EDWARDS LIFESCIENCES CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued) 7.
ACQUISITIONS (Continued) transaction closed on January 23, 2017, and the consideration paid included the issuance of approximately 2.8 million shares of the Company’s common stock (fair value of $266.5 million) and cash of $86.2 million.
The Company recognized in “Contingent Consideration Liabilities” a $162.9 million liability for the estimated fair value of the contingent milestone payments.
The fair value of the contingent milestone payments will be remeasured each quarter, with changes in the fair value recognized within operating expenses on the consolidated statements of operations.
For further information on the fair value of the contingent milestone payments, see Note 10.
In connection with the acquisition, the Company placed $27.6 million of the purchase price into escrow to satisfy any claims for indemnification made in accordance with the merger agreement.
Any funds remaining 15 months after the acquisition date will be disbursed to Valtech’s former shareholders.
Acquisition-related costs of $0.6 million and $4.1 million were recorded in “Selling, General, and Administrative Expenses” during the years ended December 31, 2017 and 2016, respectively.
Prior to the close of the transaction, Valtech spun off its earlystage transseptal mitral valve replacement technology program.
Concurrent with the closing, the Company entered into an agreement for an exclusive option to acquire that program and its associated intellectual property for approximately $200.0 million, subject to certain adjustments, plus an additional $50.0 million if a certain European regulatory approval is obtained within 10 years of the acquisition closing date.
The option expires two years after the closing date of the transaction, but can be extended by up to one year depending on the results of certain clinical trials.
Valtech is a developer of a transcatheter mitral and tricuspid valve repair system.
The Company plans to add this technology to its portfolio of mitral and tricuspid repair products.
The acquisition was accounted for as a business combination.
Tangible and intangible assets acquired were recorded based on their estimated fair values at the acquisition date.
The excess of the purchase price over the fair value of net assets acquired was recorded to goodwill.
The following table summarizes the fair values of the assets acquired and liabilities assumed (in millions):
## Table 0 ##
Goodwill includes expected synergies and other benefits the Company believes will result from the acquisition.
Goodwill was assigned to the Company’s Rest of World segment and is not deductible for tax purposes.
IPR&D has been capitalized at fair value as an intangible asset with an indefinite life and will be assessed for impairment in subsequent periods.
The fair value of the IPR&D was determined using the income approach.
This approach determines fair value based on cash flow projections which are discounted to present value using a risk-adjusted rate of return.
The discount rates used to determine the fair value of the IPR&D ranged from 18.0% to 20.0%.
Completion of successful design developments, bench testing, pre-clinical studies
The components of unamortized regulatory assets and liabilities of continuing operations shown on the consolidated balance sheets at Dec.  31 are:
## Table 1 ##
(a) Earns a return on investment in the ratemaking process.
These amounts are amortized consistent with recovery in rates.
(b) Includes amounts recorded for future recovery of AROs, less amounts recovered through nuclear decommissioning accruals and gains from decommissioning investments.
(c) Includes the fair value of certain long-term purchased power agreements used to meet energy capacity requirements.
(d) Included in other current liabilities of $350,318 and $331,419 at Dec.  31, 2009 and 2008, respectively, in the consolidated balance sheets.
(e) Includes $415.5 million for the regulatory recognition of the NSP-Minnesota pension expense and the PSCo unamortized prior service costs, offset by $18.1 million of regulatory assets related to the non-qualified pension plan.20.
Segments and Related Information The regulated electric utility operating results of NSP-Minnesota, NSP-Wisconsin, PSCo and SPS, as well as the regulated natural gas utility operating results of NSP-Minnesota, NSP-Wisconsin and PSCo are each separately and regularly reviewed by Xcel Energy’s chief operating decision maker.
Xcel Energy evaluates performance by each utility subsidiary based on profit or loss generated from the product or service provided.
These segments are managed separately because the revenue streams are dependent upon regulated rate recovery, which is separately determined for each segment.
Nuclear Decommissioning Fund — Nuclear decommissioning fund assets assigned to Level 3 consist of asset-backed and mortgage-backed securities.
To the extent appropriate, observable market inputs are utilized to estimate the fair value of these securities, however, less observable and subjective risk-based adjustments to estimated yield and forecasted prepayments are often significant to these valuations.
Therefore, estimated fair values for all asset-backed and mortgagebacked securities totaling $93.1 million in the nuclear decommissioning fund at Dec.  31, 2009 (approximately 7 percent of total assets measured at fair value), are assigned to Level 3.
Realized and unrealized gains and losses on nuclear decommissioning fund investments are deferred as a component of a nuclear decommissioning regulatory asset.
Liquidity and Capital Resources Cash Flows
## Table 2 ##
Cash provided by operating activities for continuing operations increased by $263 million for 2009 as compared to 2008.
The increase was primarily attributable to higher net income, changes in working capital due to the timing of accounts receivable, accounts payable and inventory as a result of natural gas prices and an increase in plant-related deferred income taxes.
The increase was partially offset by increased pension contributions made in 2009 and higher AFUDC due primarily to the construction of Comanche Unit 3, a power facility located in Colorado.
Cash provided by operating activities for continuing operations increased by $123 million for 2008 as compared to 2007.
The increase is primarily attributable to higher net income, changes in other current liabilities due to timing for interest payable and accounts payable and an increase in recoverable gas and electric costs.
This increase was partially offset by changes in working capital activity due to increased inventory, contributions for pension and non-pension postretirement benefits, and an increase in net regulatory assets and liabilities.
The increased inventory reflects the higher cost of natural gas combined with an increase in storage contracts.
The increase in net regulatory assets and liabilities reflects the increase in pension funding obligation, and the decrease in fair value of the investments in the decommissioning fund, partially offset by the decrease in the asset retirement obligation for the extended life of the nuclear facilities.
Cash provided by operating activities for discontinued operations decreased $75 million, primarily due to decreased income taxes received during 2008.
## Table 3 ##
Cash used in investing activities for continuing operations decreased by $421 million during 2009, primarily due to reduced capital expenditures; a withdrawal of funds, to refund customers, from the external decommissioning fund as approved by the MPUC; as well as reduced investment in the WYCO natural gas pipeline and storage project.
No cash was provided by investing activities for discontinued operations.
Cash used in investing activities for continuing operations increased by $74 million during 2008, primarily due to increased capital expenditures, and the continued investment in the WYCO natural gas pipeline and storage project.

<table><tr><td>Current assets</td><td>$22.7</td></tr><tr><td>Property and equipment, net</td><td>1.2</td></tr><tr><td>Goodwill</td><td>316.5</td></tr><tr><td>Developed technology</td><td>109.2</td></tr><tr><td>IPR&D</td><td>87.9</td></tr><tr><td>Other assets</td><td>0.8</td></tr><tr><td>Current liabilities assumed</td><td>-5.1</td></tr><tr><td>Deferred income taxes</td><td>-17.6</td></tr><tr><td>Total purchase price</td><td>515.6</td></tr><tr><td>Less: cash acquired</td><td>-4.3</td></tr><tr><td>Total purchase price, net of cash acquired</td><td>$511.3</td></tr></table>
<table><tr><td> </td><td> See Note(s)</td><td> Remaining Amortization Period</td><td> 2009</td><td> 2008</td></tr><tr><td> </td><td colspan="4"> (Thousands of Dollars) </td></tr><tr><td> Regulatory Assets</td><td></td><td></td><td></td><td></td></tr><tr><td>Current regulatory asset — Recoverable</td><td></td><td></td><td></td><td></td></tr><tr><td>purchased natural gas and electric energy costs</td><td>1</td><td>Less than one year</td><td>$56,744</td><td>$32,843</td></tr><tr><td>Pension and employee benefit obligations<sup>(e)</sup></td><td>11</td><td>Various</td><td>1,206,555</td><td>1,212,542</td></tr><tr><td>AFUDC recorded in plant<sup>(a)</sup></td><td>1</td><td>Plant lives</td><td>254,630</td><td>220,354</td></tr><tr><td>Net AROs<sup>(b)</sup></td><td>1,17</td><td>Plant lives</td><td>207,309</td><td>299,294</td></tr><tr><td>Conservation programs<sup>(a)</sup></td><td></td><td>Up to 2 years</td><td>121,678</td><td>117,188</td></tr><tr><td>Environmental costs</td><td>16,17</td><td>Generally four to six years once actual expenditures are incurred</td><td>103,297</td><td>75,880</td></tr><tr><td>Contract valuation adjustments<sup>(c)</sup></td><td>14</td><td>Term of related contract</td><td>89,026</td><td>150,723</td></tr><tr><td>Renewable and environmental initiative costs</td><td>16,17</td><td>One to six years</td><td>77,072</td><td>69,134</td></tr><tr><td>Losses on reacquired debt</td><td>1</td><td>Term of related debt</td><td>62,005</td><td>66,268</td></tr><tr><td>Nuclear outage costs</td><td>16</td><td>Generally 18-24 months</td><td>60,747</td><td>40,690</td></tr><tr><td>Purchased power contracts costs</td><td>14</td><td>Term of related contract</td><td>33,203</td><td>20,716</td></tr><tr><td>Unrecovered natural gas costs</td><td>1</td><td>One to two years</td><td>10,620</td><td>14,657</td></tr><tr><td>MISO Day 2 costs</td><td>1</td><td>Three years</td><td>9,829</td><td>11,783</td></tr><tr><td>Rate case costs</td><td>1</td><td>Various</td><td>9,519</td><td>12,085</td></tr><tr><td>State commission accounting adjustments<sup>(a)</sup></td><td>16</td><td>Various</td><td>8,839</td><td>13,148</td></tr><tr><td>Nuclear fuel storage</td><td></td><td>Three to six years</td><td>8,301</td><td>9,652</td></tr><tr><td>Nuclear decommissioning costs</td><td>18</td><td>Two years</td><td>6,293</td><td>8,775</td></tr><tr><td>Other</td><td></td><td>Various</td><td>18,713</td><td>14,390</td></tr><tr><td>Total noncurrent regulatory assets</td><td></td><td></td><td>$2,287,636</td><td>$2,357,279</td></tr><tr><td> Regulatory Liabilities</td><td></td><td></td><td></td><td></td></tr><tr><td>Current regulatory liability — Deferred electric energy costs<sup>(d)</sup></td><td></td><td></td><td>$124,335</td><td>$134,212</td></tr><tr><td>Plant removal costs</td><td>1,17</td><td></td><td>941,959</td><td>925,472</td></tr><tr><td>Contract valuation adjustments<sup>(c)</sup></td><td>14</td><td></td><td>111,413</td><td>124,676</td></tr><tr><td>Investment tax credit deferrals</td><td></td><td></td><td>65,884</td><td>68,313</td></tr><tr><td>Deferred income tax adjustment</td><td>1</td><td></td><td>46,435</td><td>42,619</td></tr><tr><td>Wisconsin overrecovered fuel costs</td><td>16</td><td></td><td>18,493</td><td>76</td></tr><tr><td>Nuclear outage costs collected in advance from customers</td><td></td><td></td><td>10,322</td><td>13,678</td></tr><tr><td>Low income discount program</td><td></td><td></td><td>7,177</td><td>3,943</td></tr><tr><td>Gain on sale of emission allowances</td><td>1</td><td></td><td>3,426</td><td>8,153</td></tr><tr><td>Interest on income tax refunds</td><td></td><td></td><td>1,302</td><td>1,736</td></tr><tr><td>Other</td><td></td><td></td><td>16,422</td><td>5,930</td></tr><tr><td>Total noncurrent regulatory liabilities</td><td></td><td></td><td>$1,222,833</td><td>$1,194,596</td></tr></table>
<table><tr><td> </td><td>2009</td><td>2008</td><td> 2007</td></tr><tr><td> </td><td colspan="3"> (Millions of Dollars) </td></tr><tr><td> Cash provided by (used in) operating activities</td><td></td><td></td><td></td></tr><tr><td>Continuing operations</td><td>$1,946</td><td>$1,683</td><td>$1,560</td></tr><tr><td>Discontinued operations</td><td>-28</td><td>-3</td><td>72</td></tr><tr><td>Total</td><td>$1,918</td><td>$1,680</td><td>$1,632</td></tr></table>
<table><tr><td> </td><td>2009</td><td>2008</td><td>2007</td></tr><tr><td> </td><td colspan="3">(Millions of Dollars)</td></tr><tr><td> Cash used in investing activities</td><td>$-1,735</td><td>$-2,156</td><td>$-2,082</td></tr></table>

Question: what are the acquisition-related costs recorded in 201cselling , general , and administrative expenses 201d as a percentage of current assets?
Answer: 0.20705