fuels used for thermoelectric generation, mainly coal, diesel and LNG, are indexed to international prices.
In 2017, the generation installed capacity in the Chilean market was composed primarily of the following:
## Table 0 ##
In the SIC, where hydroelectric plants represent a large part of the system's installed capacity, hydrological conditions influence reservoir water levels and largely determine the dispatch of the system's hydroelectric and thermoelectric generation plants and, therefore, influence spot market prices.
Precipitation in Chile occurs principally in the southern cone mostly from June to August, and is scarce during the remainder of the year.
During 2017 spot prices were also affected by a 14% increase in installed renewable energy capacity, totaling 564 MW, bringing total installed capacity to 4,719 MW.
The Ministry of Energy has primary responsibility for the Chilean electricity system directly or through the National Energy Commission and the Superintendency of Electricity and Fuels.
The electricity sector is divided into three segments: generation, transmission and distribution.
Generally, generation and transmission growth is subject to market competition, while transmission operation and distribution are subject to price regulation.
In July 2016, modifications to the Transmission Law were enacted.
This law establishes that the transmission system will be completely paid for by the end-users, gradually allocating the costs on the demand side from 2019 through 2034.
All generators can sell energy through contracts with regulated distribution companies or directly to unregulated customers.
Unregulated customers are customers whose connected capacity is higher than 2 MW.
Customers with connected capacity between 0.5 MW and 2.0 MW can opt for regulated or unregulated contracts for a minimum period of four years.
By law, both regulated and unregulated customers are required to purchase all electricity under contract.
Generators may also sell energy to other power generation companies on a short-term basis at negotiated prices outside the spot market.
Electricity prices in Chile are denominated in U. S.  dollars, although payments are made in Chilean pesos.
Business Description — In Chile, through AES Gener, we are engaged in the generation and supply of electricity (energy and capacity) in the CISEN.
AES Gener is the second largest generation operator in Chile with installed capacity of 4,150 MW, excluding energy storage and TermoAndes, and a market share of approximately 18% as of December 31, 2017.  AES Gener owns a diversified generation portfolio in Chile in terms of geography, technology, customers and fuel source.
AES Gener's installed capacity is located near the principal electricity consumption centers, including Santiago, Valparaiso and Antofagasta.
AES Gener's diverse generation portfolio provides flexibility for the management of contractual obligations with regulated and unregulated customers, provides backup energy to the spot market and facilitates operations under a variety of market and hydrological conditions.
Our commercial strategy in Chile aims to maximize margin while reducing cash flow volatility.
To achieve this, we contract a significant portion of our coal and hydroelectric baseload capacity under long-term agreements with a diversified customer base.
Power plants not considered within our baseload capacity (higher variable cost units, mainly diesel and gas fired) sell energy on the spot market when operating during scarce system supply conditions, such as low hydrology and/or plant outages.
In Chile, sales on the spot market are made only to other generation companies who are members of the CISEN at the system marginal cost.
AES Gener currently has long-term contracts, with an average remaining term of approximately 11 years, with regulated distribution companies and unregulated customers, such as mining and industrial companies.
In general, these long-term contracts include both fixed and variable payments which are indexed to the CPI and the international price of coal.
In some cases, the contracts include pass-through of fuel and regulatory costs, including changes in law.
In addition to energy payments, AES Gener also receives capacity payments to remain available during periods of peak demand.
CISEN annually determines the capacity requirements for each power plant.
The capacity price is fixed semiannually by the National Energy Commission and indexed to the CPI and other relevant indices.
The Chilean government allows the export of energy generated from plants in the SING to Argentina utilizing transmission lines owned by AES Gener.
Environmental Regulation — During 2016, the Environmental Ministry updated the Atmospheric
Risk and Insurance Brokerage Services
## Table 1 ##
During 2009 we continued to see a soft market, which began in 2007, in our retail brokerage product line.
In 2007, we experienced a soft market in many business lines and in many geographic areas.
In a ‘‘soft market,’’ premium rates flatten or decrease, along with commission revenues, due to increased competition for market share among insurance carriers or increased underwriting capacity.
Changes in premiums have a direct and potentially material impact on the insurance brokerage industry, as commission revenues are generally based on a percentage of the premiums paid by insureds.
Prices fell throughout 2007, with the greatest declines seen in large and middle-market accounts.
Prices continued to decline during 2008, although the rate of decline slowed toward the end of the year.
In our reinsurance brokerage product line, pricing overall during 2009 was also down, although during a portion of the year it was flat to up slightly.
Additionally, beginning in late 2008 and continuing throughout 2009, we faced difficult conditions as a result of unprecedented disruptions in the global economy, the repricing of credit risk and the deterioration of the financial markets.
Continued volatility and further deterioration in the credit markets have reduced our customers’ demand for our retail brokerage and reinsurance brokerage products, which have negatively hurt our operational results.
In addition, overall capacity in the industry could decrease if a significant insurer either fails or withdraws from writing insurance coverages that we offer our clients.
This failure could reduce our revenues and profitability, since we would no longer have access to certain lines and types of insurance.
Risk and Insurance Brokerage Services generated approximately 83% of our consolidated total revenues in 2009.
Revenues are generated primarily through fees paid by clients, commissions and fees paid by insurance and reinsurance companies, and investment income on funds held on behalf of clients.
Our revenues vary from quarter to quarter throughout the year as a result of the timing of our clients’ policy renewals, the net effect of new and lost business, the timing of services provided to our clients, and the income we earn on investments, which is heavily influenced by short-term interest rates.
We operate in a highly competitive industry and compete with many retail insurance brokerage and agency firms, as well as with individual brokers, agents, and direct writers of insurance coverage.
Specifically, we address the highly specialized product development and risk management needs of commercial enterprises, professional groups, insurance companies, governments, healthcare providers, and non-profit groups, among others; provide affinity products for professional liability, life, disability income, and personal lines for individuals, associations, and businesses; provide reinsurance services to insurance and reinsurance companies and other risk assumption entities by acting as brokers or intermediaries on all classes of reinsurance; provide investment banking products and services, including mergers and acquisitions and other financial advisory services, capital raising, contingent capital financing, insurance-linked securitizations and derivative applications; provide managing underwriting to independent agents and brokers as well as corporate clients; provide actuarial, loss prevention, and administrative services to businesses and consumers; and manage captive insurance companies.
In November 2008 we expanded our product offerings through the merger with Benfield, a leading independent reinsurance intermediary.
Benfield products have been integrated with our existing reinsurance products in 2009.
In February 2009, we completed the sale of the U. S.  operations of Cananwill, our premium finance business.
In June and July of 2009, we entered into agreements with third parties with respect to our
PRUDENTIAL FINANCIAL, INC.  Notes to Consolidated Financial Statements
## Table 2 ##
(1) For the year ended December 31, 2015 primarily represents distributions to and deconsolidations of noncontrolling interests and eliminations of intercompany separate account investments.
For the years ended December 31, 2014 and 2013 primarily represents reclassifications of certain assets between reporting categories.
(2) Transfers into or out of Level 3 are generally reported as the value as of the beginning of the quarter in which the transfers occur for any such assets still held at the end of the quarter.
(3) Unrealized gains or losses related to assets still held at the end of the period do not include amortization or accretion of premiums and discounts.
(4) Separate account assets represent segregated funds that are invested for certain customers.
Investment risks associated with market value changes are borne by the customers, except to the extent of minimum guarantees made by the Company with respect to certain accounts.
Separate account liabilities are not included in the above table as they are reported at contract value and not fair value in the Company’s Consolidated Statements of Financial Position.
(5) Prior period's amounts are presented on a basis consistent with the current period presentation.
(6) Includes credit-tranched securities collateralized by sub-prime mortgages, auto loans, credit cards, education loans and other asset types.
Transfers—Transfers into Level 3 are generally the result of unobservable inputs utilized within valuation methodologies and the use of indicative broker quotes for assets that were previously valued using observable inputs.
Transfers out of Level 3 are generally due to the use of observable inputs in valuation methodologies as well as the availability of pricing service information for certain assets that the Company is able to validate.
Derivative Fair Value Information The following tables present the balance of derivative assets and liabilities measured at fair value on a recurring basis, as of the date indicated, by primary underlying.
These tables include NPR and exclude embedded derivatives and associated reinsurance recoverables.
The derivative assets and liabilities shown below are included in “Trading account assets-All Other Activity,” “Other long-term investments” or “Other liabilities” in the tables presented above, under the headings “Assets and Liabilities by Hierarchy Level” and “Changes in Level 3 Assets and Liabilities.
”
## Table 3 ##

<table><tr><td></td><td>SIC</td><td>SING</td><td>CISEN</td></tr><tr><td>Thermoelectric</td><td>44%</td><td>84%</td><td>54%</td></tr><tr><td>Hydroelectric</td><td>38%</td><td>—</td><td>29%</td></tr><tr><td>Solar</td><td>8%</td><td>11%</td><td>9%</td></tr><tr><td>Wind</td><td>7%</td><td>3%</td><td>6%</td></tr><tr><td>Other</td><td>3%</td><td>2%</td><td>2%</td></tr></table>
<table><tr><td>Years Ended December 31,</td><td>2009</td><td>2008</td><td>2007</td></tr><tr><td>Segment revenue</td><td>$6,305</td><td>$6,197</td><td>$5,918</td></tr><tr><td>Segment operating income</td><td>900</td><td>846</td><td>954</td></tr><tr><td>Segment operating income margin</td><td>14.3%</td><td>13.7%</td><td>16.1%</td></tr></table>
<table><tr><td></td><td colspan="4">Year Ended December 31, 2013</td></tr><tr><td></td><td>SeparateAccountAssets-4</td><td>FuturePolicyBenefits</td><td>OtherLiabilities</td><td>NotesIssued byConsolidatedVIEs</td></tr><tr><td></td><td colspan="4">(in millions)</td></tr><tr><td>Fair Value, beginning of period</td><td>$21,132</td><td>$-3,348</td><td>$0</td><td>$-1,406</td></tr><tr><td>Total gains (losses) (realized/unrealized):</td><td></td><td></td><td></td><td></td></tr><tr><td>Included in earnings:</td><td></td><td></td><td></td><td></td></tr><tr><td>Realized investment gains (losses), net</td><td>2</td><td>3,741</td><td>-3</td><td>17</td></tr><tr><td>Interest credited to policyholders’ account balances</td><td>2,649</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Net investment income</td><td>20</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Purchases</td><td>1,653</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Sales</td><td>-832</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Issuances</td><td>0</td><td>-836</td><td>0</td><td>-1,834</td></tr><tr><td>Settlements</td><td>-2,120</td><td>0</td><td>0</td><td>-31</td></tr><tr><td>Foreign currency translation</td><td>0</td><td>2</td><td>0</td><td>0</td></tr><tr><td>Other-1</td><td>140</td><td>0</td><td>-2</td><td>0</td></tr><tr><td>Transfers into Level 3-2</td><td>89</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Transfers out of Level 3-2</td><td>-130</td><td>0</td><td>0</td><td>0</td></tr><tr><td>Fair Value, end of period</td><td>$22,603</td><td>$-441</td><td>$-5</td><td>$-3,254</td></tr><tr><td>Unrealized gains (losses) for assets/liabilities still held(3):</td><td></td><td></td><td></td><td></td></tr><tr><td>Included in earnings:</td><td></td><td></td><td></td><td></td></tr><tr><td>Realized investment gains (losses), net</td><td>$0</td><td>$3,647</td><td>$-3</td><td>$17</td></tr><tr><td>Interest credited to policyholders’ account balances</td><td>$1,652</td><td>$0</td><td>$0</td><td>$0</td></tr></table>
<table><tr><td></td><td colspan="5">As of December 31, 2015</td></tr><tr><td></td><td>Level 1</td><td>Level 2</td><td>Level 3</td><td>Netting-1</td><td>Total</td></tr><tr><td></td><td colspan="5">(in millions)</td></tr><tr><td>Derivative assets:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Rate</td><td>$11</td><td>$10,561</td><td>$7</td><td></td><td>$10,579</td></tr><tr><td>Currency</td><td>0</td><td>318</td><td>0</td><td></td><td>318</td></tr><tr><td>Credit</td><td>0</td><td>3</td><td>0</td><td></td><td>3</td></tr><tr><td>Currency/Interest Rate</td><td>0</td><td>2,995</td><td>0</td><td></td><td>2,995</td></tr><tr><td>Equity</td><td>4</td><td>254</td><td>32</td><td></td><td>290</td></tr><tr><td>Commodity</td><td>0</td><td>0</td><td>0</td><td></td><td>0</td></tr><tr><td>Netting-1</td><td></td><td></td><td></td><td>-11,457</td><td>-11,457</td></tr><tr><td>Total derivative assets</td><td>$15</td><td>$14,131</td><td>$39</td><td>$-11,457</td><td>$2,728</td></tr><tr><td>Derivative liabilities:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Interest Rate</td><td>$3</td><td>$4,573</td><td>$2</td><td></td><td>$4,578</td></tr><tr><td>Currency</td><td>0</td><td>114</td><td>0</td><td></td><td>114</td></tr><tr><td>Credit</td><td>0</td><td>53</td><td>0</td><td></td><td>53</td></tr><tr><td>Currency/Interest Rate</td><td>0</td><td>244</td><td>0</td><td></td><td>244</td></tr><tr><td>Equity</td><td>0</td><td>327</td><td>0</td><td></td><td>327</td></tr><tr><td>Commodity</td><td>0</td><td>0</td><td>0</td><td></td><td>0</td></tr><tr><td>Netting-1</td><td></td><td></td><td></td><td>-5,276</td><td>-5,276</td></tr><tr><td>Total derivative liabilities</td><td>$3</td><td>$5,311</td><td>$2</td><td>$-5,276</td><td>$40</td></tr></table>

Question: Which Level is Total derivative assets as of December 31, 2015 the largest?
Answer: 2