The remainder of the net electrical energy produced by the Partnerships, if any, is available for sale to the marketplace either directly to third parties or via NextEra Energy Resources' power marketing subsidiary. The NEA and NJEA power purchase agreements provide for fixed annual quantities with allowances for certain operational issues. |
One of the NEA power purchase agreements was required to have an energy bank to record cumulative payments made by the utility in excess of avoided cost rates scheduled or specified in that agreement. The energy bank balance bore interest at a rate specified in the agreement, and was partially secured by a letter of credit. In accordance with the agreement, in January 2007 NEA fulfilled its obligations to the utility related to the energy bank, and the energy bank requirement no longer applies.
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In December 2003, an agreement between NJEA and a New Jersey utility became effective to amend and restate the power purchase agreement in order to realize cost savings by sourcing power from the wholesale market rather than NJEA's facility during periods when market prices are lower than generation costs. The agreement provides for, among other things, the delivery of electricity to the New Jersey utility from sources other than NJEA's facility when NJEA decides to do so. In connection with this restructuring, NJEA amended its long-term natural gas supply agreement with PSE&G. Under the terms of the amended long-term natural gas supply agreement, the supplier provides all of the fuel required to run the facility when it is operating.
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In connection with the NJEA amended and restated power purchase agreement, in March 2004, NJEA exercised its option to terminate its steam sales contract since the NJEA facility no longer operates as a base load facility. Under the terms of the termination agreement, NJEA no longer supplies steam to the steam offtaker and NJEA was obligated to pay the offtaker a monthly fee of approximately $0.4 million through December 2007.
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In February 2005, the amended and restated power purchase agreements among NEA as seller and NSTAR as utility purchaser became effective. The amended and restated agreements provide for, among other things, NEA obtaining the right to source power from the wholesale market in addition to sourcing power from NEA's facility. Affiliates of NE LP's partners paid approximately $29.9 million to the utility purchasers in the form of loans to NE LP in the same amount due on December 31, 2005. This payment was capitalized as part of the power purchase agreements' intangible asset on the balance sheet at December 31, 2005. These loans were repaid with interest in April 2005 from funds otherwise available for NE LP partnership distributions.
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As a result of the amended and restated power purchase agreements, NE LP and the Partnerships adopted Emerging Issues Task Force Issue No. (EITF) 91-6, "Revenue Recognition of Long-Term Power Sales Contracts", which requires NE LP and the Partnerships to recognize revenue as the lesser of the amount billable under the agreement or the estimated average revenue over the term of the agreements.
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NEA entered into two long-term natural gas supply agreements with PMI and SEMNA effective March 31, 2005 that enable NEA to purchase sufficient fuel for production.
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The Partnerships will continue to receive the natural gas that fuels the Partnerships' facilities through long-term natural gas supply agreements with PMI and SEMNA and, in the case of NJEA, with PSE&G. Natural gas is transported to, or stored for later use by, the Partnerships pursuant to long-term natural gas transportation and storage agreements. The remainder of the daily fuel requirement is satisfied by open-market purchases.
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ESI Northeast Fuel, an indirect wholly-owned subsidiary of NextEra Energy Resources, is the fuel manager for the Partnerships and provides fuel management and administrative services by contracting with PMI. In 2005, a supplemental fuel management subcontract agreement was entered into to allow PMI to purchase energy, ancillary services and capacity from the NEA facility or from the marketplace and sell to the purchasers under the NEA amended and restated power purchase agreements.
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NextEra Operating Services, a wholly-owned indirect subsidiary of NextEra Energy Resources, provides O&M services for the Partnerships. See Management's Discussion - Related Party Information.
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Seasonality. Revenues recognized and payments due to NJEA under the JCP&L power purchase agreement during the winter and summer seasons are substantially higher than those in spring and fall. Otherwise, the business of the Partnerships is not materially subject to seasonal factors.
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Environmental. Federal, state and local environmental laws and regulations cover air and water quality, land use, power plant and transmission line siting, lead paint, asbestos, noise and aesthetics, solid waste, natural resources, wildlife mortality and other environmental matters. Compliance with these laws and regulations could increase the cost of electric service by requiring, among other things, changes in the design and operation of the facilities. Environmental laws and regulations are subject to change. The following is a discussion of emerging federal and state initiatives and rules that could potentially affect NE LP and the Partnerships.
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Climate Change - The U.S. Congress and certain states and regions are considering several legislative and regulatory proposals that would establish new regulatory requirements and reduction targets for greenhouse gases. These legislative and regulatory proposals have differing methods of implementation and the impact on NE LP's and the Partnerships' facilities and/or the financial impact (either positive or negative) to NE LP and the Partnerships could be material, depending on the eventual structure of any legislation enacted or specific implementation rules adopted.
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The Regional Greenhouse Gas Initiative (RGGI) is a greenhouse gas reduction initiative whereby ten Northeast and Mid-Atlantic member states, including Massachusetts and New Jersey, have established a cap and trade program (a system by which affected generators buy and trade allowances under a set cap) for covered electric generating units. RGGI members have agreed to stabilize power plant carbon dioxide (CO2) emissions at 2009 levels through the end of 2014 and to further reduce the sector's emissions another 10% by the end of 2018. The RGGI greenhouse gas reduction requirements will affect NE LP's and the Partnerships' two facilities, requiring those facilities to acquire CO2 allowances for emissions of CO2 beginning in 2009. All RGGI states have enacted legislation and regulations and NE LP and the Partnerships, through PMI, began participating in quarterly CO2 emissions allowance auctions in 2008. While NE LP and the Partnerships anticipate additional variable costs as a result of RGGI, the y do not expect such costs to have a materially adverse affect on their financial condition or future operating results.
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During 2008, 2007 and 2006, the registrants were not required to make capital additions to comply with environmental laws and do not anticipate incurring such costs in 2009, 2010 or 2011.
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Competition. Competitive wholesale markets in the United States continue to evolve and vary by geographic region. Revenues from electricity sales in these markets vary based on the prices obtainable for energy, capacity and other ancillary services. Some of the factors affecting success in these markets include the ability to operate generating assets efficiently and reliably, the price and supply of fuel, transmission constraints, competition from new sources of generation, effective risk management, demand growth and exposure to legal and regulatory changes. Although substantially all of the Partnerships' output is committed under the power purchase agreements described above, these factors may adversely affect energy prices under certain power purchase agreements that are tied to the wholesale electric market prices. NE LP and the Partnerships do not expect electric utility industry restructuring to result in any material adver se change to prices under the Partnerships' power purchase agreements.
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The Partnerships operate in two power pools. NEA operates in NEPOOL and NJEA operates in PJM, each of which has an independent system operator that manages the wholesale electricity market and the transmission of electricity. While legislators and state regulatory commissions will decide what impact, if any, competitive forces will have on retail transactions, the FERC has jurisdiction over potential changes which could affect competition in wholesale transactions. The FERC has approved various filings submitted by NEPOOL and PJM regarding electric industry deregulation initiatives.
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In 2006, the FERC approved a settlement agreement that established a new forward capacity market in the NEPOOL region. The parties to the settlement agreement include wholesale power generators in New England, including NEA and four of the six New England states. Under the settlement agreement, capacity payments to generators will be established competitively through annual auctions, the first of which was conducted in February 2008 to purchase capacity for the twelve months starting June 1, 2010. The settlement agreement also provides for a transition period that began on December 1, 2006 and continues through May 31, 2010, during which capacity suppliers will receive fixed capacity payments, subject to penalties for forced outages during peak demand periods. The settlement agreement, as approved by the FERC, is expected to continue to result in increased gross margins for the NEA facility during the transition period. Total fixed capacity payments received under the settlement agreement were $13.1 million, $11.3 million, and $0.9 million for the periods ended December 31, 2008, 2007, and 2006, respectively.
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Item 1A. Risk Factors |
Risks Relating to Registrants' Business
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The following are some important factors that could have a significant impact on the Acquisition Corp.'s and/or NE LP's operations and financial results, including the operations and results of the Partnerships, and could cause the Acquisition Corp.'s and/or NE LP's actual results or outcomes, including those of the Partnerships, to differ materially from those discussed in forward-looking statements made by or on behalf of the Acquisition Corp. and/or NE LP in this combined Form 10-K, in response to questions or otherwise:
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The registrants are subject to complex laws and regulations and to changes in laws or regulations, as well as changing governmental policies and regulatory actions, with respect to, among other things, initiatives regarding deregulation and restructuring of the energy industry and environmental matters, including matters related to the effects of climate change, operation of generation facilities, and present or prospective competition. This substantial and complex framework exposes the registrants to increased compliance costs and potentially significant monetary penalties for non-compliance.
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The registrants are subject to extensive federal, state and local environmental statutes, rules and regulations as well as the effect of changes in or additions to applicable statutes, rules and regulations that relate to, or in the future may relate to, for example, air quality, water quality, climate change, greenhouse gas emissions, CO2 emissions, waste management, marine and wildlife mortality, natural resources, health, safety and renewable portfolio standards that could, among other things, restrict or limit the output of certain facilities or the use of certain fuels required for the production of electricity and/or require additional pollution control equipment and otherwise increase costs. There are significant capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could be even more significant in the future.
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The registrants operate in a changing market environment influenced by various legislative and regulatory initiatives regarding regulation, deregulation or restructuring of the energy industry, including, for example, deregulation or restructuring of the production and sale of electricity, as well as increased focus on renewable and clean energy sources and reduction of carbon emissions. The registrants and the Partnerships will need to adapt to these changes and may face increasing costs and competitive pressure in doing so.
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A substantial portion of the output from the Partnerships' power generation facilities is sold to two regulated utilities under five power purchase agreements, two of which terminate in 2011 and the other three in 2016. The limited number of power purchasers creates a concentration of counterparty risk. The remaining output from the power generation facilities is sold, from time to time, in the merchant markets. In addition, it is expected that upon expiration of the power purchase agreements, the residual portion of the electrical output of the generation facilities will be sold in the merchant markets. The sale of power in the merchant markets is based on market conditions at the time of sale. The amount and timing of revenues to be received from the merchant markets in the future is uncertain. Economic factors, such as the current downturn, could adversely affect energy consumption and could adversely affect the results of operations of the registrants.
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The operation and maintenance of power generation facilities involve many risks, including, for example, start up risks, breakdown or failure of equipment, transmission lines or pipelines, the inability to properly manage or mitigate known equipment defects in the Partnerships' generation facilities unless and until such defects are remediated, use of new or unproven technology, the dependence on a specific fuel source, such as natural gas, failure or delay in the supply or transportation of fuel, or the impact of unusual or adverse weather conditions (including natural disasters), and the risk of performance below expected or contracted levels of output or efficiency. This could result in lost revenues and/or increased expenses, including, for example, the requirement to purchase power in the market at potentially higher prices to meet contractual obligations, or lost revenues due to prolonged outages. Insurance, warranties or performance guarantees may not cover any or all of the lost revenues or increased expenses, including, for example, the cost of replacement power. Breakdown or failure of an operating facility may prevent the facility from performing under applicable power sales agreements which, in certain situations, could result in termination of the agreement or incurring a liability for liquidated damages.
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NE LP and the Partnerships use derivative instruments, such as swaps, futures, and forwards, some of which are traded in the over-the-counter markets or on exchanges, to manage their commodity and financial market risks. The registrants could recognize financial losses as a result of volatility in the market values of these derivative instruments, or if a counterparty fails to perform or make payments under these derivative instruments. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these derivative instruments involves management's judgment or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the reported fair value of these derivative instruments.
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In addition to risks discussed elsewhere, risk factors specifically affecting the registrants' success in competitive wholesale markets include, for example, the ability to efficiently operate generating assets, the successful and timely completion of project restructuring activities, the price and supply of fuel (including transportation) and equipment, transmission constraints, competition from other and new sources of generation, excess generation capacity and shifting demand for power. There can be significant volatility in market prices for fuel, electricity and renewable and other energy commodities, and there are other financial, counterparty and market risks that are beyond the control of the registrants. The registrants' inability or failure to effectively hedge their assets or positions against changes in commodity prices, interest rates, counterparty credit risk or other risk measures could significantly impair their future financial results. In addition, the registrants' business depends upon pow er transmission and natural gas transportation facilities owned and operated by others; if transmission or fuel transportation is disrupted or capacity is inadequate or unavailable, the registrants' ability to sell and deliver their wholesale power may be limited or their costs may increase.
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The registrants' rely on contracts with vendors for the supply of fuel and equipment required for the operation of their facilities. If vendors fail to fulfill their contractual obligations, the registrants may need to make arrangements with other suppliers, which could result in higher costs and/or a disruption to their operations.
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The registrants' results of operations are affected by changes in the weather. Weather conditions directly influence the demand for electricity and natural gas and affect the price of energy commodities, and can affect the production of electricity at power generation facilities. The registrants' results of operations can be affected by the impact of severe weather which can be destructive, causing outages and/or property damage, may affect fuel supply, and could require additional costs to be incurred.
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The registrants are subject to costs and other potentially adverse effects of legal and regulatory proceedings, settlements, investigations and claims, as well as regulatory compliance and the effect of new, or changes in, tax laws, rates or policies, rates of inflation, accounting standards, securities laws and corporate governance requirements.
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The Partnerships are subject to mandatory reliability standards promulgated by the North American Electric Reliability Corporation and enforced by the FERC. These standards, which previously were being applied on a voluntary basis, became mandatory in June 2007. Noncompliance with these mandatory reliability standards could result in sanctions, including substantial monetary penalties.
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The registrants are subject to direct and indirect effects of terrorist threats and activities, as well as cyber attacks and disruptive activities of individuals and/or groups. Infrastructure facilities and systems, including, for example, generation, transmission and distribution facilities, physical assets and information systems, in general, have been identified as potential targets. The effects of these threats and activities include, but are not limited to, the inability to generate, purchase or transmit power, the risk of a significant slowdown in growth or a decline in the United States economy, delay in economic recovery in the United States, and the increased cost and adequacy of security and insurance.
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The registrants' ability to obtain insurance, and the cost of and coverage provided by such insurance, could be adversely affected by international, national, state or local events as well as registrant-specific events.
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The registrants, the Partnerships and the Funding Corp. are substantially leveraged. The ability of the registrants, the Partnerships and the Funding Corp. to make interest and principal payments and fund capital expenditures is dependent on the future performance of the Partnerships. Future performance is subject to general economic, financial, competitive, legislative, regulatory and other factors that are beyond the control of the registrants. The registrants, the Partnerships and the Funding Corp. are also subject to restrictive covenants under their debt agreements that will limit their ability to borrow or otherwise have access to additional funds.
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All obligations of the Partnerships are non-recourse to the direct and indirect owners of the registrants. Following any default by the Partnerships, security is limited to the owners' economic interests in the Partnerships. The owners have no meaningful revenues other than the distributions they receive from the Partnerships. In the event of default, the ability of the owners to satisfy any obligations will be limited to amounts payable by the Partnerships as distributions.
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The risks described herein are not the only risks facing the registrants. Additional risks and uncertainties also may materially adversely affect the Acquisition Corp.'s and/or NE LP's business, financial condition and/or future operating results.
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Item 1B. Unresolved Staff Comments
None.
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Item 2. Properties
Management of each of the registrants believes that the properties of the registrants and their subsidiaries are adequate for their operations. As of December 31, 2008, the Partnerships had the following properties: |
Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations |
This discussion should be read in conjunction with the Notes to Consolidated and Combined Financial Statements and Notes to Financial Statements contained herein. In the discussion of Results of Operations below, all comparisons are with the corresponding items in the prior year.
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Results of Operations
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NE LP Consolidated
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NE LP's net income for 2008, 2007 and 2006 was $133.2 million, $90.4 million and $167.2 million, respectively. Net income for 2008 increased due to favorable pricing of $68.5 million which is reflected in revenues, partially offset by increased fuel costs of $41.4 million. Net income for 2007 was affected by increased fuel costs of $55.4 million, net unrealized mark-to-market losses of $2.3 million on derivatives and favorable pricing, primarily on purchased power, of $0.4 million which is reflected in revenues. Net income for 2006 included fuel savings of $49.0 million, net unrealized mark-to-market gains of $6.1 million on derivatives and unfavorable pricing, primarily on purchased power, of $35.3 million which is reflected in revenues.
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NE LP Consolidated - 2008 compared to 2007
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In 2008, 2007 and 2006, NE LP's revenues were derived from five power purchase agreements with regulated utilities in Massachusetts and New Jersey. Under the terms of these contracts, power from the wholesale market or generated from the Partnerships' facilities was sold to these utilities at prices specified in the contracts. The pricing under the four Massachusetts amended and restated power purchase agreements is comprised of a fixed payment based on specified contract rates and a variable portion indexed to the power market. The pricing under the New Jersey amended and restated power purchase agreement is indexed to fuel indices.
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NE LP's revenues for 2008 and 2007 were comprised of $407.7 million and $331.3 million of power sales to utilities, net of purchased power, respectively. Revenue increased in 2008 compared to 2007 primarily due to favorable pricing of $68.5 million and increased volume of $8.0 million due to increased generation of power at the NJEA facility, partially offset by decreased generation of power at the NEA facility.
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Fuel expense, net of fuel sales, increased in 2008 by $41.4 million primarily due to increased fuel prices and increased generation of power at the NJEA facility, partially offset by decreased generation of power at the NEA facility.
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O&M expense increased by $1.7 million in 2008 compared to 2007 primarily as a result of increased generation of power at the NJEA facility and scheduled maintenance outages at NJEA and NEA, partially offset by decreased generation of power at the NEA facility.
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Depreciation and amortization expense increased by $2.3 million in 2008 compared to 2007 due primarily to increased depreciation of assets, measured on a unit of production basis, mainly resulting from increased generation at the NJEA facility, as well as increased amortization of the intangible assets associated with the power purchase agreements.
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NE LP makes scheduled interest and principal payments on its outstanding debt semiannually on June 30 and December 30. Interest expense for NE LP decreased in 2008 by $7.6 million due to decreasing principal balances on its outstanding debt.
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Interest income decreased in 2008 compared to 2007 by $1.0 million due primarily to decreased rates of return on cash balances.
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In February 2007, NEA incurred costs related to damage to one of NEA's combustion turbines. In October 2008, a settlement agreement was reached with the insurance companies, net of NEA's deductible, for $1.9 million, of which $1.7 million was received in 2008. As a result, in 2008, NEA recorded a gain of $1.2 million, reduced O&M expenses by $0.4 million and reduced the carrying value of certain turbine parts by $0.3 million.
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In connection with repair work performed on one of NEA's combustion turbines in November 2007, NEA recognized a loss on disposal of assets of $2.8 million in 2007. In March 2008 NEA entered into an agreement with a supplier (the Replacement Parts Agreement) under which NEA would recover up to $2.1 million of the losses recognized on the disposed assets as credits against the future purchase of replacement turbine parts. In March 2008, NEA placed orders with the supplier for $3.6 million of replacement turbine parts, which used all of the credits under the Replacement Parts Agreement, and a $1.8 million recovery under that agreement was recorded in other income in 2008.
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In connection with repair work performed on one of NEA's combustion turbines during 2007, NEA recognized a net loss on disposal of assets of $0.6 million.
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In connection with an inspection of one of NEA's combustion turbines in October 2008, damage was discovered. NEA filed a warranty claim, and the manufacturer has agreed to cover substantially all related costs for parts and labor, and accordingly, no loss on disposal of assets was recognized. The Partnerships' parts on-hand were used to replace the damaged parts.
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Transcontinental Gas Pipeline Corporation (Transco) filed a new general rate case in August 2006 with the FERC. The rate case proposed rate increases for most services, fueled largely by a proposed increase of approximately $250 million in the cost of service. NEA currently holds 50,508 MMBtu/day of capacity on Transco's system, and the proposed rates would have resulted in an annual increase of approximately $0.7 million in transportation costs for NEA. NextEra Energy Resources on behalf of NEA and other plants operated by NextEra Energy Resources, filed a protest of the rate increase with the FERC in September 2006. The filed rates went into effect on March 1, 2007. In August 2007, an agreement in principal was reached by the parties whereby the settled rates will result in an annual savings of $0.3 million in transportation costs for NEA from the filed rates, with the difference between any amounts paid on the filed rates and the settled rates through the date of the final settlement t o be refunded to NEA. The proposed settlement agreement was submitted to the FERC for review and approval and in March 2008 the FERC accepted the settlement agreement. NEA received a refund of $0.3 million under the settlement in July 2008 which was recorded to fuel expense.
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NE LP Consolidated - 2007 compared to 2006
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NE LP's revenues for 2007 and 2006 were comprised of $331.3 million and $358.8 million of power sales to utilities, net of purchased power. Power sales to utilities reflect energy bank amortization of $1.5 million and $41.5 million in 2007 and 2006, respectively. Power sales to utilities include $0 and $1.8 million of revenue from the sale of emission allowances in 2007 and 2006, respectively. Revenue decreased in 2007 compared to 2006 primarily due to lower energy bank amortization of $40.0 million resulting from NEA's satisfaction of the energy bank liability balance in January 2007, and unfavorable pricing under the restructured power purchase agreements of $59.1 million, offset by lower purchased power costs of $59.5 million due to increased generation of power from the NEA and NJEA facilities to fulfill the Partnerships' obligations under the power purchase agreements, increases in capacity revenues of $9.8 million, and increases in ancillary operating revenues of $2.3 million.
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Fuel expense increased in 2007 compared to 2006 by $55.4 million due primarily to increased generation of power from the NJEA and NEA facilities and higher unrealized mark-to-market losses on derivatives of $8.3 million primarily associated with natural gas storage supply, partially offset by higher margin on natural gas sales of $1.5 million.
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O&M expense decreased in 2007 compared to 2006 primarily as a result of scheduled maintenance outages at the NJEA and NEA facilities that occurred in 2006, partially offset in 2007 by repair work performed on one of NEA's combustion turbines.
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Depreciation and amortization expense increased in 2007 compared to 2006 due primarily to additional amortization of the 2005 addition of an intangible asset of $29.9 million related to the NEA amended and restated power purchase agreements.
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General and administrative expenditures decreased in 2007 compared to 2006 primarily due to lower municipal property tax payments on the NEA and NJEA facilities.
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NE LP makes scheduled interest and principal payments on its outstanding debt semiannually on June 30 and December 30. Interest expense for NE LP decreased in each of 2007 and 2006 as a result of decreasing principal balances on its outstanding debt and energy bank liability.
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Interest income increased in 2007 compared to 2006 due to higher average cash balances and interest rates.
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In connection with repair work performed on one of NEA's combustion turbines, NE LP and the Partnerships recognized a loss on disposal of assets of $2.8 million in 2007, partially offset by a gain on the sale of certain NEA assets of $0.4 million. In March 2008, NEA entered into an agreement with a supplier under which NEA recovered $1.8 million of the losses recognized on the disposed assets as credits against the future purchase of replacement turbine parts.
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The Partnerships
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The Partnerships' net income for 2008, 2007 and 2006 was $146.2 million, $105.4 million and $183.8 million, respectively. Net income for 2008 increased due to favorable pricing of $68.5 million which is reflected in revenues, partially offset by increased fuel costs of $41.4 million. Net income for 2007 reflected increased fuel costs of $55.4 million, net unrealized mark-to-market losses of $2.3 million on derivatives and favorable pricing primarily on purchased power of $0.4 million which is reflected in revenues. Net income for 2006 included fuel savings of $49.0 million, net unrealized mark-to-market gains of $6.1 million on derivatives and unfavorable pricing primarily on purchased power of $35.3 million which is reflected in revenues.
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The Partnerships - 2008 compared to 2007
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In 2008, 2007 and 2006, the Partnerships' revenues were derived from five power purchase agreements with regulated utilities in Massachusetts and New Jersey. Under the terms of these contracts, power from the wholesale market or generated from the Partnerships' facilities was sold to these utilities at prices specified in the contracts. The pricing under the four Massachusetts amended and restated power purchase agreements is comprised of a fixed payment based on specified contract rates and a variable portion indexed to the power market. The pricing under the New Jersey amended and restated power purchase agreement is indexed to fuel indices.
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The Partnerships' revenues for 2008 and 2007 were comprised of $407.7 million and $331.3 million of power sales to utilities, net of purchased power, respectively. Revenue increased in 2008 compared to 2007 primarily due to favorable pricing of $68.5 million and increased volume of $8.0 million due to increased generation of power at the NJEA facility, partially offset by decreased generation of power at the NEA facility.
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Fuel expense, net of fuel sales, increased in 2008 by $41.4 million primarily due to increased fuel prices and increased generation of power at the NJEA facility, partially offset by decreased generation of power at the NEA facility.
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O&M expense increased by $1.7 million in 2008 compared to 2007 primarily as a result of increased generation of power at the NJEA facility and scheduled maintenance outages, partially offset by decreased generation of power at the NEA facility.
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Depreciation and amortization expense increased by $2.3 million in 2008 compared to 2007 due primarily to increased depreciation of assets, measured on a unit of production basis, mainly resulting from increased generation at the NJEA facility, as well as increased amortization of the intangible assets associated with the power purchase agreements.
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The Partnerships make scheduled interest and principal payments on their outstanding debt semiannually on June 30 and December 30. Interest expense for the Partnerships decreased in 2008 by $5.5 million due to decreasing principal balances on their outstanding debt.
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Interest income decreased in 2008 compared to 2007 by $0.9 million due primarily to decreased rates of return on cash balances.
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In February 2007, NEA incurred costs related to damage to one of NEA's combustion turbines. In October 2008, a settlement agreement was reached with the insurance companies, net of NEA's deductible, for $1.9 million, of which $1.7 million was received in 2008. As a result, in 2008, NEA recorded a gain of $1.2 million, reduced O&M expenses by $0.4 million and reduced the carrying value of certain turbine parts by $0.3 million.
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In connection with repair work performed on one of NEA's combustion turbines in November 2007, NEA recognized a loss on disposal of assets of $2.8 million in 2007. In March 2008 NEA entered into the Replacement Parts Agreement under which NEA would recover up to $2.1 million of the losses recognized on the disposed assets as credits against the future purchase of replacement turbine parts. In March 2008, NEA placed orders with the supplier for $3.6 million of replacement turbine parts, which used all of the credits under the Replacement Parts Agreement, and a $1.8 million recovery under that agreement was recorded in other income in 2008.
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In connection with repair work performed on one of NEA's combustion turbines during 2007, NEA recognized a net loss on disposal of assets of $0.6 million.
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In connection with an inspection of one of NEA's combustion turbines in October 2008, damage was discovered. NEA has filed a warranty claim, and the manufacturer has agreed to cover substantially all related costs for parts and labor, and accordingly, no loss on disposal of assets was recognized. The Partnerships' parts on-hand were used to replace the damaged parts.
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Transco filed a new general rate case in August 2006 with the FERC. The rate case proposed rate increases for most services, fueled largely by a proposed increase of approximately $250 million in the cost of service. NEA currently holds 50,508 MMBtu/day of capacity on Transco's system, and the proposed rates would have resulted in an annual increase of approximately $0.7 million in transportation costs for NEA. NextEra Energy Resources on behalf of NEA and other plants operated by NextEra Energy Resources, filed a protest of the rate increase with the FERC in September 2006. The filed rates went into effect on March 1, 2007. In August 2007, an agreement in principal was reached by the parties whereby the settled rates will result in an annual savings of $0.3 million in transportation costs for NEA from the filed rates, with the difference between any amounts paid on the filed rates and the settled rates through the date of the final settlement to be refunded to NEA. The proposed settlemen t agreement was submitted to the FERC for review and approval and in March 2008 the FERC accepted the settlement agreement. NEA received a refund of $0.3 million under the settlement in July 2008 which was recorded to fuel expense.
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The Partnerships - 2007 compared to 2006
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The Partnerships' revenues for 2007 and 2006 were comprised of $331.3 million and $358.8 million of power sales to utilities, net of purchased power. Power sales to utilities reflect energy bank amortization of $1.5 million and $41.5 million in 2007 and 2006, respectively. Power sales to utilities include $0 and $1.8 million of revenue from the sale of emission allowances in 2007 and 2006, respectively. Revenue decreased in 2007 compared to 2006 primarily due to lower energy bank amortization of $40.0 million resulting from NEA's satisfaction of the energy bank liability balance in January 2007, and unfavorable pricing under the restructured power purchase agreements of $59.1 million, offset by lower purchased power costs of $59.5 million due to increased generation of power from the NEA and NJEA facilities to fulfill the Partnerships' obligations under the power purchase agreements, increases in capacity revenues of $9.8 million, and increases in ancillary operating revenues of $2.3 million.
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Fuel expense increased in 2007 compared to 2006 by $55.4 million due primarily to increased generation of power from the NJEA and NEA facilities and higher unrealized mark-to-market losses on derivatives of $8.3 million primarily associated with natural gas storage supply, partially offset by higher margin on natural gas sales of $1.5 million.
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O&M expense decreased in 2007 compared to 2006 primarily as a result of scheduled maintenance outages at the NJEA and NEA facilities that occurred in 2006, partially offset in 2007 by repair work performed on one of NEA's combustion turbines.
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Depreciation and amortization expense increased in 2007 compared to 2006 due primarily to additional amortization of the 2005 addition of an intangible asset of $29.9 million related to the NEA amended and restated power purchase agreements.
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General and administrative expenditures decreased in 2007 compared to 2006 primarily due to lower municipal property tax payments on the NEA and NJEA facilities.
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The Partnerships make scheduled interest and principal payments on their outstanding debt semiannually on June 30 and December 30. Interest expense for the Partnerships decreased in each of 2007 and 2006 as a result of decreasing principal balances on their outstanding debt and energy bank liability.
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Interest income increased in 2007 compared to 2006 due to higher average cash balances and interest rates.
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In connection with repair work performed on one of NEA's combustion turbines, the Partnerships recognized a loss on disposal of assets of $2.8 million in 2007, offset by a gain on the sale of certain NEA assets of $0.4 million. In March 2008, NEA entered into an agreement with a supplier under which NEA recovered $1.8 million of the losses recognized on the disposed assets as credits against the future purchase of replacement turbine parts.
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The Funding Corp. and the Acquisition Corp.
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Both the Funding Corp. and the Acquisition Corp. use interest income and principal payments received from the notes receivable from the Partnerships and NE LP, respectively, to make scheduled interest and principal payments on their outstanding debt. Both are scheduled to make semiannual principal and interest payments on June 30 and December 30. Interest expense for the Funding Corp. and the Acquisition Corp. decreased in each of 2008 and 2007 as a result of decreasing principal balances on their outstanding debt.
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Related Party Information
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NE LP and the Partnerships receive O&M, fuel management and administrative services from entities related to NextEra Energy Resources. Payments to these entities for these services were $5.3 million, $4.9 million, and $4.9 million in 2008, 2007 and 2006, respectively. For additional information see Note 5 to the Consolidated and Combined Financial Statements.
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In 2005, a supplemental fuel management subcontract agreement was entered into to allow PMI to purchase energy, ancillary services and capacity from the NEA facility or from the marketplace and sell to the purchasers under the NEA amended and restated power purchase agreements. Payments to PMI under that agreement are included in the payments described in the preceding paragraph. For additional information see Note 5 to the Consolidated and Combined Financial Statements.
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The Partnerships receive fuel pursuant to fuel supply agreements with entities related to NextEra Energy Resources and SUEZ. For additional information see Note 3 to the Consolidated and Combined Financial Statements - Fuel Supply, Transportation and Storage Agreements.
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In 2003, an affiliate of NE LP issued a $26.2 million note to NE LP to fund the payment to the New Jersey utility in accordance with the NJEA amended and restated power purchase agreement. The related interest expense was $1.1 million, $1.4 million and $1.7 million in 2008, 2007 and 2006, respectively. See Note 4 to the Consolidated and Combined Financial Statements.
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As discussed in Note 4 to the Consolidated and Combined Financial Statements, the proceeds from the issuance in 1994 of the Funding Corp.'s secured notes (Funding Corp. Securities) were used to make loans to the Partnerships, and notes of the Partnerships were issued to the Funding Corp. in an aggregate principal amount equal to the Funding Corp. Securities. The related interest expense was $15.5 million, $20.5 million and $25.5 million in 2008, 2007 and 2006, respectively.
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As discussed in Note 4 to the Consolidated and Combined Financial Statements, the proceeds from the issuance in 1998 of the Acquisition Corp.'s secured notes (Acquisition Corp. Securities) were loaned to NE LP and evidenced by a promissory note. The related interest expense was $11.5 million, $13.3 million and $14.5 million in 2008, 2007 and 2006, respectively.
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Liquidity and Capital Resources
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The Funding Corp. and the Partnerships - Cash flow generated by the Partnerships during 2008 was sufficient to fund operating expenses as well as the debt service requirements of the Funding Corp. Debt maturities of the Funding Corp. will require cash outflows of approximately $135.0 million in principal and interest through 2010, including approximately $65.0 million in 2009. It is anticipated that cash requirements for principal and interest payments in 2009 will be satisfied with the Partnerships' cash flows from operating activities. Operational cash flow may be affected by, among other things, changes in laws or regulations, including the PURPA, weather conditions, competition for retail and wholesale customers, availability, pricing and transportation of fuel and other energy commodities, and market demand for energy. See Note 3 to Funding Corp.'s Financial Statements, and Note 4 to Consolidated and Combined Financial Statements - Funding Corp.
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The trust indenture governing the Funding Corp. Securities contains certain restrictions on certain activities of the Partnerships, including incurring additional indebtedness or liens, distributions to the partners, the cancellation of power sale and fuel supply agreements and the execution of mergers, consolidations and sales of assets.
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Capital expenditures for the Partnerships were $9.1 million, $7.5 million and $3.0 million in 2008, 2007 and 2006, respectively. The increases in 2008 and 2007 relate primarily to capital spare parts used in maintenance outages and various equipment upgrades for the two generating facilities.
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Letters of credit were established to satisfy requirements in certain power purchase agreements. As of December 31, 2006, one letter of credit related to an NEA power purchase agreement remained. In January 2007, NEA fulfilled its obligations under the power purchase agreement that had required the letter of credit, and the letter of credit was not renewed upon its expiration.
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The Acquisition Corp. and NE LP - Cash flow generated by NE LP during 2008 was sufficient to fund operating expenses as well as fund the debt service requirements of the Acquisition Corp. and the Funding Corp. and NE LP's note payable-affiliate. Debt maturities of the Acquisition Corp. and the Funding Corp. will require cash outflows of approximately $283.6 million in principal and interest through 2011, including approximately $101.1 million in 2009. Debt maturities of NE LP's note payable-affiliate will require NE LP cash outflows of approximately $11.9 million in principal and interest through 2011, including approximately $4.8 million in 2009. It is anticipated that cash requirements for principal and interest payments in 2009 will be satisfied with NE LP's cash flows from operations. Operational cash flow may be affected by, among other things, changes in laws or regulations, including the PURPA, weather conditions, competition for retail and wholesale customers, availa bility, pricing and transportation of fuel and other energy commodities, and market demand for energy. See Note 3 to Acquisition Corp.'s Financial Statements, and Note 4 to Consolidated and Combined Financial Statements - Acquisition Corp.
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NE LP's capital expenditures were $9.1 million, $7.5 million and $3.0 million in 2008, 2007 and 2006, respectively. The increases in 2008 and 2007 relate primarily to capital spare parts used in maintenance outages and various equipment upgrades for the two generating facilities.
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Letters of credit were established to satisfy requirements in certain power purchase agreements. As of December 31, 2006, one letter of credit related to an NEA power purchase agreement remained. In January 2007, NEA fulfilled its obligations under the power purchase agreement that had required the letter of credit, and the letter of credit was not renewed upon its expiration.
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The long-term contractual obligations of NE LP and the Partnerships at December 31, 2008 were as follows:
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NE LP AND THE PARTNERSHIPS
December 31, 2008
(Thousands of Dollars)
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1. Nature of Business |
Northeast Energy, LP (NE LP), a Delaware limited partnership, was formed in 1997 for the purpose of acquiring ownership interests in two partnerships, each of which owns an electric power generation station in the northeastern United States (Northeast Energy Associates, a limited partnership (NEA) and North Jersey Energy Associates, a limited partnership (NJEA), collectively the Partnerships). NE LP is jointly owned by subsidiaries of ESI Energy, LLC (ESI Energy) and SUEZ Energy Generation North America, Inc. (SUEZ Power). ESI Energy is wholly-owned by NextEra Energy Resources, LLC (NextEra Energy Resources), formerly known as FPL Energy, LLC, which is an indirect wholly-owned subsidiary of FPL Group, Inc., a company listed on the New York Stock Exchange. SUEZ Power is a direct wholly-owned subsidiary of GDF SUEZ Energy North America, Inc., which is a direct wholly-owned subsidiary of GDF Suez, a worldwide energy provider. NE LP also formed a wholly-owned subsidiary, Northeast Energy, LLC (NE& nbsp;LLC) to assist in such acquisitions.
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The Partnerships were formed in 1986 to develop, construct, own, operate and manage two separate nominal 300 megawatt (mw) combined-cycle cogeneration facilities. NEA's facility is located in Bellingham, Massachusetts and NJEA's facility is located in Sayreville, New Jersey. NEA and NJEA commenced commercial operation in 1991. The Partnerships operate in the independent power industry and had been granted permission by the FERC to operate as qualifying facilities (QFs) as defined in the Public Utility Regulatory Policies Act of 1978, as amended and as defined in federal regulations. In December 2003, NJEA executed an amended and restated power purchase agreement and in February 2005, NEA executed an agreement to amend and restate certain power purchase agreements and neither facility now operates as a QF. Both NJEA and NEA now have exempt wholesale generator (EWG) status and market based rate authority which allows NEA and NJEA to sell power at market rates.
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The partners of NE LP and the Partnerships share profits and losses and have interests in assets and liabilities and cash flows in proportion to their tax basis capital accounts. Distributions to the partners may be made only after all funding requirements of the Partnerships have been met, as described in the trust indenture relating to the debt issued by the Acquisition Corp.
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2. Summary of Significant Accounting Policies
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Basis of Presentation - The accompanying consolidated financial statements include the accounts of NE LP and subsidiaries. All material intercompany balances and transactions have been eliminated in consolidation. The accompanying combined financial statements include the accounts of NEA and NJEA for all periods and are combined based on common ownership. All material intercompany transactions have been eliminated in the combination.
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Impairment of Long-Lived Assets - NE LP and the Partnerships evaluate on an ongoing basis the recoverability of their assets and related intangible assets for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable as described in Statement of Financial Accounting Standards No. (FAS) 144, "Accounting for the Impairment or Disposal of Long-Lived Assets." Each of NE LP and the Partnerships concluded there was no impairment of tangible or intangible assets in 2008, 2007, and 2006.
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Accounting for Asset Retirement Obligations - The registrants, the Partnerships and the Funding Corp. account for asset retirement obligations and conditional asset retirement obligations (collectively AROs) under FAS 143, "Accounting for Asset Retirement Obligations" and Financial Accounting Standards Board (FASB) Interpretation No. 47 (FIN 47), "Accounting for Conditional Asset Retirement Obligations." FAS 143 requires that a liability for the fair value of an ARO be recognized in the period in which it is incurred with the offsetting associated asset retirement cost capitalized as part of the carrying amount of the long-lived asset. The asset retirement cost is subsequently allocated to expense using a systematic and rational method over its useful life. Changes in the ARO resulting from the passage of time are recognized as an increase in the carrying amount of the liability and as accretion expense. FIN 47 clarifies a conditional ARO as a legal obligation to perform an asset r etirement activity in which the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the entity. Assets and liabilities related to FIN 47 are treated in accordance with FAS 143.
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Cash and Cash Equivalents - Investments purchased with an original maturity of three months or less are considered cash equivalents.Excess cash is invested in high-grade money market accounts and commercial paper and is subject to minimal credit and market risk. At December 31, 2008 and 2007, the recorded amount of cash and cash equivalents approximates its fair value.
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Accounts Receivable and Revenue - Accounts receivable primarily consist of receivables from one Massachusetts utility and one New Jersey utility for electricity delivered and sold under five power purchase agreements. Pricing under the four amended Massachusetts power purchase agreements is comprised of a fixed payment based on specified contract rates for power delivered and a variable component indexed to the power market. The pricing under the New Jersey amended and restated power purchase agreement is based on initial floor prices per kilowatt-hour, subject to adjustment based on actual volumes of electricity purchased, fixed escalation factors, fuel indices, and other conditions. Revenue is recognized based on power delivered at rates stipulated in the power purchase agreements, except that revenue is deferred to the extent that stipulated rates are in excess of amounts, either scheduled or specified, in the agreements to the extent the Partnerships have an obligation to repay such excess. Revenue r ecognized is also deferred to the extent that stipulated rates under the amended power purchase agreements are higher in early years of the agreement and exceed average rates over the term of the agreement. The amount deferred is reflected on the balance sheets in deferred revenue. Power sales to utilities includes $1.8 million of revenue from the sale of emission allowances in 2006. There was no revenue from the sale of emission allowances in 2008 and 2007. The emissions allowances have no cost basis and are recognized as revenue at the time of sale.
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Plant and Equipment and Other Assets - The facilities and other assets are depreciated using the straight-line method over their estimated useful lives ranging from 5 to 34 years, with the exception of certain turbine parts that are depreciated on a unit of production basis based upon estimated total starts over their useful lives. Depreciation expense was $21.1 million, $20.2 million and $19.6 million for 2008, 2007 and 2006, respectively.
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Major Maintenance Costs - NE LP and the Partnerships use the deferral method to account for certain planned major maintenance costs.
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Major maintenance costs for combustion turbines are capitalized and amortized on a unit of production basis based upon estimated total starts over the period from the end of the last outage to the beginning of the next planned outage. NE LP and the Partnerships deferred major maintenance costs totaled approximately $3.5 million and $4.8 million at December 31, 2008 and 2007, respectively, and are included in other assets. For the years ended December 31, 2008, 2007 and 2006, NE LP and the Partnerships recorded major maintenance expenses of approximately $2.0 million, $1.9 million and $3.5 million, respectively.
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Inventories - Fuel inventories consist of natural gas and fuel oil and are stated at the lower of cost, determined on a weighted- average cost basis, or market unless evidence indicates that the weighted-average cost (even if in excess of market) will be recovered with a normal profit upon sale in the ordinary course of business. Spare parts inventories are stated at lower of cost or market and are determined by specific identification.
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Power Purchase Agreements - The fair value of the power purchase agreements acquired are being amortized over the respective agreement periods, ranging from 14 to 24 years, on a straight-line basis or matched to scheduled fixed-price increases under the power purchase agreements, as applicable.
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Deferred Debt Issuance Costs - Deferred debt issuance costs of NE LP are being amortized over the approximate 14-year term of the Acquisition Corp.'s note payable using the effective interest method.
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Income Taxes -Partnerships are not taxable entities for federal and state income tax purposes. As such, no provision has been made for income taxes since such taxes, if any, are the responsibilities of the individual partners.
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Contract Restructurings - Due to the lack of specific accounting guidance, when a contract is restructured, NE LP and the Partnerships analogize to EITF 96-19, "Debtor's Accounting for a Modification or Exchange of Debt Instruments" and EITF 01-07, "Creditor's Accounting for a Modification or Exchange of Debt Instruments" to account for the transactions. If a contract is to be accounted for as a termination, the remaining net book value of the asset or liability is removed from the balance sheet, the cash that is exchanged between the parties is recognized as either income or expense, the fair value of the new contract is recorded on the balance sheet and a gain or loss is recognized on the statement of operations. If a contract is to be accounted for as a modification, cash that is exchanged between the parties is added or subtracted to the basis of the asset or liability.
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Accounting for Derivatives and Hedging Activities - Derivative instruments are recorded on NE LP's and the Partnerships' consolidated and combined balance sheets as either an asset or liability (in prepaid expenses and other current assets, other assets and other accrued expenses) measured at fair value in accordance with FAS 133 (as amended and interpreted). NE LP and the Partnerships use derivative instruments (primarily swaps, futures and forwards) to manage the commodity price risk inherent in the purchase and sale of fuel and electricity. In addition, NE LP and the Partnerships use derivatives to optimize the value of power generation assets.
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All changes in the derivatives' fair value (unrealized mark-to-market gains and losses) for power purchases and sales are recognized on a net basis in revenues, and fuel purchases and sales are recognized on a net basis in fuel expense unless hedge accounting is applied. While substantially all of NE LP's and the Partnerships' derivative transactions are entered into for the purposes described above, hedge accounting is only applied where specific criteria are met and it is practicable to do so. In order to apply hedge accounting, the transaction must be designated as a hedge at inception and it must be highly effective in offsetting the hedged risk. Additionally, for hedges of commodity price risk, physical delivery for forecasted commodity transactions must be probable. NE LP and the Partnerships believe that where offsetting positions exist at the same location for the same time, the transactions are considered to have been netted and therefore physical delivery has been deemed not to have occur red for financial reporting purposes. Transactions for which physical delivery is deemed not to have occurred are presented on a net basis. Generally, the hedging instrument's effectiveness is assessed using regression analysis at the inception of the hedge and on at least a quarterly basis throughout its life. At December 31, 2008 and 2007, no cash flow hedges existed at NE LP and the Partnerships. The effective portion of the gain or loss on a derivative instrument designated as a cash flow hedge is reported as a component of other comprehensive income and is reclassified into earnings in the period(s) during which the transaction being hedged affects earnings. The ineffective portion of the net unrealized gains (losses) on these hedges is reported in earnings in the current period. Settlement gains and losses are included within the line items in the statements of operations to which they relate.
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Unrealized mark-to-market losses, net, on derivative transactions were $3.2 million for the year ended December 31, 2008. The current portion of the derivative liability was $0.9 million at December 31, 2008 and is included in the combined and consolidated balance sheets under other accrued expenses. There was not a non-current component of the derivative liability at December 31, 2008. Unrealized mark-to-market losses, net, on derivative transactions were $2.3 million for the year ended December 31, 2007. The current portion of the derivative asset was $2.4 million at December 31, 2007 and is included in the combined and consolidated balance sheets under prepaid expenses and other current assets. There was not a non-current component of the derivative asset at December 31, 2007. Unrealized mark-to-market gains, net, on derivative transactions were $6.1 million for the year ended December 31, 2006.
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Natural Gas Hedging Instruments - Periodic settlements on natural gas swap agreements are recognized as adjustments to fuel costs at monthly settlement dates. Purchases of natural gas under forward purchase agreements are accounted for as fuel costs at their contract price at delivery. See Note 6.
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Fair Value Measurements - Effective January 1, 2008, NE LP and the Partnerships adopted FAS 157, "Fair Value Measurements," which clarifies how to measure fair value and requires expanded fair value measurement disclosures. The standard emphasizes that fair value is a market-based measurement not an entity-specific measurement, and sets out a fair value hierarchy intended to disclose information about the relative reliability of fair value measurements, with the highest priority being quoted prices in active markets for identical assets or liabilities. FAS 157 was effective January 1, 2008 for financial assets and liabilities, and any other fair value measurements made on a recurring basis and on January 1, 2009 for non-financial assets and liabilities that are not remeasured on a recurring basis. The adoption of the recognition provisions of FAS 157 did not have a material effect on NE LP and the Partnerships' financial statements. See Note 7.
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The Fair Value Option for Financial Assets and Financial Liabilities - In February 2007, the FASB issued FAS 159, "The Fair Value Option for Financial Assets and Financial Liabilities," which permits, but does not require, entities to account for financial assets and liabilities at fair value. The standard does not extend to non-financial instruments. NE LP and the Partnerships were permitted to adopt FAS 159 on January 1, 2008. NE LP and the Partnerships did not elect to account for any existing financial assets or liabilities under FAS 159 at January 1, 2008 but may elect to account for new financial assets and liabilities at fair value in the future. See Note 7.
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Use of Estimates - The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
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3. Cogeneration Facilities, Power Purchase Agreements and Carbon Dioxide Facility
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Power Purchase Agreements - In 1986, NEA entered into three power purchase agreements with three Massachusetts utilities, and in 1988, NEA entered into two power purchase agreements with two Massachusetts utilities. Under the five power purchase agreements, NEA agreed to sell approximately 290 mw per year at initial floor prices per kwh subject to adjustment based on actual volumes purchased, fixed escalation factors and other conditions. Performance under certain of these agreements is secured by a second mortgage on the NEA facility. In 1987, NJEA entered into an agreement with a New Jersey utility to sell approximately 250 mw per year at an initial fixed price per kwh subject to adjustments, as defined in the agreement. These power purchase agreements have initial terms with expiration dates ranging from 2011 to 2016. The majority of the Partnerships' power sales to utilities are generated through these agreements. As such, the Partnerships are directly affected by changes in the power generation industry. Substantially all of the Partnerships' accounts receivable are with these utilities. The Partnerships do not require collateral or other security to support these receivables. However, management does not believe significant credit risk exists at December 31, 2008. Restructuring of the NJEA power purchase agreement occurred in 2003 as discussed below. Restructuring of four of the NEA power purchase agreements, as discussed below, and termination of the remaining NEA power purchase agreement occurred in 2005.
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In 2003, NJEA's agreement with the New Jersey utility to amend and restate the power purchase agreement became effective. The agreement provides for, among other things, the ability to deliver electricity to the utility from sources other than NJEA's facility at NJEA's discretion. In accordance with the agreement, NJEA paid $26.2 million to the New Jersey utility through a cash contribution by NE LP. NE LP received funding through a loan to NE LP from an affiliate of NE LP which matures in June 2011. In connection with this restructuring, NJEA amended its remaining long-term natural gas supply agreement and terminated the long-term natural gas supply agreements with SEMNA and PMI in 2004. Under the terms of the amended long-term natural gas supply agreement, the supplier will provide all of the fuel required to run the facility when it is operating.
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In 2005, the amended and restated power purchase agreements among NEA as seller, and Boston Edison Company (Boston Edison) and Commonwealth Electric Company (Commonwealth) as utility purchasers became effective. Effective January 1, 2007, Boston Edison and Commonwealth became one utility, NSTAR Electric Company (NSTAR). The amended and restated agreements provide for, among other things, NEA obtaining the right to source power from the wholesale market in addition to sourcing power from NEA's facility. Affiliates of NE LP's partners paid approximately $29.9 million to the utility purchasers in the form of loans to NE LP in the same amount due on December 31, 2005. This payment is capitalized as part of the power purchase agreement's intangible asset on the balance sheet at December 31, 2005. These loans were repaid with interest in April 2005 from funds otherwise available for NE LP partnership distributions. As a result of the amended and restated power purchase agreements, NE& nbsp;LP and the Partnerships adopted EITF 91-6, "Revenue Recognition of Long-Term Power Sales Contracts", which requires NE LP and the Partnerships to recognize revenue as the lesser of the amount billable under the agreement or the estimated average revenue over the term of the agreement. Consequently, NE LP and the Partnerships recognized a reduction to revenue of $21.5 million, $21.4 million and $14.9 million for the years ended December 31, 2008, 2007 and 2006, respectively.
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For the years ended December 31, 2008, 2007 and 2006, power sale revenues from two different utilities accounted for approximately 38% and 40%, 37% and 40%, and 36% and 47%, respectively, of NE LP's and the Partnerships' total consolidated and combined revenues excluding energy bank revenues.
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Both Massachusetts and New Jersey have enacted legislation designed to deregulate the production and sale of electricity. While NE LP and the Partnerships do not expect electric utility industry restructuring to result in any material adverse change to prices under the Partnerships' power purchase agreements, the impact of electric utility industry restructuring on the companies that purchase power from the Partnerships is uncertain.
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Energy Bank Balance - As of December 31, 2006, one of the NEA power purchase agreements continued to have an energy bank and recorded cumulative payments made by the utility in excess of avoided cost rates scheduled or specified in such agreement. Amortization of the energy bank was based on power provided under the power purchase agreement and the avoided cost rates specified in the agreement. As of December 31, 2008 and 2007, there was no longer any energy bank balance. Amortization was $1.5 million and $37.6 million in 2007 and 2006, respectively. The energy bank balance bore interest at a rate specified in the agreement, and was partially secured by a letter of credit. In accordance with the power purchase agreement, NEA satisfied its energy bank obligations in January 2007 and the related letter of credit expired.
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Fuel Supply, Transportation and Storage Agreements - Natural gas is provided to the NEA and NJEA facilities primarily under long-term contracts for supply, transportation and storage. The remaining fuel requirements are provided under short-term spot arrangements. The long-term natural gas supply is provided under contracts with PSE&G, PMI and SEMNA. Various pipeline companies provide transportation of the natural gas. Natural gas storage agreements provide contractual arrangements for the storage of limited volumes of natural gas with third parties for future delivery to the Partnerships.
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The PSE&G contract commenced in 1991 and provided for the sale and delivery to NJEA of up to 25,000 MMBtu/day of natural gas for a term of 20 years. The contract price of the PSE&G natural gas is established monthly using a contractually specified mechanism.
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In connection with the amended and restated power purchase agreement mentioned above, in 2003, NJEA amended its long-term natural gas supply agreement with PSE&G. Under the terms of the amended agreement, PSE&G provides all of the fuel required to operate the facility when NJEA decides it is economically beneficial to do so. NJEA is required to pay a monthly fee of $0.2 million to PSE&G regardless of whether fuel is purchased during the month. Total charges under NJEA's contract with PSE&G, including transportation costs, during 2008, 2007 and 2006, were approximately $97.8 million, $55.6 million and $27.7 million, respectively.
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NEA entered into two long-term natural gas supply agreements with PMI and SEMNA in 2005 that enable NEA to purchase sufficient fuel for production. Fuel purchased under agreements between NEA and PMI and SEMNA was $273.9 million, $188.5 million and $161.0 million for the years ended December 31, 2008, 2007 and 2006, respectively, and are included on the Consolidated and Combined Statements of Operations in fuel expense.
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ESI Northeast Fuel, an indirect wholly-owned subsidiary of NextEra Energy Resources, is the fuel manager for the Partnerships and provides fuel management and administrative services by contracting with PMI. In 2005, a supplemental fuel management subcontract agreement was entered into to allow PMI to purchase energy, ancillary services and capacity from the NEA facility or from the marketplace and sell to the purchasers under the NEA amended and restated power purchase agreements.
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NEA's long-term fuel contractual arrangements call for monthly demand charge payments and are included on the Consolidated and Combined Statements of Operations in fuel expense. These demand charge payments reserve certain pipeline transportation capacity and are made regardless of NEA's specified fuel requirements in any month and regardless of whether NEA uses the capacity reserved. These demand charges totaled approximately $13.7 million, $13.1 million and $12.6 million for the years ended December 31, 2008, 2007 and 2006, respectively.
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NEA's facility also has the capability to burn No. 2 fuel oil which is stored on site for contingency supply.
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4. Loans Payable
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Funding Corp. - The proceeds from the Funding Corp.'s secured notes (Funding Corp. Securities) were used to make loans to the Partnerships, and notes of the Partnerships were issued to the Funding Corp. in an aggregate principal amount equal to the Funding Corp. Securities. The Funding Corp., and, thus, the Partnerships, have borrowings outstanding as follows:
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Securities Authorized for Issuance Under Equity Compensation Plans. None. |
Item 13. Certain Relationships and Related Transactions, and Director Independence
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Policies and Procedures Regarding Related Party Transactions
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The NE LP Partnership Agreement, the trust indenture for the Acquisition Corp. Securities, the trust indenture for the Funding Corp. Securities, the Administrative Services Agreement and the Partnerships' amended and restated partnership agreements set forth policies and procedures for the review and approval of certain transactions with persons affiliated with the registrants.
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The Agreement of Limited Partnership of NE LP (the NE LP Partnership Agreement) provides that a partner or an affiliate of NE LP may transact business with NE LP with the unanimous approval of the Management Committee. Any business transacted by a partner of NE LP or its affiliate with NE LP shall be on terms no less favorable to NE LP than would be available from third parties in an arm's length transaction. Management Committee approval is also required for NE LP to enter into any contract or agreement with an affiliate of a partner (other than the Administrative Services Agreement, O&M Agreements and Fuel Management Agreements, which were specifically authorized in the NE LP Partnership Agreement). The NE LP Partnership Agreement further provides that the Management Committee and the general partners must act in a commercially reasonable manner whenever any of them or their affiliates provides, or has provided by any other person, services to NE L P.
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Subject to the direction and control of the Management Committee, if ESI GP, ESI LP, SUEZ GP, SUEZ LP or an affiliate of any of them (the "Partner Affiliate"), provides or proposes to provide goods or services to NE LP, NE LLC or either or both of the Partnerships pursuant to a contract or other agreement (a "Partner Affiliate Agreement"), the other NE LP partner (the "Non-Affiliate Partner") shall be responsible for representing NE LP, NE LLC or the applicable Partnership, as the case may be, in connection with the negotiation of the terms of such Partner Affiliate Agreement. Subject to the approval, direction and control of the Management Committee, upon the execution of any Partner Affiliate Agreement, ESI GP, as Manager, shall be responsible for representing NE LP with respect to the management of the day-to-day affairs thereunder in accordance with the terms of the Administrative Services Agreement. In the event of any dispute, breach or alleged breach of a Partner Aff iliate Agreement, the Non-Affiliate Partner shall have the right to represent NE LP with respect to such dispute, breach or alleged breach (including any litigation relating thereto); provided, that the Non-Affiliate Partner may not terminate the Partner Affiliate Agreement without the approval of the Management Committee or incur expenditures on behalf of NE LP with respect to any such dispute, breach or alleged breach in excess of $100,000 without the approval of the Management Committee.
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The trust indenture for the Acquisition Corp. Securities provides that Acquisition Corp., NE LP and NE LLC may not make any payment to, or sell, lease, transfer or otherwise dispose of, any of their properties or assets to, or purchase any property or assets from, or enter into or make or amend any transaction, contract, agreement, understanding, loan, advance or guarantee with, or for the benefit of, any affiliate thereof (an "Affiliate Transaction"), unless such Affiliate Transaction is on terms that are no less favorable to Acquisition Corp., NE LP or NE LLC, as the case may be, than those that would have been obtained in a comparable transaction with an unrelated person. Certain transactions are deemed not to be Affiliate Transactions, including transactions with affiliates entered into prior to the date of the trust indenture and certain restricted payments that are permitted by the provisions of the trust indenture.
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The trust indenture for the Funding Corp. Securities provides that the Funding Corp. and each Partnership may not directly or indirectly enter into any transaction with or for the benefit of Funding Corp., each Partnership, the partners of the Partnerships, and affiliates of any of them (a related party), unless such transaction is on terms that are no less advantageous to Funding Corp. and/or the relevant Partnership as in a comparable transaction with an unrelated party. Certain transactions are deemed not to be transactions with a related party, including certain restricted payments, the incurrence of certain permitted debt and payment of certain fees and costs that are permitted by the provisions of the trust indenture.
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The Administrative Services Agreement provides that ESI GP, as Manager, shall be responsible for the negotiation and administration of contracts with NE LP or either of the Partnerships, provided that contracts with affiliates of the Manager are subject to the provisions of the NE LP Partnership Agreement regarding approval and oversight of affiliate transactions.
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The Amended and Restated Agreement of Limited Partnership for each of the Partnerships provide that a partner or an affiliate thereof may transact business with the Partnership with the approval of the general partner, and shall be on terms no less favorable than would be available from third parties in an arm's length transaction.
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Certain Relationships and Related Transactions
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Administrative Services Agreement - NE LP and an entity related to NextEra Energy Resources have entered into an administrative services agreement that provides for management and administrative services to the Partnerships. The agreement, which expires in 2018, provides for fees of a minimum of $0.6 million per year, subject to certain adjustments, and reimbursement of costs and expenses of performing services. For the years ended December 31, 2008, 2007 and 2006, the Partnerships incurred $0.9 million, $0.8 million and $0.8 million, respectively, in fees and reimbursed costs and expenses under the agreement.
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O&M Agreements - NE LP and an entity related to NextEra Energy Resources have entered into O&M agreements that provide for the operations and maintenance of the Partnerships. The agreements expire in 2016, subject to extension by mutual agreement of the parties before six months preceding expiration. The agreements provide for fees of a minimum of $0.8 million per year, subject to certain adjustments, for each Partnership and reimbursement of costs and expenses of performing services. For the years ended December 31, 2008, 2007 and 2006, the Partnerships incurred $2.2 million, $2.0 million and $1.8 million, respectively, in fees and reimbursed costs and expenses under the agreements.
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Fuel Management Agreements - NE LP has entered into fuel management agreements with an entity related to NextEra Energy Resources that provide for the management of all natural gas and fuel oil, transportation and storage agreements, and the location and purchase of any additional required natural gas or fuel oil for the Partnerships. The agreements, which expire in 2023, provide for fees of a minimum of $0.5 million per year, subject to certain adjustments, for each Partnership and reimbursement of costs and expenses of performing services. For the years ended December 31, 2008, 2007 and 2006, the Partnerships incurred $1.3 million, $1.2 million and $1.2 million, respectively, in fees and reimbursed costs and expenses under the agreements.
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In 2005, a supplemental fuel management subcontract agreement was entered into to allow PMI to purchase energy, ancillary services and capacity from the NEA facility or from the marketplace and sell to the purchasers under the NEA amended and restated power purchase agreements. This agreement provides for fees for all natural gas purchased and sold, whether physical or financial, and resulting from the purchase and sale of power, to compensate PMI for its costs of credit. Fees under the agreement were $1.0 million, $0.9 million and $1.1 million for the years ended December 31, 2008, 2007 and 2006, respectively.
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Power Sales - From time to time, PMI will purchase excess power produced or acquired from the wholesale market by the Partnerships and resell the power to the marketplace. These purchases totaled $163.9 million, $106.0 million and $61.6 million in 2008, 2007 and 2006, respectively.
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Fuel Contracts - As discussed in Note 3 to the Consolidated and Combined Financial Statements, in 2005, NEA entered into two long-term natural gas supply agreements with PMI and SEMNA that enable NEA to purchase sufficient fuel for production. Fuel purchased under these agreements was $273.9 million, $188.5 million and $161.0 million in 2008, 2007 and 2006, respectively.
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O&M of the Cogeneration Facilities - An entity related to NextEra Energy Resources provides O&M services for the Partnerships. The Partnerships incurred $15.2 million, $13.6 million and $14.9 million for O&M expense for the years ended December 31, 2008, 2007 and 2006, respectively, of which $5.4 million, $4.4 million and $4.2 million, respectively, represented salaries reimbursed to the O&M provider.
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The Partnerships pay a management fee to NE LP in an amount equal to the fees under the administrative services, O&M and fuel management agreements mentioned above.
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Accrued expenses under the administrative services, O&M and fuel management agreements were $0.5 million and $0.6 million at December 31, 2008 and 2007, respectively.
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Affiliate Debt - In December 2003, NE LP borrowed approximately $26.2 million from Northern Cross Investments, Inc., an affiliate of one of the partners of NE LP, to fund the payment to a New Jersey utility in accordance with NJEA's amended and restated power purchase agreement. The loan, which is junior and subordinated to the Acquisition Corp. Securities, has an interest rate of 8.46% and is due in June 2011 with principal and interest payments due semiannually on June 30 and December 30 of each year. Interest expense was $1.1 million, $1.4 million and $1.7 million in 2008, 2007 and 2006, respectively.
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The proceeds from the Funding Corp.'s Securities, issued in 1994, were used to make loans to the Partnerships, and notes of the Partnerships were issued to the Funding Corp. in an aggregate principal amount equal to the Funding Corp. Securities. Interest expense was $15.5 million, $20.5 million and $25.5 million in 2008, 2007 and 2006, respectively.
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The proceeds from the Acquisition Corp. Securities, issued in 1998, were loaned to NE LP and evidenced by a promissory note. Interest expense was $11.5 million, $13.3 million and $14.5 million in 2008, 2007 and 2006, respectively.
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Director Independence
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Neither of the registrants are subject to the requirements of any national securities exchange or inter dealer quotation system that a majority of its board of directors be independent, and NE LP does not have a board of directors. Assuming that the independence standards included in the listing standards of the New York Stock Exchange (NYSE) applied to the Acquisition Corp., in light of the relationship each member of the Acquisition Corp.'s board of directors has with SUEZ Power or NextEra Energy Resources or their affiliates, none of the members of the Acquisition Corp.'s board of directors is independent under the NYSE standards.
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| | | Exhibit No. | Description |
| | |
3.1(1)
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Certificate of Incorporation of the Funding Corp. as filed with the Secretary of State of the State of Delaware on November 3, 1994
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| | |
3.1.1(5)
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Certificate of Amendment of Certificate of Incorporation of the Funding Corp. as filed with the Secretary of State of the State of Delaware on February 3, 1998
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| | |
3.1.2(6)
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Certificate of Incorporation of the Acquisition Corp. as filed with the Secretary of State of the State of Delaware on January 12, 1998
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| | |
3.2(5)
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By-laws of the Funding Corp.
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| | |
3.2.1(6)
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By-laws of the Acquisition Corp.
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| | |
3.3(5)
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Amended and Restated Certificate of Limited Partnership of NEA as filed with the Secretary of State of the Commonwealth of Massachusetts on March 31, 1986, as amended and restated on January 9, 1987 and November 6, 1987, as further amended on July 6, 1989 and as amended and restated on February 16, 1998
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| | |
3.4(5)
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Amended and Restated Certificate of Limited Partnership of NJEA as filed with the Secretary of State of the State of New Jersey on November 3, 1986, as amended and restated on January 14, 1987, June 25, 1987, March 4, 1988 and February 16, 1998
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| | |
3.5(5)
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Amended and Restated Agreement of Limited Partnership of NEA dated as of November 21, 1997
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| | |
3.6(5)
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Amended and Restated Agreement of Limited Partnership of NJEA dated as of November 21, 1997
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| | |
3.7(5)
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Certificate of Limited Partnership of NE LP, a Delaware limited partnership, as filed with the Secretary of State of the State of Delaware on November 21, 1997
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| | |
3.8(5)
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Agreement of Limited Partnership of NE LP, a Delaware limited partnership, dated as of November 21, 1997
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| | |
4.1(1)
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Trust Indenture dated as of November 15, 1994, among the Partnerships, the Funding Corp. and the Trustee
|
| | |
4.2(1)
|
First Supplemental Indenture dated as of November 15, 1994, among the Partnerships, the Funding Corp and the Trustee, including forms of the securities
|
| | |
4.3(1)
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Credit Agreement dated as of December 1, 1994, among the Partnerships, each of the institutions referred to therein and Sanwa Bank Limited, New York Branch (Sanwa)
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| | |
4.4(1)
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Collateral Agency Agreement dated as of December 1, 1994 among the Partnerships, the Funding Corp., the Trustee, Sanwa, the Swap Providers (as defined therein) and State Street Bank and Trust Company, as Collateral Agent
|
| | |
4.5(1)
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Amended and Restated Project Loan and Credit Agreement dated as of December 1, 1994, between the Partnerships and the Funding Corp.
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| | |
4.6(1)
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Partnerships' Guarantee Agreement dated as of December 1, 1994, between the Partnerships and the Trustee
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| | |
4.7(1)
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Registration Rights Agreement dated as of November 21, 1994, among the Partnerships, the Funding Corp., Chase Securities, Inc., Merrill Lynch, Pierce Fenner & Smith, Incorporated and Salomon Brothers, Inc.
|
| | |
4.8(1)
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Pledge, Trust and Intercreditor Agreement dated as of December 1, 1994 among the Partnerships, Sanwa, and Sanwa Bank Trust Company of New York and the Trustee
|
| | |
4.9(1)
|
Assignment and Security Agreement dated as of December 1, 1994, between the Funding Corp. and the Trustee
|
| | |
4.10(1)
|
Amended and Restated Assignment and Security Agreement dated as of December 1, 1994, between the Partnerships, NE LP and the Trustee
|
| | |
4.11(1)
|
Amended and Restated Assignment and Security Agreement dated as of December 1, 1994, between NEA and the Trustee
|
| | |
4.12(1)
|
Amended and Restated Assignment and Security Agreement dated as of December 1, 1994, between NJEA and the Trustee
|
| | |
4.13(1)
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Amended and Restated Mortgage, Assignment of Rents, Security Agreement and Fixture Filing dated as of December 1, 1994, made by NEA in favor of the Trustee
|
| | |
4.14(1)
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Amended and Restated Mortgage, Assignment of Rents, Security Agreement and Fixture Filing (Additional Properties) dated as of December 1, 1994, made by NEA in favor of the Trustee
|
| | |
4.15(1)
|
Amended and Restated Indenture of Mortgage, Assignment of Rents, Security Agreement and Fixture Filing dated as of December 1, 1994, made by NJEA in favor of the Trustee
|
| | |
4.16(1)
|
Amended and Restated Stock Pledge Agreement dated as of December 1, 1994, between NJEA and the Trustee
|
| | |
4.17(1)
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Assignment of Mortgage dated as of December 1, 1994, between The Chase Manhattan Bank (National Association) and the Trustee with respect to the Bellingham Mortgage dated as of June 28, 1989
|
| | |
4.18(1)
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Assignment of Mortgage dated as of December 1, 1994, between The Chase Manhattan Bank (National Association) and the Trustee with respect to the Bellingham Mortgage dated August 10, 1989
|
| | |
4.19(1)
|
Assignment of Mortgage dated as of December 1, 1994, between The Chase Manhattan Bank (National Association) and the Trustee with respect to the Sayreville Mortgage dated June 28, 1989
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| | |
4.20(1)
|
Assignment of Security Agreements dated as of December 1, 1994, among The Chase Manhattan Bank (National Association), the Trustee, the Partnerships, the Funding Corp. and NE LP
|
| | |
4.21(5)
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Second Supplemental Trust Indenture dated as of January 14, 1998 among the Funding Corp., NEA, NJEA and the Trustee
|
| | |
4.22(5)
|
Amendment to Amended and Restated Assignment and Security Agreement by and between NEA, NJEA, NE LP and the Trustee dated as of January 14, 1998
|
| | |
4.23(5)
|
Termination of Pledge, Trust and Intercreditor Agreement dated as of January 30, 1998 among NEA, NJEA, Sanwa, Sanwa Bank and Trust Company of New York and the Trustee
|
| | |
4.24(6)
|
Indenture, dated as of February 19, 1998 among the Acquisition Corp., NE LP, NE LLC, and the Trustee
|
| | |
4.25(6)
|
Registration Rights Agreement, dated as of February 19, 1998 by and among the Acquisition Corp., NE LP, and Goldman Sachs & Co.
|
| | |
4.26(6)
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Company & Partner Pledge Agreement dated as of February 19, 1998 by and among the Acquisition Corp., NE LP and NE LLC in favor of the Trustee
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| | |
4.27(6)
|
Sponsor Pledge Agreement dated as of February 19, 1998 by and among ESI Northeast Acquisition, ESI GP, ESI LP, Suez GP, Suez LP, and Suez Power in favor of the Trustee
|
| | |
4.28(17)
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First Supplemental Indenture dated as of May 31, 1999 among the Acquisition Corp., NE LP, NE LLC, and the Trustee
|
| | |
10.1(1)
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Accommodation Agreement dated as of June 28, 1989, between NEA, Boston Edison (BECO), Commonwealth, Montaup, and The Chase Manhattan Bank (National Association)
|
| | |
10.2.1(1)
|
Amended and Restated Operation and Maintenance Agreement dated as of June 28, 1989 (the "Sayreville O&M Agreement"), between NJEA and Westinghouse Power
|
| | |
10.2.2(1)
|
Letter Agreement regarding the Sayreville Heat Rate dated June 23, 1993, between NJEA and Westinghouse Power
|
| | |
10.2.3(1)
|
Letter Agreement regarding extension of the Sayreville O&M Agreement dated June 23, 1993, between Westinghouse Power and NJEA
|
| | |
10.2.4(1)
|
Second Amended and Restated Operation and Maintenance Agreement dated as of June 28, 1989 (the "Bellingham O&M Agreement"), between NEA and Westinghouse Power
|
| | |
10.2.5(1)
|
Letter Agreement regarding the Bellingham Heat Rate dated June 23, 1993, between NEA and Westinghouse
|
| | |
10.2.6(1)
|
Letter Agreement regarding extension of the Bellingham O&M Agreement dated June 23, 1993, between NEA and Westinghouse Power
|
| | |
10.2.7(2)
|
Amendment No. 1 to the Bellingham O&M Agreement, dated as of May 1, 1995, by and between NEA and Westinghouse Power
|
| | |
10.3.1(1)
|
Power Purchase Agreement dated as of April 1, 1986 (the "BECO I Power Purchase Agreement"), between NEA and BECO
|
| | |
10.3.2(1)
|
First Amendment to the BECO I Power Purchase Agreement dated as of June 8, 1987, between BECO and NEA
|
| | |
10.3.3(1)
|
Second Amendment to the BECO I Power Purchase Agreement dated as of June 21, 1989, between BECO and NEA
|
| | |
10.3.4(1)
|
Power Purchase Agreement dated as of January 28, 1988 (the "BECO II Power Purchase Agreement"), between NEA and BECO
|
| | |
10.3.5(1)
|
First Amendment to the BECO II Power Purchase Agreement dated as of June 21, 1989, between NEA and BECO
|
| | |
10.3.6(1)
|
Power Sale Agreement dated as of November 26, 1986 (the "Commonwealth I Power Purchase Agreement"), between NEA and Commonwealth
|
| | |
10.3.7(1)
|
First Amendment to the Commonwealth I Power Purchase Agreement dated as of August 15, 1988, between Commonwealth and NEA
|
| | |
10.3.8(1)
|
Second Amendment to the Commonwealth I Power Purchase Agreement dated as of January 1, 1989, between Commonwealth and NEA
|
| | |
10.3.9(1)
|
Power Sale Agreement dated as of August 15, 1988 (the "Commonwealth II Power Purchase Agreement"), between NEA and Commonwealth
|
| | |
10.3.10(1)
|
First Amendment to the Commonwealth II Power Purchase Agreement dated as of January 1, 1989, between NEA and Commonwealth
|
| | |
10.3.11(1)
|
Power Purchase Agreement dated as of October 17, 1986 (the "Montaup Power Purchase Agreement"), between NEA and Montaup
|
| | |
10.3.12(1)
|
First Amendment to the Montaup Power Purchase Agreement dated as of June 28, 1989, between Montaup and NEA
|
| | |
10.3.13(1)
|
Power Purchase Agreement dated as of October 22, 1987 (the "JCP&L Power Purchase Agreement"), between NJEA and JCP&L
|
| | |
10.3.14(1)
|
First Amendment to the JCP&L Power Purchase Agreement dated as of June 16, 1989, between JCP&L and NJEA
|
| | |
10.4.1(1)
|
Firm Transportation Service Agreement dated as of February 28, 1994, among CNG Transmission Corporation, a Delaware corporation ("CNG"), NEA, ProGas U.S.A., Inc., a Delaware corporation ("ProGas USA") and ProGas
|
| | |
10.4.2(1)
|
Firm Gas Transportation Agreement (Rate Schedule X-320) dated as of February 27, 1991, between NEA and Transcontinental Gas Pipe Line Corporation, a Delaware corporation ("Transco")
|
| | |
10.4.3(1)
|
Rate Schedule X-35 Firm Gas Transportation Agreement dated as of October 1, 1993, between NEA and Algonquin Gas Transmission Company, a Delaware corporation ("Algonquin")
|
| | |
10.4.4(1)
|
Service Agreement for Rate Schedule FTS-5 dated as of February 16, 1994, between NEA and Texas Eastern Transmission Corporation, a Delaware corporation ("Texas Eastern")
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| | |
10.4.5(1)
|
ProGas/TransCanada NE Assignment Agreement dated as of July 30, 1993, between ProGas and TransCanada Pipelines Limited, an Ontario corporation ("TransCanada")
|
| | |
10.4.6(1)
|
Northeast Gas Substitution Agreement dated as of July 30, 1993, among ProGas, NEA and TransCanada
|
| | |
10.4.7(1)
|
Northeast Notice and Consent dated as of July 30, 1993, among NEA, ProGas and TransCanada
|
| | |
10.4.8(1)
|
ProGas NE Producer Assignment Agreement dated as of July 30, 1993, between ProGas and TransCanada
|
| | |
10.4.9(1)
|
Firm Transportation Service Agreement dated as of February 28, 1994, among CNG, NJEA, ProGas USA and ProGas
|
| | |
10.4.10(1)
|
Firm Gas Transportation Agreement (Rate Schedule X-319) dated as of February 27, 1991, between Transco and NJEA
|
| | |
10.4.11(1)
|
Gas Purchase and Sales Agreement dated as of May 4, 1989 (the "PSE&G Agreement"), between NJEA and PSE&G
|
| | |
10.5.1(1)
|
Service Agreement Applicable to the Storage of Natural Gas Under Rate Schedule GSS-II dated as of September 30, 1993, between CNG and NEA
|
| | |
10.5.2(1)
|
Service Agreement Applicable to the Storage of Natural Gas Under Rate Schedule GSS-II dated as of September 30, 1993, between CNG and NJEA
|
| | |
10.5.3(2)
|
Service Agreement Applicable to Transportation of Natural Gas under Rate Schedule FT dated as of February 1, 1996, by and between CNG and NEA
|
| | |
10.5.4(2)
|
Service Agreement Applicable to Transportation of Natural Gas under Rate Schedule FT dated as of February 1, 1996, by and between CNG and NJEA
|
| | |
10.6.1(1)
|
Gas Purchase Contract dated as of May 12, 1988 (the "Bellingham ProGas Agreement"), between ProGas and NEA
|
| | |
10.6.2(1)
|
First Amending Agreement to the Bellingham ProGas Agreement dated as of April 17, 1989, between ProGas and NEA
|
| | |
10.6.3(1)
|
Second Amending Agreement to the Bellingham ProGas Agreement dated as of June 23, 1989, between ProGas and NEA
|
| | |
10.6.4(1)
|
Amending Agreement to the ProGas Agreements (as defined below) dated as of November 1, 1991, between ProGas, NEA and NJEA
|
| | |
10.6.5(1)
|
Third Amending Agreement to the Bellingham ProGas Agreement dated as of July 30, 1993, between ProGas and NEA
|
| | |
10.6.6(1)
|
Letter Agreement regarding the Bellingham ProGas Agreement dated as of September 14, 1992, between ProGas and NEA
|
| | |
10.6.7(1)
|
Letter Agreement regarding the Bellingham ProGas Agreement dated as of July 30, 1993, between ProGas and NEA
|
| | |
10.7.1(1)
|
Amended and Restated Steam Sales Agreement dated as of December 21, 1990, between NEA and NECO-Bellingham, Inc., a Massachusetts corporation ("NECO")
|
| | |
10.7.2(1)
|
Industrial Steam Sales Contract dated as of June 5, 1989, between NJEA and Hercules Incorporated, a Delaware corporation ("Hercules")
|
| | |
10.8.1(1)
|
Letter agreement regarding Bellingham Project power transmission arrangements dated June 29, 1989, between NEA and BECO
|
| | |
10.8.2(1)
|
Letter agreement regarding Bellingham Project power transmission arrangements dated June 6, 1989, between NEA and Commonwealth
|
| | |
10.8.3(1)
|
Letter agreement regarding Bellingham Project power transmission arrangements dated June 28, 1989, between NEA and Montaup
|
| | |
10.9(1)
|
Amended and Restated Interconnection Agreement dated as of September 24, 1993, between BECO and NEA
|
| | |
10.10. 1(4)
|
Guaranty of Contract for Operation and Maintenance dated May 12, 1995 by Westinghouse Power
|
| | |
10.10.2(1)
|
Licensing Agreement for the Fluor Daniel Carbon Dioxide Recovery Process dated as of June 28, 1989, between Fluor Daniel Inc., a California corporation ("Fluor Daniel"), and NEA
|
| | |
10.11.1(1)
|
Ground Lease Agreement dated as of June 28, 1989, between NJEA and ETURC
|
| | |
10.11.2(1)
|
Agreement of Sublease dated as of June 28, 1989, between ETURC and NJEA
|
| | |
10.11.3(1)
|
Lease of Property dated as of June 1, 1986, between Prestwich Corporation and NE LP
|
| | |
10.12.1(1)
|
Investment Agreement dated as of December 1, 1994, between Sanwa and Sanwa Bank Trust Company of New York under the Pledge, Trust and Intercreditor Agreement
|
| | |
10.12.2(1)
|
Investment Agreement dated as of December 1, 1994, between Sanwa and Sanwa Bank Trust Company of New York under the Pledge, Trust and Intercreditor Agreement
|
| | |
10.13(1)
|
Agreement between the Water and Sewer Commissioners of the Town of Bellingham and NEA dated as of December 13, 1988 and December 30, 1988, respectively
|
| | |
10.14(1)
|
Mortgage, Assignment of Rents, Security Agreement and Fixture Filing dated June 29, 1989, by NEA in favor of BECO, Commonwealth and Montaup
|
| | |
10.15(3)
|
Declaration of Easements, Covenants, and Restrictions dated as of June 28, 1989 by NEA
|
| | |
10.16(5)
|
Operation and Maintenance Agreement dated as of November 21, 1997 by and between NE LP and NextEra Operating Services
|
| | |
10.17(5)
|
Operation and Maintenance Agreement dated as of November 21, 1997 by and between NE LP and NextEra Operating Services
|
| | |
10.18(5)
|
Fuel Management Agreement, dated as of January 20, 1998, effective retroactive to January 14, 1998, by and between NE LP and ESI Northeast Fuel, assigned by NE LP to NEA on January 20, 1998
|
| | |
10.19(5)
|
Fuel Management Agreement, dated as of January 20, 1998, effective retroactive to January 14, 1998, by and between NE LP and ESI Northeast Fuel, assigned by NE LP to NJEA on January 20, 1998
|
| | |
10.20(5)
|
Administrative Services Agreement dated as of November 21, 1997 between NE LP and ESI GP
|
| | |
10.21(6)
|
Reimbursement Agreement dated as of November 21, 1997 by and among FPL Group Capital, Suez Power and NE LP
|
| | |
10.22(7)
|
Termination Agreement, dated August 9, 2002, between ProGas and NJEA
|
| | |
10.23(8)
|
Base Contract for Sale and Purchase of Natural Gas, dated October 2, 2002, between PMI and NJEA
|
| | |
10.24(8)
|
Base Contract for Sale and Purchase of Natural Gas, dated September 26, 2002, between SEMNA and NJEA
|
| | |
10.25(8)
|
Guarantee, dated October 2, 2002, between FPL Group Capital and NJEA
|
| | |
10.26(8)
|
Guaranty, dated October 2, 2002, by Tractebel S.A. in favor of NJEA
|
| | |
10.27(9)
|
Operating Lease Agreement dated as of October 10, 2002 between NEA and The BOC Group, Inc.
|
| | |
10.28(9)
|
On-Site Steam Supply Agreement between NEA and The BOC Group, Inc. dated as of October 10, 2002
|
| | |
10.29(9)
|
Three Party Agreement dated as of October 10, 2002 among The BOC Group, Inc., Praxair, Inc. and NEA
|
| | |
10.30(9)
|
Consent and Agreement dated as of October 10, 2002 among The BOC Group, Inc. and Praxair, Inc.
|
| | |
10.31(9)
|
Flue Gas Supply Agreement dated as of October 10, 2002 between NEA and Praxair, Inc.
|
| | |
10.32(9)
|
BOC Flue Gas Agreement of Sale dated as of October 10, 2002 by and between The BOC Group, Inc. and NEA
|
| | |
10.33(9)
|
Agreement dated February 28, 2003 between JCP&L and NJEA relating to the Power Purchase Agreement dated as of October 22, 1987, as amended
|
| | |
10.34(9)
|
Transition Services Agreement dated as of October 11, 2002 by and between The BOC Group, Inc. and NEA
|
| | |
10.35(10)
|
Service Agreement, dated February 1, 2003, between Transco and NJEA
|
| | |
10.36(10)
|
Service Agreement, dated February 1, 2003, between Transco and NEA
|
| | |
10.37(10)
|
Amending Agreement, dated as of March 1, 2003, between ProGas and NEA
|
| | |
10.38(11)
|
Termination Agreement, dated as of July 11, 2003, between ProGas and NEA
|
| | |
10.39(11)
|
Partial Termination Agreement, dated July 11, 2003, between ProGas and NEA
|
| | |
10.40(12)
|
Base Contract for Sale and Purchase of Natural Gas, dated August 1, 2003, between PMI and NEA
|
| | |
10.41(12)
|
Base Contract for Sale and Purchase of Natural Gas, dated August 1, 2003, between SEMNA and NEA
|
| | |
10.42(12)
|
Guarantee, dated August 1, 2003, by FPL Group Capital in favor of NEA
|
| | |
10.43(12)
|
Guaranty, dated August 1, 2003, by Tractebel S.A. in favor of NEA
|
| | |
10.44(12)
|
First Amendment to Guarantee, dated August 1, 2003, by FPL Group Capital, with the consent and acknowledgement of NEA
|
| | |
10.45(12)
|
First Amendment to Guarantee, dated October 2, 2002, by FPL Group Capital, with the consent and acknowledgement of NJEA
|
| | |
10.46(13)
|
Amended and Restated Power Purchase Agreement dated as of May 16, 2003 by and between NJEA and JCP&L
|
| | |
10.47(13)
|
Sayreville Execution Agreement dated May 16, 2003 between JCP&L and NJEA
|
| | |
10.48(13)
|
Amendment to Gas Purchase and Sales Agreement dated as of August 20, 2003 by and between PSE&G and NJEA
|
| | |
10.49(13)
|
Capacity Transfer Agreement dated October 9, 2003 between NJEA and PSE&G Energy Resources & Trade LLC
|
| | |
10.50(13)
|
Termination Agreement dated as of October 21, 2003 between Hercules and NJEA
|
| | |
10.51(13)
|
Letter Agreement dated October 9, 2003 by and between PSE&G and NJEA
|
| | |
10.52(13)
|
First Amendment to Amended and Restated Power Purchase Agreement dated as of October 21, 2003 by and between NJEA and JCP&L
|
| | |
10.53(13)
|
First Amendment to Industrial Steam Sales Contract dated as of December 16, 2003 by and between NJEA and Hercules
|
| | |
10.54(13)
|
Second Amendment to Amended and Restated Power Purchase Agreement dated as of December 16, 2003 by and between NJEA and JCP&L
|
| | |
10.55(13)
|
Interim Agreement dated December 18, 2003 by and between NJEA and JCP&L
|
| | |
10.56(13)
|
Guaranty dated as of December 23, 2003 by Suez-Tractebel S.A. in favor of PSE&G
|
| | |
10.57(13)
|
Guarantee dated as of December 23, 2003 by FPL Group Capital in favor of PSE&G
|
| | |
10.58(13)
|
Termination Agreement dated December 23, 2003 by and between NJEA and SEMNA
|
| | |
10.59(13)
|
Termination Agreement dated December 23, 2003 by and between NJEA and PMI
|
| | |
10.60(14)
|
Termination Agreement dated as of October 21, 2003 between Hercules and NJEA
|
| | |
10.61(14)
|
Letter Agreement dated October 9, 2003 by and between PSE&G and NJEA
|
| | |
10.62(14)
|
Power Purchase Agreement dated as of January 1, 2004 by and between NJEA and SEMNA
|
| | |
10.63(14)
|
Power Purchase Agreement dated as of January 1, 2004 by and between NJEA and PMI
|
| | |
10.64(14)
|
Base Contract for Sale and Purchase of Natural Gas dated January 1, 2004 between NEA and PMI
|
| | |
10.65(14)
|
Base Contract for Sale and Purchase of Natural Gas dated January 1, 2004 between NEA and SEMNA
|
| | |
10.66(15)
|
Amended and Restated Gas Purchase and Sales Agreement dated as of March 26, 2004 between NJEA and PSE&G
|
| | |
10.67(16)
|
Bellingham Execution Agreement dated August 19, 2004 between BECO and Commonwealth (CECo) and NEA, including Amended and Restated Power Purchase Agreements dated as of August 19, 2004 by and between BECO and NEA, and Amended and Restated Power Purchase Agreements dated as of August 19, 2004 by and between CECo and NEA
|
| | |
10.68(16)
|
Termination Agreement dated January 14, 2005 between ProGas Limited and NEA
|
| | |
10.69(17)
|
Base Contract for Sale and Purchase of Natural Gas dated January 25, 2005 between PMI and NEA
|
| | |
10.70(17)
|
Special Provisions dated January 25, 2005 between PMI and NEA
|
| | |
10.71(17)
|
Base Contract for Sale and Purchase of Natural Gas dated January 25, 2005 between SEMNA and NEA
|
| | |
10.72(17)
|
Special Provisions dated January 25, 2005 between SEMNA and NEA
|
| | |
10.73(17)
|
Supplemental Fuel Management Subcontract Agreement dated as of February 28, 2005 between Bellingham Cogeneration Plant and ESI Northeast Fuel and PMI
|
| | |
21
|
Subsidiaries of the Registrants
|
| | |
31(a)
|
Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of the Acquisition Corp.
|
| | |
31(b)
|
Rule 13a-14(a)/15d-14(a) Certification of Treasurer (equivalent to the Chief Financial Officer) of the Acquisition Corp.
|
| | |
31(c)
|
Rule 13a-14(a)/15d-14(a) Certification of President (equivalent to the Chief Executive Officer) of ESI GP as Administrative General Partner of NE LP
|
| | |
31(d)
|
Rule 13a-14(a)/15d-14(a) Certification of Vice President and Treasurer (equivalent to the Chief Financial Officer) of ESI GP as Administrative General Partner of NE LP
|
| | |
32(a)
|
Section 1350 Certification of the Acquisition Corp.
|
| | |
32(b)
|
Section 1350 Certification of NE LP
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