Spreadsheet: benjamin_rogers__1206__United American Energy 03-02-00
Sheet: Assumptions

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PROJECT NAME: UAE-Lowell
ASSUMPTIONS & SUMMARY OUTPUT
SOURCES & USES: |  |  |  |  | PROJECT DESCRIPTION: |  |  |  |  |  | OPERATING COSTS ASSUMPTIONS (FROM ENGINEERS/ASSET MANAGEMENT): |  |  |  |  |  |  |  |  | Fuel | Capacity $ | VOM | Residual Value | Capacity | Chillers | Compressor | Debt
Sources of Funds | % | 000 $ | $/kW |  |  |  |  |  |  |  | (1st year Annualized) |  |  |  |  |  |  |  |  | Index | Base | Pass-through | EBITDA Exit Multiple | ISO | Yes | Yes | Bank LT Debt
Total Equity |  |  |  |  | Type of Turbine |  | LM6000 |  |  |  |  |  |  |  |  |  |  |  |  | Fixed | Low | Not Pass-through | % of Project Cost | 95 degrees | No | No | Capital Market
Debt Issuance |  |  |  |  | Cost Per Turbine (w Carry Cost) (000$) |  | 14260.44960733171 |  |  |  | CPI Escalator (%) |  | 0.03 |  |  |  |  |  |  | Custom | Index |  | 000$/MW |  |  |  | Mini-perm
 |  |  |  |  | Number of Turbines |  | 4 |  |  |  |  |  |  |  |  |  |  |  |  |  | Custom |  | None
Total Sources |  |  |  |  | Net Turbine Rating (MW) |  | 47 |  |  |  | Escalated Costs: |  |  |  |  |  |  |  |  | 1 | 1 | 1 | 1 | 2 | 1 |  | 1
Turbo Charger On | No |  |  |  | Heat Rate-New and Clean (HHV) |  | 10100 |  |  |  |  |  | 000$ -year | $/kW-year | $/mWh
 |  |  |  |  | Heat Rate-Degraded (HHV) |  | 10200 |  |  |  | Variable Operating Cost |  | 153.204 |  | 0.582
Uses of Funds |  |  |  |  | No. of Construction Months |  | 7 |  |  |  | Major [NAME] |  | 576.884 |  | 1.644 |  |  |  |  |  | With Chillers | Without Chillers
EPC (From Engineers/Nepco): |  |  |  |  | Start of Commercial Operation |  | 2001-05-01 00:00:00 |  |  |  | Total VOM |  |  |  |  |  |  |  |  | ISO | 11 | 21
Turbine (with Carrying Cost) |  |  |  |  | No. of Months in the 1st Operating year |  | 8 |  |  |  |  |  |  |  | ESC. |  |  |  |  | 95o | 12 | 22
[NAME] |  |  |  |  | Project Life (Years) |  | 20 |  |  |  | Fixed Operating Expenses |  | 225
Enhanced Sprint Option |  |  |  |  | Location (State) |  | MA |  |  |  | Insurance |  | 112
BOP & Construction |  | 21820 |  |  |  |  |  |  |  |  | SG&A |  | 100
Pipeline |  | 1500 |  |  | Residual Value (at year 20) |  |  |  |  |  | Start Charge
Power Interconnection |  | 1135 |  |  | EBITDA Exit Multiple |  | 5 |  |  |  | Marketing Fee |  | 0
SCR |  | 8000 |  |  | % of Initial Project Cost |  | 0.2 |  |  |  | Admin Fees |  | 0
Dual Fuel |  | 0 |  |  | $/kW |  | 200 |  |  |  | O&M Fees plus capital exp. |  | 93
Black Start |  | 0 |  |  |  |  |  |  |  |  | Total Fixed Escalating Cost
Gas Compression |  | 1500 |  |  | FINANCING ASSUMPTIONS:
Demineralized Water Facility |  | 0 |  |  | DEBT |  | Construction Loan |  |  |  | Non-Escalated Costs:
Noise Mitigation |  | 2350 |  |  | Debt Issued | 2000-10-01 00:00:00 |  |  |  |  | Fuel
T-Line |  | 1500 |  |  | Treasury Rate as of: | 2000-02-15 00:00:00 |  |  |  |  | Property Tax |  |  |  | 0.02
Overhead & Fees - EE&CC |  | 0 |  |  |  |  |  |  |  |  | Franchise Tax
Overhead & Fees - Nepco |  | 200 |  |  | Amount ('000 $) |  |  |  |  |  | [NAME]
LMP Cost Adder |  |  |  |  | Term (yrs) | 20 |  |  |  |  | Debt Service Reserve Fee
Chillers (Check that BOP did not already include this) |  |  |  |  | Final Maturity | 2017-04-01 00:00:00
Sub Total |  |  |  |  | Average Life (yrs) |  |  |  |  |  | DEPRECIATION ASSUMPTIONS:
 |  |  |  |  | Treasury Rate (%) | 0.065 | 0.065 |  |  |  |  |  | Year | Method | Residual (%)
Soft Cost (From Engineers/Asset Management): |  |  |  |  | Spread (%) | 0.0175 | 0.0175 |  |  |  | Federal & State Tax Depreciation
Spare Parts |  | 1300 |  |  | All-In Rate (%) |  |  |  |  |  | EPC Costs |  | 15 | MACRS | 0
EE&CC Program Management |  | 225 |  |  |  |  |  |  |  |  | Start-Up Cost |  | 5 | SL | 0
Mobilization Expenses |  | 0 |  |  | Maximum DSR Amount (000 $) | 4028.661318372296 | 6 | (months/year) |  |  | Transaction Costs |  | 20 | SL | 0
Environmental Permitting |  | 600 |  |  | Debt Service Reserve [NAME] | 0.02
Insurance |  | 0 |  |  | Interest Income Rate | 0 |  |  |  |  | Book Depreciation
Capitalized Salaries |  | 0 |  |  |  |  |  |  |  |  | EPC Costs |  | 30 | SL | 0.1
Owner's Engineer |  | 0 |  |  | EQUITY |  |  |  |  |  | Start-Up Cost |  | 5 | SL | 0
Development Expenses |  | 0 |  |  | Equity Closed | 2000-04-01 00:00:00 |  |  |  |  | Transaction Costs |  | 20 | SL | 0
Legal Expense |  | 150 |  |  | Equity Partner's Share | 0
Interconnect Study |  | 20 |  |  | Enron's Share |  |  |  |  |  | TAX ASSUMPTIONS (PROJECT MAY INCLUDE SPECIFIC TAXES):
IDC
Land |  | 1000 |  |  | PPA ASSUMPTIONS (MAKE CHANGES AS NEEDED): |  |  |  |  |  | Federal Income Tax Rate (%) |  | 0.35
Sales & Used Tax |  |  |  |  |  |  |  |  |  |  | State Income Tax Rate (average %) |  | 0.07 | (Project Specific)
Contingency |  | 0 |  |  | Fixed Price PPA |  |  |  |  |  | Franchise Tax (% on Net Asset) |  | 0 | (Project Specific)
Sub Total |  |  |  |  | No. of years |  | 20 |  |  |  | [NAME] (%) |  | 0 | (Project Specific)
 |  |  |  |  | Capacity Charge ($/kW-mo.) |  | 6.52 |  |  |  | Sales & Used Tax Rate on Fuel (%) |  | 0.015 | (Project Specific)
Financing Costs: |  |  |  |  |  |  |  |  |  |  | Sales & Used Tax Rate on Hard Cost (%) |  | 0.05 | (Project Specific)
Lender's Engineer |  | 0 |  |  | Merchant Price Period
Lender's Counsel |  | 0 |  |  | No. of years
Financing Fee (All-in Fees) |  | 1000 |  |  | Capacity Charge ($/kW-mo.)
Sub Total
 |  |  |  |  | Variable Payment ($/mWh)
Total Uses
 |  |  |  |  | Net Generation (MWh)
SUMMARY OUTPUT: |  |  |  |  | TECHNICAL ASSUMPTIONS:
All-in Capital Cost ($/kW) |  |  |  |  | Site Condition (MW)
 |  |  |  |  | LMP Adder
 |  | [NAME]. | Min |  | Evaporative Cooler (MW) |  | 0
DSCR |  |  |  |  | Net Output (MW)
Enron Equity Returns |  |  |  |  | No. of Starts per year |  | 140
20 Yrs After-Tax Cashflow with Zero Residual Value |  |  |  |  | Available PSIG |  | 400
 |  |  | Target |  | No. of Run Hours per year |  | 2500
 |  |  | 0.12
Key Stats
EBITDA (000 $)
Net Income (000 $)
Pre-Tax Cashflow (000 $)
Cashflow to Equity (000 $)