ANALOG DEVICES, INC.  NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
## Table 0 ##
The valuation allowances of $67.1 million and $52.7 million at October 29, 2016 and October 31, 2015, respectively, are valuation allowances primarily for the Company’s state credit carryover.
The Company believes that it is more-likely-than-not that these credit carryovers will not be realized and as a result has recorded a full valuation allowance as of October 29, 2016.
The state credit carryover of $67.9 million will begin to expire in 2016.
As of October 29, 2016, the Company has foreign tax credit carryforwards of $0.7 million to offset future passive income.
If not used, these carryforwards will expire between 2019 and 2023.
The Company has provided for potential tax liabilities due in the various jurisdictions in which the Company operates.
Judgment is required in determining the worldwide income tax expense provision.
In the ordinary course of global business, there are many transactions and calculations where the ultimate tax outcome is uncertain.
Some of these uncertainties arise as a consequence of cost reimbursement arrangements among related entities.
Although the Company believes its estimates are reasonable, no assurance can be given that the final tax outcome of these matters will not be different than that which is reflected in the historical income tax provisions and accruals.
Such differences could have a material impact on the Company’s income tax provision and operating results in the period in which such determination is made.
As of October 29, 2016 and October 31, 2015, the Company had a liability of $75.6 million and $75.3 million, respectively, for unrealized tax benefits, all of which, if settled in the Company’s favor, would lower the Company’s effective tax rate in the period recorded.
As of October 29, 2016 and October 31, 2015, the Company had a liability of approximately $20.1 million and $16.1 million, respectively, for interest and penalties.
The Company includes interest and penalties related to unrecognized tax benefits within the provision for taxes in the consolidated statements of income.
The total liability as of October 29, 2016 and October 31, 2015 of $81.7 million and $81.0 million, respectively, for uncertain tax positions is classified as non-current, and is included in other non-current liabilities, because the Company believes that the ultimate payment or settlement of these liabilities may not occur within the next twelve months.
The consolidated statements of income for fiscal year 2016, fiscal 2015 and fiscal 2014 include $4.0 million, $4.1 million and $1.9 million, respectively, of interest and penalties related to these uncertain tax positions.
Over the next fiscal year, the Company anticipates the liability to be reduced by $1.6 million for the possible expiration of an income tax statute of limitations.
4.
SECURITIZATIONS We use a securitization program to fund substantially all of the auto loan receivables originated by CAF.
We sell the auto loan receivables to a wholly owned, bankruptcy-remote, special purpose entity that transfers an undivided interest in the receivables to a group of third-party investors.
The special purpose entity and investors have no recourse to our assets.
Our risk is limited to the retained interest.
The investors issue commercial paper supported by the transferred receivables, and the proceeds from the sale of the commercial paper are used to pay for the securitized receivables.
This program is referred to as the warehouse facility.
The return requirements of investors in asset-backed commercial paper may fluctuate significantly depending on market conditions.
These fluctuations may have a significant impact on our funding costs.
We routinely use public securitizations to refinance the receivables previously securitized through the warehouse facility.
In a public securitization, a pool of auto loan receivables is sold to a bankruptcy-remote, special purpose entity that in turn transfers the receivables to a special purpose securitization trust.
The securitization trust issues asset-backed securities, secured or otherwise supported by the transferred receivables, and the proceeds from the sale of the securities are used to pay for the securitized receivables.
Depending on the securitization structure and market conditions, refinancing receivables in a public securitization could have a significant impact on our results of operations.
The impact of refinancing activity will depend upon the particular securitization structures and market conditions at the refinancing date.
All transfers of receivables are accounted for as sales.
When the receivables are securitized, we recognize a gain or loss on the sale of the receivables as described in Note 3.
## Table 1 ##
(1) Includes the effects of valuation adjustments, new public securitizations and the repurchase and resale of receivables in existing public securitizations, as applicable.
Retained Interest We retain an interest in the auto loan receivables that we securitize.
The retained interest includes the present value of the expected residual cash flows generated by the securitized receivables, or “interest-only strip receivables,” various reserve accounts, required excess receivables and retained subordinated bonds, as described below.
On a combined basis, the reserve accounts and required excess receivables are generally 2% to 4% of managed receivables.
The interest-only strip receivables, reserve accounts and required excess receivables serve as a credit enhancement for the benefit of the investors in the securitized receivables.
The special purpose entities and the investors have no recourse to our assets.
The fair value of the retained interest was $270.8 million as of February 29, 2008, and $202.3 million as of February 28, 2007.
The retained interest had a weighted average life of 1.5 years as of February 29, 2008, and February 28, 2007.
The weighted average life in periods (for example, months or years) of prepayable assets is calculated by multiplying the principal collections expected in each future period by the number of periods until that future period, summing those products and dividing the sum by the initial principal balance.
Interest-only strip receivables.
Interest-only strip receivables represent the present value of residual cash flows we expect to receive over the life of the securitized receivables.
The value of these receivables is determined by estimating the future cash flows using our assumptions of key factors, such as finance charge income, loss rates, prepayment rates, funding costs and discount rates appropriate for the type of asset and risk.
The value of interestonly strip receivables may be affected by external factors, such as changes in the behavior patterns of customers, changes in the strength of the economy and developments in the interest rate markets; therefore, actual performance may differ from these assumptions.
We evaluate the performance of the receivables relative to these assumptions on a regular basis.
Any financial impact resulting from a change in performance is recognized in earnings in the period in which it occurs.
The following table summarizes NRG's U. S.  coal capacity and the corresponding revenues and average natural gas prices and positions resulting from coal hedge agreements extending beyond December 31, 2016 and through 2020 for the East region:
## Table 2 ##
(a) Net coal capacity represents nominal summer net MW capacity of power generated as adjusted for the Company's ownership position excluding capacity from inactive/mothballed units, see Item 2 - Properties for units scheduled to be deactivated.
(b) Forecasted generation dispatch output (MWh) based on forward price curves as of December 31, 2016, which is then divided by number of hours in a given year to arrive at MW capacity.
The dispatch takes into account planned and unplanned outage assumptions.
(c) Includes amounts under power sales contracts and natural gas hedges.
The forward natural gas quantities are reflected in equivalent GWh based on forward market implied heat rate as of December 31, 2016, and then combined with power sales to arrive at equivalent GWh hedged.
The coal sales include swaps and delta of options sold which is subject to change.
For detailed information on the Company's hedging methodology through use of derivative instruments, see discussion in Item 15 - Note 5, Accounting for Derivative Instruments and Hedging Activities, to the Consolidated Financial Statements.
Includes inter-segment sales from the Company's wholesale power generation business to the retail business.
(d) Percentage hedged is based on total coal sales as described in (c) above divided by the forecasted coal capacity.
(e) Represents U. S.  coal sales, including energy revenue and demand charges, excluding revenues derived from capacity auctions.
Capacity and Other Contracted Revenue Sources NRG's revenues and cash flows benefit from capacity/demand payments and other contracted revenue sources, originating from market clearing capacity prices, Resource Adequacy contracts, tolling arrangements, PPAs and other long-term contractual arrangements: ?
Capacity auctions — The Company's largest sources of capacity revenues are capacity auctions in PJM, ISO-NE, and NYISO.
Both ISO-NE and PJM operate a pay-for-performance model where capacity payments are modified based on real-time performance, where NRG's actual revenues will be the combination of revenues based on the cleared auction MWs plus the net of any over- and under-performance of NRG's fleet.
In addition, MISO has an annual auction, known as the Planning Resource Auction, or PRA.
The Gulf Coast assets situated in the MISO market may participate in this auction.
Recent changes have made the decision to import external capacity into the PJM market more complicated, and the Company is evaluating the feasibility of continuing to import.  ?
Resource Adequacy and bilateral contracts — In California, there is a resource adequacy requirement that is satisfied through bilateral contracts.
The Company's newer generation in California is contracted under long-term tolling agreements.
Certain other sites in California have short-term tolling agreements or resource adequacy contracts.
In addition, NRG earns demand payments from its long-term full-requirements load contracts with nine Louisiana distribution cooperatives, which expire in 2025.
NRG also had full requirements contracts in PJM in 2016.
Demand payments from the current long-term contracts are tied to summer peak demand and provide a mechanism for recovering a portion of the costs associated with new or changed environmental laws or regulations.
In Texas, capacity and contracted revenues are through bilateral contracts with load serving entities.  ?
Long-term PPAs — Output from the majority of renewable energy assets and certain conventional energy plants is sold through long-term PPAs and tolling agreements to a single counterparty, which is often a utility or commercial customer.

Tables referenced above, in order (Table 0 first):
<table><tr><td></td><td>2016</td><td>2015</td></tr><tr><td>Deferred tax assets:</td><td></td><td></td></tr><tr><td>Inventory reserves</td><td>$22,527</td><td>$24,009</td></tr><tr><td>Deferred income on shipments to distributors</td><td>49,455</td><td>40,842</td></tr><tr><td>Reserves for compensation and benefits</td><td>48,062</td><td>45,515</td></tr><tr><td>Tax credit carryovers</td><td>68,669</td><td>64,838</td></tr><tr><td>Stock-based compensation</td><td>56,345</td><td>68,530</td></tr><tr><td>Depreciation</td><td>3,078</td><td>1,840</td></tr><tr><td>Acquisition-related costs</td><td>19,312</td><td>6,327</td></tr><tr><td>Other</td><td>47,482</td><td>36,711</td></tr><tr><td>Total gross deferred tax assets</td><td>314,930</td><td>288,612</td></tr><tr><td>Valuation allowance</td><td>-67,094</td><td>-52,675</td></tr><tr><td>Total deferred tax assets</td><td>247,836</td><td>235,937</td></tr><tr><td>Deferred tax liabilities:</td><td></td><td></td></tr><tr><td>Depreciation</td><td>-59,218</td><td>-50,389</td></tr><tr><td>Undistributed earnings of foreign subsidiaries</td><td>-60,986</td><td>-29,471</td></tr><tr><td>Acquisition-related intangibles</td><td>-199,035</td><td>-217,961</td></tr><tr><td>Other</td><td>-2,523</td><td>-2,971</td></tr><tr><td>Total gross deferred tax liabilities</td><td>-321,762</td><td>-300,792</td></tr><tr><td>Net deferred tax liabilities</td><td>$-73,926</td><td>$-64,855</td></tr></table>
<table><tr><td></td><td colspan="3">Years Ended February 29 or 28</td></tr><tr><td>(In millions)</td><td>2008</td><td>2007</td><td>2006</td></tr><tr><td>Net loans originated</td><td>$2,429.7</td><td>$2,242.3</td><td>$1,774.6</td></tr><tr><td>Total loans sold</td><td>$2,534.4</td><td>$2,322.7</td><td>$1,887.5</td></tr><tr><td>Total gain income-1</td><td>$48.5</td><td>$99.7</td><td>$77.1</td></tr><tr><td>Total gain income as a percentage of total loans sold-1</td><td>1.9%</td><td>4.3%</td><td>4.1%</td></tr></table>
<table><tr><td>East</td><td>2017</td><td>2018</td><td>2019</td><td>2020</td><td>AnnualAverage for2017-2020</td></tr><tr><td></td><td colspan="5">(Dollars in millions unless otherwise stated)</td></tr><tr><td>Net Coal Capacity (MW)<sup>(a)</sup></td><td>7,465</td><td>7,465</td><td>7,465</td><td>7,167</td><td>7,391</td></tr><tr><td>Forecasted Coal Capacity (MW)<sup>(b)</sup></td><td>3,688</td><td>3,200</td><td>2,483</td><td>2,141</td><td>2,878</td></tr><tr><td>Total Coal Sales (GWh)<sup>(c)</sup></td><td>31,905</td><td>5,265</td><td>455</td><td>81</td><td>9,427</td></tr><tr><td>Percentage Coal Capacity Sold Forward<sup>(d)</sup></td><td>99%</td><td>19%</td><td>2%</td><td>—%</td><td>30%</td></tr><tr><td>Total Forward Hedged Revenues<sup>(e)</sup></td><td>$1,162</td><td>$175</td><td>$16</td><td>$2</td><td>$—</td></tr><tr><td>Weighted Average Hedged Price ($ per MWh)<sup>(e)</sup></td><td>$36.41</td><td>$33.27</td><td>$—</td><td>$—</td><td>$—</td></tr><tr><td>Average Equivalent Natural Gas Price ($ per MMBtu)<sup>(e)</sup></td><td>$3.69</td><td>$3.29</td><td>$—</td><td>$—</td><td>$—</td></tr><tr><td>Gross Margin Sensitivities</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Gas Price Sensitivity Up $0.50/MMBtu on Coal Units</td><td>$64</td><td>$206</td><td>$230</td><td>$215</td><td>$—</td></tr><tr><td>Gas Price Sensitivity Down $0.50/MMBtu on Coal Units</td><td>$-35</td><td>$-162</td><td>$-159</td><td>$-140</td><td>$—</td></tr><tr><td>Heat Rate Sensitivity Up 1 MMBtu/MWh on Coal Units</td><td>$64</td><td>$119</td><td>$121</td><td>$110</td><td>$—</td></tr><tr><td>Heat Rate Sensitivity Down 1 MMBtu/MWh on Coal Units</td><td>$-35</td><td>$-99</td><td>$-95</td><td>$-86</td><td>$—</td></tr></table>

Question: What is the percentage of all Gross Margin Sensitivities that are positive to the total amount, in 2019?
Answer: 3.61856
Reasoning program: add(230,121), add(230,121), subtract(#1,159), subtract(#2,95), divide(#0,#3)