or Bankers’ Acceptance Stamping Fee Spread at October 3, 2005).
The Company will pay quarterly facility fees to maintain the availability under the Canadian Credit Facility at specific rates based on the Company’s debt rating (0.20% at October 3, 2005).
The Company may choose to repay or reduce its commitments under the Canadian Credit Facility at any time.
The Canadian Credit Facility contains restrictions on, among other things, additional indebtedness, distributions and dividends to stockholders, investments and capital expenditures.
Additional covenants require compliance with financial tests, including leverage and minimum earnings to fixed charges ratios.
During the fiscal year ended September 30, 2005, the Company paid $100 million to redeem the Bergen 71?4% Senior Notes due June 1, 2005, upon their maturity.
In December 2000, the Company issued $300.0 million of 5% convertible subordinated notes due December 1, 2007.
The notes had an annual interest rate of 5%, payable semiannually, and were convertible into common stock of the Company at $52.97 per share at any time before their maturity or their prior redemption or repurchase by the Company.
In December 2004, the Company announced that it would redeem its 5% convertible subordinated notes at a redemption price of 102.143% of the principal amount of the notes plus accrued interest through the redemption date of January 3, 2005.
The noteholders were given the option to accept cash or convert the notes to common stock of the Company.
The notes were convertible into 5,663,730 shares of common stock, which translated to a conversion ratio of 18.8791 shares of common stock for each $1,000 principal amount of notes.
Through January 3, 2005, the redemption date, the Company issued 5,663,144 shares of common stock from treasury to noteholders to redeem substantially all of the notes and paid $31,000 to redeem the remaining notes.
During fiscal 2005, the Company subsequently repurchased 5.7 million shares of common stock, substantially equivalent to the number of common stock shares issued in connection with the conversion of the 5% notes.
The Company’s operating results have generated cash flow, which, together with availability under its debt agreements and credit terms from suppliers, has provided sufficient capital resources to finance working capital and cash operating requirements, and to fund capital expenditures, acquisitions, repayment of debt, the payment of interest on outstanding debt and repurchases of shares of the Company’s common stock.
Cash flow from operations for the fiscal year ended September 30, 2005 was $1.53 billion primarily due to the significant decline in merchandise inventories and an increase in accounts payable during the fiscal year ended September 30, 2005.
The significant decline in merchandise inventories during the fiscal year ended September 30, 2005 reflected the impact of the business model transition, including increasing compliance under current inventory management and fee-for-service agreements.
We do not anticipate the Company will experience similar amounts of working capital reduction in future years as the Company has signed fee-for-service agreements with a substantial majority of manufacturers as of September 30, 2005.
The Company expects cash flow from operations in fiscal 2006 to be between $500 million and $600 million.
The Company’s primary ongoing cash requirements will be to finance working capital, fund the payment of interest on debt, finance merger integration initiatives and fund capital expenditures and routine growth and expansion through new business opportunities.
Significant cash flows from operations primarily resulting from the business model transition, as discussed above, has resulted in a near record low debt-to-capital ratio of 18.2% and a net debt to total capital ratio of less than zero.
The Company has been and continues to actively evaluate its alternatives to deploy its excess capital.
For example, the Company plans to repurchase $750 million of its common stock and recently announced that it will double its quarterly cash dividend.
Additionally, on October 5, 2005, the Company acquired Trent Drugs (Wholesale) Ltd (“Trent”), one of the largest national pharmaceutical distributors in Canada, for a purchase price of $81.7 million, which included the assumption of debt of $41.3 million.
The acquisition of Trent provides the Company a solid foundation to expand its pharmaceutical distribution capability into the Canadian marketplace.
The Company expects to pursue further strategic acquisitions.
Future cash flows from operations and borrowings are expected to be sufficient to fund the Company’s ongoing cash requirements.
Following is a summary of the Company’s contractual obligations for future principal and interest payments on its debt, minimum rental payments on its noncancelable operating leases and minimum payments on its other commitments at September 30, 2005 (in thousands):
## Table 0 ##
The $55 million Blanco revolving credit facility, which expires in April 2006, is included in the “Within 1 year” column in the above repayment table.
However, this borrowing is not classified in the current portion of long-term debt on the consolidated balance sheet at September 30, 2005 because the Company has the ability and intent to refinance it on a long-term basis.
In December 2004, the Company entered into a distribution agreement with a Canadian influenza vaccine manufacturer to distribute product through March 31, 2015.
The agreement includes a commitment to purchase at least 12 million doses per year of the influenza vaccine provided the vaccine is approved and available for distribution in the United States by the Food and Drug Administration (“FDA”).
The Company will be required to purchase the annual doses at market prices, as adjusted for inflation and other factors.
We expect the Canadian manufacturer will receive FDA approval by the 2006/2007 influenza season; however, FDA approval may be received earlier.
If the initial year of the purchase commitment begins in fiscal 2007, then the Company anticipates its purchase commitment for that year will approximate $66 million.
The Company anticipates its total purchase commitment (assuming the commitment commences in fiscal 2007) will be approximately $1.1 billion.
The influenza vaccine commitment is included in Other Commitments in the above table.
As of September 30, 2005, the Company has $7.1 million of remaining commitments relating to the construction of one of its new distribution facilities.
This facility commitment is included in Other Commitments in the above table.
## Table 1 ##
For further discussion of the company’s gas operating revenues and its gas results, see “Results of Operations” in Item 7.
For additional segment information, see Note N to the financial statements in Item 8.
Gas Peak Demand The gas peak demand for firm sales customers in CECONY’s service area occurs during the winter heating season.
The peak day demand during the winter 2014/2015 (through February 2, 2015) occurred on January 7, 2015 when the demand reached 1,118 MDt.
The 2014/2015 peak demand included 574 MDt for CECONY’s full-service customers and 544 MDt for customers participating in its gas energy choice program.
“Design weather” for the gas system is a standard to which the actual peak demand is adjusted for evaluation and planning purposes.
The company estimates that, under design weather conditions, the 2015/2016 service area peak demand will be 1,408 MDt, including an estimated 729 MDt for its full-service customers and 679 MDt for its gas energy choice customers.
The company forecasts average annual growth of the peak gas demand over the next five years at design conditions to be approximately 2.8 percent in its service area.
The forecasted peak demand at design conditions does not include gas used by interruptible gas customers including generating stations (electricity and steam).
Gas Supply CECONY and O&R have combined their gas requirements, and contracts to meet those requirements, into a single portfolio.
The combined portfolio is administered by, and related management services are provided by, CECONY (for itself and as agent for O&R) and costs are allocated between the Utilities in accordance with provisions approved by the NYSPSC.
See Note S to the financial statements in Item 8.
Charges from suppliers for the firm purchase of gas, which are based on formulas or indexes or are subject to negotiation, are generally designed to approximate market prices.
The gas supply contracts are for various terms extending to 2016.
The Utilities have contracts with interstate pipeline companies for the purchase of firm transportation from upstream points where gas has been purchased to the Utilities’ distribution systems, and for upstream storage services.
Charges under these transportation and storage contracts are approved by the FERC.
Such contracts are for various terms extending to 2027.
The Utilities are required to pay certain fixed charges under the supply, transportation and storage contracts whether or not the contracted capacity is actually used.
These fixed charges amounted to approximately $286 million in 2014, including $246 million for CECONY.
See “Contractual Obligations” below.
In addition, the Utilities purchase gas on the spot market and contract for interruptible gas transportation.
See “Recoverable Energy Costs” in Note A to the financial statements in Item 8.
Steam Operations Steam Facilities CECONY’s capitalized costs for utility plant, net of accumulated depreciation, for its portion of the steam-electric generation facilities were $1,795 million and $1,790 million at December 31, 2014 and 2013, respectively.
CECONY generates steam at one steam-electric generating station and five steam-only generating stations and distributes steam to its customers through approximately 105 miles of transmission, distribution, and service piping.
Foreign currency translation Partially offset by: Cost reclassifications associated with the adoption of the new revenue recognition standard.
Refer to Note 2, "Revenue Recognition" within Part 2 of this Form 10-K Cost management including restructuring cost savings 2017 vs.  2016 Selling, general and administrative expenses decreased $1 million primarily due to: Lower net periodic pension and other postretirement benefit costs Lower selling and advertising costs Restructuring cost savings Partially offset by: Wage and other cost inflation Selling, general and administrative expenses from acquired businesses Foreign currency translation Other charges and other income
## Table 2 ##
Interest expense, net of Interest income Interest expense, net of Interest income increased $10 million in 2018 versus 2017 primarily due to the issuance of longterm debt in early 2018.
Interest expense, net of Interest income decreased $14 million in 2017 versus 2016 due to lower interest rate debt outstanding in 2017.  Business restructuring, net A pretax restructuring charge of $83 million was recorded in the second quarter of 2018, offset by certain changes in estimates to complete previously recorded programs of $17 million.
A pretax charge of $191 million was recorded in 2016.
Refer to Note 8, "Business Restructuring" in Item 8 of this Form 10-K for additional information.
Pension settlement charges During 2017, PPG made lump-sum payments to certain retirees who had participated in PPG's U. S.  qualified and nonqualified pension plans totaling approximately $127 million.
As the lump-sum payments were in excess of the expected 2017 service and interest costs for the affected plans, PPG remeasured the periodic benefit obligation of these plans in the period payments were made and recorded settlement charges totaling $60 million ($38 million after-tax) during 2017.
During 2016, PPG permanently transferred approximately $1.8 billion of its U. S.  and Canadian pension obligations and assets to several highly rated insurance companies.
These actions triggered remeasurement and partial settlement of certain of the Company’s defined benefit pension plans.
PPG recognized a $968 million pre-tax settlement charge in connection with these transactions.
Refer to Note 13, "Employee Benefit Plans" in Item 8 of this Form 10-K for additional information.
Other charges Other charges in 2018 and 2016 were higher than 2017 primarily due to environmental remediation charges.
These charges were principally for environmental remediation at a former chromium manufacturing plant and associated sites in New Jersey.
Refer to Note 14, "Commitments and Contingent Liabilities" in Item 8 of this Form 10-K for additional information.
Other income Other income was lower in 2018 and 2016 than in 2017 primarily due to the gain from the sale of the Mexican Plaka business of $25 million and income from a legal settlement of $18 million in 2017.
Refer to Note 3, "Acquisitions and Divestitures" in Item 8 of this Form 10-K for additional information.

<table><tr><td></td><td colspan="5"> Payments Due by Period </td></tr><tr><td></td><td> Total </td><td> Within 1 year </td><td> 1-3 years </td><td> 4-5 years </td><td> After 5 years </td></tr><tr><td>Debt, including interest payments</td><td>$1,410,053</td><td>$109,621</td><td>$104,807</td><td>$103,750</td><td>$1,091,875</td></tr><tr><td>Operating Leases</td><td>239,803</td><td>64,259</td><td>86,839</td><td>49,012</td><td>39,693</td></tr><tr><td>Other Commitments</td><td>1,272,067</td><td>47,268</td><td>218,284</td><td>262,558</td><td>743,957</td></tr><tr><td>Total</td><td>$2,921,923</td><td>$221,148</td><td>$409,930</td><td>$415,320</td><td>$1,875,525</td></tr></table>
<table><tr><td></td><td colspan="5">Year Ended December 31,</td></tr><tr><td></td><td>2010</td><td>2011</td><td> 2012</td><td>2013</td><td>2014</td></tr><tr><td> Gas Delivered ($ in millions)</td><td></td><td></td><td></td><td colspan="2"></td></tr><tr><td>Firm Sales</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Full service</td><td>$1,099</td><td>$1,048</td><td>$889</td><td>$1,059</td><td>$1,141</td></tr><tr><td>Firm transportation</td><td>347</td><td>356</td><td>380</td><td>414</td><td>453</td></tr><tr><td> Total Firm Sales</td><td>1,446</td><td>1,404</td><td>1,269</td><td>1,473</td><td>1,594</td></tr><tr><td>Interruptible Sales</td><td>72</td><td>74</td><td>39</td><td>69</td><td>91</td></tr><tr><td> Total Gas Delivered to CECONY Customers</td><td>1,518</td><td>1,478</td><td>1,308</td><td>1,542</td><td>1,685</td></tr><tr><td>Transportation of customer-owned gas</td><td></td><td></td><td></td><td colspan="2"></td></tr><tr><td>NYPA</td><td>2</td><td>2</td><td>2</td><td>2</td><td>2</td></tr><tr><td>Other (mainly generating plants and Interruptible transportation)</td><td>71</td><td>71</td><td>68</td><td>71</td><td>70</td></tr><tr><td>Off-System Sales</td><td>-</td><td>-</td><td>5</td><td>18</td><td>-</td></tr><tr><td>Other operating revenues (mainly regulatory amortizations)</td><td>-50</td><td>-30</td><td>32</td><td>-17</td><td>-36</td></tr><tr><td> Total Sales</td><td>$1,541</td><td>$1,521</td><td>$1,415</td><td>$1,616</td><td>$1,721</td></tr><tr><td> Average Revenue per Dt Sold</td><td></td><td></td><td></td><td colspan="2"></td></tr><tr><td>Residential</td><td>$19.31</td><td>$18.45</td><td>$18.14</td><td>$18.52</td><td>$16.76</td></tr><tr><td>General</td><td>$14.28</td><td>$12.96</td><td>$11.68</td><td>$12.05</td><td>$12.38</td></tr></table>
<table><tr><td></td><td></td><td>% Change</td></tr><tr><td>($ in millions, except percentages)</td><td>2018</td><td>2017</td><td>2016</td><td>2018 vs. 2017</td><td>2017 vs. 2016</td></tr><tr><td>Interest expense, net of Interest income</td><td>$95</td><td>$85</td><td>$99</td><td>11.8%</td><td>-14.1%</td></tr><tr><td>Business restructuring, net</td><td>$66</td><td>$—</td><td>$191</td><td>N/A</td><td>-100.0%</td></tr><tr><td>Pension settlement charges</td><td>$—</td><td>$60</td><td>$968</td><td>-100.0%</td><td>-93.8%</td></tr><tr><td>Other charges</td><td>$122</td><td>$74</td><td>$242</td><td>64.9%</td><td>-69.4%</td></tr><tr><td>Other income</td><td>-$114</td><td>-$150</td><td>-$127</td><td>-24.0%</td><td>18.1%</td></tr></table>

Question: what was the total pre-tax restructuring program cost in millions?
Answer: 257