------------------------------------
</TABLE>
The sound level defined above is exclusive of any
noise radiated by the customer's exhaust system.
The sound power level is measured in dB relative
to 10-12 watts, at the exhaust plenum exit, under
base load conditions. Measuring procedures are in
accordance with ASME PTC 36 (near field) and/or
ANSI B133.8 (far field).
9.1.12 FIRE PROTECTION
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Type Low presssure CO2
---------------------------------------------------------------------------------------------
System Multi-zone
---------------------------------------------------------------------------------------------
Detector Fixed type temperature sensors
---------------------------------------------------------------------------------------------
Detector manufacturer Fenwal or equal
---------------------------------------------------------------------------------------------
Number of detectors 22
---------------------------------------------------------------------------------------------
</TABLE>
9.1.13 COOLING WATER MODULE
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Nominal heat duty* 200,000 to 317,000 Btu/min
(211 to 334 MJ/min)
---------------------------------------------------------------------------------------------
Supply temperature (maximum) 120DEG.F (49DEG.C)
---------------------------------------------------------------------------------------------
Supply pressure (maximum) 125 psig (862 KPag)
---------------------------------------------------------------------------------------------
Expected system pressure drop 45 psid (310 KPad)
---------------------------------------------------------------------------------------------
</TABLE>
* Actual value depends on site configuration and
conditions.
9.1.14 STARTING SYSTEM
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Configuration Generator static start
---------------------------------------------------------------------------------------------
Manufacturer GE
---------------------------------------------------------------------------------------------
Type Load commutating inverter (LCI)
frequency drive
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
9.1.15 CONTROLS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
Manufacturer GE
---------------------------------------------------------------------------------------------
Model SPEEDTRONIC( Mark V
---------------------------------------------------------------------------------------------
Type Triple Modular Redundant (TMR)
Microprocessor based
---------------------------------------------------------------------------------------------
Display Color graphics (CRT)
---------------------------------------------------------------------------------------------
Operator input Keyboard and cursor positioning
device (mouse or trackball)
---------------------------------------------------------------------------------------------
Control panel supply 125 Vdc
---------------------------------------------------------------------------------------------
Auxiliary power supply 120 Vac
---------------------------------------------------------------------------------------------
Enclosure NEMA Class I
---------------------------------------------------------------------------------------------
Generator control panel manufacturer GE
(includes protective relays and synchronizing
equipment)
---------------------------------------------------------------------------------------------
Auxiliary panel manufacturer GE
---------------------------------------------------------------------------------------------
MCC
---------------------------------------------------------------------------------------------
AC 480Vac, 3 phase, 60 Hz
---------------------------------------------------------------------------------------------
DC 125 Vdc
---------------------------------------------------------------------------------------------
Air conditioning and heating 240 Vac, 1 phase, 60 Hz
---------------------------------------------------------------------------------------------
Convenience outlets and lighting 120 Vac
---------------------------------------------------------------------------------------------
</TABLE>
9.1.16 BATTERY AND ACCESSORIES
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
BATTERY SYSTEM FEATURES DESCRIPTION
<S> <C>
---------------------------------------------------------------------------------------------
Battery Type 56 Cell 125Vdc nominal calcium-alloyed Flooded
lead/acid type Floated at 129Vdc (2.30 volts/cell)
Equalized at 135Vdc (2.41 volts/cell)
---------------------------------------------------------------------------------------------
Shipping Batteries shipped in special shipping contains to
the site for installation.
---------------------------------------------------------------------------------------------
Installation Mounted in the control compartment
---------------------------------------------------------------------------------------------
Charger Type Single phase 35 amp charger
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
9.1.17 EX2000P DIGITAL, STATIC, VOLTAGE REGULATOR FOR BUS FED
(STATIC) EXCITERS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
MEASUREMENT VALUE
<S> <C>
---------------------------------------------------------------------------------------------
General
---------------------------------------------------------------------------------------------
Excitation System Type Digital Static Potential Source
---------------------------------------------------------------------------------------------
Performance (per IEEE std 421.2)
---------------------------------------------------------------------------------------------
Response High Initial Response
---------------------------------------------------------------------------------------------
Standard Response 2.0 Response Ratio and 160% VFFL ceiling @ generator
terminal voltage = 1.0 per unit based on a field
winding temperature of 100DEG.C (Per IEEE 421)
---------------------------------------------------------------------------------------------
Compliant Standards
---------------------------------------------------------------------------------------------
ANSI/IEEE ANSI C37.2, C37.18, C37.20, C57.9x series,
IEEE 383, 421, 421A, 421B, 421.1
---------------------------------------------------------------------------------------------
NEMA/ICS AB1, ICS1-111, ICS6-110, SG3, WC7
---------------------------------------------------------------------------------------------
CSA All applicable standards
---------------------------------------------------------------------------------------------
NEC All applicable guidelines
---------------------------------------------------------------------------------------------
UBC Meets Zone 4 Requirements
---------------------------------------------------------------------------------------------
Rectifier Bridge
---------------------------------------------------------------------------------------------
Type 6 SCR, Full-wave, Full-inverting
---------------------------------------------------------------------------------------------
Fuses Fast-acting, Current-Limiting, one per leg
---------------------------------------------------------------------------------------------
Input Control Power Requirements
---------------------------------------------------------------------------------------------
From Preferred Station Service 120 Vac Single Phase
---------------------------------------------------------------------------------------------
Field Ground Detector 0.3 amperes continuous
---------------------------------------------------------------------------------------------
125 Vdc/250 Vdc Station Battery
---------------------------------------------------------------------------------------------
Field Flashing 15% of generator no-load field current for 15
secs
---------------------------------------------------------------------------------------------
Control Power without Hot Backup 2.50 amperes continuous
---------------------------------------------------------------------------------------------
Control Power with Hot Backup 5.00 amperes continuous
---------------------------------------------------------------------------------------------
Environmental (Enclosure)
---------------------------------------------------------------------------------------------
Operating Temperature Range 0C to +30C (32F to 86F)
---------------------------------------------------------------------------------------------
Storage Temperature Range -40C to +70C (-40F to +158F)
---------------------------------------------------------------------------------------------
Humidity 5% to 95% non-condensing
---------------------------------------------------------------------------------------------
Heat Dissipation 18,000 W @ 1900 ADC. Linear relationship for other
currents.
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C>
Line filter module (Not required for PPT
secondary Voltages LESS THAN 250 Vac)
---------------------------------------------------------------------------------------------
Dimensions 13 in. H x 19 in. D x 22 in. W
---------------------------------------------------------------------------------------------
Weight Approximately 50 lbs
---------------------------------------------------------------------------------------------
Mounting Requirements When height restrictions prevent this module from
being mounted on top of the main EX2000 enclosure,
it must be mounted within a 15 foot wire run of the
main EX2000 enclosure.
---------------------------------------------------------------------------------------------
</TABLE>
9.1.18 ESTIMATED POWER CONSUMPTION OF ELECTRICAL AUXILIARIES AT ISO CONDITIONS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
AUXILIARY START START OPS OPS STANDBY
(KW) (KW) (KW) (KW) (KW)
GAS DIST GAS DIST
FUEL FUEL FUEL FUEL
<S> <C> <C> <C> <C> <C>
---------------------------------------------------------------------------------------------
Static start 7140 7140
---------------------------------------------------------------------------------------------
Lube oil pump 83 83 83 83 83
---------------------------------------------------------------------------------------------
Hydraulic oil pump 50 50 50 50 50
---------------------------------------------------------------------------------------------
Exhaust frame blowers 68 68 68 68
---------------------------------------------------------------------------------------------
Turning gear motor 6
---------------------------------------------------------------------------------------------
Atomizing air compressor 414 414
---------------------------------------------------------------------------------------------
Turbine compt vent fans 32 32 32 32
---------------------------------------------------------------------------------------------
Liquid fuel skid vent fan 4 4 4 4
---------------------------------------------------------------------------------------------
GTE vent fan 2 2 2 2
---------------------------------------------------------------------------------------------
Load coupling compt vent fan 4 4 4 4
---------------------------------------------------------------------------------------------
Accessory compt vent fan 4 4 4 4
---------------------------------------------------------------------------------------------
Lube mist eliminator 12 12 12 12 12
---------------------------------------------------------------------------------------------
Lube oil heater 45 45 45
---------------------------------------------------------------------------------------------
Control system 50 50 50 50 50
---------------------------------------------------------------------------------------------
Generator/GTE/collector anti-condensation 9
space heaters
---------------------------------------------------------------------------------------------
Turbine/accessory/liquid fuel/gas valve 19
compt anti-condensation space heaters
---------------------------------------------------------------------------------------------
Liquid fuel pump 207 207
---------------------------------------------------------------------------------------------
H2 auxilliary seal oil pump 8
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
<TABLE>
<S> <C> <C> <C> <C> <C>
Water injection pump 207
---------------------------------------------------------------------------------------------
Water injection skid space heater 10 10 10 10 10
---------------------------------------------------------------------------------------------
Water wash skid space heater 10 10 10 10 10
---------------------------------------------------------------------------------------------
Air conditioning - PEECC 36 36 36 36 36
---------------------------------------------------------------------------------------------
Air conditioning - LCI 30 30 30 30 30
---------------------------------------------------------------------------------------------
BAC vent fan 2 2 2 2
---------------------------------------------------------------------------------------------
</TABLE>
9.2 COMPONENT WEIGHTS AND DIMENSIONS
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
ITEM LENGTH WIDTH HEIGHT WEIGHT
(FT) (FT) (FT) (LBS)
<S> <C> <C> <C> <C>
---------------------------------------------------------------------------------------------
Accessory compartment 31.00 11.50 13.83 80000
---------------------------------------------------------------------------------------------
Turbine compartment 29.33 13.25 14.00 377000
---------------------------------------------------------------------------------------------
Generator 37.20 12.08 13.80 540000
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
Exhibit 9
NATURAL GAS COMPOSITION & HEATING VALUE
BASIS: DRY GAS, 14.696 PSIA, 60+
REFERENCE: ASTM D3588 - 91
TEST DATF - Nine month average
DESCRIPTION - Transco Gas Analysis
PROJECT - Tenaska Georgia Generation
<TABLE>
<CAPTION>
GAS IHV HHV COMP. GAS MOL W1
LHV MHV COMPOSITION PROD/100 PROD/100 MOL WT PROD/100
COMPONENT BTU/SCF BTU/SCF MOL % BTU/SCF BTU/SCF LB/MOL LB/MOL
--------- ------- ------- ----------- -------- -------- ------ ----------
<S> <C> <C> <C> <C> <C> <C> <C>
CO2 0.0 0.0 0.957 0.00 0.00 44.010 0.421
N2 0.0 0.0 0.347 0.00 0.00 28.013 0.097
H2 273.9 324.2 0.000 0.00 0.00 2.016 0.000
C1 909.4 1010.0 95.512 868.58 954.67 16.043 15.323
C2 1618.7 1769.7 2.305 37.31 40.79 30.070 0.693
C3 2314.9 2516,1 0.496 11.48 12.48 44.097 0.219
IC4 3000.4 3251.9 0.129 3.87 4.19 58.123 0.075
NC4 3010.8 3262.3 0.111 3.34 3.62 50.123 0.065
IC5 3699.0 4000.9 0.046 1.70 1.84 72.160 0.033
NC5 3703.9 4008.9 0.028 1.04 1.12 72.150 0.020
C6'S 4403.9 4755.9 0.010 0.44 0.48 86.177 0.009 **
C7+ 5100.3 9502.5 0.059 3.01 3.25 100.204 0.059 **
TOTAL 100.000 930.78 1032.44 17.014
</TABLE>
CALCULATION SUMMARY
LOWER HEATING VALUE = 930.78 BTU/SCF
20,761 BTU/LB *
HIGHER HEATING VALUE = 1032.44 BTU/SCF
23,029 BTU/LB *
MOLECULAR WEIGHT = 17.014 LB/MOL
For permitting purposes assume the gas contains no more than 0.25 gr/100 SCF
112S and 2.0gr/100 SCF total Sulfur.
* At 379.5 SCF/LB MOL
** C6's and C7+ are treated as n-Hexane and n-Heptane respectively.
<PAGE>
10. FUEL ANALYSES
--------------------------------------------------------------------------------
TURBINECONTRACTAPPENDIXA-10COVER
<PAGE>
11. FACTORY SERVICES
--------------------------------------------------------------------------------
[OBJECT OMITTED]
<TABLE>
<S> <C> <C>
11.1 GE Power Generation Quality........................................11.1
11.2 Quality Services Overview..........................................11.6
11.3 Gas Turbine Quality Services.......................................11.9
11.4 Generator Quality Services........................................11.10
11.5 Purchased Equipment Quality Services..............................11.10
11.6 Standards and Procedures..........................................11.11
11.7 Customer Review of GE Documentation...............................11.13
11.8 Customer Observation Points.......................................11.13
</TABLE>
--------------------------------------------------------------------------------
11.1 GE POWER GENERATION QUALITY
GE Power Generation (GEPG) is committed to setting the
industry standard of excellence for customer satisfaction.
Inherent in this objective is our continuing determination
to perform every function, every process, to the highest
quality standards--from the way we develop and apply
technologies to the way we manufacture products and provide
services.
11.1.1 COMPANY POLICY STATEMENTS
The quality standards for the GE corporation are set in GE
Policy 20.1, Company-Wide Quality and GE Policy 20.11,
Customer Satisfaction. The highlights of Policy 20.1 are:
- Company-Wide Quality, as a corporate objective, means
attaining a level of overall performance and attitude
that makes General Electric the natural choice of
customers and earns the respect of all those affected
by the company's activities.
- Company-Wide Quality, as an individual objective, is
achieved by employees who aspire to be better than the
best. General Electric is committed to assisting
employees in their pursuit of excellence by providing
them with the leadership, cooperative climate,
training, facilities and materials consistent with the
overall company quest for quality.
<PAGE>
Policy 20.11 highlights are:
- It is the policy of GE to understand its customers'
needs for products and services, as well as all
related requirements, and to put its best effort into
responding to those customer needs before, during and
after every sales transaction.
- GE shall make commitments to its customers which
reflect GE's true ability to serve and to make every
effort to meet those commitments.
11.1.2 POWER GENERATION PHILOSOPHY
"To provide our valued customers with the highest quality
products, parts and services with unparalleled customer
service, while effectively utilizing every employee and
partner working together in an environment of mutual
respect, dignity and unyielding integrity."
11.1.2.1 OBJECTIVE
The objectives of the Quality Policy are based on the
premise that, in striving for excellence in every facet of
our operations, we will assure the highest level of customer
satisfaction and the fulfillment of their objectives through
the products and services Power Generation has provided.
Integral to this are the following key elements:
- Customers are both internal and external.
- Quality measurements must be customer oriented.
- Complete understanding of customer requirements and
expectations is essential.
- Quality is to be achieved by designing and building
quality and reliability into our products and
services, optimizing our processes and minimizing or
eliminating inspections, waste and rework.
- Business processes and procedures instrumental in the
achievement of the Quality Policy are to be defined,
documented and controlled.
- Continuous process improvement efforts will focus
around process simplification, variation reduction and
cycle time compression, utilizing when able, "Best
Practices" as models and examples.
<PAGE>
- Timely and effective corrective and preventive action
will be the key to the continuous improvement process.
- Management involvement plays a critical role in the
achievement of the quality objectives.
- The Power Generation Quality System will be based on the
International Standard ISO 9001.
11.1.2.2 IMPLEMENTATION
It is the responsibility of the President and CEO, GE Power
Systems, and his management teams at all levels, to ensure
the understanding and implementation of this policy
throughout the business and to provide the necessary
processes, practices, procedures and resources necessary to
achieve that end.
11.1.2.3 MEASUREMENT
To ensure the success of the Quality Policy, appropriate and
meaningful measurements will be identified, developed and
reviewed at all levels and functions to ensure that
appropriate corrective and preventive action needs are
identified and addressed in a timely and effective manner.
The type and degree of such measurements will be of a nature
to evaluate the performance to the objectives implied in the
quality policy and consistent with the continuous
improvement philosophy of the business.
Such measurements may include, but not be limited to:
- Customer satisfaction measurements
- Internal and external failures
- Audit results
- Process and product quality trends
- Organizational performance data
- Product performance data
- Statistical analysis techniques
- Related cost data
<PAGE>
11.1.2.4 REFERENCES
This policy is intended to support the objectives
established in Company Policy 20.1 "Company Wide Quality"
and Company Policy 20.11 "Customer Satisfaction".
11.1.2.5 REVIEW
The Quality Policy will be reviewed annually by Executive
Management in order to assure its continued applicability
and objectives.
11.1.3 ISO 9000 CERTIFICATION
The desire for customer satisfaction drives world class
quality. Customers throughout the world are not only
demanding a high level of quality, they are requiring this
quality be assured through the application of a
comprehensive quality program. The ISO 9000 program and
certification provide customers with a globally recognized
Quality Management system.
In order to be more responsive to our customer's needs GE
took this customer requirement and made it a top priority.
Our Sales, Engineering, Sourcing and Manufacturing functions
worked diligently to accomplish ISO certification. GE takes
great pride and pleasure in the fact that we were the first
power generation supplier to obtain broad scope ISO
certification. Lloyd's Register Quality Assurance has
assessed and approved GE's quality management system
standards of ISO 9001:1994, EN ISO 9001:1994 and ANSI/ASQC
Q9001-1994.
GE has focused on this quality issue, with customer
satisfaction being the top priority. The driving force
behind our total quality system is to achieve total customer
satisfaction by minimizing variances and completing the
product or services correct the first time. We established
our quality measurements and targets based on the most
demanding of our customers' perspective. To satisfy this
high level of demand, we focused on our "process" quality,
not just the end-products and services. To achieve this we
have directly involved our employees, our customers and
suppliers in these process improvements.
What really counts is our customers' perception of how well
we meet their quality requirements and goals. Therefore, our
quality measurements and procedures are being constantly
monitored and evaluated against both our own high standards
and our customers' needs.
<PAGE>
11.1.4 TOTAL QUALITY PLAN
GEPG has an integrated total quality plan which addresses
all processes, involves all employees and is driven by top
management leadership. The principles of total quality are
based on achieving total customer satisfaction by minimizing
variances and doing the right thing the first time. These
principles are:
- Total commitment to quality at every salaried and hourly
level
- Assure understanding of customer requirements and
expectations
- Directly involve our customers and suppliers in process
improvements
- Assign ownership for process design and control to
empowered Workout/Continuous Improvement teams
- Focus on "process" quality - not just end-products and
services
- Set our quality measurements/targets from the most
demanding customer's perspective
- Define the key measures needed to assess variances in
process performance
- Apply Continuous Improvement methods to reduce variances
and cycle times to progressively improve overall
performance
- Train employees and maintain a cadre of leaders
- Implement tracking and reporting systems to monitor
progress and results
- Monitor all elements of Cost Of Quality (COQ), including
prevention, appraisal, and internal and external failure,
plus the impact of "lost opportunities" on net operating
income
- Identify and progressively eliminate the source of all
avoidable COQ
- Identify, recognize, and reward exceptional individual
and team performance
GEPG recognizes that ISO 9001 certification covers the basic
fundamentals of a quality system. To attain total quality,
GEPG has created a comprehensive Quality Manual which meets
the requirements of the most demanding customer and sets the
total quality guidelines.
<PAGE>
--------------------------------------------------------------------------------
11.2 QUALITY SERVICES OVERVIEW
11.2.1 TERMS AND DEFINITIONS FOR QUALITY SERVICES
11.2.1.1 ACCEPTANCE CRITERIA
The specific set of measurements and criteria including
judgment by which a part, a component, or the whole product
is accepted or rejected. The acceptance criteria established
by GE (as designer of the equipment) will prevail in all
cases.
11.2.1.2 AUDIT TYPICAL
A customer examination of typical parts or factory
inspection practices (such as NDT, dimensional checks) in a
specific area such as turbine wheel UT examination. The
"audit typical" is frequently conducted in lieu of a witness
point when the parts or components of interest are at a
stage of production where the part does not have customer
assignment.
11.2.1.3 MATERIALS SHIPPED DIRECT (MSD)
Materials or equipment within the GE scope of supply but
manufactured by a sub-supplier and shipped directly from the
subsupplier to the installation site.
11.2.1.4 OBSERVE
Advance notice of an observation point is provided to the
customer and updated as the event nears. Production
sequences are followed and the event is not delayed or
rescheduled to accommodate customer schedules.
11.2.1.5 OBSERVATION POINT
A specific test or event in the production cycle observed by
the customer or his representative without interrupting the
normal production flow. Advance notification will be
provided to the customer for contractually specified
observation points and updated as the event nears.
Production sequences will be followed and the event will not
be delayed or rescheduled to accommodate customer schedules.
<PAGE>
11.2.1.6 QUALITY CONTROL REPORTS (QCR)
The reporting form used to identify and track manufacturing
nonconformances. The customer representative may review any
QCR pertaining to his equipment.
11.2.1.7 RECORDS REVIEW
A joint Customer-Quality representative review of
Manufacturing and Quality documentation applicable to or
typical of the customer's unit.
11.2.1.8 RIGHTS OF ACCEPTANCE
The contractually agreed and stated ultimate power to accept
a product or portion of product. Contract documents define
the limits of customer rights of acceptance; otherwise, the
manufacturer retains the rights.
11.2.2 ARRANGEMENTS AND ACCESS GUIDELINES
Customer representatives will be provided reasonable access
to manufacturing facilities for purposes of obtaining
information on production progress, determining status, and
observing inspections and tests with respect to the customer
ordered power generation equipment. All customer contacts
with GE during the manufacturing phase are scheduled in
advance through designated personnel in Project Management,
Project Engineering and/or Manufacturing.
Access will be available at the manufacturing facilities
during normal working hours and on an off-hours basis where
appropriate or necessary for observation of contractually
agreed upon production points. The main manufacturing
locations are Greenville, SC and Schenectady, NY.
11.2.3 SUPPLIERS
GE Power Generation maintains a high quality global supplier
base. These suppliers are subject to rigorous approval,
qualification and surveillance processes to maintain this
high level of quality. GE will make additions and deletions
from time to time to the current supplier list in an effort
to improve quality and delivery while maintaining the
ability to provide our customer's equipment at competitive
prices.
<PAGE>
11.2.4 QUALITY SYSTEMS MANUAL
GE Power Generation has and maintains controlled Quality
Manuals in accordance with good quality practices and
established standards.
The Quality Manuals are primarily a tool to be used by
personnel and components in their pursuit of quality. The
manuals provide information to integrate the quality system.
All quality related instructions are referenced to permit
ready access to pertinent information on any portion of the
quality system.
The Quality Manuals address the following elements:
1. Management Responsibility
2. Quality System
3. Contract Review
4. Design Control
5. Document Control
6. Purchasing
7. Purchaser Supplied Product
8. Product Identification and Traceability
9. Process Control
10. Inspection and Testing
11. Control of inspection, measuring and test equipment
12. Inspection and Test Status
13. Control of Non-Conforming Material
14. Corrective and Preventive Action
15. Handling, Storage, Packaging, Preservation and Delivery
16. Quality Records
17. Internal Quality Audits
18. Training
19. Servicing
20. Statistical Techniques
11.2.5 MONITORING AND DIAGNOSTICS
At GE's discretion, a Monitoring and Diagnostics (M&D)
system may be utilized by GE to perform quality management
during the warranty period of a
<PAGE>
new unit. The system enables GE's turbomachinery experts
located at the M&D Center in Schenectady, NY to remotely
monitor trends and detect anomalies that may lead to more
serious problems if left uncorrected.
The system requires installation of a non-intrusive,
proactive GE proprietary computer called the On Site Monitor
(OSM) at the customer site to receive and store data from
sensors in the unit. The M&D Center, which operates 24 hours
per day, seven days a week, periodically accesses the OSM
via a phone modem. At the end of the warranty, the OSM may
be removed from the customer site.
--------------------------------------------------------------------------------
11.3 GAS TURBINE QUALITY SERVICES
The following quality assurance services are available for
the Gas Turbine:
11.3.1 QUALITY SYSTEMS MANUAL (REVIEW)
The GE Gas Turbine Quality Manual and related quality system
documentation may be reviewed in detail by the customer with
a quality organization representative at the gas turbine
manufacturing facilities.
11.3.2 QUALITY PROGRAM REVIEW (PRE-INSPECTION MEETING)
A one day project-oriented review can be conducted by
manufacturing quality professionals at the manufacturing
facility. The customer's representatives are exposed to the
quality system, manufacturing facilities, quality control
methods and records system. A shop tour is conducted,
specific customer required quality services are reviewed and
any contract-level quality issues are identified.
11.3.3 PROGRESS AND QUALITY TOPICS (REVIEW)
An informal one day review guided by customer interests and
hosted by manufacturing Quality personnel can be held at the
manufacturing facility. Specific manufacturing progress is
observed, Quality documentation checked, and other customer
special interest quality topics discussed.
Typical events or activities include:
- Audit rotor or stator materials certifications
<PAGE>
- Audit rotor balance procedures and records
- General Factory Tour
- Audit typical forging NDT practices
- Review typical unit records file
11.3.4 COMPREHENSIVE PRODUCT QUALITY REPORT
Gas Turbine personnel will supply on CD ROM the
Comprehensive Product Quality Report (CPQR) containing
images of the unit certification sheet, rotor assembly and
balance data, unit assembly data, and final gas turbine
factory test data (when required). The CD ROM will contain
all files, programs, and instructions to allow its use on
any IBM Compatible personal computer with a CD ROM drive in
a Windows environment. The software provides easy
identification and retrieval of any item or image.
Three (3) copies of the CD ROM will normally be available
four weeks after unit shipment. Quality Records personnel
will prepare the CD ROM with data from quality records
files.
--------------------------------------------------------------------------------
11.4 GENERATOR QUALITY SERVICES
The following quality assurance services are available for
generator.
11.4.1 QUALITY SYSTEMS MANUAL (REVIEW)
The Generator Quality Systems Manual and related quality
systems documentation may be reviewed in detail by the
customer with a quality representative at the manufacturing
facilities.
--------------------------------------------------------------------------------
11.5 PURCHASED EQUIPMENT QUALITY SERVICES
These services are provided for the major vendor purchased
material and equipment required for the turbine-generators.
11.5.1 SUPPLIER QUALITY SYSTEM
GE Power Systems utilizes the following three step process
for selecting and controlling the quality of the products
received from our suppliers:
<PAGE>
- Supplier Approval--An approved supplier is one that
has been authorized by functional representatives to
receive a GE Power Generation Purchase Order.
Additional suppliers are selected for potential
approval on an on-going basis to maintain high
quality, cost effective suppliers.
- Supplier Qualification--Product specific reviews,
inspections and qualifications are performed once a
purchase order has been placed to assure the supplier
complies with the customer requirements. A qualified
supplier is one that has proven its ability to
manufacture a component to satisfactorily meet all GE
requirements.
- Supplier Surveillance--Inspections and quality audits
are performed where required to assure conformance to
customer requirements.
11.5.2 SUPPLIER QUALITY SYSTEM REVIEW
GE Sourcing (purchasing) personnel or a GE representative
will arrange for and accompany where necessary the
customer's representative on quality-oriented visits to
subsuppliers. Emphasis is placed on equipment to be shipped
direct to the customer site (MSD equipment). The customer's
representative may review the subsupplier's quality program,
the GE quality plan for the subject equipment and the status
and condition of the equipment designated for their unit.
This visit should be coordinated with specific supplier
production cycle events or tests as applicable.
--------------------------------------------------------------------------------
11.6 STANDARDS AND PROCEDURES
11.6.1 GENERAL
GE has traditionally designed and manufactured its products
in accordance with GE standards, specifications and
procedures which are based on U.S. National Codes and
Standards applicable to the product. Depending on product
needs, the GE standards may fully meet or exceed the
corresponding National Code (ASME, NEC, QWS), or deal with
state-of-the-art materials, or govern a new proprietary
process, or address a special foreign code requirement or
meet GE design requirements.
The customer or his representative may review and discuss
the standards at the manufacturing facilities but copies
will not be provided and contents will not be altered.
<PAGE>
GE specifications, standards, and procedures are also
applied to all purchased materials for the GE supplied
equipment.
11.6.2 NON-DESTRUCTIVE TESTING (NDT)
The non-destructive testing practices are based on ASTM
standards and ASNT recommended practices as deemed
appropriate for the manufacture of the equipment. NDT
personnel training is guided by SNT-TC-1A and the necessary
process specifications are in place to direct NDT activities
including:
- Radiographic (X-Ray)
- Liquid Penetrant (Red Dye)
- Fluorescent Penetrant (i.e. Zyglo)
- Ultrasonic
- Eddy Current
- Magnetic Particle
- Bore Etch and Spin
- Hydrostatic Testing
- Kerosene and Whiting
- Red and Blue Surface Contact
11.6.3 RIGHTS OF APPROVAL AND ACCEPTANCE
GE reserves all rights of acceptance/rejection for
components or characteristics except where specifically
defined in the GE/Customer contract documentation.
Customer reviews or observations of factory tests and
inspections do not constitute a waiver of requirements to
meet the specified operating conditions, nor does customer
inspection relieve GE of its responsibilities.
<PAGE>
11.6.4 DRAWINGS AND RECORDS
Drawings and records are available for review and discussion
on a specific case basis at the manufacturing facility.
Copies will not be provided except for normal purchaser
drawings and where specifically required in the contract.
--------------------------------------------------------------------------------
11.7 CUSTOMER REVIEW OF GE DOCUMENTATION
A customer may review whatever quality control plans,
procedures, drawings or records are necessary for
operations/tests/inspections performed on his parts. (Under
certain conditions when his parts may not be available,
`typical' documentation, may be reviewed to demonstrate
examples.) Due to the fact that such documentation usually
contains information considered proprietary, copies are not
provided.
All documentation reviews will be conducted with an
authorized representative, such as the area Quality and
Process Engineer. This is necessary as such documentation is
usually of a "working" nature and will need interpretation
by a knowledgeable individual.
Since the review of documentation and data will usually
involve in-process product and activities, certain types of
documentation may not be made available for customer review
until after full resolution and/or implementation of related
issues.
Advance submittals of specifications, procedures and
manufacturing quality plans are not provided.
--------------------------------------------------------------------------------
11.8 CUSTOMER OBSERVATION POINTS
The customer, by previous arrangements, can be notified in
advance of significant events in the manufacturing cycle for
his major hardware. The normal practice is to provide the
customer with a monthly "milestone" schedule of key
activities for each of the customer's units.
If specific observation points have been contracted, advance
notification (usually 5 days) of observation points will be
provided with confirmation of 24 - 48 hours. Production
work, testing and equipment delivery will not be delayed to
accommodate the inspector.
<PAGE>
Supplied equipment and parts are manufactured under a
production and inventory control system. Many parts are
produced for "inventory" and are not assigned to a specific
customer until time of shipment. Thus, except for certain
large components and major serialized parts, it may not be
possible to provide an observation point on the actual parts
a customer will receive. In such cases, GE recommends that a
customer observe the test or inspection on similar parts to
assure that the procedures and processes are being followed
that will assure a quality part.
The following tests and inspections are performed in the
manufacturing facilities and, are optional observation
points. This list should not be taken to mean that any one
such test will be performed on a particular part. These
points have been developed by GE based upon considerable
past experience of what some of our customers have wanted to
observe.
11.8.1 GAS TURBINE TESTS AND INSPECTIONS
11.8.1.1 ROTOR FINAL BALANCE (OBSERVE) - OPTIONAL
THE CUSTOMER REPRESENTATIVE IS INVITED TO OBSERVE THE NORMAL
PRODUCTION OPERATION OF FINAL ROTOR BALANCE AT THE
APPROPRIATE POINT DURING THE MANUFACTURING CYCLE OF THE
CUSTOMER'S UNIT. WHILE GE CAN NOT GUARANTEE THE ROTOR WILL
ACTUALLY BE USED IN THE CUSTOMER'S UNIT DUE TO SHIPMENT
PRIORITIES, GE WILL MAKE EVERY ATTEMPT TO HAVE THE
DESIGNATED ROTOR BE BALANCED. THE COMPLETED ROTOR IS SET UP
IN THE BALANCE MACHINE AND STABILIZED. UNBALANCE READINGS
ARE TAKEN IN TWO PLANES AT LOW SPEED (300 TO 500 RPM) AND
BALANCE CORRECTION IS APPLIED TO ONE OR MORE PLANES BY
WEIGHT ADDITION OR REMOVAL. FINAL BALANCE READINGS AND
MATHEMATICAL CHECKS ARE PERFORMED TO ASSURE AN ACCEPTABLE
ROTOR.
Final rotor balance is a single operation on the entire unit
for MS6001B, MS6001F, MS7001F, MS9001F gas turbine models
(two bearing designs). The MS7001E and MS9001E models,
(three bearing designs), have separate balance operations
for the compressor section rotor and the turbine section
rotor. Manufacturing methods and priorities are such that
the customer should plan on separate visits where multiple
balancing operations are to be observed.
Since GT rotors are considered rigid and are made up of
individually balanced, geometrically-controlled components,
the low speed balancing operation adequately ensures low
vibration levels in the operation unit.
<PAGE>
11.8.1.2 TURBINE FACTORY FINAL TEST (OBSERVE) - OPTIONAL
Factory no-load testing is the principal method of assuring
that the gas turbine unit is operable and that the
aero-thermal performance is acceptable as compared to
factory testing on similar models. Factory testing of gas
turbines will be performed on an audit basis as determined
by GE. When a customer's specific machine is scheduled for
testing, the customer or his representative(s) may be
invited to directly observe operation of his gas turbine
during its normal final fire testing.
11.8.1.3 UNIT READY FOR SHIPMENT (OBSERVE) - OPTIONAL
Consisting of up to two (2) distinct inspection points
depending on the machine and the customer objectives, this
option starts with a walk around inspection of the unit in
the final stages of preparation for shipment. This
inspection is after final painting but before the bolting of
batten strips which secure the side panels and prevent
internal access for machines with on-base lagging. During
this inspection the customer may review overall workmanship,
completeness of assembly, adequacy of prime painting,
application of flange blanking plates, preservation
techniques and general shipping practices.
Next the customer may desire to see his unit on
the rail car ready for shipment. The unit is
fully enclosed, if an on-base lagging design, is
secured to the car and appropriately marked. It
is then shipped by rail, either to location or to
port.
11.8.2 GENERATOR TEST AND INSPECTIONS
11.8.2.1 GENERATOR STATOR
11.8.2.1.1 FINAL ELECTRICAL TEST (OBSERVE)
The typically two (2) to four (4) hour inspection includes
the following:
- GENERAL VISUAL INSPECTION OF THE FULLY ASSEMBLED STATOR
- WINDING RESISTANCE MEASUREMENT--The dc resistance of each
phase is measured with a low resistance ohm meter along
with the winding temperature.
<PAGE>
- INSULATION RESISTANCE MEASUREMENT--Prior to the final
winding high potential test, the insulation resistance
over a ten minute period is measured with a 500 volt dc
insulation tester.
- HIGH-POTENTIAL TEST--The windings of the armature are
tested by grounding two phases and applying a 60 Hz
voltage whose RMS value is twice the machine's rated
voltage plus 1000 volts. This test is repeated for each
phase. This test is done per GE standard which meets or
exceeds IEEE 115 and ANSI C50.10.
11.8.2.2 GENERATOR FIELD
11.8.2.2.1 OVERSPEED AND BALANCE (OBSERVE)
OVERSPEED TEST--The overspeed test is intended to expose
the components of the field assembly to forces higher than
normal and demonstrate the ability of the field assembly to
withstand such forces. The field is set up in the high speed
balance facility, it is held for three minutes at a speed
20% above the rated speed of the unit.
HIGH SPEED BALANCE--The generator field will undergo a
high speed balance. The primary objective of precision
balancing is to reduce the residual unbalance of the
field to the lowest possible level. The approach used in
balancing fields is called modal balancing. Each mode of
vibration, or critical speed, is balanced in turn,
starting with the lowest speed, on first mode. The
process proceeds to each critical in turn from the first
to the highest critical within the operating speed range.
After all criticals are balanced to a small residual
vibration level, balance at rated speed is evaluated.
11.8.2.2.2 FINAL ELECTRICAL TEST (OBSERVE)
- WINDING RESISTANCE MEASUREMENT--The dc resistance of each
phase is measured with a low resistance bridge. The
winding temperature is also measured.
- INSULATION RESISTANCE MEASUREMENT--Prior to the final
winding high potential test, the insulation resistance
over a ten minute period is measured with a 500 volt dc
insulation tester.
- High-Potential Test--The windings of the field are tested
by applying 10 times the rated field voltage but not less
than 1500 volts ac between the field winding and ground
for field voltages of 500 volts or less. For fields
<PAGE>
rated greater than 500 volts, the test voltage is twice
the rated voltage plus 4000 volts ac. This test is done
per GE standard which meets or exceeds IEEE 115 and
ANSI C50.10.
11.8.3 CONTROL PANEL FACTORY TEST (OBSERVE)
The gas turbine control panels are manufactured at GE's
Salem, Virginia plant. Components and modules such as
electronic cards and page assemblies undergo extensive
inspection and automated computer testing before they arrive
at final assembly. All modules with back plane wiring are
automatically machine wired and computer checked.
After the components and modules are assembled in their
parent panel, the equipment is made ready for final test and
inspection. The major portions of this procedure include
testing and checking of the following:
- All final assembly wiring
- Power distribution and supply systems
- Input/output systems
- Automated (PC based) hardware loop back-checks
- System operation using test software
- Customized requisition software checked in a "Software
Test Bed" facility using permanent electronic modules for
test
- For a control panel installed in a control compartment,
interfaces between generator control panel and other
compartment systems.
TURBINECONTRACTAPPENDIXA-11
<PAGE>
12. FACTORY TESTING
--------------------------------------------------------------------------------
Please refer to Tab 11 for the GE Factory Testing Programs.
TURBINECONTRACTAPPENDIXA-12
<PAGE>
13. MECHANICAL
--------------------------------------------------------------------------------
TURBINECONTRACTAPPENDIXA-13
<PAGE>
14. ELECTRICAL
--------------------------------------------------------------------------------
TURBINECONTRACTAPPENDIXA-14
<PAGE>
15. REFERENCE DOCUMENTS
--------------------------------------------------------------------------------
The following is a description of information which cannot be submitted
electronically:
<TABLE>
<S> <C>
Process Specification Fuel Gases for Combustion in Heavy-Duty Gas Turbines - 14 Pages GEI-41040F
Gas Turbine Liquid Fuel Specifications - 24 Pages GEI-41047H
Recommendations for Storage of Liquid Fuels - 5 Pages GEK-28163
Cooling Water Recommendations for Closed Cooling System - 8 Pages GEI-41004G
Compressor Cleaning - 16 Pages GEK-103623B
Standard Field Performance Testing Procedure - 11 Pages GEK-28106A
Standard Field Testing Procedure for NOx Emission Compliance - 8 Pages GEK-28172F
Gas Turbine and Accessory Equipment Preservation - 11 Pages GEK-28156C
Lubricating Oil Recommendations for Gas Turbines with Bearing Ambients above
500DEG.F (260DEG.C) - 13 Pages GEK-32568E
Heavy Duty Gas Turbine Operating and Maintenance Considerations - 34 Pages GER-3620F
Lubricating Oil Piping Specification - 58 Pages 351A7897
Secondary Steam and Water Piping Specification - 48 Pages 351A7892
</TABLE>
TURBINECONTRACTAPPENDIXA-15
<PAGE>
EQUIPMENT AND SERVICES SPECIFICATION
APPENDIX A - M
FOR
SIX (6) PG7241FA 60 HZ
COMBUSTION GAS TURBINE
PACKAGED POWER PLANTS
TO
TENASKA INC.
FOR THE
TENASKA GEORGIA GENERATING PROJECT
HEARD COUNTY,GEORGIA
SPECIFICATION NO: 80905
-----
DATED:AUGUST, 1999
------
GE PROPRIETARY INFORMATION appears on all pages in the Data Sheet,
Performance Specification, Equipment Scope of Supply, and Commercial
Sections of this proposal.
<PAGE>
Table Of Contents
<TABLE>
<CAPTION>
TAB
----------------------------------------------------------------------------------------------------------------
<S> <C>
APPENDIX A
DESCRIPTION OF EQUIPMENT
General Equipment Description........................................................1
Gas Turbine-Generator................................................................2
Gas Turbine Major Equipment and Services List
Gas Turbine Mechanical Description
Gas Turbine Electrical Description
Gas Turbine Control Description
</TABLE>
--------------------------------------------------------------------------------
PERFORMANCE AND OPERATION
<TABLE>
<S> <C>
Component Performance Specifications.................................................4
Estimated Gas Turbine Performance....................................................5
Performance Curves...................................................................6
Turbine and Generator Performance Curves
Gas Turbine Performance Curves
Gas Turbine Hydrogen Cooled Generator
Performance Curves
Gas Turbine Startup Curves and Duration
</TABLE>
--------------------------------------------------------------------------------
DESIGN BASIS
<TABLE>
<S> <C>
Division of Responsibility/Supply by Others..........................................7
Codes and Standards..................................................................8
Data Sheets..........................................................................9
Fuel Analyses.......................................................................10
</TABLE>
<PAGE>
--------------------------------------------------------------------------------
SERVICES
<TABLE>
<S> <C>
Factory Services....................................................................11
Factory Testing.....................................................................12
</TABLE>
--------------------------------------------------------------------------------
DRAWINGS AND DIAGRAMS
<TABLE>
<S> <C>
Mechanical..........................................................................13
Electrical..........................................................................14
</TABLE>
--------------------------------------------------------------------------------
REFERENCE DOCUMENTS
<TABLE>
<S> <C>
Reference Documents.................................................................15
TURBINECONTRACTAPPENDIXA-MCOVER & TOC
</TABLE>
<PAGE>
Appendix B - Payment and Cancellation Schedule
--------------------------------------------------------------------------------
TURBINECONTRACTAPPENDIXBCOVER
<PAGE>
APPENDIX B-1 - PAYMENT SCHEDULE HEARD COUNTY GEORGIA
[*] The following two (2) pages have been omitted and filed separately with
the Securities and Exchange Commission as part of a Confidential Treatment
Request.
<PAGE>
Appendix C
APPENDIX C - GUARANTEED
PERFORMANCE CRITERIA AND TEST
PROVISIONS
<PAGE>
--------------------------------------------------------------------------------
APPENDIX C
GUARANTEED PERFORMANCE CRITERIA AND TEST PROVISIONS
All references to sections in this Appendix C shall be to sections of this
Appendix C unless otherwise specifically stated.
1.0 LIQUIDATED DAMAGE PERFORMANCE GUARANTEES
1.1 NET EQUIPMENT ELECTRICAL OUTPUT: Seller guarantees that the
Net Equipment Electrical Output, defined as the difference of
i.) the sum of the electrical output at the generator
terminals of all gas turbine Units at a Site less ii.) the sum
of all gas turbine Unit auxiliary loads at a Site (with the
gas turbine field performance test data corrected in
accordance with Section 3 to the Basis of Liquidated Damage
Performance Guarantees conditions set forth in Section 2
below) when using the specified fuel shall not be less than
the product of i.) number of Units being tested at the Site
times ii.) the corresponding values in the column labeled
"Guaranteed Net Equipment Electrical Output" in Table 1-1.
The Performance Minimum for Net Equipment Electrical Output
will be equal to the product of i) the number of Units being
tested at the Site times ii) the corresponding value in the
column labeled "Performance Minimum Net Equipment Electrical
Output" in Table 1-1.
The Interim Performance Requirement for Net Equipment
Electrical Output will be equal to the product of i) the
number of Units being tested at the Site times ii) the
corresponding value in the column labeled "Interim Performance
Requirement Net Equipment Electrical Output" in Table 1-1.
1.2 NET EQUIPMENT HEAT RATE: Seller guarantees that the Net
Equipment Heat Rate, defined as the quotient of i.) the total
fuel consumption of all gas turbine Units being tested at the
Site divided by ii.) the total Net Equipment Electric Output
of all gas turbine Units being tested at the Site (with the
gas turbine field performance test data corrected in
accordance with Section 3 to the Basis of Liquidated Damage
Performance Guarantees conditions set forth in Section 2),
shall have a value not greater than the corresponding value
shown in the columns labeled "Guaranteed Net Equipment Heat
Rate" in Tables 1-1 attached using the specified fuel.
<PAGE>
The Performance Minimum for Net Equipment Heat Rate will be
equal to the corresponding value in the column labeled
"Performance Minimum Net Equipment Heat Rate" in Table 1-1
attached.
The Interim Performance Requirement for Net Equipment Heat
Rate for each Unit shall be equal to the corresponding value
in the column labeled "Interim Performance Requirement Net
Equipment Heat Rate" in Table 1-1 attached.
2.0 BASIS OF LIQUIDATED DAMAGE PERFORMANCE GUARANTEES
Upon completion of any Performance Tests for determining Net Equipment
Electrical Output and Net Equipment Heat Rate, gas turbine performance test data
shall be corrected in accordance with Section 3 to the Operating Conditions set
forth below. The corrected data shall be used to calculate the test results for
comparison to the guaranteed values to determine whether the guarantees for Net
Equipment Electrical Output in Section 1.1 and Net Equipment Heat Rate set forth
in Section 1.2 have been satisfied.
2.1 Compressor Inlet Temperature 77.0deg F
2.2 Compressor Inlet Relative Humidity 88 %
2.3 Barometric Pressure for 785 foot above sea level elevation 14.29 psia
2.4 Inlet and Exhaust Pressure Loss, inches H2O 4.0 inlet/5.5 exhaust
above atmospheric pressure
2.5 Generator power factor 0.95 lagging
2.6 Generator terminal frequency (no correction allowed) 60 Hertz
2.7 Customer Gas composition per page A2-1of this Appendix.
2.8 The fuel will be considered to be a Light Distillate or Diesel Fuel as
defined in Appendix A in GEI-41047H.
2.9 Net gas turbine electrical output is defined as the measured gross
output at the generator terminals less the applicable measured
auxiliary loads. The applicable auxiliary loads are those loads for
which values are given on Table 2-1 of this Appendix.
2.10 Evaporative coolers are in service.
3. TEST CRITERIA AND CORRECTION OF SITE TEST DATA
<PAGE>
The following criteria shall apply to all Performance Tests performed
to determine satisfaction of the Performance Guarantees.
3.1 Correction factors shall be developed by the Seller with the
participation of the Buyer as part of the procedure of performing the
test, described herein. These corrections shall be limited to:
3.1.1 Compressor inlet temperature
3.1.2 Compressor inlet relative humidity
3.1.3 Barometric pressure for site elevation
3.1.4 Fuel analyses and corresponding fuel temperatures
3.1.5 Generator power factor. Every effort will be made to
conduct the Performance Tests at a 0.95 lagging power
factor.
3.2 Seller shall provide during the engineering of the Equipment
and upon agreement on test procedures all correction curves
required to correct the test data to the Basis of the
Liquidated Damage Performance Guarantee conditions.
3.3 Performance Tests shall be run in two operating modes: 1)
base load on gas, and 2) base load on oil.
3.4 If more than [*] have elapsed for each gas turbine Unit
before the time Performance Tests are conducted, Seller shall
have the right to inspect the Equipment to assure that the
Equipment is in a new and clean condition and request an
offline water wash. Upon such request the Contractor shall
perform the offline water wash. If the Buyer, at its sole
discretion, operates a gas turbine Unit in excess of [*],
then the attached performance degradation schedule shall be
used.
3.5 The overall Performance Test measurement uncertainty shall not
exceed [*] on Net Equipment Electrical Output or [*] on Net
Equipment Heat Rate.
3.6 Data for each Performance Test will consist of instrument
readings taken at no greater than ten-minute intervals over a
two hour continuous time span after steady state conditions
and one hour stabilization period have been established. Four
consecutive thirty minute tests will be conducted, and the
average of the four tests' results will be used to determine
the achievement of the Liquidated Damages Performance
Guarantees.
<PAGE>
3.7 The gas turbine will be considered to be in a steady state
condition when the turbine wheel space temperatures do not
change more than 5 degrees F in 15 minutes prior to the test
point.
3.8 Barometric pressure at the project location will be measured
with a calibrated digital barometer.
3.9 The Transco natural gas custody transfer meter will be used
for all heat rate calculations applicable when burning gas.
Gas fuel flow to the plant will be measured with a flat plate
orifice installed in accordance with the requirements of ASME
MFC-3M-1989 and ISO-5157-1.[Editors Note: Tenaska/Transco may
consider AGA-3 as the preferred standard. The upstream
pressure will be measured with a precision test instrument,
calibrated differential pressure transducer or gauge, and the
gas temperature with a thermometer or thermocouple.
3.10 Gas samples will be taken from the fuel gas system during the
gas fired tests for laboratory measurement of higher heating
value and specific gravity. The higher and lower heating value
will be determined from the laboratory gas analysis per ASTM
D3588. At least one gas sample will be taken every 30 minutes
during the tests.
3.11 Fuel oil samples will be taken from the fuel oil system during
the oil fired tests for laboratory measurement of higher
heating value and specific gravity. The hydrogen content will
be determined by ASTM D1018, or equivalent. The heating value
will be determined from the laboratory gas analysis per ASTM
D2382, or equivalent. The specific gravity will be determined
by ASTM D1480, or equivalent. At least one oil sample will be
taken every 30 minutes during the tests.
3.12 Calculation of gas flow will be done in accordance with the
latest AGA standards using compressibility factors calculated
from Detail Method of AGA Report No. 8 - 1994.
3.13 Gas turbine performance corrections will be based on
compressor inlet temperature measurements. Compressor inlet
air temperature will be measured with at least four (4) RTD's
or thermocouples supplied by Seller and installed in the inlet
air duct near the gas turbine compressor inlet.
3.14 Ambient conditions will be measured near the gas turbine inlet
air filter. Dry bulb temperature will be measured with a
thermometer or thermocouple. Relative humidity or wet bulb
temperatures will be determined using a psychrometer.
<PAGE>
3.15 Units # 2 and # 3 will not require commissioning or testing on
fuel oil as a condition of Substantial Completion.
Commissioning on fuel oil and completion of the Deferred Tests
shall be performed after Commercial Operation. The Deferred
Tests are those tests which require fuel oil firing as
follows:
a. Net Equipment Heatrate Test (Section 1.2) on
fuel oil.
b. Air Emissions Test (Section 4.1) on fuel oil.
c. Gas Turbine Fuel Switching Test (Section 6.2).
d. Minimum Load Operation at 50% Base Load on
fuel oil (Section 6.3).
e. Gas Turbine Startup on fuel oil (Section 6.4).
f. Gas Turbine Load Rate Change on fuel oil
(Section 6.5).
g. Gas Turbine Fuel Oil Firing (Section 6.7).
3.16 In any case where this Appendix C, and the "Standard Field
Performance Testing Procedure", GEK-28106A, are in conflict,
this Appendix C shall prevail.
4.0 PERFORMANCE GUARANTEES (Air Emissions and Noise)
4.1 Seller guarantees that the hourly average exhaust emissions
at base load shall not exceed the concentrations on the
attached pages A4-1 through A4-4 for each Unit in steady-state
operation.
These emissions are based on the following conditions:
1. Natural gas fuel shall be in compliance with GE, Gas Fuel
Specification GEI-41040F, Sections 10 and 15 of Appendix
A.
2. Distillate No. 2 fuel oil shall be in compliance with GE
Gas Turbine Liquid Fuel Specifications GEI-41047H, Section
15 of Appendix A.
3. Testing and system adjustments are conducted in accordance
with GE document GEK-28172F, Standard Field Testing
Procedure For Emissions Compliance, Section 15 of Appendix
A; provided that in the event of a conflict between the
foregoing document and the applicable state Emission Test
requirements, the state requirements shall prevail.
4. Emissions are on a one hour average basis (except for
Opacity).
5. PM10. Seller reserves the right to determine the emission
rates on a net basis wherein emissions at the gas turbine
inlet are subtracted from the measured exhaust emission
rate if required to demonstrate emission rate.
<PAGE>
Satisfaction of the above emission limits will be determined
in the Emission Test. The Emission Test will be conducted on
behalf of Buyer by the EPC Contractor for the gas turbine in
accordance with the Prevention of Significant Deterioration
(PSD) permit to construct. The Emission Test will be
conducted at the Plant stacks for the following pollutants:
a. NOx - EPA Method 20 (or equivalent)
b. CO - EPA Method 10 or 10B
c. Particulates and PM-10 - EPA Method 201A and 202
or Method 5 modified to include back-half
condensables
d. VOC - EPA Method 25A modified to exclude methane
and ethane
e. Opacity - EPA Method 9
f. O - EPA Method 20 (or equivalent)
2
g. Moisture - EPA Method 4
h. Flue gas flow - EPA Method 2
4.2 Noise. Seller guarantees that the actual near field A-weighted
sound pressure level in a free field environment resulting
from the operation of the gas turbine generators at steady
state conditions at any load above 50% of base load shall not
exceed 90 dB (A) average, when measured in a free field 3 feet
in the horizontal plane from the outermost surfaces of
equipment, including piping, conduit, framework, barriers and
personnel protection devices if provided, and at an elevation
of 5 feet from the machine baseline. Start up, shut down,
transients, and off normal conditions are excluded from the
warranty.
Noise testing methodology will be based on ASME PTC-36-1985
for near field readings and ANSI B133.8 for far field
readings. Testing will be done in accordance to a test plan
agreed to by Buyer and Seller.
Intermittent noises such as safety valve blow off and filter
pulse noise are not included in the above guarantees.
5.0 GENERAL REQUIREMENTS FOR ACCEPTANCE TESTING
<PAGE>
5.1 The Acceptance Testing described in this Appendix C consists
of the Performance Test, the Emissions Test, and Noise Tests
described in Sections 1, 2, 3 and 4, Demonstration Tests
described in Section 6, Availability Tests described in
Section 7 and Utility Tests described in Section 8.
5.2 During all Acceptance Testing the Equipment will be operated
within normal design limits of the Equipment and in a manner
consistent with good utility practices for continuous
long-term operation, and the gas turbine control temperatures
shall not exceed Seller's recommendation for continuous
long-term operation. During Acceptance Testing, the Equipment
will be operated from the control room with systems normally
operated in automatic operating in the automatic mode.
5.3 During Acceptance Testing the gas turbine emissions shall be
equal to or less than the emission limits specified in Section
4.1.
Emissions Test compliance will be determined using the results
measured by the CEMS. Prior to the Emissions Test, CEMS
equipment will be tested in accordance with the applicable
requirements of 40 CFR Pt. 60, App F and 40 CFR Pt. 75,
Appendix A, as appropriate prior to the start of testing and
CEMS will be in service throughout the tests.
The EPC Contractor will be responsible for the field
functional testing and calibration testing of the CEMS prior
to all Acceptance Testing. The EPC Contractor will be
responsible for developing CEMS certification protocol and
calibration.
5.4 Prior to and during all Acceptance Testing, all Systems must
be ready for normal and continuous operation. The use of
temporary equipment will not be allowed unless approved by
Buyer and EPC Contractor. Temporary instrumentation will be
used where required. During Acceptance Testing the Equipment
will operate with normal Plant staffing (all operating
functions will be conducted by the permanent operating staff
and the EPC Contractor's personnel, including the Seller's
technical service representatives, will provide supervision
only and will not perform any hands-on operating functions).
The Equipment will run in a normal manner with no required
Equipment shutdown to reduce auxiliary load. Only Equipment
required for normal operation will be in operation.
5.5 During all Acceptance Testing the Equipment shall be operated
in compliance with all permit limits and requirements as
measured by Plant instrumentation.
5.6 Net Equipment Electrical Output will be determined for all
Units at a Site in accordance with Section 1.1 and for each
combustion turbine Unit individually, as it is available for
testing.
<PAGE>
5.7 Net Equipment Heat Rate will be determined for all Units at a
Site in accordance with Section 1.2 and for each combustion
turbine Unit individually, as it is available for testing.
6.0 DEMONSTRATION TEST REQUIREMENTS
The following is a list of requirements which shall be demonstrated by the
Equipment:
6.1 GENERATORS LEADING / LAGGING OPERATION. The gas turbine
Unit generator shall operate at each power factor constant
limit of 0.95 leading to 0.85 lagging for a period of one (1)
hour.
6.2 GAS TURBINE FUEL SWITCHING. The gas turbine Unit shall
change from primary fuel to alternate fuel and then return to
primary fuel at gas turbine baseload conditions. The duration
of each fuel change shall not exceed twenty (20) minutes.
6.3 MINIMUM LOAD OPERATION AT 50% OF BASE LOAD. The gas
turbine Unit shall operate stable at a power output of 50% of
base load for a duration of two (2) hours. The gas turbine
Units shall operate within permitted emissions limits as
specified in Section 4.1.
6.4 GAS TURBINE STARTUP ON NATURAL GAS AND FUEL OIL. Each gas
turbine Unit will be started up in the two ways described
below. The gas turbine Unit on turning gear prior to the
start. Each start will be comprised of start initiation,
acceleration to full speed no load, synchonization, and
loading to base load output.
Startup tests and test criteria:
a) A normal Start firing natural gas will not exceed 30
minutes.
b) A normal Start firing fuel oil will not exceed 30 minutes.
6.5 GAS TURBINE LOAD CHANGE RATE. Each gas turbine generator Unit
shall have a loading/unloading rate of no less than 8.3 % of
base load output per minute between 0-100% of base load on
either fuel.
6.6 GAS TURBINE EVAPORATIVE COOLER TEST. The gas turbine Units'
evaporative coolers shall maintain at least 85% effectiveness
for a duration of one hour. This Performance Test Requirement
for the Evaporative Coolers may be satisfied only when: (1)
the dry bulb temperature exceeds 60 DEG.F,
<PAGE>
and (2) there is a minimum 10DEG.F difference between wet
bulb and dry bulb temperatures.
Evaporative cooler effectiveness shall be determined by test
data as follows:
X = (Dbt - CITt) / (Dbt - Wbt)
Where:
X - tested evaporative cooler effectiveness
(expressed as a fraction)
Dbt - dry bulb temperature, deg F
CITt - compressor inlet temperature, deg F
Wbt - wet bulb temperature, deg F
t - at test conditions
6.7 GAS TURBINE FUEL OIL FIRING. Each gas turbine Unit shall
operate for one hour at base load, in a stable manner, while
fired 100% with the specified #2 fuel oil and without any
combustion system or combustion turbine temperature alarms.
7.0 AVAILABILITY TEST
The Availability Test will demonstrate the ability of each gas turbine Unit to
operate reliably with a [*] availability or greater. The Availability Test will
be deemed satisfied when each Unit operates reliably and with a [*] availability
for 12 consecutive hours per day over a period of 2 consecutive days or Buyer
provides Seller written notification that the Availability Test is satisfied
During each hour of the Availability Test, the Unit will be expected to operate
above the applicable gas-fired, base load Guaranteed Net Equipment Electrical
Output value shown in Table 1-1 of this Appendix. Credit for Unit output above
the applicable value in the tables will not be allowed. No corrections to Unit
output will be made unless ambient conditions exceed the test rating conditions
in Section 3.1. The Availability Test will be deemed successful if the corrected
net energy (kWh) value divided by the number of hours operated during the
Availability Test is greater than [*] multiplied by the the applicable
Guaranteed Net Equipment Electrical Output value from Tables 1-1 of this
Appendix.
If the gas turbine Units are available to run but cannot due to reasons beyond
Seller's control, the Availability Test will be deemed satisfied when :
1) each Unit operates reliably and with a [*] availability for 40 hours, or
<PAGE>
2) 30 calendar days have passed since Seller has made the Units available for
the Availability Test.
The "10 Hour Availability Test" referred to in Sections 17.1(b) and 17.2(d) of
the Agreement will be deemed passed when the Unit successfully completes ten
hours of continuous operation when burning natural gas and at base load.
8.0 UTILITY TESTS
8.1 The Utility Tests shall consist of a Capacity Test and a Gas
turbine Evaporative Cooler Test. Seller has no requirements
arising out of the Utility Test; provided that Buyer or the
EPC Contractor on Buyer's behalf will use the Utility Tests to
determine satisfaction of certain guarantees and requirements
made by Seller.
8.1.1 The Capacity Tests will be used by Buyer or the EPC
Contractor to establish the Plant capacity under the
Utilities Power Purchase Agreement(s). These tests
require simultaneous operation of the gas turbines.
As part of the Capacity Test, a Gas turbine
Evaporative Cooler Utility Test will be conducted as
specified in Section 8.2.2 herein. The test may
coincide with the test described in Section 6.6.
8.1.2 Test corrections will be used to adjust the tested
output of the Plant to the conditions defined in
Section 8.3.
8.1.3 Seller's data and performance curves will be used for
developing corrections to test data to Standard
Conditions listed in Section 8.3.
8.2 Procedures and Test Requirements
8.2.1 General
8.2.1.1 The Capacity Test will be 2 hours in duration.
8.2.1.2 The Capacity Test will be conducted with all normally
operated auxiliaries in service and with the Plant
operated at a power factor between 0.95 leading to
0.95 lagging.
8.2.1.3 The Plant will be operated on natural gas.
8.2.1.4 Buyer or EPC Contractor on Buyer's behalf will
provide notice to Seller at least 50 hours before the
Capacity Tests. Utility personnel will be allowed to
witness the Capacity Tests.
<PAGE>
8.2.1.5 Reactive power data will be collected from the
Utility (kWh) meter used for measuring net reactive
power output to the transmission system. The change
in meter readings over a set time period will be used
to calculate a net capacity value.
8.2.1.6 The output of the gas turbine generators shall be
corrected in accordance with the conditions specified
herein. The corrections will then be applied to the
Utility kWh meter readings.
8.2.1.7 Calculated contract capacity shall be rounded off to
the nearest 100 kW.
8.2.1.8 No adjustments shall be made to the capacity
calculations for tolerances due to measurement
uncertainties.
8.2.1.9 A minimum of six (6) complete sets of data shall be
collected at ten-minute intervals for each one hour
test run.
8.2.1.10 Computations for correcting capacity shall be
performed immediately following each test run.
8.2.1.11 The preliminary corrected capacity results shall be
available upon completion second test run
calculations.
8.2.1.12 The Plant Net Capacity shall be the average of the net
plant output corrected to Standard Conditions (Section
2) calculated for each test run.
8.2.1.13 A preliminary report summarizing the test results will
be prepared and issued by the EPC Contractor or the
Buyer within 24 hours upon which the test is
completed. EPC Contractor shall issue final report
within two (2) weeks of test completion.
8.2.2 Gas Turbine Evaporative Cooler Utility Test
8.2.2.1 Gas Turbine Evaporative Cooler Effectiveness shall be
determined by test data as follows:
X = (Db - CIT ) / (Db - WB )
t t t t
Test evaporative cooler effectiveness will be used to
determine the compressor inlet temperatures at Standard Conditions (Section 8.3)
as follows:
CIT = Db - X (Db - Wb ) = 94 - X (20)
sc sc sc sc
Where:
<PAGE>
X = tested evaporative cooler effectiveness
DB = dry bulb temperature, DEG.F
t
CIT = compressor inlet temperature, DEG.F
t
WB = wet bulb temperature, DEG.F
t
t = at test conditions
sc = standard conditions
DB = 94 DEG.F
sc
Wb = 74 DEG.F
sc
8.2.2.2 The Evaporative Cooler Utility Test shall be performed only
if : (1) the dry bulb temperature exceeds 60 DEG.F, and (2)
there is a minimum 10 DEG.F difference between wet bulb and
dry bulb temperatures.
8.2.2.3 If the Evaporative Cooler Utility Test cannot be performed
due to restrictions in Section 8.2.2.2 above, then the
Sellers design evaporative cooler effectiveness (85%) will
be used during the interim to determine Plant Net Capacity.
The evaporative cooler will be tested independently at
earliest time acceptable to all parties (Utility, Owner, EPC
Contractor and Seller).
8.2.3 Gas Turbine
8.2.3.1 Utility Test shall be performed at the gas turbine
manufacturer rating for continuous service which is normally
designated as "base firing mode" for a dry low NO(SUB.x)
combustion system without gas turbine diluent injection for
NO(SUB.x) control.
8.2.3.2 Capacity corrections curves shall be provided to adjust for
the effects of compressor inlet temperature and barametric
pressure
8.2.3.3 The tests will be performed after the gas turbine Unit
reaches steady state condition. The Unit will be considered
in a steady state condition when turbine exhaust temperature
does not change by more than 5 DEG.F in fifteen minutes prior
to test.
8.2.3.4 The effect of relative humidity on turbine performance will be
neglected, except for the effect on compressor inlet
temperature.
8.2.3.5 No adjustment shall be made for inlet or exhaust pressure drop.
<PAGE>
8.2.3.6 The measured value of barometric pressure shall be corrected
for temperature if required by measuring device. The
recorded pressure shall then be compared to the standard
conditions for determining the capacity correction factor.
Only the gas turbine output will be corrected for barometric
pressure.
8.2.3.7 Compressor inlet temperature shall be measured with the
permanently installed compressor inlet thermocouple or RTD's.
Four (4) measuring devices shall be in service.
8.3 Standard Conditions Test data from the Utility Test described in this
Section 8.0, shall be corrected to the Standard Conditions set forth in
this Section 8.3. Correction factors shall be developed by the Seller
with the participation of the Buyer as part of the procedure for
performing the test, and at the EPC Contractor's option, in accordance
with the guidelines set forth in ASME PTC-22 for the gas turbines.
8.3.1 Standard Conditions for correcting Utility Test results
are given in Section 2.
<PAGE>
TURBINE CONTRACT APPENDIX C
<PAGE>
APPENDIX C
GUARANTEED PERFORMANCE AND INTERIM PERFORMANCE REQUIREMENTS
Table 1-1
[*] This one (1) page has been omitted and filed separately with the
Securities and Exchange Commission as part of a Confidential Treatment
Request.
<PAGE>
APPENDIX C TABLE 2-1
[*] This one (1) page has been omitted and filed separately with the
Securities and Exchange Commission as part of a Confidential Treatment
Request.
<PAGE>
[Graph]
<PAGE>
[*] The following four (4) pages have been omitted and filed separately with the
Securities and Exchange Commission as part of a Confidential Treatment
Request.
<PAGE>
[Graph]
<PAGE>
CUSTOMER GAS COMPOSITION
See Section 10.0 "Fuel Analyses", of Appendix A to this Contract for the
Customer Gas Composition.
<PAGE>
APPENDIX D - OPTION LIST
--------------------------------------------------------------------------------
<PAGE>
CONFIDENTIAL
APPENDIX D - OPTIONS
In accordance with the provisions of Section 9.2 of the Contract for Purchase,
the following is a summary of the options available to the Buyer in connection
with the Equipment. The scheduled Delivery Date shall not be impacted provided
that Buyer exercises such options on or prior to the submission of the
Manufacture Release Notice.
<TABLE>
<CAPTION>
A. Gas Turbines Unit Price Unit Price Georgia Contract
Change (CT 1-3) Change (CT 4-6) Pricechange
<S> <C> <C> <C>
1 Two static start systems for three gas turbines (cross connected) [*] [*] [*]
2 Two years extended warranty with "in and out" for three (3) units [*] [*] [*]
3 Inlet chilling system to 45 o F CIT (per unit) [*] [*] [*]
4 Gas turbine generator performance monitoring instrumentation (per unit). [*] [*] [*]
Compressor bellmouth static and differential pressure transmitters and
compressor inlet RTDs.
5 AACA generator protection panel in lieu of BABA panel (per unit) [*] [*] [*]
6 Current transformers (per unit). Additional C800 class CTs for [*] [*] [*]
transformer differential scheme.
7 Delete Power System Stabilizer (PSS) but have capability to add later [*] [*] [*]
(per unit)
8 Generator line-side compartment drawout PTs (price per unit) [*] [*] [*]
Excitation (1 set per unit). Relaying (1 set per unit)
9 Second single-phase standard battery charger (per unit) [*] [*] [*]
10 Gas turbine generator breaker (per unit) [*] [*] [*]
11 Second generator breaker synchronization (per unit) [*] [*] [*]
12 Silencers for all vent fans (per unit) [*] [*] [*]
13 Delete fire protection system CO2 tanks (per unit) [*] [*] [*]
14 VAR/Power Factor control via Mark V (per unit) [*] [*] [*]
15 Combustion Monitoring System [*] [*] [*]
16 FM200 Tanks and Supply (per unit) [*] [*] [*]
17 Local Operator Multi-Unit Interface [I] up to eight units [*] [*] [*]
18 Two-stage standard pad-type media filters versus self-cleaning [*] [*] [*]
inlet filters (per unit)
19 Corrosion-resistant versus standard media filters (per unit) [*] [*] [*]
20 Delete unit walkways (per unit) [*] [*] [*]
21 Delete natural gas fuel heater (per unit) [*] [*] [*]
22 Delete air processing unit (per unit) [*] [*] [*]
23 Freight differential to Georgia versus shipment to Texas (per unit) [*] [*] [*]
24 Additional remote [I] (per unit) [*] [*] [*]
25 Additional GEC equipment (Heard County vs. Frontier) (per unit) [*] [*] [*]
26 Cooling water module (i.e., for simple cycle operation) (per unit) [*] [*] [*]
27 Acoustic barrier wall (per unit) [*] [*] [*]
28 Epoxy paint for inlet ducting (per unit) [*] [*] [*]
29 Additional air conditioner (per unit) [*] [*] [*]
30 Mark V configuration changes (Heard County vs. Frontier) (per unit) [*] [*] [*]
31 Static Start Differential (3 for 6 vs. 2 for 3) (per unit) [*] [*] [*]
32 TDI Differential (75 mnwks/unit vs. 100 mnwks/unit) (per unit) [*] [*] [*]
33 Exhaust Stack (per unit) [*] [*] [*]
34 DLN 2.6 at 9 ppmv NOx in lieu of 15 ppmv NOx (per unit) [*] [*] [*]
35 Stainless steel generator cooler tubes in lieu of 90/10 copper [*] [*] [*]
nickel (per unit)
36 Freight differential to Alabama versus shipment to Texas (per unit) [*] [*] [*]
37 Mark V remote control and monitoring to include: two (2) [*] [*] [*]
ETHERNET links (one for each of two remote [I]/[G];
two (2) remote multi-unit [I]/[G] processors; and one
(1) []]/[G] for the Mark V [C] communications processor
and one (1) for the redundant [D] processor (per unit)
38 Provide time synchronizing card to the time synchronize the [*] [*] [*]
Mark V's to the plant controls
39 GE gas meter runs. Furnish to AGA-3 requirements. (per unit) [*] [*] [*]
</TABLE>
<PAGE>
APPENDIX E - TRAINING
-------------------------------------------------------------------------------
SUMMARY
A comprehensive training program is conducted for
a selected number of Owner's engineers,
operations and maintenance personnel. The
training will be conducted at the Owner's job
site. Optional training at facilities in the
United States can be provided at extra cost.
The Owner's personnel assigned for training must
have prior general knowledge of power plant
systems operation.
A GE training coordinator is designated for the
project who is familiar with overall plant design
and system operations. This person schedules and
coordinates job site training, as well as
integrates individual systems training into the
overall plant operation from Schenectady, NY. An
on site training coordinator may be provided at
extra cost.
The training programs will cover the areas
specified below and detailed on the following
pages:
OPERATORS TRAINING
<TABLE>
<CAPTION>
---------------------------------------------------------------------------------------------
Gas Turbine-Generator Operation (On-Site) 2 weeks
<S> <C>
---------------------------------------------------------------------------------------------
TOTAL OPERATORS TRAINING 2 WEEKS
---------------------------------------------------------------------------------------------
MAINTENANCE TRAINING
---------------------------------------------------------------------------------------------
Gas Turbine (On-Site) 1 week
---------------------------------------------------------------------------------------------
TOTAL MAINTENANCE TRAINING 1 WEEK
---------------------------------------------------------------------------------------------
I&C AND ELECTRICAL TRAINING
---------------------------------------------------------------------------------------------
Excitation for AC Generators (On-Site) 1 day
---------------------------------------------------------------------------------------------
Excitation for AC Generators (Schenectady) 1 week
---------------------------------------------------------------------------------------------
SPEEDTRONIC Mark V for Operators (On-Site) 1 week
---------------------------------------------------------------------------------------------
SPEEDTRONIC Mark V Technician's Level (Schenectady) 2 weeks
---------------------------------------------------------------------------------------------
LCI Static Start (Off-Site - Salem) 1 week
---------------------------------------------------------------------------------------------
TOTAL I&C AND ELECTRICAL TRAINING 6.2 WEEKS
---------------------------------------------------------------------------------------------
---------------------------------------------------------------------------------------------
TOTAL TRAINING 9.2 WEEKS
---------------------------------------------------------------------------------------------
</TABLE>
<PAGE>
--------------------------------------------------------------------------------
TRAINING MATERIAL AND RELATED CONDITIONS (ON-SITE TRAINING)
- Classes run daily (five days/week) and are limited to six
(6) hours. The actual class time, a.m. and p.m. hours, is
dictated by the availability of the equipment and the
students per the normal work schedule. Each class time
period should be agreed to by the Owner's management and
GE's instructor(s) at the beginning of the program. The
six (6) hour class limitation will allow ample time for
the instructor(s) to prepare the next session's work plan.
- A maximum of fifteen (15) students per class can be
accommodated On-Site.
- This training is scheduled to be conducted during 2001. If
performance of training is delayed beyond 2001, a six
percent (6%) per year escalation charge shall be added to
quoted rates and fees. o English-speaking instructor(s)
will be furnished for the course duration.
- Each student will be furnished a suitable bound course
instruction and reference handbook in English; shipment
costs have been included in the firm price quoted herein.
Any materials furnished are exclusively for the use of the
Owner's personnel. This material is not for resale or to
be distributed to third parties, nor is it to be copied or
reproduced without GE's prior written permission.
- A climate controlled class room suitable to accommodate
and seat comfortably all students and provide a 35mm slide
projector, an overhead projector for transparencies,
projector for personal computers, chalk, erasers, pencils
and flip chart paper as required.
- Equipment walk around and panel familiarization will be
dependent upon equipment availability.
- For SPEEDTRONIC Mark V training, Buyer needs to provide
PCs capable of running the Mark V [I] processor software
for "hands on" experience in class. One (1) PC for a
maximum of every three (3) students is recommended and
they will have to meet the following requirements:
-- Free hard disk space: 40 megabytes
-- Minimum RAM: 16 megabytes
-- No disk memory manager programs running (e.g. stacker
or double space)
<PAGE>
-- 80386 or higher INTEL processor
-- MSDOS 5.0 or higher (No Windows 95 or NT)
-- VGA monitor
-- Mouse or trackball and driver software
-- 3 1/2" floppy disk drive
-- PCs must be desktop computers with expansion slots that
will accept an ARCNET card (e.g. No. IBM PS2 computers
or laptop computers)
-- Maximum number of computers: 6
(ARCNET Lan will not support more than 6)
-- Maximum number of students per computer: 3
- Any audio or video recording of GE's lecture material is
prohibited unless GE grants permission in writing in
advance of the training program.
- The instructor(s) will retain all visual aids such as 35mm
slides and transparencies used to conduct the course.
- The power plant equipment should preferably be operable
and available to support this course of study.
- GE shall be responsible for the instructors travel and
living expenses during the training period.
- Buyer agrees to pay GE for any additional time spent by
the instructor at the request of Buyer beyond those quoted
herein. This shall include all overtime hours. For such
additional training, GE shall invoice Buyer at GE's
current Commercial Rate Schedule, IDR, copy to be provided
at Buyer's request.
--------------------------------------------------------------------------------
TRAINING MATERIAL AND RELATED CONDITIONS - GE SITE BASED TRAINING
- This training is scheduled to be conducted during 2001. If
performance of training is delayed beyond 2001, a six
percent (6%) per year escalation charge shall be added to
quoted rates and fees.
- One (1) daily class (five days/week) will be limited to
six (6) hours. The actual class time, a.m. and p.m. hours,
is dictated by the availability of the equipment and the
students per the normal work schedule. Each class time
<PAGE>
period is agreed to by the Owner's management and GE's
instructor(s) at the beginning of the program.
- A maximum of fifteen (15) students per class can be
accommodated on-site, the number of students that can be
accommodated in Schenectady is three (3).
- Each student will be furnished a suitable bound course
instruction and reference handbook in English. Any
materials furnished are exclusively for the use of the
Owner's personnel. This material is not for resale or to
be distributed to third parties, nor is it to be copied or
reproduced without GE's prior written permission.
- Any audio or video recording of GE's lecture material is
prohibited unless GE grants permission in writing in
advance of the training program.
- The instructor(s) will retain all visual aids such as 35
mm slides and transparencies used to conduct the course.
--------------------------------------------------------------------------------
TRAINING SCHEDULE
After engineering design has been finalized, training is
conducted during a mutually-agreeable time.
--------------------------------------------------------------------------------
COURSE CONTENTS FOR THE MAJOR PLANT COMPONENTS
GAS TURBINE-GENERATOR OPERATION COURSE
COURSE DESCRIPTION:
This site-specific course is designed to enable engineers,
supervisors, operations and maintenance personnel to safely
operate GE designed heavy duty turbine generator units. This
course develops a background in turbine generator operation
which will enable participants to properly analyze operating
problems and take the necessary corrective action.
Emphasis is placed on the operator's responsibilities with
regard to auxiliary systems, operational data taking, and
data evaluation. Operators are instructed in how to
interpret fault annunciation. The
<PAGE>
course focuses on the starting, loading, and specific
operator checks of the various turbine support and auxiliary
systems to ensure safe and reliable operation of the turbine
unit. Also covered is the effect that operation has on major
mechanical maintenance.
Content:
The typical Operation course covers the following areas:
Gas Turbine Operations
----------------------
- Gas Turbine-Generator Fundamentals
- Basic theory of operation
- Base and machine arrangement
- Support Systems Operation, and System Checks
- Inlet Filter
- Lube Oil
- Hydraulic and Control Oil
- Cooling Water
- Cooling and Sealing Air
- Fuel system(s)
- Starting Means
- Heating and Ventilation
- Fire Protection
- Control System
- Arrangements
- Control Functions and Operating Sequences
- Protection Functions
- Operator Responsibilities
- Data Taking and Evaluation
- Operating Limits
- Required Operator Action on Various
- Annunciation Indications
- Unit Operation
- Startup
- Normal Operation
- Shutdown
- Emergency Procedures
- Generator
- Machine Theory
<PAGE>
- Components Stator/Field
- Power System Load Characteristics And Power Factor
- Excitation
- Equipment Operation
- Alarms, Trips
- Generator
-- Fundamentals
-- Generator Construction
- Generator Auxiliary Systems
-- Lubrication
-- Generator Cooling System
-- Seal Oil/Seal Air
- Generator Controls and Protection
-- Excitation System
-- Digital Generator Protection
- Turbine Generator Operation
-- Operating parameters
-- Start up
-- Loading
-- Shutdown
-- Generator Operation
- Operator Responsibilities
-- Data Taking and Evaluation
Operating Limits and Required Operator Actions
COURSE DURATION: 2 WEEKS
Course duration is dependent upon the size and complexity of
the gas turbine generator unit and the student's background
and experience level with power generation equipment.
<PAGE>
GAS TURBINE-GENERATOR SYSTEMS MAINTENANCE COURSE
COURSE DESCRIPTION:
This site-specific course is designed to introduce
operations and maintenance personnel to the routine
preventative maintenance procedures of the turbine-generator
support systems required to attain high levels of
availability and reliability from the turbine-generator.
This course does NOT cover the turbine-generator disassembly
inspections required for major mechanical maintenance.
Operating and maintenance personnel should attend this
course together to develop a working relationship regarding
the routine maintenance requirements of the unit.
The training will include detailed descriptions of the
turbine-generator support systems. This will include a
functional description of the system as well as the routine
maintenance requirements of the system. If the course is
held at the customer's location it will include site visits
to familiarize personnel with the location of the various
system components and to allow personnel to correlate the
system piping schematics to the system hardware. The
training will not incorporate any "hands-on" training or
component disassembly.
CONTENT:
The typical Systems Maintenance course covers the following
topics:
GAS TURBINE MAINTENANCE
- Gas Turbine Introduction
- Explanation of how a gas turbine works
- Introduction to the customer-specific unit
- Gas Turbine-Generator Arrangements
- Site turbine and accessory base arrangements and
enclosures
- Site generator and load gear (if applicable)
arrangements and enclosures
- Support Systems Operation and Routine Maintenance
- Inlet and Exhaust Systems including Generator Cooling
Air and Inlet Bleed Heat (if applicable)
<PAGE>
- Lube Oil System
- Hydraulic Oil System
- Trip Oil System
- Seal Oil System (if applicable)
- Inlet Guide Vanes
- Cooling Water System
- Cooling and Sealing Air System
- Fuel System(s)
- Atomizing Air System (if applicable)
- Water/Steam Injection (if applicable)
- Purge Air System(s) (if applicable)
- Starting System, including slow-roll/cooldown function
- Heating and Ventilation Systems
- Fire Protection System
- Generator Hydrogen System (if applicable)
- Generator Auxiliary Systems (Brush Rigging, Coolers)
- Water Wash System as a maintenance tool
- Bearings
- Inspection and Repair
- Bearing Alignment
- Turbine Fluid Systems
- Lubrication oil and high pressure hydraulic systems
- Fluid specifications
- Inspection, evaluation, repair and flushing procedures
- Turbine Auxiliary Systems
- Turning gear, shaft grounding, T.S.I.
- Recommended calibration
- Inspection, evaluation and repair of the systems
- Generator Maintenance
- Bearing and coupling inspection and repair, including
alignment
- Cleaning and inspection of components / systems
- Disassembly and assembly of components
<PAGE>
- Generator Auxiliary Systems
- Brush rigging, coolers, high voltage bushings
- Preventative maintenance
- Inspection, evaluation and possible repairs
- Hydrogen and Stator Water Cooling Systems (if applicable)
- Preventative maintenance
- Inspection and repair of components
- Flushing procedures
COURSE DURATION: 1 WEEK
Course duration is dependent upon the size and complexity of
the gas turbine generator unit and the student's background
and experience level with power generation equipment.
GENERATOR CONTROL-EXCITATION (EX2000) (TECHNICIANS LEVELS)
COURSE DESCRIPTION:
This site specific course covers generator parameters,
EX2000 control and protective circuits and excitation system
settings. A simulator is used to enhance the classroom
training.
This course is designed to provide a solid background in
Digital Excitation System maintenance and troubleshooting
skills.
CONTENT:
The generator Control for Technicians course covers the
following areas:
- Excitation Fundamentals
- Generator Parameters
- Excitation System One Line and Excitation Drawings
<PAGE>
- Manual/Auto Regulation
- Control and Protective Circuits
- Digital Excitation System Overview
- EX2000 Programmer
- Analog and Digital Signal Training
- On Line and Off Troubleshooting Maintenance
- Digital Generator Protection
COURSE DURATION: 1 WEEK
The course duration will vary, depending upon the student's
background and their familiarity with generator controls and
computer based control systems.
GENERATOR CONTROL FOR OPERATORS
COURSE DESCRIPTION:
The course focuses on the operation of the Generator Control
System. Operational safety precautions are emphasized for
personnel and equipment during operation.
To improve the ability of personnel to safely operate the
generator and EX2000 excitation system.
CONTENT:
The Generator Control for Operators course covers the
following areas:
- Generator Curves
- Excitation System Parameters i.e. UEL, V/Hz
- Auto and Manual Voltage Regulators
- Start/Stop and Synchronizing
- On line Operation
- Alarms and Fault Codes
<PAGE>
COURSE DURATION: 1 DAY FOR A TOTAL OF 8 HOURS
The course duration will vary, depending upon the student's
background and their familiarity with generator controls and
computer based control systems.
SPEEDTRONIC-TM- MARK V GAS TURBINE OPERATOR
COURSE DESCRIPTION:
This site specific course is designed to instruct a
qualified gas turbine operator to the modifications made to
upgrade the unit to a SPEEDTRONIC-TM- Mark V Control System.
This course covers major topics in the fundamentals of the
Gas Turbine Mark V control system and related systems,
documentation, backup operators interface [BOI] and the
operator's control interface [I].
Emphasis is placed on enabling operators and supervisors to
confidently operate and monitor the gas turbine using the
SPEEDTRONIC-TM- Mark V control system.
CONTENT:
The typical SPEEDTRONIC-TM- Mark V Turbine Operator Course
covers the following areas:
GAS TURBINE MARK V
------------------
- Gas Turbine
- Hardware Modification and Interface
- Introduction to SPEEDTRONIC-TM- FundamentaLS
- Introduction to control function
- Redundancy, Hardware, Security
- Startup, Speed, Temperature, Controls
- Fuel systems
- Protection systems
<PAGE>
- SPEEDTRONIC-TM- Control Documentation
- Function
- Interpretation and use
- Operator Interface [I]
- Operation
- Data retrieval
- Display modification
- Backup Operator Interface [BOI]
- Operation
- Data recovery
- Startup and shutdown sequence
COURSE DURATION: 1 WEEK
The course duration will vary, depending upon the student's
background and their familiarity with generator controls and
computer based control systems.
GAS TURBINE SPEEDTRONIC-TM- MARK V TECHNICIANS TRAINING
COURSE DESCRIPTION:
This site specific course is designed to enable engineers
and competent instrument and control technicians to
confidently calibrate the controls and diagnose problems in
General Electric Gas Turbine SPEEDTRONIC-TM- Mark V Control
Systems. The course is designed to provide a solid
background in turbine governing systems. Participants
increase their skills in relating machine operating
requirements to the SPEEDTRONIC-TM- control.
<PAGE>
CONTENT:
The Gas Turbine SPEEDTRONIC-TM- Mark V Controls course
covers the following areas:
- Gas Turbine Control Fundamentals
- Gas turbine principles of operation
- Governing system requirements
- Gas Turbine Systems
- Piping schematics
- Electrical wiring diagrams
- Gas Turbine Control
- Startup/speed/temperature/other controls
- Protection
- Control Displays
- User's manual
- Control System Software
- IDOS
- File descriptions
- Micro Processor Initialization
- Troubleshooting
- Valve Calibration (LVDT)
- Input/output configuration screens
- Software Tools
- Modifying and downloading control configuration
- Data acquisition on Mark V interface
- Software backup
- Troubleshooting
- Gas turbine process alarms
<PAGE>
- Mark V panel diagnostic alarms
- Governing system requirements
- Protection requirements
- Documentation Conventions/Terminology
- Mechanical
- Electrical
- Controls
- Mark V Hardware - Mark V panel
- Operator interfaces [I] [BOI]
- Printers
COURSE DURATION: 2 WEEKS
The course duration will vary, depending upon the student's
background and their familiarity with turbine generator
controls and computer based control systems.
TURBINECONTRACTAPPENDIXE
<PAGE>
--------------------------------------------------------------------------------
APPENDIX F - NOT USED
--------------------------------------------------------------------------------
TURBINECONTRACTAPPENDIXF
<PAGE>
APPENDIX G
DOCUMENTATION AND SPECIAL REQUIREMENTS
TENASKA GEORGIA GENERATION PROJECT
1.0 RESERVED
2.0 GAS TURBINE DOCUMENTATION
This section describes the documentation to support the Buyer's efforts
to design, install, operate and maintain the Gas Turbine-Generator
Packaged Power Plant. The documentation requirements are summarized
below in two categories that are generally aligned with the major
phases of the Project. These categories are as follows:
- Buyer Design Drawings
- Startup and Operation Documents
SELLER SHALL FURNISH THE NUMBER OF COPIES OF DOCUMENTS IN THE NUMBER OF
WEEKS SHOWN AFTER THE ORDER DEFINITION MEETING AS SHOWN BELOW:
Approvals
Only the Electrical One-Line Diagram and the Mechanical Outline are
submitted for Buyer's approval. Errors detected by the Buyer in any
drawings submitted will be corrected. Approval of these documents by
the Buyer will not be construed as a complete check of the documents
and will not lessen the responsibility of Seller.
The Seller will make available at the time of the Design Finalization Meeting
(DFM) "typical" gas turbine Buyer Design drawings as defined in the list below
to facilitate Buyer's preliminary work. A "marked-up" one-line diagram
reflecting the scope of supply under Appendix A shall also be provided.
Significant document revisions by the Seller after the initial issue "For
Approval" or "Approved for Installation" shall constitute the Seller's failure
to meet the Seller's contract obligations for documentation.
<TABLE>
<CAPTION>
----------------------------------------------------------------------------------------------------------------------------
Issued--Approved
Issued--For Approval for Installation
-------- ---------------------------------------- --------- ------------------------------- --------------------------------
GE Repro- Repro-
Code Category Code ducible Prints Wks ducible Prints Wks
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
LD 0 One-Line Diagram MLI 1 6 11
Information: 0444
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
1 General Arrangement Information:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 1.1 GTG Mechanical Outline MLI 1 6 12
1.2 Inlet air Filter Outline 0306
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<PAGE>
<CAPTION>
----------------------------------------------------------------------------------------------------------------------------
Issued--Approved
Issued--For Approval for Installation
-------- ---------------------------------------- --------- ------------------------------- --------------------------------
GE Repro- Repro-
Code Category Code ducible Prints Wks ducible Prints Wks
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
2 Cross-Sectional Drawings: *
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
3 Outline Drawings:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 3.1 Buyer's Electrical Connection MLI 1 6 14
Outline 0301
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 3.2 Buyer's Piping Connection MLI 1 6 14
Outline 0313
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 3.2 Notes for Buyer's Piping MLI 1 6 14
Connection Outline 0314
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
4&5 Foundation Drawings, Loading &
Bolt Setting Arrangement:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD .1 Foundation Interface Outline MLI 1 6 14
including inlet air filter 0323
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD .2 Foundation Bolting MLI 1 6 14
Arrangement including inlet air 1603
filter
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD .3 Off-Base Equipment MLI 1 6 14
Foundation Interface Outline 0326
including isolation transformer, DC link
reactor, BACC Electrical Outline, PEECC
Electrical Outline, Generator Terminal
Enclosure & Access platforms
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
6 Calculations: N/A
-------- ---------------------------------------- --------- ----------------------------------------------------------------
LD 7 Erection Drawings: Information and Procedures for Installation with shipment of
equipment and Temporary Storage. 90 Days Before Shipment.
-------- ---------------------------------------- --------- ----------------------------------------------------------------
8 Welding Procedures:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
8.1 Document List MLI 1 6 6
0438
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
9 Bills of Material:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
9.1 Device Summary MLI 1 6 11
0414
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
10 Piping Schematics:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 10.1 Schematic Piping Diagrams MLI 1 6 10
0040
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<PAGE>
<CAPTION>
----------------------------------------------------------------------------------------------------------------------------
Issued--Approved
Issued--For Approval for Installation
-------- ---------------------------------------- --------- ------------------------------- --------------------------------
GE Repro- Repro-
Code Category Code ducible Prints Wks ducible Prints Wks
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
11 Electrical Wiring Diagrams:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 11.1 Cable Summary MLI 1 6 12
0463
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
Interconnection Diagram MIL-0301/ 1 6 14
0330
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
12 Control and/or Annunciator *
Schematics:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 12.1 Turbine Control One month prior to SHIP
Specification
-------- ---------------------------------------- --------- ----------------------------------------------------------------
LD 12.2 Generator Protection & Turbine @ SHIP
Auxiliary Elementary Diagrams
-------- ---------------------------------------- --------- ----------------------------------------------------------------
13 Utility Requirements and Diagram See Code 10 Drawing
-------- ---------------------------------------- --------- ----------------------------------------------------------------
14 Control Panel Drawings *
(and/or Operator Station):
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
15 Allowable Pipe Forces and Moments: See Code 3 Drawing
-------- ---------------------------------------- --------- ----------------------------------------------------------------
16 Parts Lists: *
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
17
-------- ---------------------------------------- --------- ----------------------------------------------------------------
18 Performance Curves: See Appendix A
-------- ---------------------------------------- --------- ----------------------------------------------------------------
LD Control System Configuration A108 1 6 12
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
Excitation System Elementary Diagrams 1 6 12
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
19 Material Test and Mill Certificates: N/A
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD 20 Operating & Maintenance Manuals: 12 Copies @ Delivery
-------- ---------------------------------------- --------- ----------------------------------------------------------------
21 Motor Data Sheets (See Section 6.0) 2
including Atomizing air Compressor monthss
and Water Injection Skid: prior
to ship
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
22 Hydrostatic/Running/Performance
Tests:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
23 Max. Piece Weight and Dimension
Data:
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
23.1 Gas Turbine Package Weight MLI 1 6 14
& Center of Gravity & Lifting 0408
Relative Data
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<PAGE>
<CAPTION>
----------------------------------------------------------------------------------------------------------------------------
Issued--Approved
Issued--For Approval for Installation
-------- ---------------------------------------- --------- ------------------------------- --------------------------------
GE Repro- Repro-
Code Category Code ducible Prints Wks ducible Prints Wks
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
24 Manufacturer's Data: *
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
25 Vessel, Tank, Exchanger Drawings: *
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
26 Instrument Installation Drawings: @ SHIP
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
27 Control System Configuration: @ SHIP
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
LD Platform/walkway Details 1 6 9
-------- ---------------------------------------- --------- ----------- ---------- -------- ----------- ---------- ---------
</TABLE>
------------------
* Provided in O&M Service Manuals
(1) Weeks are from the Order Definition Meeting
3.0 NOTES
3.1 Prior to receipt of Buyer approval on drawings issued "For
Approval", Seller may proceed at its risk, subject to the
terms of the P.O., with fabrication.
3.2 Documents submitted to Buyer "For Approval" will be marked,
signed and returned. Those marked "Approved as Noted" or
"Disapproved" must be corrected by Seller and returned to
Buyer within 30 working days after receipt of comments. A
response and/or disposition to returned drawings shall be made
within no more than 30 working days.
4.0 TESTS
4.1 Seller shall conduct shop tests as specified in Appendix A.
4.2 Seller shall notify the Buyer at least 10 working days in
advance of starting any test where possible. Neither
completion of the work nor shipment of any part of the
equipment, however, will be delayed to accommodate Buyer's
inspector.
5.0 INSTRUCTIONS
5.1 Equipment must be tagged with Seller's device tag numbers as
designated in the purchase order, or on the first issue of
approval drawings, for proper identification at jobsite.
5.2 Each Seller document requested above must be identified by a
specific project number and by both the Seller's equipment tag
numbers of the individual components, if any, and the package
as a whole.
5.3 All Seller documents plus one (1) copy of Transmittal Letter
shall be forwarded to:
Buyer: (_________________) Seller: (__________________)
<PAGE>
5.4 When submitting drawings and/or data, Seller shall incorporate
as many similar items as possible on each document.
5.5 Any Seller documents required as a result of issuing of
supplements to the Purchase Order shall be handled in the
manner outlined above.
6.0 MOTOR DATA
SELLER SHALL FURNISH THE FOLLOWING ELECTRICAL DATA IN ACCORDANCE WITH
CODE 21 ON PAGE 7:
6.1 Motor manufacturer's certified outline drawing.
6.2 Manufacturer's certified standard nameplate report data sheet.
The following is a minimum requirement:
1) Manufacturer's Type and Frame Size
2) Horsepower Output
3) Time Rating
4) Max Ambient Design Temperature
5) Insulation System Design
6) RPM at rated load.
7) Frequency
8) Number of phases
9) Rated load ampere
10) Rated voltage
11) Code letter for lock rotor kVA
12) Design letter
13) NEMA nominal efficiency
14) Service factor
Nameplate shall be of stainless steel and stamped per NEMA
Standard MG 1 Part 10. Nameplate information shall include as
a minimum, in addition to MG 1, the nominal efficiency value
per NEMA Standard MG 1 Part 12, the manufacturers stock,
design, and/or serial number, the UL, CSA, or other approved
Listing Mark, a connection or phase sequence diagram with
rotational arrows, and bearing replacement information. The
bearing identification shall conform with accepted industry
standards, not vendors proprietary nomenclature. Motor shall
also be properly marked for the hazardous atmosphere rating of
the internal anti-condensation heater, and of the motor, if
applicable.
7.0 SPECIAL DATA REQUIREMENTS
7.1 For pressure vessels, fabrication shall be in accordance with
the ASME Boiler and Pressure Vessel Code if required by
Appendix A. Section VIII, Division 1, or Section 1, where
applicable, and where not applicable, fabrication shall be
equivalent to ASME Code.
7.2 Manufacturer of pressure vessels (lube oil coolers) shall make
available at its facility data regarding pressure vessel
design and manufacture for Buyer's review. Unit specific data
pertinent to the operation and maintenance of the equipment
shall be provided in Seller's Service Manuals, submitted at
the time of shipment.
7.2.1 The following information, where available, shall be
included:
<PAGE>
(A) ASME Manufacturer's Data Sheet (Form U-1)
(B) ASME Dimensional Sketch ("As Built") where
spot x-rays shall be shown on the "As Built"
Drawing.
(C) Certified Record Showing Location of Heat
Numbers
(D) Radiograph Record
(E) Certified Report of Chemical Analysis and
Physical Properties of all materials used.
(F) Photostatic Copy of Stress Relief Recording
Charts (Affidavit Attesting Acceptance)
(G) Code Stamp Facsimile (Rubbings) of Nameplate.
8.0 STAMPING AND NAMEPLATE
8.1 A GE nameplate suitable for outdoor installation shall be
supplied and mounted on a readily visible part of the
Equipment. Information contained on the nameplate shall be
reviewed at the Design Finalization Meeting.
8.2 The Buyer's order number, item identification number (tag
no.), official code symbol and other data as required by the
specified code or local authorities having jurisdiction over
the installation shall be stamped by Buyer's EPC Contractor
on-site. Seller shall provide a ship loose tag kit to
facilitate this requirement.
9.0 EPC CONTRACTOR DOCUMENTATION REQUESTS
Other documentation required by the Buyer's EPC Contractor will be
specified prior to equipment release for engineering and mutually
agreed to at the Design Finalization Meeting.
10.0 PREPARATION FOR SHIPMENT
All equipment parts shall be dry, thoroughly cleaned inside and outside
and free of all dirt and loose foreign materials. All flange faces and
other machined surfaces shall be coated with a readily removable rust
preventative coating and protected against damage during shipment all
in accordance with Seller's standard practices. Threaded openings shall
be protected with solid steel plugs.
11.0 GENERAL NOTES
11.1 Reserved
11.2 Gas Turbine Documentation
The information contained on each drawing and the purpose of
each is described below:
ONE-LINE DIAGRAM - MLI 0444
This drawing contains a simplified electrical schematic of the
power system from generator ground to the Buyer's high voltage
bus including protective relaying, excitation system and
synchronizing system. Also shown on this drawing are auxiliary
power systems with schematic display of distribution panels. A
location key is used to indicate component locations. Device
nomenclature follows the IEEE standard for electrical
switchgear.
The purpose of this drawing is to define for system
coordination protective functions, operational functions
(synchronization, breaker closure, load control), short
circuit limitations and auxiliary power requirements.
<PAGE>
CABLE SUMMARY - MLI 0463
This drawing contains information for interconnecting cables
and wires connecting to Seller supplied equipment. It
indicates "from/to" information, cable size for Seller
supplied cables and voltage level requirements, information
for the Buyer to supply interconnecting cable/wire not
furnished by Seller, and prepare bid specifications for
quotation on installation of all required cable/wire.
The purpose is to define requirements for Seller and
Buyer-supplied cables/wires and necessary information for
installation bids.
BUYER'S ELECTRICAL CONNECTION OUTLINE - MLI 0301
This drawing contains dimensional data concerning location of
gas turbine power plant equipment junction boxes, receptacles,
cutouts, electrical devices requiring field interconnections
and ground stud locations.
Cable routing through conduit embedments shown on the
Foundation Interface Drawing is shown on this drawing.
The purpose is to provide necessary information to allow the
Buyer to determine cable trenches and conduit needs for Seller
and Buyer-supplied cables/wiring. This drawing identifies the
routing of Seller supplied cables through the foundation
conduit embedments.
GAS TURBINE GENERATOR MECHANICAL OUTLINE - MLI 0306
The mechanical outline provides dimensional data (length,
width, and height) of the gas turbine package, inlet air
filter and all other major pieces of Seller supplied
equipment.
The purpose of this drawing is to define space requirements
for station layout, show generator rotor removal dimensions,
cooler tube bundle and lubrication oil filter removal
dimension, vertical centerlines for major pieces and outline
dimensions of the pieces of equipment that extend beyond the
perimeter of the gas turbine package.
BUYER'S PIPING CONNECTION OUTLINE - MLI 0313
This drawing shows the outline of the gas turbine package with
detailed dimensions for Buyer supplied field piping
connections with interface dimensions for points that must be
connected to a station sump or drain.
The purpose is to define the location of field piping
connections for Seller supplied loose piping and components,
as well as Buyer supplied piping. This includes LCI pre-cooler
and cooler.
NOTES FOR BUYER'S PIPING CONNECTION OUTLINE - MLI 0314
The Buyer's piping connection notes give piping interface data
including thread and flange sizes and ratings. Descriptive
information is given for connections that are normally plugged
and/or are to be connected to the station sump.
The purpose is to define piping connections shown on The
Buyer's Piping Connection Outline. This includes LCI
pre-cooler and cooler.
<PAGE>
FOUNDATION INTERFACE OUTLINE - MLI 0323
This drawing contains foundation interface information for the
main gas turbine and inlet air filter foundation including pad
locations and loadings for embedded sole plates. Embedded
conduit locations and sizes within the gas turbine foundations
are defined.
The purpose is to provide information for the design of the
foundation for the gas turbine supplied components located on
the unit centerline.
FOUNDATION BOLTING ARRANGEMENT - MLI 1603
This drawing depicts the arrangement of the bolting of the gas
turbine, generator, Seller supplied components located on the
gas turbine centerline, inlet and exhaust ducts and inlet air
filter to the main foundation. The material required for
leveling and bolting the components to the foundation and the
shims, keyways and keys required for alignment of the gas
turbine are defined and the materials that are supplied by
Seller are identified.
The purpose of this drawing is to supplement the information
presented on the Foundation Interface drawing and to define
the material supplied by Seller.
OFF-BASE EQUIPMENT FOUNDATION INTERFACE OUTLINE - MLI 0326
This drawing contains the same information as the preceding
drawing except it is for the off-base mechanical and
electrical components supplied by Seller. It also includes
equipment envelope dimensions and piping and electrical
connection points. It also includes platform foundation
interface information.
GAS TURBINE PACKAGE WEIGHT AND CENTER OF GRAVITY -
MLI 0407 & 0408
This drawing contains the location of package unit weights and
center of gravity for the control compartment, accessory and
turbine compartment, generator, GAC, inlet compartment, inlet
and exhaust systems, static start equipment, and on-base
coolant water module, if provided.
The purpose is to provide suggested slinging arrangements and
to assist the Buyer in determining lifting requirements for
heavier pieces of equipment.
SCHEMATIC PIPING DIAGRAMS - MLI 0040
These diagrams are functional representations of all packaged
power plant fluid systems, such as lubrication oil, coolant
system, fuel and fuel forwarding. They contain information
regarding flow rates, pressures and temperature requirements
at Buyer connection points and identify system capacity to
determine initial fill requirements.
The purpose is to provide information to allow the Buyer to
determine station interconnecting piping design requirements,
location of off-base skids, and the amount of lubrication oil
and coolant required for operation of the power plant. The
schematics also act as source documents for generation of the
device summary.
DEVICE SUMMARY - MLI 0414
The device summary defines the functional characteristics for
all mechanical and electrical devices on the gas
turbine-generator and their associate components. It is
developed from all the schematic drawings and forms the basis
for the cable block diagram and connection outlines.
<PAGE>
DOCUMENTATION LIST - MLI 0438
This drawing is intended to provide a list of commonly
required specifications and recommendations for equipment or
commodities supplied by the Buyer.
The following is provided as applicable:
- Buyer documentation index
- Coolant recommendations for closed cooling system
(not included)
- Fuel oil specification
- Fuel gas specification
- Lubrication oil recommendations
- Welding symbol interpretation
- Cable installation data
- Drafting symbols
- Insulation recommendations
The purpose is to provide information to allow the Buyer to
determine requirements for the aforementioned items.
STARTUP AND OPERATION DOCUMENTS
Documentation associated with the checkout, initial startup
and routine operation of the Gas Turbine Generator Packaged
Power Plant include the following:
- Consolidated Service Manuals; available at time of unit
shipment
- Turbine Control Specification; available at time of unit
shipment
- Elementary Diagrams; available at time of unit shipment
- Startup Report; available after initial operation of
the unit
In addition, previously supplied functional drawings such as
the one line, schematic piping device summary and elementary
diagrams are heavily utilized during the functional checkout
and initial startup operations.
CONSOLIDATED SERVICE MANUALS
The Consolidated Service Manuals are comprised of: Instruction
Book, Inspection & Maintenance Manual and Spare and Renewal
Parts Book. Twelve (12) copies are provided.
The Instruction Book portion of the Consolidated Service
Manuals contains site specific information on turbine
generator operation. Normal operating sequences are described,
together with normal running inspections for all supplied
equipment and systems. Trouble-shooting and diagnostic
recommendations are also included. Special notes, and
cautionary and warning statements are included and highlighted
throughout the instruction book to enable easy recognition of
special procedures and techniques which must be followed to
ensure correctness and safety for equipment and personnel.
Operating information is also included for all components and
systems that are standardized in their design.
The Inspection and Maintenance Manual provides information for
inspection and maintenance of the gas turbine, its accessories
and auxiliary systems over the life of the equipment.
Recommended procedures for scheduling inspections and planning
maintenance outages, including recommended spares, tools and
equipment are provided. Standard practices for
<PAGE>
disassembly, component inspection and reassembly are described
in detail. Copies of the necessary reporting forms are also
provided.
The Spare and Renewal Parts Book includes all necessary gas
turbine accessory and auxiliary system drawings to allow the
ordering of replacement and expendable materials, parts,
components, and assemblies for all routine inspection and
maintenance activities. It is organized along the same lines
as the model list, or master drawing index, used to
manufacture the gas turbine in the factory, and is specific to
the site.
TURBINE CONTROL SPECIFICATION
The turbine control specification provides all recommended
turbine control panel settings, control system calibration
procedures and turbine operating sequences. It is a site
specific document, and together with the device summary and
gas turbine and generator elementary, provides information on
all field settable control and protective equipment.
ELEMENTARY DIAGRAMS
Elementary diagrams are provided for the gas turbine and
generator controls, including the excitation system. The
turbine control elementary diagram is primarily functional,
and although some hardware representation is included where
appropriate, it concentrates on a pictorial representation of
the turbine and auxiliary system sequencing and control and
protection algorithms implemented in the panel software. The
turbine control panel is also supported for checkout purposes
by a hardware connection diagram that depicts all internal
hardware connections.
The generator and power system elementary diagram is also
functional, however, since control, protection and sequencing
are accomplished with hardware elements, it is more
representative of the actual system hardware configuration.
The same is also true of the motor control centers for all
electrically powered auxiliaries.
STARTUP REPORT
The startup report is prepared by Seller's field startup
engineer after completion of the initial operation of the
unit. It provides an indication of the initial settings and
startup control characteristics for the gas turbine, generator
and all auxiliary systems. It is useful for anticipating
trouble and performing diagnostic work at least through the
first inspection period, and in many cases, over the life of
the installation.
<PAGE>
GE POWER SYSTEMS
---------------------------------------------
APPENDIX H - EPC SCHEDULE
--------------------------------------------------------------------------------
The following is a description of information which cannot be submitted
electronically:
EXHIBIT VII - EPC PROJECT SCHEDULE - GEORGIA
Nine Pages of Project Schedule
<PAGE>
APPENDIX I - TECHNICAL ADVISORY SERVICES
AND COMMISSIONING ASSISTANCE
Qualified electrical, mechanical and controls Technical Advisors to
support the installation, startup and commissioning and performance
testing of the supplied equipment are provided.
DEFINITION
Technical Advisory Service is defined as technical advice and
counsel based on good engineering, manufacturing, installation
and operation practices as applicable to the equipment. Such
services may also include testing, adjustment, programming and
other similar services.
DESCRIPTION OF TYPICAL TECHNICAL ADVISORY SERVICES
GE TURBINE-GENERATOR INSTALLATION
LEAD TECHNICAL ADVISOR
The Turbine-Generator Installation Team is headed by the Lead
Technical Advisor; an experienced GE turbine-generator
installation engineer whose functions and responsibilities
include the following:
- The effective guidance and counseling of the other
GE Technical Advisors to provide for broader
utilization of their skills.
- The integration of the assigned service work with
the Owner representatives to assist in meeting
scheduled startup, completion and operation dates.
- The reporting of pertinent facts on failure of
equipment warranted by GE and its Suppliers to the
proper personnel to permit prompt and equitable
settlement of warranty claims.
- The submittal of timely reports on job progress
and resolution of problems.
- The planning, organization and direction of the
other GE personnel for the installation, startup,
testing and warranty implementation of the
supplied equipment.
- The maintenance of installation records and job
log book.
<PAGE>
TURBINE-GENERATOR INSTALLATION TEAM
The Turbine-Generator Installation Team is comprised of Technical
Advisors skilled in one or more of the following areas: mechanical
erection of gas and steam turbines and related equipment, electrical
equipment installation and testing, SPEEDTRONIC Control System
checkout, calibration and unit startup. Their principal functions and
responsibilities, with respect to Technical Advisory Services, include:
- The inspection and unloading of the major components at the
installation site and their placement on the foundations.
- The setting of necessary shims between sole plates and the
turbines.
- The removal of shipping supports on the turbine and generator
packages.
- The installation of the turbine units to the proper center
line and elevation.
- The alignment of the accessory equipment and generators to the
turbines.
- The installation and checkout of conduit, piping, control
wiring and instrumentation between the turbines and GE
supplied auxiliary equipment and generators.
- Checkout and initial operation of the turbine starting
equipment.
- The sequencing and checkout of the turbine SPEEDTRONIC Control
Panels.
- The installation and checkout of the generator
excitation/electric systems.
- The startup of the turbine units with the Owner's operating
personnel.
- Mark up two (2) sets of drawings to reflect the "as-built"
condition of the equipment. One (l) set for site records and
one (1) set to be returned to GE Customer Service.
2
<PAGE>
GE POWER SYSTEMS
---------------------------------------------
APPENDIX J - NOT USED
--------------------------------------------------------------------------------
TURBINE CONTRACT APPENDIX J
<PAGE>
GE POWER SYSTEMS
---------------------------------------------
APPENDIX K - SITE LEGAL DESCRIPTION
--------------------------------------------------------------------------------
TURBINE CONTRACT APPENDIX K COVER
<PAGE>
LEGAL DESCRIPTION FOR TENASKA PLANT SITE
----------------------------------------
ALL THAT TRACT OR PARCEL OF LAND SITUATE, LYING AND BEING IN LAND LOT
237 OF THE THIRD LAND DISTRICT OF HEARD COUNTY, GEORGIA, AND BEING MORE
PARTICULARLY DESCRIBED AS FOLLOWS:
COMMENCING AT THE INTERSECTION OF THE WESTERLY RIGHT OF WAY LINE OF JOE
STEPHENS ROAD (80 FOOT WIDTH) WITH THE SOUTHERLY RIGHT OF WAY LINE OF GEORGE
BROWN ROAD (PRESCRIPTIVE RIGHT OF WAY, 40 FEET, MORE OR LESS, IN WIDTH), SAID
POINT BEING THE POINT OF REFERENCE; THENCE ALONG THE SOUTHERLY RIGHT OF WAY LINE
OF GEORGE BROWN ROAD SOUTH 72 DEGREES 57 MINUTES 18 SECONDS WEST FOR A DISTANCE
OF 916.24 FEET TO A STEEL FENCE POST FLUSH WITH THE GROUND, SAID POINT BEING THE
POINT OF BEGINNING FOR THE HEREIN DESCRIBED PARCEL OF LAND. THENCE SOUTH 00
DEGREES 16 MINUTES 00 SECONDS WEST FOR A DISTANCE OF 902.40 FEET TO A STEEL
FENCE POST; THENCE SOUTH 02 DEGREES 39 MINUTES 49 SECONDS EAST FOR A DISTANCE OF
321.00 FEET TO A ONE INCH PIPE; THENCE SOUTH 00 DEGREES 34 MINUTES 44 SECONDS
EAST FOR A DISTANCE OF 802.62 FEET TO A ONE INCH PIPE; THENCE SOUTH 00 DEGREES
34 MINUTES 44 SECONDS EAST FOR A DISTANCE OF 291.17 FEET TO A POINT IN THE
CENTERLINE OF HILLY MILL CREEK; THENCE FOLLOWING THE COURSE OF THE CENTERLINE OF
HILLY MILL CREEK IN A WESTERLY DIRECTION, TRAVERSED AS FOLLOWS; NORTH 62 DEGREES
07 MINUTES 20 SECONDS WEST FOR A DISTANCE OF 98.34 FEET TO A POINT IN THE
CENTERLINE OF THE CREEK; THENCE SOUTH 20 DEGREES 00 MINUTES 44 SECONDS WEST FOR
A DISTANCE OF 136.80 FEET TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE
NORTH 74 DEGREES 21 MINUTES 03 SECONDS WEST FOR A DISTANCE OF 223.86 FEET TO A
POINT AT THE CENTERLINE OF A GEORGIA POWER COMPANY TRANSMISSION LINE RIGHT OF
WAY (150 FOOT WIDTH); THENCE NORTH 74 DEGREES 21 MINUTES 03 SECONDS WEST FOR A
DISTANCE OF 36.90 FEET TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE NORTH
47 DEGREES 24 MINUTES 20 SECONDS WEST FOR A DISTANCE OF 127.90 FEET TO A POINT
IN THE CENTERLINE OF THE CREEK; THENCE NORTH 79 DEGREES 16 MINUTES 25 SECONDS
WEST FOR A DISTANCE OF 274.76 FEET TO A POINT IN THE CENTERLINE OF THE CREEK;
THENCE NORTH 54 DEGREES 59 MINUTES 10 SECONDS WEST FOR A DISTANCE OF 188.31 FEET
TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE LEAVING THE CENTERLINE OF THE
CREEK NORTH 27 DEGREES 08 MINUTES 04 SECONDS WEST FOR A DISTANCE OF 142.40 FEET
TO A POINT; THENCE NORTH 76 DEGREES 02 MINUTES 42 SECONDS WEST FOR A DISTANCE OF
170.99 FEET TO A POINT; THENCE NORTH 54 DEGREES 14 MINUTES 27 SECONDS WEST FOR A
DISTANCE OF 280.96 FEET TO A POINT; THENCE NORTH 66 DEGREES 49 MINUTES 01
SECONDS WEST FOR A DISTANCE OF 101.90 FEET TO A POINT; THENCE SOUTH 55 DEGREES
21 MINUTES 00 SECONDS WEST FOR A DISTANCE OF 162.95 FEET TO A POINT; THENCE
NORTH 81 DEGREES 39 MINUTES 29 SECONDS WEST FOR A DISTANCE OF 406.05 FEET TO A
POINT; THENCE NORTH 30 DEGREES 16 MINUTES 39 SECONDS WEST FOR A DISTANCE OF
<PAGE>
496.12 FEET TO AN INTERSECTION OF SAID LINE WITH THE CENTERLINE OF AN UNNAMED
CREEK FROM THE NORTHEAST; THENCE FOLLOWING THE CENTERLINE OF SAID UNNAMED CREEK
TO THE NORTHEAST, TRAVERSED AS FOLLOWS; NORTH 67 DEGREES 00 MINUTES 13 SECONDS
EAST FOR A DISTANCE OF 336.28 FEET TO A POINT IN THE CENTERLINE OF THE CREEK;
THENCE NORTH 64 DEGREES 26 MINUTES 52 SECONDS EAST FOR A DISTANCE OF 296.07 FEET
TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE NORTH 53 DEGREES 40 MINUTES 03
SECONDS EAST FOR A DISTANCE OF 67.68 FEET TO A POINT IN THE CENTERLINE OF THE
CREEK; THENCE NORTH 16 DEGREES 14 MINUTES 29 SECONDS EAST FOR A DISTANCE OF
228.26 FEET TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE NORTH 22 DEGREES
18 MINUTES 47 SECONDS EAST FOR A DISTANCE OF 241.49 FEET TO A POINT IN THE
CENTERLINE OF THE CREEK; THENCE NORTH 06 DEGREES 14 MINUTES 09 SECONDS EAST FOR
A DISTANCE OF 71.42 FEET TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE NORTH
78 DEGREES 23 MINUTES 44 SECONDS EAST FOR A DISTANCE OF 307.88 FEET TO A POINT
IN THE CENTERLINE OF THE CREEK; THENCE NORTH 47 DEGREES 11 MINUTES 56 SECONDS
EAST FOR A DISTANCE OF 157.63 FEET TO A POINT IN THE CENTERLINE OF THE CREEK;
THENCE NORTH 26 DEGREES 01 MINUTES 20 SECONDS EAST FOR A DISTANCE OF 111.97 FEET
TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE NORTH 54 DEGREES 06 MINUTES 33
SECONDS EAST FOR A DISTANCE OF 128.35 FEET TO A POINT IN THE CENTERLINE OF THE
CREEK; THENCE NORTH 07 DEGREES 03 MINUTES 45 SECONDS EAST FOR A DISTANCE OF
34.61 FEET TO A POINT IN THE CENTERLINE OF THE CREEK; THENCE LEAVING THE CREEK
SOUTH 89 DEGREES 40 MINUTES 10 SECONDS EAST FOR A DISTANCE OF 290.53 FEET TO
POINT AT THE CENTERLINE OF A GEORGIA POWER COMPANY TRANSMISSION LINE EASEMENT
(150 FOOT WIDTH); THENCE SOUTH 89 DEGREES 40 MINUTES 10 SECONDS EAST FOR A
DISTANCE OF 177.44 FEET TO A 12 INCH DIAMETER WOOD POST; THENCE NORTH 71 DEGREES
45 MINUTES 00 SECONDS EAST FOR A DISTANCE OF 405.46 FEET TO A STEEL FENCE POST
FLUSH WITH THE GROUND; SAID POINT BEING THE POINT OF BEGINNING.
SAID PARCEL CONTAINS 73.53 ACRES OF LAND, AND IS MORE PARTICULARLY SHOWN AS
TRACT "A" ON SHEET 1 0F 2 OF THAT CERTAIN ALTA/ACSM LAND TITLE SURVEY FOR
TENASKA, INC., FIRST AMERICAN TITLE INSURANCE COMPANY AND OTHER PARTIES TO BE
NAMED, PREPARED BY DONALDSON, GARRET & ASSOCIATES, INC., MACON, GEORGIA, DATED
APRIL 3, 1998.
<PAGE>
GE POWER SYSTEMS
---------------------------------------------
APPENDIX L - WITNESS PLAN
--------------------------------------------------------------------------------
(See Appendix A, Section 11)
TURBINE CONTRACT APPENDIX L
<PAGE>
GE POWER SYSTEMS
---------------------------------------------
APPENDIX M - RIGHTS AND OBLIGATIONS RETAINED BY BUYER
--------------------------------------------------------------------------------
TURBINE CONTRACT APPENDIX M COVER
<PAGE>
APPENDIX M - Section 22.1
RIGHTS AND OBLIGATIONS RETAINED BY BUYER
In the event of the assignment of this Contract pursuant to Section 22.1(b), the
term Buyer as used in this Contract shall mean such Section 22.1(b) Contractor
Assignee, except that Buyer or Buyer's assignee under Section 22.1(a) ("Owner"),
may, at its option, retain some or all of the following rights:
Section 2.4 rights to exercise all Options under Sections
2.4. and 9.2.
Section 4.1 the right under Section 4.1 to (i) direct Seller
to deliver the Equipment to a Delivery Point
other than a location at or near the Site, (ii)
the right to notify Seller to delay shipment of
any Unit(s) and to request a specific alternate
Delivery Date, and (iii) the right to make any
elections under Section 4.1(a).
Section 4.4 the right, jointly with assignee, to exercise
all of the inspection rights under Section 4.4.
Section 5.1 together with assignee, the rights of access set
forth in Section 5.1.
Section 5.2 the right to agree upon a specific list of
Witness Tests.
Section 7.1 the right, along with assignee, to receive all
notices to be delivered by Seller under Section
7.1.
Section 8.1 rights, along with assignee, to the benefits of
all warranties in Section 8.1 and to notify
Seller of a breach under Section 8.1.
Article 9.1 the right to consent to all change orders,
including Directed Change Orders, under Section
9.1 and to receive copies of all dispute notices
delivered by Seller pursuant to Section 9.1.
Article 10 rights, along with assignee, to all warranties
in Article 10, including rights to receive all
payments of liquidated damages due under Article
10.
Article 11 rights to enforce Seller's covenants regarding
confidentiality with respect to the confidential
information of Tenaska, Inc., Owner, and
assignee.
Section 12.1 rights, along with assignee, to be indemnified
by Seller.
<PAGE>
Section 12.2 rights, along with assignee, to require Seller
to provide remedies for infringement.
Section 14.1 the right to consent to the termination of the
Contract under Section 14.1 and in all other
circumstances.
Section 15.1 the right to be included as an Indemnified party
under Section 15.1.
Section 17.2 the right, along with assignee, to receive
delivery of all notices to be delivered by
Seller under Section 17.2.
Section 17.2(d) the right to require Seller to continue remedy
and testing activities.
Section 18.1 the right to appoint a qualified staff member to
function as a Project Coordinator.
