Valuation techniques – Cash equivalents are mostly comprised of short-term money-market instruments and are valued at cost, which approximates fair value.
U. S.  equity securities and international equity securities categorized as Level 1 are traded on active national and international exchanges and are valued at their closing prices on the last trading day of the year.
For U. S.  equity securities and international equity securities not traded on an active exchange, or if the closing price is not available, the trustee obtains indicative quotes from a pricing vendor, broker, or investment manager.
These securities are categorized as Level 2 if the custodian obtains corroborated quotes from a pricing vendor or categorized as Level 3 if the custodian obtains uncorroborated quotes from a broker or investment manager.
Commingled equity funds are investment vehicles valued using the Net Asset Value (NAV) provided by the fund managers.
The NAV is the total value of the fund divided by the number of shares outstanding.
Commingled equity funds are categorized as Level 1 if traded at their NAV on a nationally recognized securities exchange or categorized as Level 2 if the NAV is corroborated by observable market data (e. g. , purchases or sales activity) and we are able to redeem our investment in the near-term.
Fixed income investments categorized as Level 2 are valued by the trustee using pricing models that use verifiable observable market data (e. g. , interest rates and yield curves observable at commonly quoted intervals and credit spreads), bids provided by brokers or dealers, or quoted prices of securities with similar characteristics.
Fixed income investments are categorized at Level 3 when valuations using observable inputs are unavailable.
The trustee obtains pricing based on indicative quotes or bid evaluations from vendors, brokers, or the investment manager.
Private equity funds, real estate funds, and hedge funds are valued using the NAV based on valuation models of underlying securities which generally include significant unobservable inputs that cannot be corroborated using verifiable observable market data.
Valuations for private equity funds and real estate funds are determined by the general partners.
Depending on the nature of the assets, the general partners may use various valuation methodologies, including the income and market approaches in their models.
The market approach consists of analyzing market transactions for comparable assets while the income approach uses earnings or the net present value of estimated future cash flows adjusted for liquidity and other risk factors.
Hedge funds are valued by independent administrators using various pricing sources and models based on the nature of the securities.
Private equity funds, real estate funds, and hedge funds are generally categorized as Level 3 as we cannot fully redeem our investment in the near-term.
Commodities are traded on an active commodity exchange and are valued at their closing prices on the last trading day of the year.
Contributions and Expected Benefit Payments We generally determine funding requirements for our defined benefit pension plans in a manner consistent with CAS and Internal Revenue Code rules.
In 2013, we made contributions of $2.25 billion related to our qualified defined benefit pension plans.
We currently plan to make contributions of approximately $1.0 billion related to the qualified defined benefit pension plans in 2014.
In 2013, we made contributions of $98 million to our retiree medical and life insurance plans.
We do not expect to make contributions related to the retiree medical and life insurance plans in 2014 as a result of our 2013 contributions.
The following table presents estimated future benefit payments, which reflect expected future employee service, as of December 31, 2013 (in millions):
## Table 0 ##
Defined Contribution Plans We maintain a number of defined contribution plans, most with 401(k) features, that cover substantially all of our employees.
Under the provisions of our 401(k) plans, we match most employees’ eligible contributions at rates specified in the plan documents.
Our contributions were $383 million in 2013, $380 million in 2012, and $378 million in 2011, the majority of which were funded in our common stock.
Our defined contribution plans held approximately 44.7 million and 48.6 million shares of our common stock as of December 31, 2013 and 2012.
Restricted Stock Units, or RSUs Typically, RSUs granted under the Company’s LTIP fully vest three years from the date of issuance.
Fair value of the RSUs is based on the closing price of NRG common stock on the date of grant.
The following table summarizes the Company’s non-vested RSU awards and changes during the year:
## Table 1 ##
The total fair value of RSUs vested during the years ended December 31, 2010, 2009, and 2008, was $9 million, $8 million and $22 million, respectively.
The weighted average grant date fair value of RSUs granted during the years ended December 31, 2010, 2009 and 2008 was $22.78, $26.13 and $39.84, respectively.
Deferred Stock Units, or DSUs DSUs represent the right of a participant to be paid one share of NRG common stock at the end of a deferral period established under the terms of the award.
DSUs granted under the Company’s LTIP are fully vested at the date of issuance.
Fair value of the DSUs, which is based on the closing price of NRG common stock on the date of grant, is recorded as compensation expense in the period of grant.
The following table summarizes the Company’s outstanding DSU awards and changes during the year:
## Table 2 ##
The aggregate intrinsic values for DSUs outstanding as of December 31, 2010, 2009, and 2008 were approximately $7 million, $7 million, and $6 million respectively.
The aggregate intrinsic values for DSUs converted to common stock for the years ended December 31, 2010, 2009, and 2008 were $0.7 million, $0.5 million and $1.5 million, respectively.
The weighted average grant date fair value of DSUs granted during the years ended December 31, 2010, 2009, and 2008 was $22.18, $22.77 and $35.12, respectively.
Performance Units, or PUs PUs granted under the Company’s LTIP fully vest three years from the date of issuance.
PUs granted prior to January 1, 2009, are paid out upon vesting if the closing price of NRG’s common stock on the vesting date, or the Measurement Price, is equal to or greater than the Target Price.
PUs granted after January 1, 2009, are paid out upon vesting if the Measurement Price is equal to or greater than Threshold Price.
The Threshold Price, Target Price and Maximum Price are determined on the date of issuance.
The payout for each PU will be equal to: (i) a pro-rata amount between 0.5 and 1 share of common stock, if the Measurement Price is equal to or greater than the target Threshold Price but less than the Target Price, for grants made after January 1, 2009; (ii) one share of common stock, if the Measurement Price equals the Target Price; (iii) a pro-rata amount between one and two shares of common stock, if the Measurement Price is greater than the Target Price but less than the Maximum Price; and (iv) two shares of common stock, if the Measurement Price is equal to, or greater than, the Maximum Price.
The following table summarizes NRG's global generation portfolio as of December 31, 2014:
## Table 3 ##
(a) Includes 95 active fossil fuel and nuclear plants, 14 Utility Scale Solar facilities, 35 wind farms and multiple Distributed Solar facilities.
All Utility Scale Solar and Distributed Solar facilities are described in megawatts on an alternating current basis.
MW figures provided represent nominal summer net megawatt capacity of power generated as adjusted for the Company's owned or leased interest excluding capacity from inactive/mothballed units.
(b) The NRG Yield operating segment consists of two dual-fuel (natural gas and oil) simple-cycle generation facilities.
In addition, the Company's thermal assets, which are part of the NRG Yield operating segment, provide steam and chilled water capacity of approximately 1,464 MWt through the district energy business, 118 MWt of which is available under right-to-use provisions contained in agreements between two of NRG's thermal facilities and certain of their customers.
NRG's portfolio diversification and commercial operations hedging strategy provides the Company with reliable future cash flows.
NRG has hedged a portion of its coal and nuclear capacity with decreasing hedge levels through 2019.
As a result of the GenOn acquisition, the majority of the Company's generation is in markets with forward capacity markets that extend three years into the future.
These capacity revenues not only enhance the reliability of future cash flows but are not correlated to natural gas prices.
NRG also has cooperative load contract obligations in the Gulf Coast region expiring at various dates through 2025, which largely hedges the Company's generation in this region.
In addition, as of December 31, 2014, the Company had purchased fuel forward under fixed price contracts, with contractually-specified price escalators, for approximately 50% of its expected coal requirement from 2015 to 2019, excluding inventory.
The Company enters into additional hedges when it deems market conditions to be favorable.
The Company also has the advantage of being able to supply its retail businesses with its own generation, which can reduce the need to sell and buy power from other institutions and intermediaries, resulting in lower transaction costs and credit exposures.
This combination of generation and retail allows for a reduction in actual and contingent collateral, through offsetting transactions and by reducing the need to hedge the retail power supply through third parties.
The generation and retail combination also provides stability in cash flows, as changes in commodity prices generally have offsetting impacts between the two businesses.
The offsetting nature of generation and retail, in relation to changes in market prices, is an integral part of NRG's goal of providing a reliable source of future cash flow for the Company.
When developing new renewable and conventional power generation facilities, NRG typically secures long-term PPAs, which insulate the Company from commodity market volatility and provide future cash flow stability.
These PPAs are typically contracted with high credit quality local utilities and have durations from 10 years to as much as 25 years.
Credit Ratings Credit rating agencies rate a firm's public debt securities.
These ratings are utilized by the debt markets in evaluating a firm's credit risk.
Ratings influence the price paid to issue new debt securities by indicating to the market the Company's ability to pay principal, interest and preferred dividends.
Rating agencies evaluate a firm's industry, cash flow, leverage, liquidity, and hedge profile, among other factors, in their credit analysis of a firm's credit risk.
The following table summarizes the credit ratings for NRG Energy, Inc. , its Term Loan Facility and its Senior Notes, GenOn Senior Notes, GenOn Americas Generation Senior Notes, and NRG Yield, Inc.  as of December 31, 2014:

<table><tr><td></td><td>2014</td><td>2015</td><td>2016</td><td>2017</td><td>2018</td><td>2019 - 2023</td></tr><tr><td>Qualified defined benefit pension plans</td><td>$1,960</td><td>$2,030</td><td>$2,110</td><td>$2,200</td><td>$2,300</td><td>$13,240</td></tr><tr><td>Retiree medical and life insurance plans</td><td>200</td><td>210</td><td>210</td><td>220</td><td>220</td><td>1,070</td></tr></table>
<table><tr><td> </td><td>Units</td><td> Weighted Average Grant-Date Fair Value per Unit</td></tr><tr><td> </td><td colspan="2"> (In whole) </td></tr><tr><td>Non-vested at December 31, 2009</td><td>1,614,769</td><td>$30.78</td></tr><tr><td>Granted</td><td>472,900</td><td>22.78</td></tr><tr><td>Forfeited</td><td>-174,720</td><td>29.06</td></tr><tr><td>Vested</td><td>-473,110</td><td>37.05</td></tr><tr><td> Non-vested at December 31, 2010</td><td>1,439,839</td><td>26.30</td></tr></table>
<table><tr><td> </td><td>Units</td><td> Weighted Average Grant-Date Fair Value per Unit</td></tr><tr><td> </td><td colspan="2"> (In whole) </td></tr><tr><td>Outstanding at December 31, 2009</td><td>304,049</td><td>$19.34</td></tr><tr><td>Granted</td><td>59,067</td><td>22.18</td></tr><tr><td>Conversions</td><td>-28,395</td><td>21.77</td></tr><tr><td> Outstanding at December 31, 2010</td><td>334,721</td><td>19.63</td></tr></table>
<table><tr><td></td><td colspan="9">Global Generation Portfolio<sup>(a)</sup> (In MW)</td></tr><tr><td></td><td colspan="3">NRG Business</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Generation Type</td><td>Gulf Coast</td><td>East</td><td>West</td><td>NRG Home Solar</td><td>NRG Renew</td><td>NRG Yield<sup>(b)</sup></td><td>Total Domestic</td><td>Other (Inter-national)</td><td>Total Global</td></tr><tr><td>Natural gas</td><td>8,547</td><td>7,744</td><td>7,617</td><td>—</td><td>—</td><td>1,393</td><td>25,301</td><td>144</td><td>25,445</td></tr><tr><td>Coal</td><td>5,689</td><td>11,045</td><td>—</td><td>—</td><td>—</td><td>—</td><td>16,734</td><td>605</td><td>17,339</td></tr><tr><td>Oil</td><td>—</td><td>5,818</td><td>—</td><td>—</td><td>—</td><td>190</td><td>6,008</td><td>—</td><td>6,008</td></tr><tr><td>Nuclear</td><td>1,176</td><td>—</td><td>—</td><td>—</td><td>—</td><td>—</td><td>1,176</td><td>—</td><td>1,176</td></tr><tr><td>Wind</td><td>—</td><td>—</td><td>—</td><td>—</td><td>1,964</td><td>1,048</td><td>3,012</td><td>—</td><td>3,012</td></tr><tr><td>Utility Scale Solar</td><td>—</td><td>—</td><td>—</td><td>—</td><td>807</td><td>343</td><td>1,150</td><td>—</td><td>1,150</td></tr><tr><td>Distributed Solar</td><td>—</td><td>—</td><td>—</td><td>50</td><td>37</td><td>10</td><td>97</td><td>—</td><td>97</td></tr><tr><td>Total generation capacity</td><td>15,412</td><td>24,607</td><td>7,617</td><td>50</td><td>2,808</td><td>2,984</td><td>53,478</td><td>749</td><td>54,227</td></tr><tr><td>Capacity attributable to noncontrolling interest</td><td>—</td><td>—</td><td>—</td><td>—</td><td>-630</td><td>-1,334</td><td>-1,964</td><td>—</td><td>-1,964</td></tr><tr><td>Total net generation capacity</td><td>15,412</td><td>24,607</td><td>7,617</td><td>50</td><td>2,178</td><td>1,650</td><td>51,514</td><td>749</td><td>52,263</td></tr></table>

Question: Which Gulf Coast makes up more than10 % of the total for generation capacity for East?