inventories valued under the lifo method comprised $ 1.57 billion and $ 1.56 billion of total inventories at december 31 , 2018 and 2017 , respectively .

note 7 : financial instruments financial instruments that potentially subject us to credit risk consist principally of trade receivables and interest- bearing investments .

wholesale distributors of life-science products account for a substantial portion of our trade receivables ; collateral is generally not required .

we seek to mitigate the risk associated with this concentration through our ongoing credit-review procedures and insurance .

a large portion of our cash is held by a few major financial institutions .

we monitor our exposures with these institutions and do not expect any of these institutions to fail to meet their obligations .

major financial institutions represent the largest component of our investments in corporate debt securities .

in accordance with documented corporate risk-management policies , we monitor the amount of credit exposure to any one financial institution or corporate issuer .

we are exposed to credit-related losses in the event of nonperformance by counterparties to risk-management instruments but do not expect any counterparties to fail to meet their obligations given their high credit ratings .

we consider all highly liquid investments with a maturity of three months or less from the date of purchase to be cash equivalents .

the cost of these investments approximates fair value .

our equity investments are accounted for using three different methods depending on the type of equity investment : 2022 investments in companies over which we have significant influence but not a controlling interest are accounted for using the equity method , with our share of earnings or losses reported in other-net , ( income ) expense .

2022 for equity investments that do not have readily determinable fair values , we measure these investments at cost , less any impairment , plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investment of the same issuer .

any change in recorded value is recorded in other-net , ( income ) expense .

2022 our public equity investments are measured and carried at fair value .

any change in fair value is recognized in other-net , ( income ) expense .

we review equity investments other than public equity investments for indications of impairment on a regular basis .

our derivative activities are initiated within the guidelines of documented corporate risk-management policies and are intended to offset losses and gains on the assets , liabilities , and transactions being hedged .

management reviews the correlation and effectiveness of our derivatives on a quarterly basis. .

what was the total in raw materials and supplies in 2018?

Question: and what was it in 2017?

Answer: 488.8


note 6 : inventories we use the last-in , first-out ( lifo ) method for the majority of our inventories located in the continental u.s .

other inventories are valued by the first-in , first-out ( fifo ) method .

fifo cost approximates current replacement cost .

inventories measured using lifo must be valued at the lower of cost or market .

inventories measured using fifo must be valued at the lower of cost or net realizable value .

inventories at december 31 consisted of the following: .

inventories valued under the lifo method comprised $ 1.57 billion and $ 1.56 billion of total inventories at december 31 , 2018 and 2017 , respectively .

note 7 : financial instruments financial instruments that potentially subject us to credit risk consist principally of trade receivables and interest- bearing investments .

wholesale distributors of life-science products account for a substantial portion of our trade receivables ; collateral is generally not required .

we seek to mitigate the risk associated with this concentration through our ongoing credit-review procedures and insurance .

a large portion of our cash is held by a few major financial institutions .

we monitor our exposures with these institutions and do not expect any of these institutions to fail to meet their obligations .

major financial institutions represent the largest component of our investments in corporate debt securities .

in accordance with documented corporate risk-management policies , we monitor the amount of credit exposure to any one financial institution or corporate issuer .

we are exposed to credit-related losses in the event of nonperformance by counterparties to risk-management instruments but do not expect any counterparties to fail to meet their obligations given their high credit ratings .

we consider all highly liquid investments with a maturity of three months or less from the date of purchase to be cash equivalents .

the cost of these investments approximates fair value .

our equity investments are accounted for using three different methods depending on the type of equity investment : 2022 investments in companies over which we have significant influence but not a controlling interest are accounted for using the equity method , with our share of earnings or losses reported in other-net , ( income ) expense .

2022 for equity investments that do not have readily determinable fair values , we measure these investments at cost , less any impairment , plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investment of the same issuer .

any change in recorded value is recorded in other-net , ( income ) expense .

2022 our public equity investments are measured and carried at fair value .

any change in fair value is recognized in other-net , ( income ) expense .

we review equity investments other than public equity investments for indications of impairment on a regular basis .

our derivative activities are initiated within the guidelines of documented corporate risk-management policies and are intended to offset losses and gains on the assets , liabilities , and transactions being hedged .

management reviews the correlation and effectiveness of our derivatives on a quarterly basis. .

1		2018	2017

2	finished products	$ 988.1	$ 1211.4

3	work in process	2628.2	2697.7

4	raw materials and supplies	506.5	488.8

5	total ( approximates replacement cost )	4122.8	4397.9

6	increase ( reduction ) to lifo cost	-11.0 ( 11.0 )	60.4

7	inventories	$ 4111.8	$ 4458.3

Question: what was, then, the change over the year?

Answer: 17.7


inventories valued under the lifo method comprised $ 1.57 billion and $ 1.56 billion of total inventories at december 31 , 2018 and 2017 , respectively .

note 7 : financial instruments financial instruments that potentially subject us to credit risk consist principally of trade receivables and interest- bearing investments .

wholesale distributors of life-science products account for a substantial portion of our trade receivables ; collateral is generally not required .

we seek to mitigate the risk associated with this concentration through our ongoing credit-review procedures and insurance .

a large portion of our cash is held by a few major financial institutions .

we monitor our exposures with these institutions and do not expect any of these institutions to fail to meet their obligations .

major financial institutions represent the largest component of our investments in corporate debt securities .

in accordance with documented corporate risk-management policies , we monitor the amount of credit exposure to any one financial institution or corporate issuer .

we are exposed to credit-related losses in the event of nonperformance by counterparties to risk-management instruments but do not expect any counterparties to fail to meet their obligations given their high credit ratings .

we consider all highly liquid investments with a maturity of three months or less from the date of purchase to be cash equivalents .

the cost of these investments approximates fair value .

our equity investments are accounted for using three different methods depending on the type of equity investment : 2022 investments in companies over which we have significant influence but not a controlling interest are accounted for using the equity method , with our share of earnings or losses reported in other-net , ( income ) expense .

2022 for equity investments that do not have readily determinable fair values , we measure these investments at cost , less any impairment , plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investment of the same issuer .

any change in recorded value is recorded in other-net , ( income ) expense .

2022 our public equity investments are measured and carried at fair value .

any change in fair value is recognized in other-net , ( income ) expense .

we review equity investments other than public equity investments for indications of impairment on a regular basis .

our derivative activities are initiated within the guidelines of documented corporate risk-management policies and are intended to offset losses and gains on the assets , liabilities , and transactions being hedged .

management reviews the correlation and effectiveness of our derivatives on a quarterly basis. .

what was, then, the change over the year?

Question: what was the total in raw materials and supplies in 2017?

Answer: 488.8


inventories valued under the lifo method comprised $ 1.57 billion and $ 1.56 billion of total inventories at december 31 , 2018 and 2017 , respectively .

note 7 : financial instruments financial instruments that potentially subject us to credit risk consist principally of trade receivables and interest- bearing investments .

wholesale distributors of life-science products account for a substantial portion of our trade receivables ; collateral is generally not required .

we seek to mitigate the risk associated with this concentration through our ongoing credit-review procedures and insurance .

a large portion of our cash is held by a few major financial institutions .

we monitor our exposures with these institutions and do not expect any of these institutions to fail to meet their obligations .

major financial institutions represent the largest component of our investments in corporate debt securities .

in accordance with documented corporate risk-management policies , we monitor the amount of credit exposure to any one financial institution or corporate issuer .

we are exposed to credit-related losses in the event of nonperformance by counterparties to risk-management instruments but do not expect any counterparties to fail to meet their obligations given their high credit ratings .

we consider all highly liquid investments with a maturity of three months or less from the date of purchase to be cash equivalents .

the cost of these investments approximates fair value .

our equity investments are accounted for using three different methods depending on the type of equity investment : 2022 investments in companies over which we have significant influence but not a controlling interest are accounted for using the equity method , with our share of earnings or losses reported in other-net , ( income ) expense .

2022 for equity investments that do not have readily determinable fair values , we measure these investments at cost , less any impairment , plus or minus changes resulting from observable price changes in orderly transactions for the identical or similar investment of the same issuer .

any change in recorded value is recorded in other-net , ( income ) expense .

2022 our public equity investments are measured and carried at fair value .

any change in fair value is recognized in other-net , ( income ) expense .

we review equity investments other than public equity investments for indications of impairment on a regular basis .

our derivative activities are initiated within the guidelines of documented corporate risk-management policies and are intended to offset losses and gains on the assets , liabilities , and transactions being hedged .

management reviews the correlation and effectiveness of our derivatives on a quarterly basis. .

what was the total in raw materials and supplies in 2017?

Question: and how much does that change represent in relation to this 2017 total, in percentage?

Answer: 0.03621


/ 2007 annual report 31 the following section provides a comparative discussion of jpmorgan chase 2019s consolidated results of operations on a reported basis for the three-year period ended december 31 , 2007 .

factors that relate primarily to a single business segment are discussed in more detail within that business segment than they are in this consolidated sec- tion .

for a discussion of the critical accounting estimates used by the firm that affect the consolidated results of operations , see pages 96 201398 of this annual report .

2007 compared with 2006 total net revenue of $ 71.4 billion was up $ 9.4 billion , or 15% ( 15 % ) , from the prior year .

higher net interest income , very strong private equity gains , record asset management , administration and commissions revenue , higher mortgage fees and related income and record investment banking fees contributed to the revenue growth .

these increases were offset partially by lower trading revenue .

investment banking fees grew in 2007 to a level higher than the pre- vious record set in 2006 .

record advisory and equity underwriting fees drove the results , partially offset by lower debt underwriting fees .

for a further discussion of investment banking fees , which are primarily recorded in ib , see the ib segment results on pages 40 201342 of this annual report .

principal transactions revenue consists of trading revenue and private equity gains .

trading revenue declined significantly from the 2006 level , primarily due to markdowns in ib of $ 1.4 billion ( net of hedges ) on subprime positions , including subprime cdos , and $ 1.3 billion ( net of fees ) on leveraged lending funded loans and unfunded commitments .

also in ib , markdowns in securitized products on nonsubprime mortgages and weak credit trading performance more than offset record revenue in currencies and strong revenue in both rates and equities .

equities benefited from strong client activity and record trading results across all products .

ib 2019s credit portfolio results increased compared with the prior year , primarily driven by higher revenue from risk management activities .

the increase in private equity gains from 2006 reflected a significantly higher level of gains , the classification of certain private equity carried interest as compensation expense and a fair value adjustment in the first quarter of 2007 on nonpublic private equity investments resulting from the adoption of sfas 157 ( 201cfair value measurements 201d ) .

for a further discussion of principal transactions revenue , see the ib and corporate segment results on pages 40 201342 and 59 201360 , respectively , and note 6 on page 122 of this annual report .

lending & deposit-related fees rose from the 2006 level , driven pri- marily by higher deposit-related fees and the bank of new york transaction .

for a further discussion of lending & deposit-related fees , which are mostly recorded in rfs , tss and cb , see the rfs segment results on pages 43 201348 , the tss segment results on pages 54 201355 , and the cb segment results on pages 52 201353 of this annual report .

asset management , administration and commissions revenue reached a level higher than the previous record set in 2006 .

increased assets under management and higher performance and placement fees in am drove the record results .

the 18% ( 18 % ) growth in assets under management from year-end 2006 came from net asset inflows and market appreciation across all segments : institutional , retail , private bank and private client services .

tss also contributed to the rise in asset management , administration and commissions revenue , driven by increased product usage by new and existing clients and market appreciation on assets under custody .

finally , commissions revenue increased , due mainly to higher brokerage transaction volume ( primarily included within fixed income and equity markets revenue of ib ) , which more than offset the sale of the insurance business by rfs in the third quarter of 2006 and a charge in the first quarter of 2007 resulting from accelerated surrenders of customer annuities .

for additional information on these fees and commissions , see the segment discussions for ib on pages 40 201342 , rfs on pages 43 201348 , tss on pages 54 201355 , and am on pages 56 201358 , of this annual report .

the favorable variance resulting from securities gains in 2007 compared with securities losses in 2006 was primarily driven by improvements in the results of repositioning of the treasury invest- ment securities portfolio .

also contributing to the positive variance was a $ 234 million gain from the sale of mastercard shares .

for a fur- ther discussion of securities gains ( losses ) , which are mostly recorded in the firm 2019s treasury business , see the corporate segment discussion on pages 59 201360 of this annual report .

1	year ended december 31 ( in millions )	2007	2006	2005

2	investment banking fees	$ 6635	$ 5520	$ 4088

3	principal transactions	9015	10778	8072

4	lending & deposit-related fees	3938	3468	3389

5	asset management administration and commissions	14356	11855	9988

6	securities gains ( losses )	164	-543 ( 543 )	-1336 ( 1336 )

7	mortgage fees and related income	2118	591	1054

8	credit card income	6911	6913	6754

9	other income	1829	2175	2684

10	noninterest revenue	44966	40757	34693

11	net interest income	26406	21242	19555

12	total net revenue	$ 71372	$ 61999	$ 54248

Question: what were investment banking fees in 2007?

Answer: 6635.0


2007 compared with 2006 total net revenue of $ 71.4 billion was up $ 9.4 billion , or 15% ( 15 % ) , from the prior year .

higher net interest income , very strong private equity gains , record asset management , administration and commissions revenue , higher mortgage fees and related income and record investment banking fees contributed to the revenue growth .

these increases were offset partially by lower trading revenue .

investment banking fees grew in 2007 to a level higher than the pre- vious record set in 2006 .

record advisory and equity underwriting fees drove the results , partially offset by lower debt underwriting fees .

for a further discussion of investment banking fees , which are primarily recorded in ib , see the ib segment results on pages 40 201342 of this annual report .

principal transactions revenue consists of trading revenue and private equity gains .

trading revenue declined significantly from the 2006 level , primarily due to markdowns in ib of $ 1.4 billion ( net of hedges ) on subprime positions , including subprime cdos , and $ 1.3 billion ( net of fees ) on leveraged lending funded loans and unfunded commitments .

also in ib , markdowns in securitized products on nonsubprime mortgages and weak credit trading performance more than offset record revenue in currencies and strong revenue in both rates and equities .

equities benefited from strong client activity and record trading results across all products .

ib 2019s credit portfolio results increased compared with the prior year , primarily driven by higher revenue from risk management activities .

the increase in private equity gains from 2006 reflected a significantly higher level of gains , the classification of certain private equity carried interest as compensation expense and a fair value adjustment in the first quarter of 2007 on nonpublic private equity investments resulting from the adoption of sfas 157 ( 201cfair value measurements 201d ) .

for a further discussion of principal transactions revenue , see the ib and corporate segment results on pages 40 201342 and 59 201360 , respectively , and note 6 on page 122 of this annual report .

lending & deposit-related fees rose from the 2006 level , driven pri- marily by higher deposit-related fees and the bank of new york transaction .

for a further discussion of lending & deposit-related fees , which are mostly recorded in rfs , tss and cb , see the rfs segment results on pages 43 201348 , the tss segment results on pages 54 201355 , and the cb segment results on pages 52 201353 of this annual report .

asset management , administration and commissions revenue reached a level higher than the previous record set in 2006 .

increased assets under management and higher performance and placement fees in am drove the record results .

the 18% ( 18 % ) growth in assets under management from year-end 2006 came from net asset inflows and market appreciation across all segments : institutional , retail , private bank and private client services .

tss also contributed to the rise in asset management , administration and commissions revenue , driven by increased product usage by new and existing clients and market appreciation on assets under custody .

finally , commissions revenue increased , due mainly to higher brokerage transaction volume ( primarily included within fixed income and equity markets revenue of ib ) , which more than offset the sale of the insurance business by rfs in the third quarter of 2006 and a charge in the first quarter of 2007 resulting from accelerated surrenders of customer annuities .

for additional information on these fees and commissions , see the segment discussions for ib on pages 40 201342 , rfs on pages 43 201348 , tss on pages 54 201355 , and am on pages 56 201358 , of this annual report .

the favorable variance resulting from securities gains in 2007 compared with securities losses in 2006 was primarily driven by improvements in the results of repositioning of the treasury invest- ment securities portfolio .

also contributing to the positive variance was a $ 234 million gain from the sale of mastercard shares .

for a fur- ther discussion of securities gains ( losses ) , which are mostly recorded in the firm 2019s treasury business , see the corporate segment discussion on pages 59 201360 of this annual report .

what were investment banking fees in 2007?

Question: what were they in 2006?

Answer: 5520.0


2007 compared with 2006 total net revenue of $ 71.4 billion was up $ 9.4 billion , or 15% ( 15 % ) , from the prior year .

higher net interest income , very strong private equity gains , record asset management , administration and commissions revenue , higher mortgage fees and related income and record investment banking fees contributed to the revenue growth .

these increases were offset partially by lower trading revenue .

investment banking fees grew in 2007 to a level higher than the pre- vious record set in 2006 .

record advisory and equity underwriting fees drove the results , partially offset by lower debt underwriting fees .

for a further discussion of investment banking fees , which are primarily recorded in ib , see the ib segment results on pages 40 201342 of this annual report .

principal transactions revenue consists of trading revenue and private equity gains .

trading revenue declined significantly from the 2006 level , primarily due to markdowns in ib of $ 1.4 billion ( net of hedges ) on subprime positions , including subprime cdos , and $ 1.3 billion ( net of fees ) on leveraged lending funded loans and unfunded commitments .

also in ib , markdowns in securitized products on nonsubprime mortgages and weak credit trading performance more than offset record revenue in currencies and strong revenue in both rates and equities .

equities benefited from strong client activity and record trading results across all products .

ib 2019s credit portfolio results increased compared with the prior year , primarily driven by higher revenue from risk management activities .

the increase in private equity gains from 2006 reflected a significantly higher level of gains , the classification of certain private equity carried interest as compensation expense and a fair value adjustment in the first quarter of 2007 on nonpublic private equity investments resulting from the adoption of sfas 157 ( 201cfair value measurements 201d ) .

for a further discussion of principal transactions revenue , see the ib and corporate segment results on pages 40 201342 and 59 201360 , respectively , and note 6 on page 122 of this annual report .

lending & deposit-related fees rose from the 2006 level , driven pri- marily by higher deposit-related fees and the bank of new york transaction .

for a further discussion of lending & deposit-related fees , which are mostly recorded in rfs , tss and cb , see the rfs segment results on pages 43 201348 , the tss segment results on pages 54 201355 , and the cb segment results on pages 52 201353 of this annual report .

asset management , administration and commissions revenue reached a level higher than the previous record set in 2006 .

increased assets under management and higher performance and placement fees in am drove the record results .

the 18% ( 18 % ) growth in assets under management from year-end 2006 came from net asset inflows and market appreciation across all segments : institutional , retail , private bank and private client services .

tss also contributed to the rise in asset management , administration and commissions revenue , driven by increased product usage by new and existing clients and market appreciation on assets under custody .

finally , commissions revenue increased , due mainly to higher brokerage transaction volume ( primarily included within fixed income and equity markets revenue of ib ) , which more than offset the sale of the insurance business by rfs in the third quarter of 2006 and a charge in the first quarter of 2007 resulting from accelerated surrenders of customer annuities .

for additional information on these fees and commissions , see the segment discussions for ib on pages 40 201342 , rfs on pages 43 201348 , tss on pages 54 201355 , and am on pages 56 201358 , of this annual report .

the favorable variance resulting from securities gains in 2007 compared with securities losses in 2006 was primarily driven by improvements in the results of repositioning of the treasury invest- ment securities portfolio .

also contributing to the positive variance was a $ 234 million gain from the sale of mastercard shares .

for a fur- ther discussion of securities gains ( losses ) , which are mostly recorded in the firm 2019s treasury business , see the corporate segment discussion on pages 59 201360 of this annual report .

Question: what is the difference of the 2007 value less that in 2006?

Answer: 1115.0


2007 compared with 2006 total net revenue of $ 71.4 billion was up $ 9.4 billion , or 15% ( 15 % ) , from the prior year .

higher net interest income , very strong private equity gains , record asset management , administration and commissions revenue , higher mortgage fees and related income and record investment banking fees contributed to the revenue growth .

these increases were offset partially by lower trading revenue .

investment banking fees grew in 2007 to a level higher than the pre- vious record set in 2006 .

record advisory and equity underwriting fees drove the results , partially offset by lower debt underwriting fees .

for a further discussion of investment banking fees , which are primarily recorded in ib , see the ib segment results on pages 40 201342 of this annual report .

principal transactions revenue consists of trading revenue and private equity gains .

trading revenue declined significantly from the 2006 level , primarily due to markdowns in ib of $ 1.4 billion ( net of hedges ) on subprime positions , including subprime cdos , and $ 1.3 billion ( net of fees ) on leveraged lending funded loans and unfunded commitments .

also in ib , markdowns in securitized products on nonsubprime mortgages and weak credit trading performance more than offset record revenue in currencies and strong revenue in both rates and equities .

equities benefited from strong client activity and record trading results across all products .

ib 2019s credit portfolio results increased compared with the prior year , primarily driven by higher revenue from risk management activities .

the increase in private equity gains from 2006 reflected a significantly higher level of gains , the classification of certain private equity carried interest as compensation expense and a fair value adjustment in the first quarter of 2007 on nonpublic private equity investments resulting from the adoption of sfas 157 ( 201cfair value measurements 201d ) .

for a further discussion of principal transactions revenue , see the ib and corporate segment results on pages 40 201342 and 59 201360 , respectively , and note 6 on page 122 of this annual report .

lending & deposit-related fees rose from the 2006 level , driven pri- marily by higher deposit-related fees and the bank of new york transaction .

for a further discussion of lending & deposit-related fees , which are mostly recorded in rfs , tss and cb , see the rfs segment results on pages 43 201348 , the tss segment results on pages 54 201355 , and the cb segment results on pages 52 201353 of this annual report .

asset management , administration and commissions revenue reached a level higher than the previous record set in 2006 .

increased assets under management and higher performance and placement fees in am drove the record results .

the 18% ( 18 % ) growth in assets under management from year-end 2006 came from net asset inflows and market appreciation across all segments : institutional , retail , private bank and private client services .

tss also contributed to the rise in asset management , administration and commissions revenue , driven by increased product usage by new and existing clients and market appreciation on assets under custody .

finally , commissions revenue increased , due mainly to higher brokerage transaction volume ( primarily included within fixed income and equity markets revenue of ib ) , which more than offset the sale of the insurance business by rfs in the third quarter of 2006 and a charge in the first quarter of 2007 resulting from accelerated surrenders of customer annuities .

for additional information on these fees and commissions , see the segment discussions for ib on pages 40 201342 , rfs on pages 43 201348 , tss on pages 54 201355 , and am on pages 56 201358 , of this annual report .

the favorable variance resulting from securities gains in 2007 compared with securities losses in 2006 was primarily driven by improvements in the results of repositioning of the treasury invest- ment securities portfolio .

also contributing to the positive variance was a $ 234 million gain from the sale of mastercard shares .

for a fur- ther discussion of securities gains ( losses ) , which are mostly recorded in the firm 2019s treasury business , see the corporate segment discussion on pages 59 201360 of this annual report .

what is the difference of the 2007 value less that in 2006?

Question: what is the net change divided by the 2006 value?

Answer: 0.20199


and subsidiaries notes to consolidated financial statements in the tables above : 2030 the gross fair values exclude the effects of both counterparty netting and collateral netting , and therefore are not representative of the firm 2019s exposure .

2030 counterparty netting is reflected in each level to the extent that receivable and payable balances are netted within the same level and is included in counterparty netting in levels .

where the counterparty netting is across levels , the netting is included in cross-level counterparty netting .

significant unobservable inputs the table below presents the amount of level 3 assets ( liabilities ) , and ranges , averages and medians of significant unobservable inputs used to value the firm 2019s level 3 derivatives .

level 3 assets ( liabilities ) and range of significant unobservable inputs ( average/median ) as of december $ in millions 2017 2016 .

in the table above : 2030 derivative assets are shown as positive amounts and derivative liabilities are shown as negative amounts .

2030 ranges represent the significant unobservable inputs that were used in the valuation of each type of derivative .

2030 averages represent the arithmetic average of the inputs and are not weighted by the relative fair value or notional of the respective financial instruments .

an average greater than the median indicates that the majority of inputs are below the average .

for example , the difference between the average and the median for credit spreads and oil spread inputs indicates that the majority of the inputs fall in the lower end of the range .

2030 the ranges , averages and medians of these inputs are not representative of the appropriate inputs to use when calculating the fair value of any one derivative .

for example , the highest correlation for interest rate derivatives is appropriate for valuing a specific interest rate derivative but may not be appropriate for valuing any other interest rate derivative .

accordingly , the ranges of inputs do not represent uncertainty in , or possible ranges of , fair value measurements of the firm 2019s level 3 derivatives .

2030 interest rates , currencies and equities derivatives are valued using option pricing models , credit derivatives are valued using option pricing , correlation and discounted cash flow models , and commodities derivatives are valued using option pricing and discounted cash flow models .

2030 the fair value of any one instrument may be determined using multiple valuation techniques .

for example , option pricing models and discounted cash flows models are typically used together to determine fair value .

therefore , the level 3 balance encompasses both of these techniques .

2030 correlation within currencies and equities includes cross- product type correlation .

2030 natural gas spread represents the spread per million british thermal units of natural gas .

2030 oil spread represents the spread per barrel of oil and refined products .

range of significant unobservable inputs the following is information about the ranges of significant unobservable inputs used to value the firm 2019s level 3 derivative instruments : 2030 correlation .

ranges for correlation cover a variety of underliers both within one product type ( e.g. , equity index and equity single stock names ) and across product types ( e.g. , correlation of an interest rate and a currency ) , as well as across regions .

generally , cross-product type correlation inputs are used to value more complex instruments and are lower than correlation inputs on assets within the same derivative product type .

ranges for volatility cover numerous underliers across a variety of markets , maturities and strike prices .

for example , volatility of equity indices is generally lower than volatility of single stocks .

2030 credit spreads , upfront credit points and recovery rates .

the ranges for credit spreads , upfront credit points and recovery rates cover a variety of underliers ( index and single names ) , regions , sectors , maturities and credit qualities ( high-yield and investment-grade ) .

the broad range of this population gives rise to the width of the ranges of significant unobservable inputs .

Question: what is the net change in the value of commodities from 2016 to 2017?

Answer: -26.0


in the table above : 2030 derivative assets are shown as positive amounts and derivative liabilities are shown as negative amounts .

2030 ranges represent the significant unobservable inputs that were used in the valuation of each type of derivative .

2030 averages represent the arithmetic average of the inputs and are not weighted by the relative fair value or notional of the respective financial instruments .

an average greater than the median indicates that the majority of inputs are below the average .

for example , the difference between the average and the median for credit spreads and oil spread inputs indicates that the majority of the inputs fall in the lower end of the range .

2030 the ranges , averages and medians of these inputs are not representative of the appropriate inputs to use when calculating the fair value of any one derivative .

for example , the highest correlation for interest rate derivatives is appropriate for valuing a specific interest rate derivative but may not be appropriate for valuing any other interest rate derivative .

accordingly , the ranges of inputs do not represent uncertainty in , or possible ranges of , fair value measurements of the firm 2019s level 3 derivatives .

2030 interest rates , currencies and equities derivatives are valued using option pricing models , credit derivatives are valued using option pricing , correlation and discounted cash flow models , and commodities derivatives are valued using option pricing and discounted cash flow models .

2030 the fair value of any one instrument may be determined using multiple valuation techniques .

for example , option pricing models and discounted cash flows models are typically used together to determine fair value .

therefore , the level 3 balance encompasses both of these techniques .

2030 correlation within currencies and equities includes cross- product type correlation .

2030 natural gas spread represents the spread per million british thermal units of natural gas .

2030 oil spread represents the spread per barrel of oil and refined products .

range of significant unobservable inputs the following is information about the ranges of significant unobservable inputs used to value the firm 2019s level 3 derivative instruments : 2030 correlation .

ranges for correlation cover a variety of underliers both within one product type ( e.g. , equity index and equity single stock names ) and across product types ( e.g. , correlation of an interest rate and a currency ) , as well as across regions .

generally , cross-product type correlation inputs are used to value more complex instruments and are lower than correlation inputs on assets within the same derivative product type .

ranges for volatility cover numerous underliers across a variety of markets , maturities and strike prices .

for example , volatility of equity indices is generally lower than volatility of single stocks .

2030 credit spreads , upfront credit points and recovery rates .

the ranges for credit spreads , upfront credit points and recovery rates cover a variety of underliers ( index and single names ) , regions , sectors , maturities and credit qualities ( high-yield and investment-grade ) .

the broad range of this population gives rise to the width of the ranges of significant unobservable inputs .

what is the net change in the value of commodities from 2016 to 2017?

Question: what is the percent change?

Answer: -0.35616


market for the registrant 2019s common equity , related stockholder matters and issuer purchases of equity securities the following graph compares annual total return of our common stock , the standard & poor 2019s 500 composite stock index ( 201cs&p 500 index 201d ) and our peer group ( 201cloews peer group 201d ) for the five years ended december 31 , 2015 .

the graph assumes that the value of the investment in our common stock , the s&p 500 index and the loews peer group was $ 100 on december 31 , 2010 and that all dividends were reinvested. .

( a ) the loews peer group consists of the following companies that are industry competitors of our principal operating subsidiaries : ace limited , w.r .

berkley corporation , the chubb corporation , energy transfer partners l.p. , ensco plc , the hartford financial services group , inc. , kinder morgan energy partners , l.p .

( included through november 26 , 2014 when it was acquired by kinder morgan inc. ) , noble corporation , spectra energy corp , transocean ltd .

dividend information we have paid quarterly cash dividends on loews common stock in each year since 1967 .

regular dividends of $ 0.0625 per share of loews common stock were paid in each calendar quarter of 2015 and 2014. .

Question: what is the net change in loews common stock from 2013 to 2014?

Answer: -15.64


what is the net change in loews common stock from 2013 to 2014?

Question: what is the percent change?

Answer: -0.1239


in september 2016 the ferc accepted the february 2016 compliance filing subject to a further compliance filing made in november 2016 .

the further compliance filing was required as a result of an order issued in september 2016 ruling on the january 2016 rehearing requests filed by the lpsc , the apsc , and entergy .

in the order addressing the rehearing requests , the ferc granted the lpsc 2019s rehearing request and directed that interest be calculated on the payment/receipt amounts .

the ferc also granted the apsc 2019s and entergy 2019s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation .

in november 2016 , entergy submitted its compliance filing in response to the ferc 2019s order on rehearing .

the compliance filing included a revised refund calculation of the true-up payments and receipts based on 2009 test year data and interest calculations .

the lpsc protested the interest calculations .

in november 2017 the ferc issued an order rejecting the november 2016 compliance filing .

the ferc determined that the payments detailed in the november 2016 compliance filing did not include adequate interest for the payments from entergy arkansas to entergy louisiana because it did not include interest on the principal portion of the payment that was made in february 2016 .

in december 2017 , entergy recalculated the interest pursuant to the november 2017 order .

as a result of the recalculations , entergy arkansas owed very minor payments to entergy louisiana , entergy mississippi , and entergy new orleans .

2011 rate filing based on calendar year 2010 production costs in may 2011 , entergy filed with the ferc the 2011 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in july a02011 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a01 , a02011 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2011 rate filing with the 2012 , 2013 , and 2014 rate filings for settlement and hearing procedures .

see discussion below regarding the consolidated settlement and hearing procedures in connection with this proceeding .

2012 rate filing based on calendar year 2011 production costs in may 2012 , entergy filed with the ferc the 2012 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in august 2012 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a02012 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2012 rate filing with the 2011 , 2013 , and 2014 rate filings for settlement and hearing procedures .

2013 rate filing based on calendar year 2012 production costs in may 2013 , entergy filed with the ferc the 2013 rates in accordance with the ferc 2019s orders in the system agreement proceeding .

the city council intervened and filed comments related to including the outcome of a related ferc proceeding in the 2013 cost equalization calculation .

in august 2013 the ferc issued an order accepting the 2013 rates , effective june 1 , 2013 , subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2013 rate filing with the 2011 , 2012 , and 2014 rate filings for settlement and hearing procedures .

entergy corporation and subsidiaries notes to financial statements .

1		payments ( receipts ) ( in millions )

2	entergy arkansas	$ 2

3	entergy louisiana	$ 6

4	entergy mississippi	( $ 4 )

5	entergy new orleans	( $ 1 )

6	entergy texas	( $ 3 )

Question: what was the total of payments for entergy arkansas, in millions?

Answer: 6.0


in september 2016 the ferc accepted the february 2016 compliance filing subject to a further compliance filing made in november 2016 .

the further compliance filing was required as a result of an order issued in september 2016 ruling on the january 2016 rehearing requests filed by the lpsc , the apsc , and entergy .

in the order addressing the rehearing requests , the ferc granted the lpsc 2019s rehearing request and directed that interest be calculated on the payment/receipt amounts .

the ferc also granted the apsc 2019s and entergy 2019s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation .

in november 2016 , entergy submitted its compliance filing in response to the ferc 2019s order on rehearing .

the compliance filing included a revised refund calculation of the true-up payments and receipts based on 2009 test year data and interest calculations .

the lpsc protested the interest calculations .

in november 2017 the ferc issued an order rejecting the november 2016 compliance filing .

the ferc determined that the payments detailed in the november 2016 compliance filing did not include adequate interest for the payments from entergy arkansas to entergy louisiana because it did not include interest on the principal portion of the payment that was made in february 2016 .

in december 2017 , entergy recalculated the interest pursuant to the november 2017 order .

as a result of the recalculations , entergy arkansas owed very minor payments to entergy louisiana , entergy mississippi , and entergy new orleans .

2011 rate filing based on calendar year 2010 production costs in may 2011 , entergy filed with the ferc the 2011 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in july a02011 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a01 , a02011 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2011 rate filing with the 2012 , 2013 , and 2014 rate filings for settlement and hearing procedures .

see discussion below regarding the consolidated settlement and hearing procedures in connection with this proceeding .

2012 rate filing based on calendar year 2011 production costs in may 2012 , entergy filed with the ferc the 2012 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in august 2012 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a02012 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2012 rate filing with the 2011 , 2013 , and 2014 rate filings for settlement and hearing procedures .

2013 rate filing based on calendar year 2012 production costs in may 2013 , entergy filed with the ferc the 2013 rates in accordance with the ferc 2019s orders in the system agreement proceeding .

the city council intervened and filed comments related to including the outcome of a related ferc proceeding in the 2013 cost equalization calculation .

in august 2013 the ferc issued an order accepting the 2013 rates , effective june 1 , 2013 , subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2013 rate filing with the 2011 , 2012 , and 2014 rate filings for settlement and hearing procedures .

entergy corporation and subsidiaries notes to financial statements .

what was the total of payments for entergy arkansas, in millions?

Question: and what was it for entergy louisiana?

Answer: 2.0


in september 2016 the ferc accepted the february 2016 compliance filing subject to a further compliance filing made in november 2016 .

the further compliance filing was required as a result of an order issued in september 2016 ruling on the january 2016 rehearing requests filed by the lpsc , the apsc , and entergy .

in the order addressing the rehearing requests , the ferc granted the lpsc 2019s rehearing request and directed that interest be calculated on the payment/receipt amounts .

the ferc also granted the apsc 2019s and entergy 2019s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation .

in november 2016 , entergy submitted its compliance filing in response to the ferc 2019s order on rehearing .

the compliance filing included a revised refund calculation of the true-up payments and receipts based on 2009 test year data and interest calculations .

the lpsc protested the interest calculations .

in november 2017 the ferc issued an order rejecting the november 2016 compliance filing .

the ferc determined that the payments detailed in the november 2016 compliance filing did not include adequate interest for the payments from entergy arkansas to entergy louisiana because it did not include interest on the principal portion of the payment that was made in february 2016 .

in december 2017 , entergy recalculated the interest pursuant to the november 2017 order .

as a result of the recalculations , entergy arkansas owed very minor payments to entergy louisiana , entergy mississippi , and entergy new orleans .

2011 rate filing based on calendar year 2010 production costs in may 2011 , entergy filed with the ferc the 2011 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in july a02011 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a01 , a02011 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2011 rate filing with the 2012 , 2013 , and 2014 rate filings for settlement and hearing procedures .

see discussion below regarding the consolidated settlement and hearing procedures in connection with this proceeding .

2012 rate filing based on calendar year 2011 production costs in may 2012 , entergy filed with the ferc the 2012 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in august 2012 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a02012 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2012 rate filing with the 2011 , 2013 , and 2014 rate filings for settlement and hearing procedures .

2013 rate filing based on calendar year 2012 production costs in may 2013 , entergy filed with the ferc the 2013 rates in accordance with the ferc 2019s orders in the system agreement proceeding .

the city council intervened and filed comments related to including the outcome of a related ferc proceeding in the 2013 cost equalization calculation .

in august 2013 the ferc issued an order accepting the 2013 rates , effective june 1 , 2013 , subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2013 rate filing with the 2011 , 2012 , and 2014 rate filings for settlement and hearing procedures .

entergy corporation and subsidiaries notes to financial statements .

Question: what was, then, the difference between them?

Answer: 4.0


in september 2016 the ferc accepted the february 2016 compliance filing subject to a further compliance filing made in november 2016 .

the further compliance filing was required as a result of an order issued in september 2016 ruling on the january 2016 rehearing requests filed by the lpsc , the apsc , and entergy .

in the order addressing the rehearing requests , the ferc granted the lpsc 2019s rehearing request and directed that interest be calculated on the payment/receipt amounts .

the ferc also granted the apsc 2019s and entergy 2019s rehearing request and ordered the removal of both securitized asset accumulated deferred income taxes and contra-securitization accumulated deferred income taxes from the calculation .

in november 2016 , entergy submitted its compliance filing in response to the ferc 2019s order on rehearing .

the compliance filing included a revised refund calculation of the true-up payments and receipts based on 2009 test year data and interest calculations .

the lpsc protested the interest calculations .

in november 2017 the ferc issued an order rejecting the november 2016 compliance filing .

the ferc determined that the payments detailed in the november 2016 compliance filing did not include adequate interest for the payments from entergy arkansas to entergy louisiana because it did not include interest on the principal portion of the payment that was made in february 2016 .

in december 2017 , entergy recalculated the interest pursuant to the november 2017 order .

as a result of the recalculations , entergy arkansas owed very minor payments to entergy louisiana , entergy mississippi , and entergy new orleans .

2011 rate filing based on calendar year 2010 production costs in may 2011 , entergy filed with the ferc the 2011 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in july a02011 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a01 , a02011 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2011 rate filing with the 2012 , 2013 , and 2014 rate filings for settlement and hearing procedures .

see discussion below regarding the consolidated settlement and hearing procedures in connection with this proceeding .

2012 rate filing based on calendar year 2011 production costs in may 2012 , entergy filed with the ferc the 2012 rates in accordance with the ferc 2019s orders in the system agreement proceeding . a0 a0several parties intervened in the proceeding at the ferc , including the lpsc , which also filed a protest . a0 a0in august 2012 the ferc a0accepted entergy 2019s proposed rates for filing , a0effective june a02012 , a0subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2012 rate filing with the 2011 , 2013 , and 2014 rate filings for settlement and hearing procedures .

2013 rate filing based on calendar year 2012 production costs in may 2013 , entergy filed with the ferc the 2013 rates in accordance with the ferc 2019s orders in the system agreement proceeding .

the city council intervened and filed comments related to including the outcome of a related ferc proceeding in the 2013 cost equalization calculation .

in august 2013 the ferc issued an order accepting the 2013 rates , effective june 1 , 2013 , subject to refund .

after an abeyance of the proceeding schedule , in december 2014 the ferc consolidated the 2013 rate filing with the 2011 , 2012 , and 2014 rate filings for settlement and hearing procedures .

entergy corporation and subsidiaries notes to financial statements .

what was, then, the difference between them?

Question: and what was the entergy louisiana amount as a percent of the entergy arkansas one?

Answer: 0.33333


2012 sales of $ 451.1 increased primarily from higher lng project activity .

operating income of $ 65.5 increased from the higher lng project activity .

the sales backlog for the equipment business at 30 september 2013 was $ 402 , compared to $ 450 at 30 september 2012 .

it is expected that approximately $ 250 of the backlog will be completed during 2014 .

2011 sales of $ 420.1 increased 5% ( 5 % ) , or $ 19.5 , reflecting higher air separation unit ( asu ) activity .

operating income of $ 44.6 decreased 29% ( 29 % ) , or $ 18.2 , reflecting lower lng project activity .

the sales backlog for the equipment business at 30 september 2012 was $ 450 , compared to $ 334 at 30 september 2011 .

other operating income ( loss ) primarily includes other expense and income that cannot be directly associated with the business segments , including foreign exchange gains and losses .

also included are lifo inventory valuation adjustments , as the business segments use fifo , and the lifo pool valuation adjustments are not allocated to the business segments .

other also included stranded costs resulting from discontinued operations , as these costs were not reallocated to the businesses in 2012 .

2012 other operating loss was $ 4.7 , compared to $ 6.6 in the prior year .

the current year includes an unfavorable lifo adjustment versus the prior year of $ 11 .

the prior year loss included stranded costs from discontinued operations of $ 10 .

2011 other operating loss was $ 6.6 , compared to $ 39.3 in the prior year , primarily due to a reduction in stranded costs , a decrease in the lifo adjustment as a result of decreases in inventory values , and favorable foreign exchange , partially offset by gains on asset sales in the prior year. .

Question: in 2013, what was the ratio of sales to operating income?

Answer: 6.88702


in 2013, what was the ratio of sales to operating income?

Question: and in 2012?

Answer: 9.41928


amortized over a nine-year period beginning december 2015 .

see note 2 to the financial statements for further discussion of the business combination and customer credits .

the volume/weather variance is primarily due to the effect of more favorable weather during the unbilled period and an increase in industrial usage , partially offset by the effect of less favorable weather on residential sales .

the increase in industrial usage is primarily due to expansion projects , primarily in the chemicals industry , and increased demand from new customers , primarily in the industrial gases industry .

the louisiana act 55 financing savings obligation variance results from a regulatory charge for tax savings to be shared with customers per an agreement approved by the lpsc .

the tax savings resulted from the 2010-2011 irs audit settlement on the treatment of the louisiana act 55 financing of storm costs for hurricane gustav and hurricane ike .

see note 3 to the financial statements for additional discussion of the settlement and benefit sharing .

included in other is a provision of $ 23 million recorded in 2016 related to the settlement of the waterford 3 replacement steam generator prudence review proceeding , offset by a provision of $ 32 million recorded in 2015 related to the uncertainty at that time associated with the resolution of the waterford 3 replacement steam generator prudence review proceeding . a0 see note 2 to the financial statements for a discussion of the waterford 3 replacement steam generator prudence review proceeding .

entergy wholesale commodities following is an analysis of the change in net revenue comparing 2016 to 2015 .

as shown in the table above , net revenue for entergy wholesale commodities decreased by approximately $ 124 million in 2016 primarily due to : 2022 lower realized wholesale energy prices and lower capacity prices , the amortization of the palisades below- market ppa , and vermont yankee capacity revenue .

the effect of the amortization of the palisades below- market ppa and vermont yankee capacity revenue on the net revenue variance from 2015 to 2016 is minimal ; 2022 the sale of the rhode island state energy center in december 2015 .

see note 14 to the financial statements for further discussion of the rhode island state energy center sale ; and 2022 lower volume in the entergy wholesale commodities nuclear fleet resulting from more refueling outage days in 2016 as compared to 2015 and larger exercise of resupply options in 2016 as compared to 2015 .

see 201cnuclear matters - indian point 201d below for discussion of the extended indian point 2 outage in the second quarter entergy corporation and subsidiaries management 2019s financial discussion and analysis .

1		amount ( in millions )

2	2015 net revenue	$ 1666

3	nuclear realized price changes	-149 ( 149 )

4	rhode island state energy center	-44 ( 44 )

5	nuclear volume	-36 ( 36 )

6	fitzpatrick reimbursement agreement	41

7	nuclear fuel expenses	68

8	other	-4 ( 4 )

9	2016 net revenue	$ 1542

Question: how much did net revenue change between 2015 and 2016?

Answer: 124.0


how much did net revenue change between 2015 and 2016?

Question: and the percentage change during this time?

Answer: 0.08042


and the percentage change during this time?

Question: what were nuclear fuel expenses as a percentage of 2016 net revenue?

Answer: 0.0441


investing activities for the year ended 30 september 2014 , cash used for investing activities was $ 1638.0 , primarily capital expenditures for plant and equipment .

for the year ended 30 september 2013 , cash used for investing activities was $ 1697.0 , primarily capital expenditures for plant and equipment and acquisitions .

for the year ended 30 september 2012 , cash used for investing activities was $ 2435.2 , primarily capital expenditures for plant and equipment , acquisitions , and investments in unconsolidated affiliates .

refer to the capital expenditures section below for additional detail .

capital expenditures capital expenditures are detailed in the following table: .

( a ) we utilize a non-gaap measure in the computation of capital expenditures and include spending associated with facilities accounted for as capital leases and purchases of noncontrolling interests .

certain contracts associated with facilities that are built to provide product to a specific customer are required to be accounted for as leases , and such spending is reflected as a use of cash within cash provided by operating activities , if the arrangement qualifies as a capital lease .

additionally , the payment for subsidiary shares from noncontrolling interests in a subsidiary is accounted for as an equity transaction and will be reflected as a financing activity in the statement of cash flows .

the presentation of this non-gaap measure is intended to enhance the usefulness of information by providing a measure that our management uses internally to evaluate and manage our expenditures .

capital expenditures on a gaap basis in 2014 totaled $ 1682.2 , compared to $ 1747.8 in 2013 .

the decrease of $ 65.6 was primarily due to the acquisitions in 2013 .

additions to plant and equipment are largely in support of the merchant gases and tonnage gases businesses .

additions to plant and equipment also included support capital of a routine , ongoing nature , including expenditures for distribution equipment and facility improvements .

spending in 2014 and 2013 included plant and equipment constructed to provide oxygen for coal gasification in china , hydrogen to the global market , and renewable energy in the u.k .

in 2013 , we completed three acquisitions with an aggregate cash use , net of cash acquired , of $ 224.9 .

in the fourth quarter , we acquired an air separation unit and integrated gases liquefier in guiyang , china .

during the third quarter , we acquired epco , the largest independent u.s .

producer of liquid carbon dioxide ( co2 ) , and wcg .

in 2012 , we acquired a controlling stake in indura s.a .

dupont de nemours and co. , inc . 2019s 50% ( 50 % ) interest in our joint venture , da nanomaterials for $ 147 .

we also purchased a 25% ( 25 % ) equity interest in abdullah hashim industrial gases & equipment co .

( ahg ) , an unconsolidated affiliate , for $ 155 .

refer to note 5 , business combinations , and note 7 , summarized financial information of equity affiliates , to the consolidated financial statements for additional details regarding the acquisitions and the investments .

capital expenditures on a non-gaap basis in 2014 totaled $ 1885.1 compared to $ 1996.7 in 2013 .

capital lease expenditures of $ 202.4 decreased by $ 32.5 , reflecting lower project spending .

2015 outlook excluding acquisitions , capital expenditures for new plant and equipment in 2015 on a gaap basis are expected to be between $ 1650 and $ 1800 , and on a non-gaap basis are expected to be between $ 1700 and $ 1900 .

the non-gaap capital expenditures include spending associated with facilities accounted for as capital leases , which are expected to be between $ 50 and $ 100 .

a majority of the total capital expenditures is expected to be for new plants .

it is anticipated that capital expenditures will be funded principally with cash from continuing operations .

in addition , we intend to continue to evaluate acquisition opportunities and investments in equity affiliates .

financing activities for the year ended 2014 , cash used by financing activities was $ 504.3 primarily attributable to cash used to pay dividends of $ 627.7 , which was partially offset by proceeds from stock option exercises of $ 141.6 .

our borrowings ( short- and long-term proceeds , net of repayments ) were a net source of cash ( issuance ) of $ 1.1 and included $ 148.7 of net commercial paper and other short-term debt issuances , debt proceeds from the issuance of a .

1		2014	2013	2012

2	additions to plant and equipment	$ 1684.2	$ 1524.2	$ 1521.0

3	acquisitions less cash acquired	2014	224.9	863.4

4	investments in and advances to unconsolidated affiliates	-2.0 ( 2.0 )	-1.3 ( 1.3 )	175.4

5	capital expenditures on a gaap basis	$ 1682.2	$ 1747.8	$ 2559.8

6	capital lease expenditures ( a )	202.4	234.9	212.2

7	purchase of noncontrolling interests in asubsidiary ( a )	.5	14.0	6.3

8	capital expenditures on a non-gaap basis	$ 1885.1	$ 1996.7	$ 2778.3

Question: what were the capital expenditures on a non-gaap basis in 2012?

Answer: 2778.3


( a ) we utilize a non-gaap measure in the computation of capital expenditures and include spending associated with facilities accounted for as capital leases and purchases of noncontrolling interests .

certain contracts associated with facilities that are built to provide product to a specific customer are required to be accounted for as leases , and such spending is reflected as a use of cash within cash provided by operating activities , if the arrangement qualifies as a capital lease .

additionally , the payment for subsidiary shares from noncontrolling interests in a subsidiary is accounted for as an equity transaction and will be reflected as a financing activity in the statement of cash flows .

the presentation of this non-gaap measure is intended to enhance the usefulness of information by providing a measure that our management uses internally to evaluate and manage our expenditures .

capital expenditures on a gaap basis in 2014 totaled $ 1682.2 , compared to $ 1747.8 in 2013 .

the decrease of $ 65.6 was primarily due to the acquisitions in 2013 .

additions to plant and equipment are largely in support of the merchant gases and tonnage gases businesses .

additions to plant and equipment also included support capital of a routine , ongoing nature , including expenditures for distribution equipment and facility improvements .

spending in 2014 and 2013 included plant and equipment constructed to provide oxygen for coal gasification in china , hydrogen to the global market , and renewable energy in the u.k .

in 2013 , we completed three acquisitions with an aggregate cash use , net of cash acquired , of $ 224.9 .

in the fourth quarter , we acquired an air separation unit and integrated gases liquefier in guiyang , china .

during the third quarter , we acquired epco , the largest independent u.s .

producer of liquid carbon dioxide ( co2 ) , and wcg .

in 2012 , we acquired a controlling stake in indura s.a .

dupont de nemours and co. , inc . 2019s 50% ( 50 % ) interest in our joint venture , da nanomaterials for $ 147 .

we also purchased a 25% ( 25 % ) equity interest in abdullah hashim industrial gases & equipment co .

( ahg ) , an unconsolidated affiliate , for $ 155 .

refer to note 5 , business combinations , and note 7 , summarized financial information of equity affiliates , to the consolidated financial statements for additional details regarding the acquisitions and the investments .

capital expenditures on a non-gaap basis in 2014 totaled $ 1885.1 compared to $ 1996.7 in 2013 .

capital lease expenditures of $ 202.4 decreased by $ 32.5 , reflecting lower project spending .

2015 outlook excluding acquisitions , capital expenditures for new plant and equipment in 2015 on a gaap basis are expected to be between $ 1650 and $ 1800 , and on a non-gaap basis are expected to be between $ 1700 and $ 1900 .

the non-gaap capital expenditures include spending associated with facilities accounted for as capital leases , which are expected to be between $ 50 and $ 100 .

a majority of the total capital expenditures is expected to be for new plants .

it is anticipated that capital expenditures will be funded principally with cash from continuing operations .

in addition , we intend to continue to evaluate acquisition opportunities and investments in equity affiliates .

financing activities for the year ended 2014 , cash used by financing activities was $ 504.3 primarily attributable to cash used to pay dividends of $ 627.7 , which was partially offset by proceeds from stock option exercises of $ 141.6 .

our borrowings ( short- and long-term proceeds , net of repayments ) were a net source of cash ( issuance ) of $ 1.1 and included $ 148.7 of net commercial paper and other short-term debt issuances , debt proceeds from the issuance of a .

what were the capital expenditures on a non-gaap basis in 2012?

Question: and what were the capital expenditures on a gaap basis in that same year?

Answer: 2559.8


( a ) we utilize a non-gaap measure in the computation of capital expenditures and include spending associated with facilities accounted for as capital leases and purchases of noncontrolling interests .

certain contracts associated with facilities that are built to provide product to a specific customer are required to be accounted for as leases , and such spending is reflected as a use of cash within cash provided by operating activities , if the arrangement qualifies as a capital lease .

additionally , the payment for subsidiary shares from noncontrolling interests in a subsidiary is accounted for as an equity transaction and will be reflected as a financing activity in the statement of cash flows .

the presentation of this non-gaap measure is intended to enhance the usefulness of information by providing a measure that our management uses internally to evaluate and manage our expenditures .

capital expenditures on a gaap basis in 2014 totaled $ 1682.2 , compared to $ 1747.8 in 2013 .

the decrease of $ 65.6 was primarily due to the acquisitions in 2013 .

additions to plant and equipment are largely in support of the merchant gases and tonnage gases businesses .

additions to plant and equipment also included support capital of a routine , ongoing nature , including expenditures for distribution equipment and facility improvements .

spending in 2014 and 2013 included plant and equipment constructed to provide oxygen for coal gasification in china , hydrogen to the global market , and renewable energy in the u.k .

in 2013 , we completed three acquisitions with an aggregate cash use , net of cash acquired , of $ 224.9 .

in the fourth quarter , we acquired an air separation unit and integrated gases liquefier in guiyang , china .

during the third quarter , we acquired epco , the largest independent u.s .

producer of liquid carbon dioxide ( co2 ) , and wcg .

in 2012 , we acquired a controlling stake in indura s.a .

dupont de nemours and co. , inc . 2019s 50% ( 50 % ) interest in our joint venture , da nanomaterials for $ 147 .

we also purchased a 25% ( 25 % ) equity interest in abdullah hashim industrial gases & equipment co .

( ahg ) , an unconsolidated affiliate , for $ 155 .

refer to note 5 , business combinations , and note 7 , summarized financial information of equity affiliates , to the consolidated financial statements for additional details regarding the acquisitions and the investments .

capital expenditures on a non-gaap basis in 2014 totaled $ 1885.1 compared to $ 1996.7 in 2013 .

capital lease expenditures of $ 202.4 decreased by $ 32.5 , reflecting lower project spending .

2015 outlook excluding acquisitions , capital expenditures for new plant and equipment in 2015 on a gaap basis are expected to be between $ 1650 and $ 1800 , and on a non-gaap basis are expected to be between $ 1700 and $ 1900 .

the non-gaap capital expenditures include spending associated with facilities accounted for as capital leases , which are expected to be between $ 50 and $ 100 .

a majority of the total capital expenditures is expected to be for new plants .

it is anticipated that capital expenditures will be funded principally with cash from continuing operations .

in addition , we intend to continue to evaluate acquisition opportunities and investments in equity affiliates .

financing activities for the year ended 2014 , cash used by financing activities was $ 504.3 primarily attributable to cash used to pay dividends of $ 627.7 , which was partially offset by proceeds from stock option exercises of $ 141.6 .

our borrowings ( short- and long-term proceeds , net of repayments ) were a net source of cash ( issuance ) of $ 1.1 and included $ 148.7 of net commercial paper and other short-term debt issuances , debt proceeds from the issuance of a .

and what were the capital expenditures on a gaap basis in that same year?

Question: how much, then, do the capital expenditures on a non-gaap basis represent in relation to the ones on a gaap basis, in 2012?

Answer: 1.08536


( a ) we utilize a non-gaap measure in the computation of capital expenditures and include spending associated with facilities accounted for as capital leases and purchases of noncontrolling interests .

certain contracts associated with facilities that are built to provide product to a specific customer are required to be accounted for as leases , and such spending is reflected as a use of cash within cash provided by operating activities , if the arrangement qualifies as a capital lease .

additionally , the payment for subsidiary shares from noncontrolling interests in a subsidiary is accounted for as an equity transaction and will be reflected as a financing activity in the statement of cash flows .

the presentation of this non-gaap measure is intended to enhance the usefulness of information by providing a measure that our management uses internally to evaluate and manage our expenditures .

capital expenditures on a gaap basis in 2014 totaled $ 1682.2 , compared to $ 1747.8 in 2013 .

the decrease of $ 65.6 was primarily due to the acquisitions in 2013 .

additions to plant and equipment are largely in support of the merchant gases and tonnage gases businesses .

additions to plant and equipment also included support capital of a routine , ongoing nature , including expenditures for distribution equipment and facility improvements .

spending in 2014 and 2013 included plant and equipment constructed to provide oxygen for coal gasification in china , hydrogen to the global market , and renewable energy in the u.k .

in 2013 , we completed three acquisitions with an aggregate cash use , net of cash acquired , of $ 224.9 .

in the fourth quarter , we acquired an air separation unit and integrated gases liquefier in guiyang , china .

during the third quarter , we acquired epco , the largest independent u.s .

producer of liquid carbon dioxide ( co2 ) , and wcg .

in 2012 , we acquired a controlling stake in indura s.a .

dupont de nemours and co. , inc . 2019s 50% ( 50 % ) interest in our joint venture , da nanomaterials for $ 147 .

we also purchased a 25% ( 25 % ) equity interest in abdullah hashim industrial gases & equipment co .

( ahg ) , an unconsolidated affiliate , for $ 155 .

refer to note 5 , business combinations , and note 7 , summarized financial information of equity affiliates , to the consolidated financial statements for additional details regarding the acquisitions and the investments .

capital expenditures on a non-gaap basis in 2014 totaled $ 1885.1 compared to $ 1996.7 in 2013 .

capital lease expenditures of $ 202.4 decreased by $ 32.5 , reflecting lower project spending .

2015 outlook excluding acquisitions , capital expenditures for new plant and equipment in 2015 on a gaap basis are expected to be between $ 1650 and $ 1800 , and on a non-gaap basis are expected to be between $ 1700 and $ 1900 .

the non-gaap capital expenditures include spending associated with facilities accounted for as capital leases , which are expected to be between $ 50 and $ 100 .

a majority of the total capital expenditures is expected to be for new plants .

it is anticipated that capital expenditures will be funded principally with cash from continuing operations .

in addition , we intend to continue to evaluate acquisition opportunities and investments in equity affiliates .

financing activities for the year ended 2014 , cash used by financing activities was $ 504.3 primarily attributable to cash used to pay dividends of $ 627.7 , which was partially offset by proceeds from stock option exercises of $ 141.6 .

our borrowings ( short- and long-term proceeds , net of repayments ) were a net source of cash ( issuance ) of $ 1.1 and included $ 148.7 of net commercial paper and other short-term debt issuances , debt proceeds from the issuance of a .

how much, then, do the capital expenditures on a non-gaap basis represent in relation to the ones on a gaap basis, in 2012?

Question: and what is the difference between this value and the number one?

Answer: 0.08536


performance graph the graph below compares the cumulative total shareholder return on pmi's common stock with the cumulative total return for the same period of pmi's peer group and the s&p 500 index .

the graph assumes the investment of $ 100 as of december 31 , 2013 , in pmi common stock ( at prices quoted on the new york stock exchange ) and each of the indices as of the market close and reinvestment of dividends on a quarterly basis .

date pmi pmi peer group ( 1 ) s&p 500 index .

( 1 ) the pmi peer group presented in this graph is the same as that used in the prior year .

the pmi peer group was established based on a review of four characteristics : global presence ; a focus on consumer products ; and net revenues and a market capitalization of a similar size to those of pmi .

the review also considered the primary international tobacco companies .

as a result of this review , the following companies constitute the pmi peer group : altria group , inc. , anheuser-busch inbev sa/nv , british american tobacco p.l.c. , the coca-cola company , colgate-palmolive co. , diageo plc , heineken n.v. , imperial brands plc , japan tobacco inc. , johnson & johnson , kimberly-clark corporation , the kraft-heinz company , mcdonald's corp. , mondel z international , inc. , nestl e9 s.a. , pepsico , inc. , the procter & gamble company , roche holding ag , and unilever nv and plc .

note : figures are rounded to the nearest $ 0.10. .

Question: what is the net change in the price for pmi common stock from 2013 to 2018?

Answer: -3.5


what is the net change in the price for pmi common stock from 2013 to 2018?

Question: what is that change over 100?

Answer: -0.035


entergy corporation notes to consolidated financial statements ( a ) consists of pollution control revenue bonds and environmental revenue bonds , certain series of which are secured by non-interest bearing first mortgage bonds .

( b ) the bonds are subject to mandatory tender for purchase from the holders at 100% ( 100 % ) of the principal amount outstanding on september 1 , 2005 and can then be remarketed .

( c ) the bonds are subject to mandatory tender for purchase from the holders at 100% ( 100 % ) of the principal amount outstanding on september 1 , 2004 and can then be remarketed .

( d ) the bonds had a mandatory tender date of october 1 , 2003 .

entergy louisiana purchased the bonds from the holders , pursuant to the mandatory tender provision , and has not remarketed the bonds at this time .

entergy louisiana used a combination of cash on hand and short-term borrowing to buy-in the bonds .

( e ) on june 1 , 2002 , entergy louisiana remarketed $ 55 million st .

charles parish pollution control revenue refunding bonds due 2030 , resetting the interest rate to 4.9% ( 4.9 % ) through may 2005 .

( f ) the bonds are subject to mandatory tender for purchase from the holders at 100% ( 100 % ) of the principal amount outstanding on june 1 , 2005 and can then be remarketed .

( g ) pursuant to the nuclear waste policy act of 1982 , entergy's nuclear owner/licensee subsidiaries have contracts with the doe for spent nuclear fuel disposal service .

the contracts include a one-time fee for generation prior to april 7 , 1983 .

entergy arkansas is the only entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee , plus accrued interest , in long-term ( h ) the fair value excludes lease obligations , long-term doe obligations , and other long-term debt and includes debt due within one year .

it is determined using bid prices reported by dealer markets and by nationally recognized investment banking firms .

the annual long-term debt maturities ( excluding lease obligations ) for debt outstanding as of december 31 , 2003 , for the next five years are as follows: .

in november 2000 , entergy's non-utility nuclear business purchased the fitzpatrick and indian point 3 power plants in a seller-financed transaction .

entergy issued notes to nypa with seven annual installments of approximately $ 108 million commencing one year from the date of the closing , and eight annual installments of $ 20 million commencing eight years from the date of the closing .

these notes do not have a stated interest rate , but have an implicit interest rate of 4.8% ( 4.8 % ) .

in accordance with the purchase agreement with nypa , the purchase of indian point 2 resulted in entergy's non-utility nuclear business becoming liable to nypa for an additional $ 10 million per year for 10 years , beginning in september 2003 .

this liability was recorded upon the purchase of indian point 2 in september 2001 , and is included in the note payable to nypa balance above .

in july 2003 , a payment of $ 102 million was made prior to maturity on the note payable to nypa .

under a provision in a letter of credit supporting these notes , if certain of the domestic utility companies or system energy were to default on other indebtedness , entergy could be required to post collateral to support the letter of credit .

covenants in the entergy corporation notes require it to maintain a consolidated debt ratio of 65% ( 65 % ) or less of its total capitalization .

if entergy's debt ratio exceeds this limit , or if entergy or certain of the domestic utility companies default on other indebtedness or are in bankruptcy or insolvency proceedings , an acceleration of the notes' maturity dates may occur. .

Question: as of december 31, 2003, what was the total amount of long-term debt due in the years of 2004 and 2005, in thousands?

Answer: 965635.0


as of december 31, 2003, what was the total amount of long-term debt due in the years of 2004 and 2005, in thousands?

Question: what is that in millions?

Answer: 965.635


Question: and including the long-term debt due in 2006, what then becomes that total amount?

Answer: 1041531.0


and including the long-term debt due in 2006, what then becomes that total amount?

Question: how much is this three year amount in millions?

Answer: 1041.531


notes to consolidated financial statements ( continued ) ( in thousands , except per share data ) acquisition and the adjustments did not have a material impact on the company 2019s financial position or results of operation .

there have no other material changes to the purchase price allocation as disclosed in the company 2019s form 10-k for the year ended september 30 , 2006 .

as part of the purchase price allocation , all intangible assets that were a part of the acquisition were identified and valued .

it was determined that only customer relationship , trade name , developed technology and know how and in-process research and development had separately identifiable values .

customer relationship represents r2 2019s strong active customer base , dominant market position and strong partnership with several large companies .

trade name represents the r2 product names that the company intends to continue to use .

order backlog consists of customer orders for which revenue has not yet been recognized .

developed technology and know how represents currently marketable purchased products that the company continues to resell as well as utilize to enhance and incorporate into the company 2019s existing products .

the estimated $ 10200 of purchase price allocated to in-process research and development projects primarily related to r2 2019s digital cad products .

the projects added direct digital algorithm capabilities as well as a new platform technology to analyze images and breast density measurement .

the projects were substantially completed as planned in fiscal 2007 .

the deferred income tax asset relates to the tax effect of acquired net operating loss carry forwards that the company believes are realizable partially offset by acquired identifiable intangible assets , and fair value adjustments to acquired inventory as such amounts are not deductible for tax purposes .

on july 27 , 2006 , the company completed the acquisition of suros surgical systems , inc .

( suros ) , pursuant to an agreement and plan of merger dated april 17 , 2006 .

the results of operations for suros have been included in the company 2019s consolidated financial statements from the date of acquisition as part of its mammography/breast care business segment .

suros , located in indianapolis , indiana , develops , manufactures and sells minimally invasive interventional breast biopsy technology and products for biopsy , tissue removal and biopsy site marking .

the initial aggregate purchase price for suros of approximately $ 248100 ( subject to adjustment ) consisted of 2300 shares of hologic common stock valued at $ 106500 , cash paid of $ 139000 , and approximately $ 2600 for acquisition related fees and expenses .

the company determined the fair value of the shares issued in connection with the acquisition in accordance with eitf issue no .

99-12 , determination of the measurement date for the market price of acquirer securities issued in a purchase business combination .

the components and allocation of the purchase price , consists of the following approximate amounts: .

the acquisition also provides for a two-year earn out .

the earn-out is payable in two annual cash installments equal to the incremental revenue growth in suros 2019 business in the two years following the closing. .

1	net tangible assets acquired as of july 27 2006	$ 11800

2	in-process research and development	4900

3	developed technology and know how	46000

4	customer relationship	17900

5	trade name	5800

6	deferred income taxes	-21300 ( 21300 )

7	goodwill	202000

8	estimated purchase price	$ 267100

Question: what was the average individual price of the shares used in the acquisition of suros?

Answer: 46.30435


notes to consolidated financial statements ( continued ) ( in thousands , except per share data ) acquisition and the adjustments did not have a material impact on the company 2019s financial position or results of operation .

there have no other material changes to the purchase price allocation as disclosed in the company 2019s form 10-k for the year ended september 30 , 2006 .

as part of the purchase price allocation , all intangible assets that were a part of the acquisition were identified and valued .

it was determined that only customer relationship , trade name , developed technology and know how and in-process research and development had separately identifiable values .

customer relationship represents r2 2019s strong active customer base , dominant market position and strong partnership with several large companies .

trade name represents the r2 product names that the company intends to continue to use .

order backlog consists of customer orders for which revenue has not yet been recognized .

developed technology and know how represents currently marketable purchased products that the company continues to resell as well as utilize to enhance and incorporate into the company 2019s existing products .

the estimated $ 10200 of purchase price allocated to in-process research and development projects primarily related to r2 2019s digital cad products .

the projects added direct digital algorithm capabilities as well as a new platform technology to analyze images and breast density measurement .

the projects were substantially completed as planned in fiscal 2007 .

the deferred income tax asset relates to the tax effect of acquired net operating loss carry forwards that the company believes are realizable partially offset by acquired identifiable intangible assets , and fair value adjustments to acquired inventory as such amounts are not deductible for tax purposes .

on july 27 , 2006 , the company completed the acquisition of suros surgical systems , inc .

( suros ) , pursuant to an agreement and plan of merger dated april 17 , 2006 .

the results of operations for suros have been included in the company 2019s consolidated financial statements from the date of acquisition as part of its mammography/breast care business segment .

suros , located in indianapolis , indiana , develops , manufactures and sells minimally invasive interventional breast biopsy technology and products for biopsy , tissue removal and biopsy site marking .

the initial aggregate purchase price for suros of approximately $ 248100 ( subject to adjustment ) consisted of 2300 shares of hologic common stock valued at $ 106500 , cash paid of $ 139000 , and approximately $ 2600 for acquisition related fees and expenses .

the company determined the fair value of the shares issued in connection with the acquisition in accordance with eitf issue no .

99-12 , determination of the measurement date for the market price of acquirer securities issued in a purchase business combination .

the components and allocation of the purchase price , consists of the following approximate amounts: .

what was the average individual price of the shares used in the acquisition of suros?

Question: and what was the total acquisition price in that transaction?

Answer: 267100.0


notes to consolidated financial statements ( continued ) ( in thousands , except per share data ) acquisition and the adjustments did not have a material impact on the company 2019s financial position or results of operation .

there have no other material changes to the purchase price allocation as disclosed in the company 2019s form 10-k for the year ended september 30 , 2006 .

as part of the purchase price allocation , all intangible assets that were a part of the acquisition were identified and valued .

it was determined that only customer relationship , trade name , developed technology and know how and in-process research and development had separately identifiable values .

customer relationship represents r2 2019s strong active customer base , dominant market position and strong partnership with several large companies .

trade name represents the r2 product names that the company intends to continue to use .

order backlog consists of customer orders for which revenue has not yet been recognized .

developed technology and know how represents currently marketable purchased products that the company continues to resell as well as utilize to enhance and incorporate into the company 2019s existing products .

the estimated $ 10200 of purchase price allocated to in-process research and development projects primarily related to r2 2019s digital cad products .

the projects added direct digital algorithm capabilities as well as a new platform technology to analyze images and breast density measurement .

the projects were substantially completed as planned in fiscal 2007 .

the deferred income tax asset relates to the tax effect of acquired net operating loss carry forwards that the company believes are realizable partially offset by acquired identifiable intangible assets , and fair value adjustments to acquired inventory as such amounts are not deductible for tax purposes .

on july 27 , 2006 , the company completed the acquisition of suros surgical systems , inc .

( suros ) , pursuant to an agreement and plan of merger dated april 17 , 2006 .

the results of operations for suros have been included in the company 2019s consolidated financial statements from the date of acquisition as part of its mammography/breast care business segment .

suros , located in indianapolis , indiana , develops , manufactures and sells minimally invasive interventional breast biopsy technology and products for biopsy , tissue removal and biopsy site marking .

the initial aggregate purchase price for suros of approximately $ 248100 ( subject to adjustment ) consisted of 2300 shares of hologic common stock valued at $ 106500 , cash paid of $ 139000 , and approximately $ 2600 for acquisition related fees and expenses .

the company determined the fair value of the shares issued in connection with the acquisition in accordance with eitf issue no .

99-12 , determination of the measurement date for the market price of acquirer securities issued in a purchase business combination .

the components and allocation of the purchase price , consists of the following approximate amounts: .

and what was the total acquisition price in that transaction?

Question: what percentage of this price was dedicated to goodwill?

Answer: 0.75627