Document And Entity Information
Document And Entity Information - Jun. 30, 2015 - shares | Total |
Entity Registrant Name | ALLIANT ENERGY CORP |
Entity Central Index Key | 352,541 |
Current Fiscal Year End Date | --12-31 |
Entity Filer Category | Large Accelerated Filer |
Entity Common Stock, Shares Outstanding | 113,263,624 |
Document Fiscal Year Focus | 2,015 |
Document Fiscal Period Focus | Q2 |
Document Type | 10-Q |
Amendment Flag | false |
Document Period End Date | Jun. 30, 2015 |
IPL [Member] | |
Entity Registrant Name | INTERSTATE POWER & LIGHT CO |
Entity Central Index Key | 52,485 |
Entity Filer Category | Non-accelerated Filer |
Entity Common Stock, Shares Outstanding | 13,370,788 |
WPL [Member] | |
Entity Registrant Name | WISCONSIN POWER & LIGHT CO |
Entity Central Index Key | 107,832 |
Entity Filer Category | Non-accelerated Filer |
Entity Common Stock, Shares Outstanding | 13,236,601 |
Condensed Consolidated Statemen
Condensed Consolidated Statements Of Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Utility: | ||||
Electric | $ 640.4 | $ 643.9 | $ 1,311.7 | $ 1,319.7 |
Gas | 51.7 | 76.9 | 250.1 | 317.6 |
Other | 14.8 | 15.6 | 31.2 | 38.4 |
Non-regulated | 10.3 | 13.9 | 21.6 | 27.4 |
Total operating revenues | 717.2 | 750.3 | 1,614.6 | 1,703.1 |
Utility: | ||||
Electric production fuel and purchased power | 185.2 | 214.1 | 401.1 | 452.8 |
Electric transmission service | 116.9 | 105.5 | 240.1 | 219.6 |
Cost of gas sold | 21.9 | 45 | 152.7 | 206.9 |
Other operation and maintenance | 157.3 | 160.7 | 303.9 | 321.7 |
Non-regulated operation and maintenance | 0 | 1.8 | 1.3 | 3.1 |
Depreciation and amortization | 100.4 | 95.8 | 200.6 | 191.3 |
Taxes other than income taxes | 26.5 | 24.1 | 53 | 50.2 |
Total operating expenses | 608.2 | 647 | 1,352.7 | 1,445.6 |
Operating income | 109 | 103.3 | 261.9 | 257.5 |
Interest expense and other: | ||||
Interest expense | 46.5 | 45.1 | 93.1 | 90.3 |
Equity income from unconsolidated investments, net | (11.3) | (11.3) | (17.8) | (22.7) |
Allowance for funds used during construction | (8.6) | (8.4) | (15.4) | (17.5) |
Interest income and other | (0.2) | 0.1 | (0.3) | (1.6) |
Total interest expense and other | 26.4 | 25.5 | 59.6 | 48.5 |
Income from continuing operations before income taxes | 82.6 | 77.8 | 202.3 | 209 |
Income tax expense (benefit) | 11.2 | 13.2 | 31.7 | 33.8 |
Income from continuing operations, net of tax | 71.4 | 64.6 | 170.6 | 175.2 |
Loss from discontinued operations, net of tax | (1.3) | (0.3) | (1.3) | (0.3) |
Net income (loss) | 70.1 | 64.3 | 169.3 | 174.9 |
Preferred dividend requirements of IPL | 2.5 | 2.5 | 5.1 | 5.1 |
Net income (loss) attributable to common shareowners | $ 67.6 | $ 61.8 | $ 164.2 | $ 169.8 |
Weighted average number of common shares outstanding (basic and diluted) (in shares) | 113.1 | 110.8 | 112.1 | 110.8 |
Earnings per weighted average common share attributable to Alliant Energy common shareowners (basic and diluted): | ||||
Income from continuing operations, net of tax (in dollars per share) | $ 0.61 | $ 0.56 | $ 1.47 | $ 1.53 |
Loss from discontinued operations, net of tax (in dollars per share) | (0.01) | 0 | (0.01) | 0 |
Net income (in dollars per share) | $ 0.60 | $ 0.56 | $ 1.46 | $ 1.53 |
Amounts attributable to common shareowners: | ||||
Income from continuing operations, net of tax | $ 68.9 | $ 62.1 | $ 165.5 | $ 170.1 |
Loss from discontinued operations, net of tax | (1.3) | (0.3) | (1.3) | (0.3) |
Net income (loss) attributable to common shareowners | $ 67.6 | $ 61.8 | $ 164.2 | $ 169.8 |
Dividends declared per common share (in dollars per share) | $ 0.55 | $ 0.51 | $ 1.10 | $ 1.02 |
IPL [Member] | ||||
Utility: | ||||
Electric | $ 339.4 | $ 354.6 | $ 702 | $ 728.8 |
Gas | 29.8 | 43.7 | 141 | 179.4 |
Other | 13 | 13.6 | 28.2 | 32.6 |
Total operating revenues | 382.2 | 411.9 | 871.2 | 940.8 |
Utility: | ||||
Electric production fuel and purchased power | 90.5 | 122.9 | 200.6 | 262.9 |
Electric transmission service | 77.9 | 75.4 | 161.8 | 159 |
Cost of gas sold | 13 | 25.7 | 84 | 113.8 |
Other operation and maintenance | 100.6 | 92.1 | 193.2 | 189.3 |
Depreciation and amortization | 52.1 | 48.9 | 103.9 | 97.6 |
Taxes other than income taxes | 14.3 | 12.9 | 28.4 | 26.7 |
Total operating expenses | 348.4 | 377.9 | 771.9 | 849.3 |
Operating income | 33.8 | 34 | 99.3 | 91.5 |
Interest expense and other: | ||||
Interest expense | 23.9 | 22.6 | 48 | 45.1 |
Allowance for funds used during construction | (6.7) | (6) | (12) | (12) |
Interest income and other | 0 | (0.1) | (0.1) | (0.1) |
Total interest expense and other | 17.2 | 16.5 | 35.9 | 33 |
Income from continuing operations before income taxes | 16.6 | 17.5 | 63.4 | 58.5 |
Income tax expense (benefit) | (2.6) | (3.4) | (6.2) | (8.4) |
Net income (loss) | 19.2 | 20.9 | 69.6 | 66.9 |
Preferred dividend requirements of IPL | 2.5 | 2.5 | 5.1 | 5.1 |
Net income (loss) attributable to common shareowners | 16.7 | 18.4 | 64.5 | 61.8 |
Amounts attributable to common shareowners: | ||||
Net income (loss) attributable to common shareowners | 16.7 | 18.4 | 64.5 | 61.8 |
WPL [Member] | ||||
Utility: | ||||
Electric | 301 | 289.3 | 609.7 | 590.9 |
Gas | 21.9 | 33.2 | 109.1 | 138.2 |
Other | 1.8 | 2 | 3 | 5.8 |
Total operating revenues | 324.7 | 324.5 | 721.8 | 734.9 |
Utility: | ||||
Electric production fuel and purchased power | 94.7 | 91.2 | 200.5 | 189.9 |
Electric transmission service | 39 | 30.1 | 78.3 | 60.6 |
Cost of gas sold | 8.9 | 19.3 | 68.7 | 93.1 |
Other operation and maintenance | 56.7 | 68.6 | 110.7 | 132.4 |
Depreciation and amortization | 45.8 | 44.7 | 91.8 | 89.4 |
Taxes other than income taxes | 11.3 | 10.6 | 22.7 | 21.8 |
Total operating expenses | 256.4 | 264.5 | 572.7 | 587.2 |
Operating income | 68.3 | 60 | 149.1 | 147.7 |
Interest expense and other: | ||||
Interest expense | 23.3 | 21.1 | 46.4 | 42.2 |
Equity income from unconsolidated investments, net | (11.3) | (11.4) | (19.1) | (22.8) |
Allowance for funds used during construction | (1.9) | (2.4) | (3.4) | (5.5) |
Interest income and other | (0.1) | 0.3 | 0 | 0.3 |
Total interest expense and other | 10 | 7.6 | 23.9 | 14.2 |
Income from continuing operations before income taxes | 58.3 | 52.4 | 125.2 | 133.5 |
Income tax expense (benefit) | 18.8 | 17.8 | 40.9 | 44.1 |
Net income (loss) | 39.5 | 34.6 | 84.3 | 89.4 |
Net income attributable to noncontrolling interest | 0.5 | 0 | 0.7 | 0 |
Net income (loss) attributable to common shareowners | 39 | 34.6 | 83.6 | 89.4 |
Amounts attributable to common shareowners: | ||||
Net income (loss) attributable to common shareowners | $ 39 | $ 34.6 | $ 83.6 | $ 89.4 |
Condensed Consolidated Balance
Condensed Consolidated Balance Sheets - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Current assets: | ||
Cash and cash equivalents | $ 54.8 | $ 56.9 |
Accounts receivable, less allowance for doubtful accounts | 297.3 | 427.3 |
Production fuel, at weighted average cost | 78.8 | 83.8 |
Materials and supplies, at weighted average cost | 82.3 | 72.9 |
Gas stored underground, at weighted average cost | 24.1 | 67.1 |
Regulatory assets | 71.1 | 68.1 |
Other | 435.5 | 267 |
Total current assets | 1,043.9 | 1,043.1 |
Property, plant and equipment, net | 9,173.5 | 8,938.4 |
Investments: | ||
Investment in American Transmission Company LLC | 293.5 | 286.5 |
Other | 56.4 | 58.4 |
Total investments | 349.9 | 344.9 |
Other assets: | ||
Regulatory assets | 1,706.8 | 1,715.6 |
Deferred charges and other | 38.2 | 43.9 |
Total other assets | 1,745 | 1,759.5 |
Total assets | 12,312.3 | 12,085.9 |
Current liabilities: | ||
Current maturities of long-term debt | 33.5 | 183 |
Commercial paper | 120.9 | 141.3 |
Accounts payable | 374.9 | 427.9 |
Regulatory liabilities | 197.7 | 200.1 |
Other | 264.5 | 262.4 |
Total current liabilities | 991.5 | 1,214.7 |
Long-term debt, net (excluding current portion) | 3,717.4 | 3,606.7 |
Other liabilities: | ||
Deferred income tax liabilities | 2,449.1 | 2,321.1 |
Regulatory liabilities | 572.4 | 621.1 |
Pension and other benefit obligations | 417.4 | 421.7 |
Other | 342.8 | 260.1 |
Total other liabilities | $ 3,781.7 | $ 3,624 |
Commitments and contingencies (Note 13) | ||
Common equity: | ||
Common stock | $ 1.1 | $ 1.1 |
Additional paid-in capital | 1,649 | 1,509.1 |
Retained earnings | 1,979.3 | 1,938 |
Accumulated other comprehensive loss | (0.6) | (0.6) |
Shares in deferred compensation trust - 206,419 and 238,935 shares at a weighted average cost of $38.82 and $37.45 per share | (8) | (8.9) |
Total common equity | 3,620.8 | 3,438.7 |
Cumulative preferred stock of Interstate Power and Light Company | 200 | 200 |
Noncontrolling interest | 0.9 | 1.8 |
Total equity | 3,821.7 | 3,640.5 |
Total liabilities and equity | 12,312.3 | 12,085.9 |
IPL [Member] | ||
Current assets: | ||
Cash and cash equivalents | 2 | 5.3 |
Accounts receivable, less allowance for doubtful accounts | 104.2 | 216.7 |
Production fuel, at weighted average cost | 44.9 | 52.7 |
Materials and supplies, at weighted average cost | 47.5 | 42 |
Gas stored underground, at weighted average cost | 8.2 | 30.8 |
Regulatory assets | 28 | 38.7 |
Other | 308.1 | 169.9 |
Total current assets | 542.9 | 556.1 |
Property, plant and equipment, net | 4,687.8 | 4,554.7 |
Investments: | ||
Total investments | 19.5 | 19.1 |
Other assets: | ||
Regulatory assets | 1,322.7 | 1,319.2 |
Deferred charges and other | 15 | 12.7 |
Total other assets | 1,337.7 | 1,331.9 |
Total assets | 6,587.9 | 6,461.8 |
Current liabilities: | ||
Current maturities of long-term debt | 0 | 150 |
Commercial paper | 0 | |
Accounts payable | 222.1 | 259.6 |
Accounts payable to associated companies | 43.6 | 31.3 |
Regulatory liabilities | 129.5 | 129.7 |
Other | 148 | 135.3 |
Total current liabilities | 543.2 | 705.9 |
Long-term debt, net (excluding current portion) | 1,730.2 | 1,618.7 |
Other liabilities: | ||
Deferred income tax liabilities | 1,418.8 | 1,341.4 |
Regulatory liabilities | 402.5 | 453.8 |
Pension and other benefit obligations | 141.5 | 142.4 |
Other | 243 | 185.5 |
Total other liabilities | $ 2,205.8 | $ 2,123.1 |
Commitments and contingencies (Note 13) | ||
Common equity: | ||
Common stock | $ 33.4 | $ 33.4 |
Additional paid-in capital | 1,342.8 | 1,242.8 |
Retained earnings | 532.5 | 537.9 |
Total common equity | 1,908.7 | 1,814.1 |
Cumulative preferred stock of Interstate Power and Light Company | 200 | 200 |
Total equity | 2,108.7 | 2,014.1 |
Total liabilities and equity | 6,587.9 | 6,461.8 |
WPL [Member] | ||
Current assets: | ||
Cash and cash equivalents | 48.8 | 46.7 |
Accounts receivable, less allowance for doubtful accounts | 166.6 | 185.8 |
Production fuel, at weighted average cost | 33.9 | 31.1 |
Materials and supplies, at weighted average cost | 32.8 | 29.2 |
Gas stored underground, at weighted average cost | 15.9 | 36.3 |
Regulatory assets | 43.1 | 29.4 |
Deferred income tax assets | 61 | 37.5 |
Other | 51.9 | 61.2 |
Total current assets | 454 | 457.2 |
Property, plant and equipment, net | 4,028.4 | 3,938.9 |
Investments: | ||
Investment in American Transmission Company LLC | 293.5 | 286.5 |
Other | 19 | 19.5 |
Total investments | 312.5 | 306 |
Other assets: | ||
Regulatory assets | 384.1 | 396.4 |
Deferred charges and other | 23.8 | 29.7 |
Total other assets | 407.9 | 426.1 |
Total assets | 5,202.8 | 5,128.2 |
Current liabilities: | ||
Current maturities of long-term debt | 30.6 | 30.6 |
Commercial paper | 0 | |
Accounts payable | 98 | 112.9 |
Accounts payable to associated companies | 18 | 25.5 |
Regulatory liabilities | 68.2 | 70.4 |
Other | 82.4 | 70.9 |
Total current liabilities | 297.2 | 310.3 |
Long-term debt, net (excluding current portion) | 1,543.5 | 1,543.3 |
Other liabilities: | ||
Deferred income tax liabilities | 1,014.9 | 970 |
Regulatory liabilities | 169.9 | 167.3 |
Capital lease obligations - Sheboygan Falls Energy Facility | 86.6 | 89.4 |
Pension and other benefit obligations | 179 | 180.4 |
Other | 177.9 | 155.2 |
Total other liabilities | $ 1,628.3 | $ 1,562.3 |
Commitments and contingencies (Note 13) | ||
Common equity: | ||
Common stock | $ 66.2 | $ 66.2 |
Additional paid-in capital | 959 | 959 |
Retained earnings | 698.7 | 678.6 |
Total common equity | 1,723.9 | 1,703.8 |
Noncontrolling interest | 9.9 | 8.5 |
Total equity | 1,733.8 | 1,712.3 |
Total liabilities and equity | $ 5,202.8 | $ 5,128.2 |
Condensed Consolidated Balance4
Condensed Consolidated Balance Sheets (Parenthetical) - $ / shares | Jun. 30, 2015 | Dec. 31, 2014 |
Common stock, par value | $ 0.01 | $ 0.01 |
Common stock, shares authorized (in shares) | 240,000,000 | 240,000,000 |
Common stock, shares outstanding (in shares) | 113,263,624 | 110,935,680 |
Shares in deferred compensation trust (in shares) | 206,419 | 238,935 |
Shares in deferred compensation trust, weighted average cost per share (in dollars per share) | $ 38.82 | $ 37.45 |
IPL [Member] | ||
Common stock, par value | $ 2.50 | $ 2.50 |
Common stock, shares authorized (in shares) | 24,000,000 | 24,000,000 |
Common stock, shares outstanding (in shares) | 13,370,788 | 13,370,788 |
WPL [Member] | ||
Common stock, par value | $ 5 | $ 5 |
Common stock, shares authorized (in shares) | 18,000,000 | 18,000,000 |
Common stock, shares outstanding (in shares) | 13,236,601 | 13,236,601 |
Condensed Consolidated Stateme5
Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2015 | Jun. 30, 2014 | |
Cash flows from operating activities: | ||
Net income | $ 169.3 | $ 174.9 |
Adjustments to reconcile net income to net cash flows from operating activities: | ||
Depreciation and amortization | 200.6 | 191.3 |
Deferred tax expense and investment tax credits | 43 | 37.3 |
Other | 3.5 | 11.7 |
Other changes in assets and liabilities: | ||
Accounts receivable | 33.7 | 47.6 |
Sales of accounts receivable | 78 | (19) |
Regulatory assets | (22.7) | (71.6) |
Derivative assets | 3.6 | (92.3) |
Accounts payable | (25.3) | 35.8 |
Regulatory liabilities | (40) | 45.2 |
Deferred income taxes | 48 | 51.5 |
Other | 25.6 | 35.8 |
Net cash flows from operating activities | 517.3 | 448.2 |
Cash flows used for investing activities: | ||
Utility construction and acquisition expenditures | (436.2) | (332.6) |
Alliant Energy Corporate Services, Inc. and non-regulated businesses construction and acquisition expenditures | (32.2) | (31.9) |
Other | (1.9) | (4.5) |
Net cash flows used for investing activities | (470.3) | (369) |
Cash flows used for financing activities: | ||
Common stock dividends | (122.9) | (112.9) |
Proceeds from issuance of common stock, net | 139.5 | 0 |
Payments to retire long-term debt | (151.4) | (0.8) |
Net change in commercial paper | 90.8 | 28.5 |
Other | (5.1) | 12.4 |
Net cash flows used for financing activities | (49.1) | (72.8) |
Net increase (decrease) in cash and cash equivalents | (2.1) | 6.4 |
Cash and cash equivalents at beginning of period | 56.9 | 9.8 |
Cash and cash equivalents at end of period | 54.8 | 16.2 |
Supplemental cash flows information: | ||
Interest, net of capitalized interest | (93.5) | (90.5) |
Income taxes, net | 0.1 | 3.8 |
Significant non-cash investing and financing activities: | ||
Accrued capital expenditures | 162.1 | 124.9 |
IPL [Member] | ||
Cash flows from operating activities: | ||
Net income | 69.6 | 66.9 |
Adjustments to reconcile net income to net cash flows from operating activities: | ||
Depreciation and amortization | 103.9 | 97.6 |
Other | 24.9 | (4) |
Other changes in assets and liabilities: | ||
Accounts receivable | 16.9 | 48.3 |
Sales of accounts receivable | 78 | (19) |
Gas stored underground | 23.6 | 7.5 |
Regulatory assets | (20) | (48.5) |
Derivative assets | (2.7) | (51.9) |
Accounts payable | (22) | 23.4 |
Regulatory liabilities | (38.9) | (2.7) |
Deferred income taxes | 44.7 | 54.7 |
Other | 16.5 | 33.8 |
Net cash flows from operating activities | 294.5 | 206.1 |
Cash flows used for investing activities: | ||
Utility construction and acquisition expenditures | (281.3) | (184.9) |
Other | (3.9) | (11.5) |
Net cash flows used for investing activities | (285.2) | (196.4) |
Cash flows used for financing activities: | ||
Common stock dividends | (69.9) | (70) |
Capital contributions from parent | 100 | 60 |
Payments to retire long-term debt | (150) | 0 |
Net change in commercial paper | 111.2 | 0 |
Other | (3.9) | 1.3 |
Net cash flows used for financing activities | (12.6) | (8.7) |
Net increase (decrease) in cash and cash equivalents | (3.3) | 1 |
Cash and cash equivalents at beginning of period | 5.3 | 4.4 |
Cash and cash equivalents at end of period | 2 | 5.4 |
Supplemental cash flows information: | ||
Interest, net of capitalized interest | (48.3) | (45.2) |
Income taxes, net | 18.6 | 9 |
Significant non-cash investing and financing activities: | ||
Accrued capital expenditures | 118.8 | 76.1 |
WPL [Member] | ||
Cash flows from operating activities: | ||
Net income | 84.3 | 89.4 |
Adjustments to reconcile net income to net cash flows from operating activities: | ||
Depreciation and amortization | 91.8 | 89.4 |
Other amortizations | 2.7 | 24.9 |
Deferred tax expense and investment tax credits | 20.4 | 37.1 |
Other | (8.1) | (8.1) |
Other changes in assets and liabilities: | ||
Regulatory assets | (2.7) | (23.1) |
Derivative assets | 6.3 | (40.4) |
Regulatory liabilities | (1.1) | 47.9 |
Other | 36.6 | 18.4 |
Net cash flows from operating activities | 230.2 | 235.5 |
Cash flows used for investing activities: | ||
Utility construction and acquisition expenditures | (154.9) | (147.7) |
Other | (7.1) | (3.4) |
Net cash flows used for investing activities | (162) | (151.1) |
Cash flows used for financing activities: | ||
Common stock dividends | (63.5) | (59.4) |
Net change in commercial paper | 0 | (25.7) |
Other | (2.6) | 6.6 |
Net cash flows used for financing activities | (66.1) | (78.5) |
Net increase (decrease) in cash and cash equivalents | 2.1 | 5.9 |
Cash and cash equivalents at beginning of period | 46.7 | 0.5 |
Cash and cash equivalents at end of period | 48.8 | 6.4 |
Supplemental cash flows information: | ||
Interest, net of capitalized interest | (46.5) | (42.2) |
Income taxes, net | (3.7) | (9.4) |
Significant non-cash investing and financing activities: | ||
Accrued capital expenditures | $ 39.5 | $ 46.7 |
Summary Of Significant Accounti
Summary Of Significant Accounting Policies | 6 Months Ended |
Jun. 30, 2015 | |
Summary Of Significant Accounting Policies | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (a) General - The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. As discussed in Note 16 , IPL’s Minnesota electric distribution assets qualified as held for sale as of June 30, 2015. (b) New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
IPL [Member] | |
Summary Of Significant Accounting Policies | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (a) General - The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. As discussed in Note 16 , IPL’s Minnesota electric distribution assets qualified as held for sale as of June 30, 2015. (b) New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
WPL [Member] | |
Summary Of Significant Accounting Policies | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (a) General - The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. As discussed in Note 16 , IPL’s Minnesota electric distribution assets qualified as held for sale as of June 30, 2015. (b) New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
Regulatory Matters
Regulatory Matters | 6 Months Ended |
Jun. 30, 2015 | |
Regulatory Matters [Line Items] | |
Regulatory Matters | REGULATORY MATTERS Regulatory Assets and Regulatory Liabilities - Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 Tax-related - Alliant Energy’s and IPL’s tax-related regulatory assets are generally impacted by certain property-related differences at IPL for which deferred tax is not recorded in the income statement pursuant to Iowa rate-making principles. Deferred tax amounts for such property-related differences at IPL are recorded to regulatory assets, along with the necessary revenue requirement tax gross-ups. During the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s tax-related regulatory assets increased primarily due to property-related differences for qualifying repair expenditures. Certain tax-related regulatory assets associated with IPL’s Minnesota electric distribution assets were classified as held for sale as of June 30, 2015 on Alliant Energy’s and IPL’s balance sheets. Derivatives - Refer to Note 12 for discussion of derivative assets and derivative liabilities. IPL’s tax benefit riders - IPL’s tax benefit riders utilize regulatory liabilities to credit bills of IPL’s Iowa retail electric and gas customers to help offset the impact of rate increases on such customers. These regulatory liabilities are related to tax benefits from tax accounting method changes for repairs expenditures, allocation of mixed service costs, allocation of insurance proceeds from floods in 2008, and cost of removal expenditures. For the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by $41 million as follows (in millions): Electric tax benefit rider credits $35 Gas tax benefit rider credits 6 $41 Refer to Note 8 for additional details regarding IPL’s tax benefit riders. Utility Rate Cases - IPL’s Iowa Retail Electric Rate Settlement Agreement - The IUB approved a settlement agreement in 2014 related to rates charged to IPL’s Iowa retail electric customers. The settlement agreement extends IPL’s Iowa retail electric base rates authorized in its 2009 Test Year rate case through 2016 and provides targeted retail electric customer billing credits beginning May 2014. For the three and six months ended June 30 , IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Billing credits to reduce retail electric customers’ bills $6 $20 $12 $20 WPL’s Retail Fuel-related Rate Filing (2016 Test Year) - In July 2015, WPL filed a request with the PSCW to increase annual rates for WPL’s retail electric customers by $15 million , or approximately 1% , in 2016. The increase reflects anticipated increases in retail electric fuel-related costs in 2016. Any rate changes granted from this request are expected to be effective on January 1, 2016. WPL currently expects a decision from the PSCW regarding this rate filing by the end of 2015. WPL’s Retail Fuel-related Rate Filing (2014 Test Year) - Pursuant to a 2013 PSCW order, WPL’s 2014 fuel-related costs were subject to deferral since they were outside an annual bandwidth of plus or minus 2% of the approved annual forecasted fuel-related costs. Retail fuel-related costs incurred by WPL through December 31, 2014 were higher than fuel-related costs used to determine rates for such period resulting in an under-collection of fuel-related costs for 2014 of $33 million (including $28 million outside the approved range for 2014). The $28 million of deferred fuel-related costs is included in “Commodity cost recovery” in Alliant Energy’s and WPL’s regulatory assets table above. In July 2015, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $28 million , or approximately 3% , effective January 1, 2016 to recover the 2014 Test Year deferred fuel-related costs. |
IPL [Member] | |
Regulatory Matters [Line Items] | |
Regulatory Matters | REGULATORY MATTERS Regulatory Assets and Regulatory Liabilities - Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 Tax-related - Alliant Energy’s and IPL’s tax-related regulatory assets are generally impacted by certain property-related differences at IPL for which deferred tax is not recorded in the income statement pursuant to Iowa rate-making principles. Deferred tax amounts for such property-related differences at IPL are recorded to regulatory assets, along with the necessary revenue requirement tax gross-ups. During the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s tax-related regulatory assets increased primarily due to property-related differences for qualifying repair expenditures. Certain tax-related regulatory assets associated with IPL’s Minnesota electric distribution assets were classified as held for sale as of June 30, 2015 on Alliant Energy’s and IPL’s balance sheets. Derivatives - Refer to Note 12 for discussion of derivative assets and derivative liabilities. IPL’s tax benefit riders - IPL’s tax benefit riders utilize regulatory liabilities to credit bills of IPL’s Iowa retail electric and gas customers to help offset the impact of rate increases on such customers. These regulatory liabilities are related to tax benefits from tax accounting method changes for repairs expenditures, allocation of mixed service costs, allocation of insurance proceeds from floods in 2008, and cost of removal expenditures. For the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by $41 million as follows (in millions): Electric tax benefit rider credits $35 Gas tax benefit rider credits 6 $41 Refer to Note 8 for additional details regarding IPL’s tax benefit riders. Utility Rate Cases - IPL’s Iowa Retail Electric Rate Settlement Agreement - The IUB approved a settlement agreement in 2014 related to rates charged to IPL’s Iowa retail electric customers. The settlement agreement extends IPL’s Iowa retail electric base rates authorized in its 2009 Test Year rate case through 2016 and provides targeted retail electric customer billing credits beginning May 2014. For the three and six months ended June 30 , IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Billing credits to reduce retail electric customers’ bills $6 $20 $12 $20 WPL’s Retail Fuel-related Rate Filing (2016 Test Year) - In July 2015, WPL filed a request with the PSCW to increase annual rates for WPL’s retail electric customers by $15 million , or approximately 1% , in 2016. The increase reflects anticipated increases in retail electric fuel-related costs in 2016. Any rate changes granted from this request are expected to be effective on January 1, 2016. WPL currently expects a decision from the PSCW regarding this rate filing by the end of 2015. WPL’s Retail Fuel-related Rate Filing (2014 Test Year) - Pursuant to a 2013 PSCW order, WPL’s 2014 fuel-related costs were subject to deferral since they were outside an annual bandwidth of plus or minus 2% of the approved annual forecasted fuel-related costs. Retail fuel-related costs incurred by WPL through December 31, 2014 were higher than fuel-related costs used to determine rates for such period resulting in an under-collection of fuel-related costs for 2014 of $33 million (including $28 million outside the approved range for 2014). The $28 million of deferred fuel-related costs is included in “Commodity cost recovery” in Alliant Energy’s and WPL’s regulatory assets table above. In July 2015, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $28 million , or approximately 3% , effective January 1, 2016 to recover the 2014 Test Year deferred fuel-related costs. |
WPL [Member] | |
Regulatory Matters [Line Items] | |
Regulatory Matters | REGULATORY MATTERS Regulatory Assets and Regulatory Liabilities - Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 Tax-related - Alliant Energy’s and IPL’s tax-related regulatory assets are generally impacted by certain property-related differences at IPL for which deferred tax is not recorded in the income statement pursuant to Iowa rate-making principles. Deferred tax amounts for such property-related differences at IPL are recorded to regulatory assets, along with the necessary revenue requirement tax gross-ups. During the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s tax-related regulatory assets increased primarily due to property-related differences for qualifying repair expenditures. Certain tax-related regulatory assets associated with IPL’s Minnesota electric distribution assets were classified as held for sale as of June 30, 2015 on Alliant Energy’s and IPL’s balance sheets. Derivatives - Refer to Note 12 for discussion of derivative assets and derivative liabilities. IPL’s tax benefit riders - IPL’s tax benefit riders utilize regulatory liabilities to credit bills of IPL’s Iowa retail electric and gas customers to help offset the impact of rate increases on such customers. These regulatory liabilities are related to tax benefits from tax accounting method changes for repairs expenditures, allocation of mixed service costs, allocation of insurance proceeds from floods in 2008, and cost of removal expenditures. For the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by $41 million as follows (in millions): Electric tax benefit rider credits $35 Gas tax benefit rider credits 6 $41 Refer to Note 8 for additional details regarding IPL’s tax benefit riders. Utility Rate Cases - IPL’s Iowa Retail Electric Rate Settlement Agreement - The IUB approved a settlement agreement in 2014 related to rates charged to IPL’s Iowa retail electric customers. The settlement agreement extends IPL’s Iowa retail electric base rates authorized in its 2009 Test Year rate case through 2016 and provides targeted retail electric customer billing credits beginning May 2014. For the three and six months ended June 30 , IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Billing credits to reduce retail electric customers’ bills $6 $20 $12 $20 WPL’s Retail Fuel-related Rate Filing (2016 Test Year) - In July 2015, WPL filed a request with the PSCW to increase annual rates for WPL’s retail electric customers by $15 million , or approximately 1% , in 2016. The increase reflects anticipated increases in retail electric fuel-related costs in 2016. Any rate changes granted from this request are expected to be effective on January 1, 2016. WPL currently expects a decision from the PSCW regarding this rate filing by the end of 2015. WPL’s Retail Fuel-related Rate Filing (2014 Test Year) - Pursuant to a 2013 PSCW order, WPL’s 2014 fuel-related costs were subject to deferral since they were outside an annual bandwidth of plus or minus 2% of the approved annual forecasted fuel-related costs. Retail fuel-related costs incurred by WPL through December 31, 2014 were higher than fuel-related costs used to determine rates for such period resulting in an under-collection of fuel-related costs for 2014 of $33 million (including $28 million outside the approved range for 2014). The $28 million of deferred fuel-related costs is included in “Commodity cost recovery” in Alliant Energy’s and WPL’s regulatory assets table above. In July 2015, WPL received an order from the PSCW authorizing an annual retail electric rate increase of $28 million , or approximately 3% , effective January 1, 2016 to recover the 2014 Test Year deferred fuel-related costs. |
Property, Plant and Equipment
Property, Plant and Equipment | 6 Months Ended |
Jun. 30, 2015 | |
Property, Plant and Equipment [Line Items] | |
Property, Plant and Equipment | PROPERTY, PLANT AND EQUIPMENT Utility - Emission Controls Project - WPL’s Edgewater Unit 5 - WPL is currently constructing a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions at the EGU. Construction began in 2014 and is expected to be completed in 2016. As of June 30, 2015 , Alliant Energy and WPL recorded capitalized expenditures for construction work in progress of $132 million and AFUDC of $5 million for the scrubber and baghouse in “Property, plant and equipment, net” on their balance sheets. Natural Gas-Fired Generation Project - IPL’s Marshalltown Generating Station - IPL is currently constructing Marshalltown, an approximate 650 MW natural gas-fired combined-cycle EGU. Construction began in 2014 and is expected to be completed in 2017. As of June 30, 2015 , Alliant Energy and IPL recorded capitalized expenditures for construction work in progress of $343 million and AFUDC of $12 million for Marshalltown in “Property, plant and equipment, net” on their balance sheets. Sales of IPL’s Minnesota Electric and Natural Gas Distribution Assets - In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets and received proceeds of $11 million and a promissory note of $2 million . In July 2015, IPL completed the sale of its Minnesota electric distribution assets and received proceeds of $127 million , which were used to reduce cash proceeds received from IPL’s sales of accounts receivable program. Final proceeds are subject to post-closing adjustments based on the value of the net assets as of the closing date and are expected to be approximately $130 million . The premium received over the book value of the property, plant and equipment sold was more than offset by tax-related regulatory assets associated with the distribution assets. As a result, Alliant Energy and IPL recorded pre-tax charges of $9 million and $3 million for the Minnesota electric and natural gas distribution asset transactions, respectively, in “Utility - Other operation and maintenance” in their income statements for the three and six months ended June 30, 2015. Refer to Note 16 for details of the Minnesota electric distribution assets, which qualified as held for sale as of June 30, 2015. In July 2015, FERC approved the wholesale power supply agreement between IPL and Southern Minnesota Energy Cooperative, which became effective upon the sale of IPL’s Minnesota electric distribution assets. Non-regulated and Other - Corporate Services and Other - Corporate Services is implementing a new customer billing and information system for IPL and WPL, which is currently expected to be placed in service by the end of the first quarter of 2016. As of June 30, 2015 , Alliant Energy recorded capitalized expenditures of $79 million and capitalized interest of $2 million for the system in “Property, plant and equipment, net” on its balance sheet. |
IPL [Member] | |
Property, Plant and Equipment [Line Items] | |
Property, Plant and Equipment | PROPERTY, PLANT AND EQUIPMENT Utility - Emission Controls Project - WPL’s Edgewater Unit 5 - WPL is currently constructing a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions at the EGU. Construction began in 2014 and is expected to be completed in 2016. As of June 30, 2015 , Alliant Energy and WPL recorded capitalized expenditures for construction work in progress of $132 million and AFUDC of $5 million for the scrubber and baghouse in “Property, plant and equipment, net” on their balance sheets. Natural Gas-Fired Generation Project - IPL’s Marshalltown Generating Station - IPL is currently constructing Marshalltown, an approximate 650 MW natural gas-fired combined-cycle EGU. Construction began in 2014 and is expected to be completed in 2017. As of June 30, 2015 , Alliant Energy and IPL recorded capitalized expenditures for construction work in progress of $343 million and AFUDC of $12 million for Marshalltown in “Property, plant and equipment, net” on their balance sheets. Sales of IPL’s Minnesota Electric and Natural Gas Distribution Assets - In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets and received proceeds of $11 million and a promissory note of $2 million . In July 2015, IPL completed the sale of its Minnesota electric distribution assets and received proceeds of $127 million , which were used to reduce cash proceeds received from IPL’s sales of accounts receivable program. Final proceeds are subject to post-closing adjustments based on the value of the net assets as of the closing date and are expected to be approximately $130 million . The premium received over the book value of the property, plant and equipment sold was more than offset by tax-related regulatory assets associated with the distribution assets. As a result, Alliant Energy and IPL recorded pre-tax charges of $9 million and $3 million for the Minnesota electric and natural gas distribution asset transactions, respectively, in “Utility - Other operation and maintenance” in their income statements for the three and six months ended June 30, 2015. Refer to Note 16 for details of the Minnesota electric distribution assets, which qualified as held for sale as of June 30, 2015. In July 2015, FERC approved the wholesale power supply agreement between IPL and Southern Minnesota Energy Cooperative, which became effective upon the sale of IPL’s Minnesota electric distribution assets. |
WPL [Member] | |
Property, Plant and Equipment [Line Items] | |
Property, Plant and Equipment | PROPERTY, PLANT AND EQUIPMENT Utility - Emission Controls Project - WPL’s Edgewater Unit 5 - WPL is currently constructing a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions at the EGU. Construction began in 2014 and is expected to be completed in 2016. As of June 30, 2015 , Alliant Energy and WPL recorded capitalized expenditures for construction work in progress of $132 million and AFUDC of $5 million for the scrubber and baghouse in “Property, plant and equipment, net” on their balance sheets. |
Receivables
Receivables | 6 Months Ended |
Jun. 30, 2015 | |
Receivables [Line Items] | |
Receivables | RECEIVABLES (a) Sales of Accounts Receivable - IPL maintains a Receivables Agreement whereby it may sell its Iowa customer accounts receivables, unbilled revenues and certain other accounts receivables to a third party through wholly-owned and consolidated special purpose entities. The transfers of receivables meet the criteria for sale accounting established by the transfer of financial assets accounting rules. As of June 30, 2015 , IPL sold $177.8 million of receivables to the third party, received $100.0 million in cash proceeds and recorded deferred proceeds of $73.4 million . IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Maximum outstanding aggregate cash proceeds (based on daily outstanding balances) $125.0 $75.0 $125.0 $75.0 Average outstanding aggregate cash proceeds (based on daily outstanding balances) 77.3 34.2 72.7 30.9 For the three and six months ended June 30 , 2015 and 2014 , IPL’s costs incurred related to the sales of accounts receivable program were not material. The attributes of IPL’s receivables sold under the Receivables Agreement were as follows (in millions): June 30, 2015 December 31, 2014 Customer accounts receivable $100.4 $134.8 Unbilled utility revenues 77.2 69.7 Other receivables 0.2 0.1 Receivables sold to third party 177.8 204.6 Less: cash proceeds (a) 100.0 22.0 Deferred proceeds 77.8 182.6 Less: allowance for doubtful accounts 4.4 5.4 Fair value of deferred proceeds $73.4 $177.2 Outstanding receivables past due $14.0 $19.9 (a) Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Collections reinvested in receivables $417.1 $475.8 $923.0 $1,017.2 Credit losses, net of recoveries 2.5 3.9 3.5 6.4 (b) Whiting Petroleum Tax Sharing Agreement - Prior to an initial public offering of Whiting Petroleum in 2003, Alliant Energy and Whiting Petroleum entered into a tax separation and indemnification agreement pursuant to which Alliant Energy and Whiting Petroleum made certain tax elections. These tax elections had the effect of increasing the tax basis of the assets of Whiting Petroleum’s consolidated tax group based on the sales price of Whiting Petroleum’s shares in the initial public offering. The increase in the tax basis of the assets was included in income in Alliant Energy’s U.S. federal income tax return for the calendar year 2003. Pursuant to the tax separation and indemnification agreement, Whiting Petroleum paid Resources the final payment of $26 million in March 2014, which represented the present value of certain future tax benefits expected to be realized by Whiting Petroleum through future tax deductions. The $26 million received by Alliant Energy is presented in operating activities in its cash flows statement for the six months ended June 30 , 2014. |
IPL [Member] | |
Receivables [Line Items] | |
Receivables | RECEIVABLES (a) Sales of Accounts Receivable - IPL maintains a Receivables Agreement whereby it may sell its Iowa customer accounts receivables, unbilled revenues and certain other accounts receivables to a third party through wholly-owned and consolidated special purpose entities. The transfers of receivables meet the criteria for sale accounting established by the transfer of financial assets accounting rules. As of June 30, 2015 , IPL sold $177.8 million of receivables to the third party, received $100.0 million in cash proceeds and recorded deferred proceeds of $73.4 million . IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Maximum outstanding aggregate cash proceeds (based on daily outstanding balances) $125.0 $75.0 $125.0 $75.0 Average outstanding aggregate cash proceeds (based on daily outstanding balances) 77.3 34.2 72.7 30.9 For the three and six months ended June 30 , 2015 and 2014 , IPL’s costs incurred related to the sales of accounts receivable program were not material. The attributes of IPL’s receivables sold under the Receivables Agreement were as follows (in millions): June 30, 2015 December 31, 2014 Customer accounts receivable $100.4 $134.8 Unbilled utility revenues 77.2 69.7 Other receivables 0.2 0.1 Receivables sold to third party 177.8 204.6 Less: cash proceeds (a) 100.0 22.0 Deferred proceeds 77.8 182.6 Less: allowance for doubtful accounts 4.4 5.4 Fair value of deferred proceeds $73.4 $177.2 Outstanding receivables past due $14.0 $19.9 (a) Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Collections reinvested in receivables $417.1 $475.8 $923.0 $1,017.2 Credit losses, net of recoveries 2.5 3.9 3.5 6.4 |
Investments
Investments | 6 Months Ended |
Jun. 30, 2015 | |
Schedule of Investments [Line Items] | |
Investments | INVESTMENTS Unconsolidated Equity Investments - Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and six months ended June 30 was as follows (in millions): Alliant Energy WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 ATC ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) Other (0.4 ) (0.2 ) 0.9 (0.4 ) (0.4 ) (0.3 ) (0.4 ) (0.5 ) ($11.3 ) ($11.3 ) ($17.8 ) ($22.7 ) ($11.3 ) ($11.4 ) ($19.1 ) ($22.8 ) |
WPL [Member] | |
Schedule of Investments [Line Items] | |
Investments | INVESTMENTS Unconsolidated Equity Investments - Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and six months ended June 30 was as follows (in millions): Alliant Energy WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 ATC ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) Other (0.4 ) (0.2 ) 0.9 (0.4 ) (0.4 ) (0.3 ) (0.4 ) (0.5 ) ($11.3 ) ($11.3 ) ($17.8 ) ($22.7 ) ($11.3 ) ($11.4 ) ($19.1 ) ($22.8 ) |
Common Equity
Common Equity | 6 Months Ended |
Jun. 30, 2015 | |
Common Equity [Line Items] | |
Common Equity | COMMON EQUITY Common Share Activity - A summary of Alliant Energy’s common stock activity was as follows: Shares outstanding, January 1, 2015 110,935,680 At-the-market offering program 2,186,617 Shareowner Direct Plan 107,412 Equity-based compensation plans ( Note 9(b) ) 56,378 Other (22,463 ) Shares outstanding, June 30, 2015 113,263,624 At-the-Market Offering Program - In March 2015, Alliant Energy filed a prospectus supplement under which it may sell up to $150 million of its common stock through an at-the-market offering program. As of June 30, 2015 , Alliant Energy issued 2,186,617 shares of common stock through this program and received cash proceeds of $133 million , net of $2 million in fees and commissions. The proceeds from the issuances of common stock were used for general corporate purposes. Alliant Energy currently has no plans to issue any additional common stock through the at-the-market offering program. Dividend Restrictions - As of June 30, 2015 , IPL’s amount of retained earnings that were free of dividend restrictions was $533 million . As of June 30, 2015 , WPL’s amount of retained earnings that were free of dividend restrictions was $64 million for the remainder of 2015 . Restricted Net Assets of Subsidiaries - As of June 30, 2015 , the amount of net assets of IPL and WPL that were not available to be transferred to their parent company, Alliant Energy, in the form of loans, advances or cash dividends without the consent of IPL’s and WPL’s regulatory authorities was $1.4 billion and $1.7 billion , respectively. Capital Transactions with Subsidiaries - For the six months ended June 30 , 2015 , IPL received capital contributions of $100.0 million from its parent company. For the six months ended June 30 , 2015 , IPL and WPL each paid common stock dividends of $69.9 million and $63.5 million , respectively, to its parent company. Comprehensive Income - For the three and six months ended June 30, 2015 and 2014 , Alliant Energy had no other comprehensive income; therefore, its comprehensive income was equal to its net income and its comprehensive income attributable to Alliant Energy common shareowners was equal to its net income attributable to Alliant Energy common shareowners for such periods. For the three and six months ended June 30, 2015 and 2014 , IPL and WPL had no other comprehensive income; therefore, their comprehensive income was equal to their net income and their comprehensive income available for common stock was equal to their earnings available for common stock for such periods. |
IPL [Member] | |
Common Equity [Line Items] | |
Common Equity | COMMON EQUITY Common Share Activity - A summary of Alliant Energy’s common stock activity was as follows: Shares outstanding, January 1, 2015 110,935,680 At-the-market offering program 2,186,617 Shareowner Direct Plan 107,412 Equity-based compensation plans ( Note 9(b) ) 56,378 Other (22,463 ) Shares outstanding, June 30, 2015 113,263,624 At-the-Market Offering Program - In March 2015, Alliant Energy filed a prospectus supplement under which it may sell up to $150 million of its common stock through an at-the-market offering program. As of June 30, 2015 , Alliant Energy issued 2,186,617 shares of common stock through this program and received cash proceeds of $133 million , net of $2 million in fees and commissions. The proceeds from the issuances of common stock were used for general corporate purposes. Alliant Energy currently has no plans to issue any additional common stock through the at-the-market offering program. Dividend Restrictions - As of June 30, 2015 , IPL’s amount of retained earnings that were free of dividend restrictions was $533 million . As of June 30, 2015 , WPL’s amount of retained earnings that were free of dividend restrictions was $64 million for the remainder of 2015 . Restricted Net Assets of Subsidiaries - As of June 30, 2015 , the amount of net assets of IPL and WPL that were not available to be transferred to their parent company, Alliant Energy, in the form of loans, advances or cash dividends without the consent of IPL’s and WPL’s regulatory authorities was $1.4 billion and $1.7 billion , respectively. Capital Transactions with Subsidiaries - For the six months ended June 30 , 2015 , IPL received capital contributions of $100.0 million from its parent company. For the six months ended June 30 , 2015 , IPL and WPL each paid common stock dividends of $69.9 million and $63.5 million , respectively, to its parent company. Comprehensive Income - For the three and six months ended June 30, 2015 and 2014 , Alliant Energy had no other comprehensive income; therefore, its comprehensive income was equal to its net income and its comprehensive income attributable to Alliant Energy common shareowners was equal to its net income attributable to Alliant Energy common shareowners for such periods. For the three and six months ended June 30, 2015 and 2014 , IPL and WPL had no other comprehensive income; therefore, their comprehensive income was equal to their net income and their comprehensive income available for common stock was equal to their earnings available for common stock for such periods. |
WPL [Member] | |
Common Equity [Line Items] | |
Common Equity | COMMON EQUITY Common Share Activity - A summary of Alliant Energy’s common stock activity was as follows: Shares outstanding, January 1, 2015 110,935,680 At-the-market offering program 2,186,617 Shareowner Direct Plan 107,412 Equity-based compensation plans ( Note 9(b) ) 56,378 Other (22,463 ) Shares outstanding, June 30, 2015 113,263,624 At-the-Market Offering Program - In March 2015, Alliant Energy filed a prospectus supplement under which it may sell up to $150 million of its common stock through an at-the-market offering program. As of June 30, 2015 , Alliant Energy issued 2,186,617 shares of common stock through this program and received cash proceeds of $133 million , net of $2 million in fees and commissions. The proceeds from the issuances of common stock were used for general corporate purposes. Alliant Energy currently has no plans to issue any additional common stock through the at-the-market offering program. Dividend Restrictions - As of June 30, 2015 , IPL’s amount of retained earnings that were free of dividend restrictions was $533 million . As of June 30, 2015 , WPL’s amount of retained earnings that were free of dividend restrictions was $64 million for the remainder of 2015 . Restricted Net Assets of Subsidiaries - As of June 30, 2015 , the amount of net assets of IPL and WPL that were not available to be transferred to their parent company, Alliant Energy, in the form of loans, advances or cash dividends without the consent of IPL’s and WPL’s regulatory authorities was $1.4 billion and $1.7 billion , respectively. Capital Transactions with Subsidiaries - For the six months ended June 30 , 2015 , IPL received capital contributions of $100.0 million from its parent company. For the six months ended June 30 , 2015 , IPL and WPL each paid common stock dividends of $69.9 million and $63.5 million , respectively, to its parent company. Comprehensive Income - For the three and six months ended June 30, 2015 and 2014 , Alliant Energy had no other comprehensive income; therefore, its comprehensive income was equal to its net income and its comprehensive income attributable to Alliant Energy common shareowners was equal to its net income attributable to Alliant Energy common shareowners for such periods. For the three and six months ended June 30, 2015 and 2014 , IPL and WPL had no other comprehensive income; therefore, their comprehensive income was equal to their net income and their comprehensive income available for common stock was equal to their earnings available for common stock for such periods. |
Debt
Debt | 6 Months Ended |
Jun. 30, 2015 | |
Debt [Line Items] | |
Debt | DEBT (a) Short-term Debt - Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. (b) Long-term Debt - In June 2015, IPL retired its $150.0 million , 3.3% senior debentures. As of June 30, 2015 , $111.2 million of commercial paper was recorded in “Long-term debt, net” on Alliant Energy’s and IPL’s balance sheets due to the existence of long-term credit facilities that back-stop this commercial paper balance, along with Alliant Energy’s and IPL’s intent and ability to refinance these balances on a long-term basis. As of June 30, 2015 , this commercial paper balance had a weighted average remaining maturity of 6 days and a 0.5% interest rate. |
IPL [Member] | |
Debt [Line Items] | |
Debt | DEBT (a) Short-term Debt - Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. (b) Long-term Debt - In June 2015, IPL retired its $150.0 million , 3.3% senior debentures. As of June 30, 2015 , $111.2 million of commercial paper was recorded in “Long-term debt, net” on Alliant Energy’s and IPL’s balance sheets due to the existence of long-term credit facilities that back-stop this commercial paper balance, along with Alliant Energy’s and IPL’s intent and ability to refinance these balances on a long-term basis. As of June 30, 2015 , this commercial paper balance had a weighted average remaining maturity of 6 days and a 0.5% interest rate. |
WPL [Member] | |
Debt [Line Items] | |
Debt | DEBT (a) Short-term Debt - Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2015 | |
Income Taxes [Line Items] | |
Income Taxes | INCOME TAXES Income Tax Rates - The provision for income taxes for earnings from continuing operations is based on an estimated annual effective income tax rate that excludes the impact of significant unusual or infrequently occurring items, discontinued operations or extraordinary items. The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % IPL’s tax benefit riders - Alliant Energy’s and IPL’s effective income tax rates include the impact of reducing income tax expense with offsetting reductions to regulatory liabilities as a result of implementing IPL’s tax benefit riders. Refer to Note 2 for additional details of the tax benefit riders. Effect of rate-making on property-related differences - Alliant Energy’s and IPL’s effective income tax rates are impacted by the effect of rate-making principles on certain property-related differences for which deferred tax is not recognized in the income statement, substantially all of which relates to IPL. The increased benefits from property-related differences recognized during the three and six months ended June 30 , 2015 were primarily due to additional repairs deductions. Deferred Tax Assets and Liabilities - For the six months ended June 30 , 2015 , Alliant Energy’s, IPL’s and WPL’s non-current deferred tax liabilities increased $128.0 million , $77.4 million and $44.9 million , respectively. These increases in non-current deferred tax liabilities were primarily due to utilization of federal net operating loss carryforwards, and property-related differences recorded during the six months ended June 30 , 2015 , including an increase in qualifying repairs expenditures. Carryforwards - At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
IPL [Member] | |
Income Taxes [Line Items] | |
Income Taxes | INCOME TAXES Income Tax Rates - The provision for income taxes for earnings from continuing operations is based on an estimated annual effective income tax rate that excludes the impact of significant unusual or infrequently occurring items, discontinued operations or extraordinary items. The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % IPL’s tax benefit riders - Alliant Energy’s and IPL’s effective income tax rates include the impact of reducing income tax expense with offsetting reductions to regulatory liabilities as a result of implementing IPL’s tax benefit riders. Refer to Note 2 for additional details of the tax benefit riders. Effect of rate-making on property-related differences - Alliant Energy’s and IPL’s effective income tax rates are impacted by the effect of rate-making principles on certain property-related differences for which deferred tax is not recognized in the income statement, substantially all of which relates to IPL. The increased benefits from property-related differences recognized during the three and six months ended June 30 , 2015 were primarily due to additional repairs deductions. Deferred Tax Assets and Liabilities - For the six months ended June 30 , 2015 , Alliant Energy’s, IPL’s and WPL’s non-current deferred tax liabilities increased $128.0 million , $77.4 million and $44.9 million , respectively. These increases in non-current deferred tax liabilities were primarily due to utilization of federal net operating loss carryforwards, and property-related differences recorded during the six months ended June 30 , 2015 , including an increase in qualifying repairs expenditures. Carryforwards - At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
WPL [Member] | |
Income Taxes [Line Items] | |
Income Taxes | INCOME TAXES Income Tax Rates - The provision for income taxes for earnings from continuing operations is based on an estimated annual effective income tax rate that excludes the impact of significant unusual or infrequently occurring items, discontinued operations or extraordinary items. The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % IPL’s tax benefit riders - Alliant Energy’s and IPL’s effective income tax rates include the impact of reducing income tax expense with offsetting reductions to regulatory liabilities as a result of implementing IPL’s tax benefit riders. Refer to Note 2 for additional details of the tax benefit riders. Effect of rate-making on property-related differences - Alliant Energy’s and IPL’s effective income tax rates are impacted by the effect of rate-making principles on certain property-related differences for which deferred tax is not recognized in the income statement, substantially all of which relates to IPL. The increased benefits from property-related differences recognized during the three and six months ended June 30 , 2015 were primarily due to additional repairs deductions. Deferred Tax Assets and Liabilities - For the six months ended June 30 , 2015 , Alliant Energy’s, IPL’s and WPL’s non-current deferred tax liabilities increased $128.0 million , $77.4 million and $44.9 million , respectively. These increases in non-current deferred tax liabilities were primarily due to utilization of federal net operating loss carryforwards, and property-related differences recorded during the six months ended June 30 , 2015 , including an increase in qualifying repairs expenditures. Carryforwards - At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
Benefit Plans
Benefit Plans | 6 Months Ended |
Jun. 30, 2015 | |
Benefit Plans | BENEFIT PLANS (a) Pension and Other Postretirement Benefits Plans - Net Periodic Benefit Costs (Credits) - The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 401(k) Savings Plans - A significant number of employees participate in defined contribution retirement plans (401(k) savings plans). For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. (b) Equity-based Compensation Plans - A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 As of June 30, 2015 , total unrecognized compensation cost related to share-based compensation awards was $9.6 million , which is expected to be recognized over a weighted average period of between 1 and 2 years. Share-based compensation expense is recognized on a straight-line basis over the requisite service periods and is primarily recorded in “Utility - Other operation and maintenance” in the income statements. Performance Shares and Units - Performance Shares - A summary of the performance shares activity was as follows: 2015 (a) 2014 (a) Nonvested shares, January 1 144,424 139,940 Granted 45,403 51,221 Vested (45,612 ) (45,235 ) Forfeited — (1,502 ) Nonvested shares, June 30 144,215 144,424 (a) Share amounts represent the target number of performance shares. During the six months ended June 30 , certain performance shares vested, resulting in payouts (a combination of cash and common stock) as follows: 2015 2014 2012 Grant 2011 Grant Performance shares vested 45,612 45,235 Percentage of target number of performance shares 167.5 % 147.5 % Aggregate payout value (in millions) $5.1 $3.4 Payout - cash (in millions) $3.2 $2.9 Payout - common stock shares issued 10,975 4,810 Performance Units - A summary of the performance units activity was as follows: 2015 (a) 2014 (a) Nonvested units, January 1 63,665 65,912 Granted 17,837 20,422 Vested (22,845 ) (20,751 ) Forfeited (333 ) (761 ) Nonvested units, June 30 58,324 64,822 (a) Unit amounts represent the target number of performance units. During the six months ended June 30 , certain performance units vested, resulting in cash payouts as follows: 2015 2014 2012 Grant 2011 Grant Performance units vested 22,845 20,751 Percentage of target number of performance units 167.5 % 147.5 % Payout value (in millions) $1.6 $1.2 Fair Value of Awards - Information related to fair values of nonvested performance shares and units at June 30, 2015 , by year of grant, was as follows: Performance Shares Performance Units 2015 Grant 2014 Grant 2013 Grant 2015 Grant 2014 Grant 2013 Grant Nonvested awards 45,403 49,719 49,093 17,504 19,440 21,380 Alliant Energy common stock closing price on June 30, 2015 $57.72 $57.72 $57.72 Alliant Energy common stock closing price on grant date $65.09 $53.77 $47.58 Estimated payout percentage based on performance criteria 100 % 133 % 180 % 100 % 133 % 180 % Fair values of each nonvested award $57.72 $76.77 $103.90 $65.09 $71.51 $85.64 At June 30, 2015 , fair values of nonvested performance shares and units were calculated based on Alliant Energy’s stock price and anticipated total shareowner returns of Alliant Energy and its investor-owned utility peer group over the performance period. The portion of the fair values based on anticipated total shareowner returns was estimated using a model that incorporates the probability of meeting performance targets based on historical returns relative to the peer group. Performance Contingent Restricted Stock - A summary of the performance contingent restricted stock activity was as follows: 2015 2014 Shares Weighted Average Fair Value Shares Weighted Average Fair Value Nonvested shares, January 1 98,812 $50.69 158,922 $42.71 Granted 45,403 65.09 51,221 53.77 Vested (a) (49,093 ) 47.58 (90,847 ) 40.91 Forfeited — — (20,484 ) 39.85 Nonvested shares, June 30 95,122 59.17 98,812 50.69 (a) In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met. Performance Contingent Cash Awards - A summary of the performance contingent cash awards activity was as follows: 2015 2014 Nonvested awards, January 1 78,930 96,977 Granted 41,105 42,446 Vested (a) (37,332 ) (55,517 ) Forfeited (709 ) (4,098 ) Nonvested awards, June 30 81,994 79,808 (a) In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million . In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million , respectively. |
IPL [Member] | |
Benefit Plans | BENEFIT PLANS (a) Pension and Other Postretirement Benefits Plans - Net Periodic Benefit Costs (Credits) - The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 401(k) Savings Plans - A significant number of employees participate in defined contribution retirement plans (401(k) savings plans). For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. (b) Equity-based Compensation Plans - A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 As of June 30, 2015 , total unrecognized compensation cost related to share-based compensation awards was $9.6 million , which is expected to be recognized over a weighted average period of between 1 and 2 years. Share-based compensation expense is recognized on a straight-line basis over the requisite service periods and is primarily recorded in “Utility - Other operation and maintenance” in the income statements. Performance Shares and Units - Performance Shares - A summary of the performance shares activity was as follows: 2015 (a) 2014 (a) Nonvested shares, January 1 144,424 139,940 Granted 45,403 51,221 Vested (45,612 ) (45,235 ) Forfeited — (1,502 ) Nonvested shares, June 30 144,215 144,424 (a) Share amounts represent the target number of performance shares. During the six months ended June 30 , certain performance shares vested, resulting in payouts (a combination of cash and common stock) as follows: 2015 2014 2012 Grant 2011 Grant Performance shares vested 45,612 45,235 Percentage of target number of performance shares 167.5 % 147.5 % Aggregate payout value (in millions) $5.1 $3.4 Payout - cash (in millions) $3.2 $2.9 Payout - common stock shares issued 10,975 4,810 Performance Units - A summary of the performance units activity was as follows: 2015 (a) 2014 (a) Nonvested units, January 1 63,665 65,912 Granted 17,837 20,422 Vested (22,845 ) (20,751 ) Forfeited (333 ) (761 ) Nonvested units, June 30 58,324 64,822 (a) Unit amounts represent the target number of performance units. During the six months ended June 30 , certain performance units vested, resulting in cash payouts as follows: 2015 2014 2012 Grant 2011 Grant Performance units vested 22,845 20,751 Percentage of target number of performance units 167.5 % 147.5 % Payout value (in millions) $1.6 $1.2 Fair Value of Awards - Information related to fair values of nonvested performance shares and units at June 30, 2015 , by year of grant, was as follows: Performance Shares Performance Units 2015 Grant 2014 Grant 2013 Grant 2015 Grant 2014 Grant 2013 Grant Nonvested awards 45,403 49,719 49,093 17,504 19,440 21,380 Alliant Energy common stock closing price on June 30, 2015 $57.72 $57.72 $57.72 Alliant Energy common stock closing price on grant date $65.09 $53.77 $47.58 Estimated payout percentage based on performance criteria 100 % 133 % 180 % 100 % 133 % 180 % Fair values of each nonvested award $57.72 $76.77 $103.90 $65.09 $71.51 $85.64 At June 30, 2015 , fair values of nonvested performance shares and units were calculated based on Alliant Energy’s stock price and anticipated total shareowner returns of Alliant Energy and its investor-owned utility peer group over the performance period. The portion of the fair values based on anticipated total shareowner returns was estimated using a model that incorporates the probability of meeting performance targets based on historical returns relative to the peer group. Performance Contingent Restricted Stock - A summary of the performance contingent restricted stock activity was as follows: 2015 2014 Shares Weighted Average Fair Value Shares Weighted Average Fair Value Nonvested shares, January 1 98,812 $50.69 158,922 $42.71 Granted 45,403 65.09 51,221 53.77 Vested (a) (49,093 ) 47.58 (90,847 ) 40.91 Forfeited — — (20,484 ) 39.85 Nonvested shares, June 30 95,122 59.17 98,812 50.69 (a) In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met. Performance Contingent Cash Awards - A summary of the performance contingent cash awards activity was as follows: 2015 2014 Nonvested awards, January 1 78,930 96,977 Granted 41,105 42,446 Vested (a) (37,332 ) (55,517 ) Forfeited (709 ) (4,098 ) Nonvested awards, June 30 81,994 79,808 (a) In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million . In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million , respectively. |
WPL [Member] | |
Benefit Plans | BENEFIT PLANS (a) Pension and Other Postretirement Benefits Plans - Net Periodic Benefit Costs (Credits) - The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 401(k) Savings Plans - A significant number of employees participate in defined contribution retirement plans (401(k) savings plans). For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. (b) Equity-based Compensation Plans - A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 As of June 30, 2015 , total unrecognized compensation cost related to share-based compensation awards was $9.6 million , which is expected to be recognized over a weighted average period of between 1 and 2 years. Share-based compensation expense is recognized on a straight-line basis over the requisite service periods and is primarily recorded in “Utility - Other operation and maintenance” in the income statements. Performance Shares and Units - Performance Shares - A summary of the performance shares activity was as follows: 2015 (a) 2014 (a) Nonvested shares, January 1 144,424 139,940 Granted 45,403 51,221 Vested (45,612 ) (45,235 ) Forfeited — (1,502 ) Nonvested shares, June 30 144,215 144,424 (a) Share amounts represent the target number of performance shares. During the six months ended June 30 , certain performance shares vested, resulting in payouts (a combination of cash and common stock) as follows: 2015 2014 2012 Grant 2011 Grant Performance shares vested 45,612 45,235 Percentage of target number of performance shares 167.5 % 147.5 % Aggregate payout value (in millions) $5.1 $3.4 Payout - cash (in millions) $3.2 $2.9 Payout - common stock shares issued 10,975 4,810 Performance Units - A summary of the performance units activity was as follows: 2015 (a) 2014 (a) Nonvested units, January 1 63,665 65,912 Granted 17,837 20,422 Vested (22,845 ) (20,751 ) Forfeited (333 ) (761 ) Nonvested units, June 30 58,324 64,822 (a) Unit amounts represent the target number of performance units. During the six months ended June 30 , certain performance units vested, resulting in cash payouts as follows: 2015 2014 2012 Grant 2011 Grant Performance units vested 22,845 20,751 Percentage of target number of performance units 167.5 % 147.5 % Payout value (in millions) $1.6 $1.2 Fair Value of Awards - Information related to fair values of nonvested performance shares and units at June 30, 2015 , by year of grant, was as follows: Performance Shares Performance Units 2015 Grant 2014 Grant 2013 Grant 2015 Grant 2014 Grant 2013 Grant Nonvested awards 45,403 49,719 49,093 17,504 19,440 21,380 Alliant Energy common stock closing price on June 30, 2015 $57.72 $57.72 $57.72 Alliant Energy common stock closing price on grant date $65.09 $53.77 $47.58 Estimated payout percentage based on performance criteria 100 % 133 % 180 % 100 % 133 % 180 % Fair values of each nonvested award $57.72 $76.77 $103.90 $65.09 $71.51 $85.64 At June 30, 2015 , fair values of nonvested performance shares and units were calculated based on Alliant Energy’s stock price and anticipated total shareowner returns of Alliant Energy and its investor-owned utility peer group over the performance period. The portion of the fair values based on anticipated total shareowner returns was estimated using a model that incorporates the probability of meeting performance targets based on historical returns relative to the peer group. Performance Contingent Restricted Stock - A summary of the performance contingent restricted stock activity was as follows: 2015 2014 Shares Weighted Average Fair Value Shares Weighted Average Fair Value Nonvested shares, January 1 98,812 $50.69 158,922 $42.71 Granted 45,403 65.09 51,221 53.77 Vested (a) (49,093 ) 47.58 (90,847 ) 40.91 Forfeited — — (20,484 ) 39.85 Nonvested shares, June 30 95,122 59.17 98,812 50.69 (a) In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met. Performance Contingent Cash Awards - A summary of the performance contingent cash awards activity was as follows: 2015 2014 Nonvested awards, January 1 78,930 96,977 Granted 41,105 42,446 Vested (a) (37,332 ) (55,517 ) Forfeited (709 ) (4,098 ) Nonvested awards, June 30 81,994 79,808 (a) In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million . In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million , respectively. |
Asset Retirement Obligations
Asset Retirement Obligations | 6 Months Ended |
Jun. 30, 2015 | |
Asset Retirement Obligations [Line Items] | |
Asset Retirement Obligations | ASSET RETIREMENT OBLIGATIONS A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
IPL [Member] | |
Asset Retirement Obligations [Line Items] | |
Asset Retirement Obligations | ASSET RETIREMENT OBLIGATIONS A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
WPL [Member] | |
Asset Retirement Obligations [Line Items] | |
Asset Retirement Obligations | ASSET RETIREMENT OBLIGATIONS A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
Fair Value Measurements
Fair Value Measurements | 6 Months Ended |
Jun. 30, 2015 | |
Fair Value Measurements | FAIR VALUE MEASUREMENTS Fair Value of Financial Instruments - The carrying amounts of current assets and current liabilities approximate fair value because of the short maturity of such financial instruments. Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 Valuation Hierarchy - At each reporting date, Level 1 items included IPL’s 5.1% cumulative preferred stock, Level 2 items included certain non-exchange traded commodity contracts and substantially all of the long-term debt instruments, and Level 3 items included FTRs, certain non-exchange traded commodity contracts and IPL’s deferred proceeds. Valuation Techniques - Derivative assets and derivative liabilities - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs, and risk policies are maintained that govern the use of such derivative instruments. Derivative instruments were not designated as hedging instruments and included the following: Risk management purpose Type of instrument Mitigate pricing volatility for: Electricity purchased to supply customers Electric swap and physical forward contracts (IPL and WPL) Fuel used to supply natural gas-fired EGUs Natural gas swap, options and physical forward contracts (IPL and WPL) Natural gas supplied to retail customers Natural gas options and physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Fuel used at coal-fired EGUs Coal physical forward contracts (IPL and WPL) Optimize the value of natural gas pipeline capacity Natural gas physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Manage transmission congestion costs FTRs (IPL and WPL) Swap, option and physical forward commodity contracts were non-exchange-based derivative instruments and were valued using indicative price quotations from a pricing vendor that provides daily exchange forward price settlements, from broker or dealer quotations, from market publications or from on-line exchanges. The indicative price quotations reflected the average of the bid-ask mid-point prices and were obtained from sources believed to provide the most liquid market for the commodity. A portion of these indicative price quotations were corroborated using quoted prices for similar assets or liabilities in active markets and categorized derivative instruments based on such indicative price quotations as Level 2. Commodity contracts that were valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping and indicative price quotations that could not be readily corroborated were categorized as Level 3. Swap, option and physical forward commodity contracts were predominately at liquid trading points. FTRs were valued using monthly or annual auction shadow prices from relevant auctions and were categorized as Level 3. Refer to Note 12 for additional details of derivative assets and derivative liabilities. The fair value measurements of Level 3 derivative instruments include observable and unobservable inputs. The observable inputs are obtained from third-party pricing sources, counterparties and brokers and include bids, offers, historical transactions (including historical price differences between locations with both observable and unobservable prices) and executed trades. The significant unobservable inputs used in the fair value measurement of commodity contracts are forecasted electricity, natural gas and coal prices, and the expected volatility of such prices. Significant changes in any of those inputs would result in a significantly lower or higher fair value measurement. Deferred proceeds (sales of receivables) - The fair value of IPL’s deferred proceeds related to its sales of accounts receivable program was calculated each reporting date using the cost approach valuation technique. The fair value represents the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold due to the short-term nature of the collection period. These inputs were considered unobservable and deferred proceeds were categorized as Level 3. Deferred proceeds represent IPL’s maximum exposure to loss related to the receivables sold. Refer to Note 4(a) for additional information regarding deferred proceeds. Long-term debt (including current maturities) - The fair value of long-term debt instruments was based on quoted market prices for similar liabilities at each reporting date or on a discounted cash flow methodology, which utilizes assumptions of current market pricing curves at each reporting date. Refer to Note 7(b) for additional information regarding long-term debt. Cumulative preferred stock - The fair value of IPL’s 5.1% cumulative preferred stock was based on its closing market price quoted by the New York Stock Exchange at each reporting date. Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 Unrealized gains and losses from derivative instruments are generally recorded with offsets to regulatory assets or regulatory liabilities, based on fuel and natural gas cost recovery mechanisms, as well as other specific regulatory authorizations. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities resulted in comparable changes to regulatory assets, and the changes in the fair value of derivative assets resulted in comparable changes to regulatory liabilities. Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. Commodity Contracts - The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
IPL [Member] | |
Fair Value Measurements | FAIR VALUE MEASUREMENTS Fair Value of Financial Instruments - The carrying amounts of current assets and current liabilities approximate fair value because of the short maturity of such financial instruments. Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 Valuation Hierarchy - At each reporting date, Level 1 items included IPL’s 5.1% cumulative preferred stock, Level 2 items included certain non-exchange traded commodity contracts and substantially all of the long-term debt instruments, and Level 3 items included FTRs, certain non-exchange traded commodity contracts and IPL’s deferred proceeds. Valuation Techniques - Derivative assets and derivative liabilities - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs, and risk policies are maintained that govern the use of such derivative instruments. Derivative instruments were not designated as hedging instruments and included the following: Risk management purpose Type of instrument Mitigate pricing volatility for: Electricity purchased to supply customers Electric swap and physical forward contracts (IPL and WPL) Fuel used to supply natural gas-fired EGUs Natural gas swap, options and physical forward contracts (IPL and WPL) Natural gas supplied to retail customers Natural gas options and physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Fuel used at coal-fired EGUs Coal physical forward contracts (IPL and WPL) Optimize the value of natural gas pipeline capacity Natural gas physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Manage transmission congestion costs FTRs (IPL and WPL) Swap, option and physical forward commodity contracts were non-exchange-based derivative instruments and were valued using indicative price quotations from a pricing vendor that provides daily exchange forward price settlements, from broker or dealer quotations, from market publications or from on-line exchanges. The indicative price quotations reflected the average of the bid-ask mid-point prices and were obtained from sources believed to provide the most liquid market for the commodity. A portion of these indicative price quotations were corroborated using quoted prices for similar assets or liabilities in active markets and categorized derivative instruments based on such indicative price quotations as Level 2. Commodity contracts that were valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping and indicative price quotations that could not be readily corroborated were categorized as Level 3. Swap, option and physical forward commodity contracts were predominately at liquid trading points. FTRs were valued using monthly or annual auction shadow prices from relevant auctions and were categorized as Level 3. Refer to Note 12 for additional details of derivative assets and derivative liabilities. The fair value measurements of Level 3 derivative instruments include observable and unobservable inputs. The observable inputs are obtained from third-party pricing sources, counterparties and brokers and include bids, offers, historical transactions (including historical price differences between locations with both observable and unobservable prices) and executed trades. The significant unobservable inputs used in the fair value measurement of commodity contracts are forecasted electricity, natural gas and coal prices, and the expected volatility of such prices. Significant changes in any of those inputs would result in a significantly lower or higher fair value measurement. Deferred proceeds (sales of receivables) - The fair value of IPL’s deferred proceeds related to its sales of accounts receivable program was calculated each reporting date using the cost approach valuation technique. The fair value represents the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold due to the short-term nature of the collection period. These inputs were considered unobservable and deferred proceeds were categorized as Level 3. Deferred proceeds represent IPL’s maximum exposure to loss related to the receivables sold. Refer to Note 4(a) for additional information regarding deferred proceeds. Long-term debt (including current maturities) - The fair value of long-term debt instruments was based on quoted market prices for similar liabilities at each reporting date or on a discounted cash flow methodology, which utilizes assumptions of current market pricing curves at each reporting date. Refer to Note 7(b) for additional information regarding long-term debt. Cumulative preferred stock - The fair value of IPL’s 5.1% cumulative preferred stock was based on its closing market price quoted by the New York Stock Exchange at each reporting date. Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 Unrealized gains and losses from derivative instruments are generally recorded with offsets to regulatory assets or regulatory liabilities, based on fuel and natural gas cost recovery mechanisms, as well as other specific regulatory authorizations. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities resulted in comparable changes to regulatory assets, and the changes in the fair value of derivative assets resulted in comparable changes to regulatory liabilities. Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. Commodity Contracts - The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
WPL [Member] | |
Fair Value Measurements | FAIR VALUE MEASUREMENTS Fair Value of Financial Instruments - The carrying amounts of current assets and current liabilities approximate fair value because of the short maturity of such financial instruments. Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 Valuation Hierarchy - At each reporting date, Level 1 items included IPL’s 5.1% cumulative preferred stock, Level 2 items included certain non-exchange traded commodity contracts and substantially all of the long-term debt instruments, and Level 3 items included FTRs, certain non-exchange traded commodity contracts and IPL’s deferred proceeds. Valuation Techniques - Derivative assets and derivative liabilities - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs, and risk policies are maintained that govern the use of such derivative instruments. Derivative instruments were not designated as hedging instruments and included the following: Risk management purpose Type of instrument Mitigate pricing volatility for: Electricity purchased to supply customers Electric swap and physical forward contracts (IPL and WPL) Fuel used to supply natural gas-fired EGUs Natural gas swap, options and physical forward contracts (IPL and WPL) Natural gas supplied to retail customers Natural gas options and physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Fuel used at coal-fired EGUs Coal physical forward contracts (IPL and WPL) Optimize the value of natural gas pipeline capacity Natural gas physical forward contracts (IPL and WPL) Natural gas swap contracts (IPL) Manage transmission congestion costs FTRs (IPL and WPL) Swap, option and physical forward commodity contracts were non-exchange-based derivative instruments and were valued using indicative price quotations from a pricing vendor that provides daily exchange forward price settlements, from broker or dealer quotations, from market publications or from on-line exchanges. The indicative price quotations reflected the average of the bid-ask mid-point prices and were obtained from sources believed to provide the most liquid market for the commodity. A portion of these indicative price quotations were corroborated using quoted prices for similar assets or liabilities in active markets and categorized derivative instruments based on such indicative price quotations as Level 2. Commodity contracts that were valued using indicative price quotations based on significant assumptions such as seasonal or monthly shaping and indicative price quotations that could not be readily corroborated were categorized as Level 3. Swap, option and physical forward commodity contracts were predominately at liquid trading points. FTRs were valued using monthly or annual auction shadow prices from relevant auctions and were categorized as Level 3. Refer to Note 12 for additional details of derivative assets and derivative liabilities. The fair value measurements of Level 3 derivative instruments include observable and unobservable inputs. The observable inputs are obtained from third-party pricing sources, counterparties and brokers and include bids, offers, historical transactions (including historical price differences between locations with both observable and unobservable prices) and executed trades. The significant unobservable inputs used in the fair value measurement of commodity contracts are forecasted electricity, natural gas and coal prices, and the expected volatility of such prices. Significant changes in any of those inputs would result in a significantly lower or higher fair value measurement. Deferred proceeds (sales of receivables) - The fair value of IPL’s deferred proceeds related to its sales of accounts receivable program was calculated each reporting date using the cost approach valuation technique. The fair value represents the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold due to the short-term nature of the collection period. These inputs were considered unobservable and deferred proceeds were categorized as Level 3. Deferred proceeds represent IPL’s maximum exposure to loss related to the receivables sold. Refer to Note 4(a) for additional information regarding deferred proceeds. Long-term debt (including current maturities) - The fair value of long-term debt instruments was based on quoted market prices for similar liabilities at each reporting date or on a discounted cash flow methodology, which utilizes assumptions of current market pricing curves at each reporting date. Refer to Note 7(b) for additional information regarding long-term debt. Cumulative preferred stock - The fair value of IPL’s 5.1% cumulative preferred stock was based on its closing market price quoted by the New York Stock Exchange at each reporting date. Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 Unrealized gains and losses from derivative instruments are generally recorded with offsets to regulatory assets or regulatory liabilities, based on fuel and natural gas cost recovery mechanisms, as well as other specific regulatory authorizations. Based on these recovery mechanisms, the changes in the fair value of derivative liabilities resulted in comparable changes to regulatory assets, and the changes in the fair value of derivative assets resulted in comparable changes to regulatory liabilities. Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. Commodity Contracts - The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
Derivative Instruments
Derivative Instruments | 6 Months Ended |
Jun. 30, 2015 | |
Derivative Instruments [Line Items] | |
Derivative Instruments | DERIVATIVE INSTRUMENTS Commodity Derivatives - Purpose - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs. Refer to Note 11 for detailed discussion of derivative instruments. Notional Amounts - As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 Financial Statement Presentation - Derivative instruments are recorded at fair value each reporting date on the balance sheets as assets or liabilities. The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 Credit Risk-related Contingent Features - Various agreements contain credit risk-related contingent features, including requirements to maintain certain credit ratings and/or limitations on liability positions under the agreements based on credit ratings. Certain of these agreements with credit risk-related contingency features are accounted for as derivative instruments. In the event of a material change in creditworthiness or if liability positions exceed certain contractual limits, credit support may need to be provided in the form of letters of credit or cash collateral up to the amount of exposure under the contracts, or the contracts may need to be unwound and underlying liability positions paid. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 Balance Sheet Offsetting - The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 Fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) are not offset against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. |
IPL [Member] | |
Derivative Instruments [Line Items] | |
Derivative Instruments | DERIVATIVE INSTRUMENTS Commodity Derivatives - Purpose - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs. Refer to Note 11 for detailed discussion of derivative instruments. Notional Amounts - As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 Financial Statement Presentation - Derivative instruments are recorded at fair value each reporting date on the balance sheets as assets or liabilities. The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 Credit Risk-related Contingent Features - Various agreements contain credit risk-related contingent features, including requirements to maintain certain credit ratings and/or limitations on liability positions under the agreements based on credit ratings. Certain of these agreements with credit risk-related contingency features are accounted for as derivative instruments. In the event of a material change in creditworthiness or if liability positions exceed certain contractual limits, credit support may need to be provided in the form of letters of credit or cash collateral up to the amount of exposure under the contracts, or the contracts may need to be unwound and underlying liability positions paid. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 Balance Sheet Offsetting - The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 Fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) are not offset against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. |
WPL [Member] | |
Derivative Instruments [Line Items] | |
Derivative Instruments | DERIVATIVE INSTRUMENTS Commodity Derivatives - Purpose - Derivative instruments are periodically used for risk management purposes to mitigate exposures to fluctuations in certain commodity prices and transmission congestion costs. Refer to Note 11 for detailed discussion of derivative instruments. Notional Amounts - As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 Financial Statement Presentation - Derivative instruments are recorded at fair value each reporting date on the balance sheets as assets or liabilities. The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 Credit Risk-related Contingent Features - Various agreements contain credit risk-related contingent features, including requirements to maintain certain credit ratings and/or limitations on liability positions under the agreements based on credit ratings. Certain of these agreements with credit risk-related contingency features are accounted for as derivative instruments. In the event of a material change in creditworthiness or if liability positions exceed certain contractual limits, credit support may need to be provided in the form of letters of credit or cash collateral up to the amount of exposure under the contracts, or the contracts may need to be unwound and underlying liability positions paid. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 Balance Sheet Offsetting - The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 Fair value amounts recognized for the right to reclaim cash collateral (receivable) or the obligation to return cash collateral (payable) are not offset against fair value amounts recognized for derivative instruments executed with the same counterparty under the same master netting arrangement. |
Commitments And Contingencies
Commitments And Contingencies | 6 Months Ended |
Jun. 30, 2015 | |
Commitments and Contingencies Disclosure | COMMITMENTS AND CONTINGENCIES (a) Capital Purchase Obligations - Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects. WPL’s projects include the installation of a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions, and generation maintenance and performance improvements at Columbia Units 1 and 2. At June 30, 2015 , Alliant Energy’s and WPL’s minimum future commitments related to certain contractual obligations for these projects were $30 million . (b) Operating Expense Purchase Obligations - Various commodity supply, transportation and storage contracts help meet obligations to provide electricity and natural gas to utility customers. Other operating expense purchase obligations with various vendors provide other goods and services. At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . (c) Legal Proceedings - IPL Consent Decree - In July 2015, IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. In July 2015, the Consent Decree was lodged with, and is subject to approval by, the U.S. District Court for the Northern District of Iowa. Under the Consent Decree, IPL is required to install the following emission control systems: • Scrubber and baghouse at the Ottumwa Generating Station by December 31, 2015 (placed in service in 2014); • Scrubber and baghouse at the Lansing Generating Station by December 31, 2016 (placed in service in June 2015 and in 2010, respectively); and • SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019. IPL is also required to fuel switch or retire the following EGUs: • M.L. Kapp Generating Station by August 31, 2015 (switched the fuel type from coal to natural gas in June 2015); • Prairie Creek Unit 4 by June 1, 2018; • Burlington Generating Station by December 31, 2021; and • Prairie Creek Units 1 and 3 by December 31, 2025. In addition, IPL is required to either install combined cycle technology at, or retire, the Dubuque and Sutherland Generation Stations by June 1, 2019. IPL previously switched the fuel type from coal to natural gas at these EGUs. The Consent Decree also establishes SO2, NOx and particulate matter emission rate limits with varying averaging times for the Burlington, Lansing, M.L. Kapp, Ottumwa and Prairie Creek Generating Stations. In addition, the Consent Decree includes calendar-year SO2 and NOx emission caps for the Prairie Creek Generating Station, and calendar-year SO2 and NOx emission caps in aggregate for the Burlington, Dubuque, Lansing, M.L. Kapp, Ottumwa, Prairie Creek and Sutherland Generating Stations. IPL will also pay a civil penalty of approximately $1 million and complete approximately $6 million in environmental mitigation projects. Alliant Energy and IPL currently expect to recover costs incurred by IPL related to the emission control systems and environmental mitigation projects from IPL’s electric customers. The recovery of such costs will be decided by IPL’s regulators in future rate cases or other proceedings. Alliant Energy and IPL currently do not expect to recover costs related to the civil penalty from IPL’s electric customers. Flood Damage Claims - In June 2013, several plaintiffs purporting to represent a class of residential and commercial property owners filed a complaint against CRANDIC, Alliant Energy and various other defendants in the Iowa District Court for Linn County. Plaintiffs assert claims of negligence and strict liability based on their allegations that CRANDIC (along with other defendants) caused or exacerbated flooding of the Cedar River in June 2008. In July 2013, the case was removed from state court to federal court based on federal jurisdiction. In September 2013, the U.S. District Court for the Northern District of Iowa dismissed the Plaintiffs’ claims and transferred the case for resolution to the Surface Transportation Board, the administrative agency that oversees the Interstate Commerce Commission Termination Act. In October 2013, the Plaintiffs appealed the federal court’s dismissal of the case to the Eighth Circuit Court of Appeals. In May 2015, the Eighth Circuit Court of Appeals vacated the U.S. District Court for the Northern District of Iowa’s decision and ordered the case remanded back to the Iowa District Court for Linn County. Alliant Energy and CRANDIC believe the case is without merit and will continue to vigorously contest the case. As a result, Alliant Energy does not currently believe any material losses from these claims are both probable and reasonably estimated, and therefore, has not recognized any material loss contingency amounts for this complaint as of June 30, 2015 . Due to the lack of specific damages identified and the procedural nature of the activity to date, Alliant Energy is currently unable to provide an estimate of potential loss or range of potential loss. (d) Guarantees and Indemnifications - RMT - In 2013, Alliant Energy sold RMT. RMT provided renewable energy services, including construction and high voltage connection services for wind and solar projects. As part of the sale, Alliant Energy indemnified the buyer for any claims, including claims of warranty under the project obligations that were commenced or are based on actions that occurred prior to the sale, except for liabilities already accounted for through adjustments to the purchase price. The indemnification obligations either cease to exist when the statute of limitation for such claims is met or, in the case of RMT’s projects, when the warranty period under the agreements expires. The contractual warranty periods for RMT’s projects generally range from 12 to 60 months with the latest expiring in 2016. Limited warranties may be extended in certain cases for warranty work performed. Alliant Energy also continues to guarantee RMT’s performance obligations related to certain of RMT’s projects that were commenced prior to Alliant Energy’s sale of RMT. As of June 30, 2015 , Alliant Energy had $198 million of performance guarantees outstanding, with $75 million , $48 million and $75 million currently expected to expire in 2015, 2016 and 2017, respectively. The expiration of these performance guarantees may be extended depending on when all valid warranty claims are resolved for the respective projects. Although Alliant Energy has received warranty claims related to certain of these projects, it does not currently believe that material losses are both probable and reasonably estimated, and therefore, has not recognized any material liabilities related to these matters as of June 30, 2015 . Alliant Energy does not currently believe that the range of future potential loss from any warranty claims will be material. Refer to Note 16 for further discussion of RMT, including amounts Alliant Energy recorded to “Operating expenses” in the second quarter of 2015 related to certain warranty claims. Whiting Petroleum - In 2004, Alliant Energy sold its remaining interest in Whiting Petroleum. Whiting Petroleum is an independent oil and gas company. Alliant Energy continues to guarantee the obligations related to the abandonment of certain platforms off the coast of California and related onshore plant and equipment that were owned by Whiting Petroleum prior to Alliant Energy’s sale of Whiting Petroleum. The guarantee does not include a maximum limit. As of June 30, 2015 , the present value of the abandonment obligations is estimated at $36 million . Alliant Energy believes that no payments will be made under this guarantee. Alliant Energy has not recognized any material liabilities related to this guarantee as of June 30, 2015 . (e) Environmental Matters - MGP Sites - IPL and WPL have current or previous ownership interests in various sites that are previously associated with the production of gas for which IPL and WPL have, or may have in the future, liability for investigation, remediation and monitoring costs. IPL and WPL are working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around these former MGP sites in order to protect public health and the environment. IPL and WPL are currently monitoring and/or remediating 24 and 5 sites, respectively. No longer included in IPL’s sites is a Minnesota site for which responsibility of monitoring and/or remediating the site was transferred to the buyer as part of the sale of IPL’s Minnesota natural gas distribution assets completed in April 2015. Environmental liabilities related to the MGP sites are recorded based upon periodic studies. Such amounts are based on the best current estimate of the remaining amount to be incurred for investigation, remediation and monitoring costs for those sites where the investigation process has been or is substantially completed, and the minimum of the estimated cost range for those sites where the investigation is in its earlier stages. There are inherent uncertainties associated with the estimated remaining costs for MGP projects primarily due to unknown site conditions and potential changes in regulatory agency requirements. It is possible that future cost estimates will be greater than current estimates as the investigation process proceeds and as additional facts become known. The amounts recognized as liabilities are reduced for expenditures incurred and are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted. At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 WPL Consent Decree - In 2009, the EPA sent a notice of violation to WPL as an owner and the operator of Edgewater, Nelson Dewey and Columbia alleging that the owners of such EGUs failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin State Implementation Plan. In 2010, the Sierra Club filed complaints against WPL, as owner and operator of Nelson Dewey and Columbia, and separately as owner and operator of Edgewater, based on allegations that modifications were made at the facilities without complying with the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and state regulatory counterparts contained within the Wisconsin State Implementation Plan designed to implement the CAA. In April 2013, WPL, along with the other owners of Edgewater and Columbia, entered into a Consent Decree with the EPA and the Sierra Club to resolve the claims relating to Edgewater, Columbia and Nelson Dewey, while admitting no liability. In June 2013, the Consent Decree was approved by the U.S. District Court for the Western District of Wisconsin, thereby resolving all claims against WPL. Under the Consent Decree, WPL is required to install the following emission controls systems: • SCR system at Edgewater Unit 5 by May 1, 2013 (placed in service in 2012); • Scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 (placed in service in 2014); • Scrubber and baghouse at Edgewater Unit 5 by December 31, 2016; and • SCR system at Columbia Unit 2 by December 31, 2018. WPL is also required to fuel switch or retire Nelson Dewey Units 1 and 2 and Edgewater Unit 3 by December 31, 2015, and Edgewater Unit 4 by December 31, 2018. In addition, the Consent Decree establishes emission rate limits for SO2, NOx and particulate matter for Columbia Units 1 and 2, Nelson Dewey Units 1 and 2 and Edgewater Units 4 and 5. The Consent Decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia, Edgewater and Nelson Dewey. In addition, WPL will complete approximately $7 million in environmental mitigation projects. Final recovery of the costs expected to be incurred related to the Consent Decree will be decided by the PSCW in future rate cases or other proceedings. Alliant Energy and WPL currently expect to recover any material costs incurred by WPL related to compliance with the terms of the Consent Decree from WPL’s electric customers. Other Environmental Contingencies - In addition to the environmental liabilities discussed above, various environmental rules are monitored that may have a significant impact on future operations. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Given uncertainties regarding the outcome, timing and compliance plans for these environmental matters, the complete financial impact of each of these rules is not able to be determined; however future capital investments and/or modifications to EGUs to comply with certain of these rules could be significant. Specific current, proposed or potential environmental matters include, among others: Cross-State Air Pollution Rule, Clean Air Visibility Rule, Mercury and Air Toxic Standard Rule, Industrial Boiler and Process Heater Maximum Achievable Control Technology Rule, Ozone National Ambient Air Quality Standards Rule, SO2 National Ambient Air Quality Standards Rule, Federal Clean Water Act including Section 316(b), Effluent Limitation Guidelines, Hydroelectric Fish Passage Device, CCR Rule, and various legislation and EPA regulations to monitor and regulate the emission of greenhouse gases, including carbon emissions from new (CAA Section 111(b)) and existing (CAA Section 111(d)) fossil-fueled EGUs. Some recent developments concerning these environmental matters are included below: Air Quality - Clean Air Act Section 111(d) - In August 2015, the EPA issued final standards under Section 111(d) of the CAA, which establish guidelines for states to follow in developing plans to reduce carbon dioxide emissions from existing fossil-fueled EGUs. The final standards include an interim compliance period from 2022 through 2029 and a final compliance goal beginning in 2030. In August 2015, the EPA also issued a proposed federal plan that would be implemented in states that do not have a fully approved state plan. Clean Air Act Section 111(b) - In August 2015, the EPA issued final standards under Section 111(b) of the CAA, which establish carbon dioxide emissions limits for certain new fossil-fueled EGUs. Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these standards. Marshalltown is being constructed, and WPL’s proposed Riverside expansion is being designed, to achieve compliance with these standards. Land and Solid Waste - CCR Rule - Refer to Note 10 for discussion of the final CCR Rule, including additional AROs that were recognized in the second quarter of 2015 related to such rule. |
IPL [Member] | |
Commitments and Contingencies Disclosure | COMMITMENTS AND CONTINGENCIES (a) Capital Purchase Obligations - Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects. WPL’s projects include the installation of a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions, and generation maintenance and performance improvements at Columbia Units 1 and 2. At June 30, 2015 , Alliant Energy’s and WPL’s minimum future commitments related to certain contractual obligations for these projects were $30 million . (b) Operating Expense Purchase Obligations - Various commodity supply, transportation and storage contracts help meet obligations to provide electricity and natural gas to utility customers. Other operating expense purchase obligations with various vendors provide other goods and services. At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . (c) Legal Proceedings - IPL Consent Decree - In July 2015, IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. In July 2015, the Consent Decree was lodged with, and is subject to approval by, the U.S. District Court for the Northern District of Iowa. Under the Consent Decree, IPL is required to install the following emission control systems: • Scrubber and baghouse at the Ottumwa Generating Station by December 31, 2015 (placed in service in 2014); • Scrubber and baghouse at the Lansing Generating Station by December 31, 2016 (placed in service in June 2015 and in 2010, respectively); and • SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019. IPL is also required to fuel switch or retire the following EGUs: • M.L. Kapp Generating Station by August 31, 2015 (switched the fuel type from coal to natural gas in June 2015); • Prairie Creek Unit 4 by June 1, 2018; • Burlington Generating Station by December 31, 2021; and • Prairie Creek Units 1 and 3 by December 31, 2025. In addition, IPL is required to either install combined cycle technology at, or retire, the Dubuque and Sutherland Generation Stations by June 1, 2019. IPL previously switched the fuel type from coal to natural gas at these EGUs. The Consent Decree also establishes SO2, NOx and particulate matter emission rate limits with varying averaging times for the Burlington, Lansing, M.L. Kapp, Ottumwa and Prairie Creek Generating Stations. In addition, the Consent Decree includes calendar-year SO2 and NOx emission caps for the Prairie Creek Generating Station, and calendar-year SO2 and NOx emission caps in aggregate for the Burlington, Dubuque, Lansing, M.L. Kapp, Ottumwa, Prairie Creek and Sutherland Generating Stations. IPL will also pay a civil penalty of approximately $1 million and complete approximately $6 million in environmental mitigation projects. Alliant Energy and IPL currently expect to recover costs incurred by IPL related to the emission control systems and environmental mitigation projects from IPL’s electric customers. The recovery of such costs will be decided by IPL’s regulators in future rate cases or other proceedings. Alliant Energy and IPL currently do not expect to recover costs related to the civil penalty from IPL’s electric customers. Flood Damage Claims - In June 2013, several plaintiffs purporting to represent a class of residential and commercial property owners filed a complaint against CRANDIC, Alliant Energy and various other defendants in the Iowa District Court for Linn County. Plaintiffs assert claims of negligence and strict liability based on their allegations that CRANDIC (along with other defendants) caused or exacerbated flooding of the Cedar River in June 2008. In July 2013, the case was removed from state court to federal court based on federal jurisdiction. In September 2013, the U.S. District Court for the Northern District of Iowa dismissed the Plaintiffs’ claims and transferred the case for resolution to the Surface Transportation Board, the administrative agency that oversees the Interstate Commerce Commission Termination Act. In October 2013, the Plaintiffs appealed the federal court’s dismissal of the case to the Eighth Circuit Court of Appeals. In May 2015, the Eighth Circuit Court of Appeals vacated the U.S. District Court for the Northern District of Iowa’s decision and ordered the case remanded back to the Iowa District Court for Linn County. Alliant Energy and CRANDIC believe the case is without merit and will continue to vigorously contest the case. As a result, Alliant Energy does not currently believe any material losses from these claims are both probable and reasonably estimated, and therefore, has not recognized any material loss contingency amounts for this complaint as of June 30, 2015 . Due to the lack of specific damages identified and the procedural nature of the activity to date, Alliant Energy is currently unable to provide an estimate of potential loss or range of potential loss. (d) Guarantees and Indemnifications - RMT - In 2013, Alliant Energy sold RMT. RMT provided renewable energy services, including construction and high voltage connection services for wind and solar projects. As part of the sale, Alliant Energy indemnified the buyer for any claims, including claims of warranty under the project obligations that were commenced or are based on actions that occurred prior to the sale, except for liabilities already accounted for through adjustments to the purchase price. The indemnification obligations either cease to exist when the statute of limitation for such claims is met or, in the case of RMT’s projects, when the warranty period under the agreements expires. The contractual warranty periods for RMT’s projects generally range from 12 to 60 months with the latest expiring in 2016. Limited warranties may be extended in certain cases for warranty work performed. Alliant Energy also continues to guarantee RMT’s performance obligations related to certain of RMT’s projects that were commenced prior to Alliant Energy’s sale of RMT. As of June 30, 2015 , Alliant Energy had $198 million of performance guarantees outstanding, with $75 million , $48 million and $75 million currently expected to expire in 2015, 2016 and 2017, respectively. The expiration of these performance guarantees may be extended depending on when all valid warranty claims are resolved for the respective projects. Although Alliant Energy has received warranty claims related to certain of these projects, it does not currently believe that material losses are both probable and reasonably estimated, and therefore, has not recognized any material liabilities related to these matters as of June 30, 2015 . Alliant Energy does not currently believe that the range of future potential loss from any warranty claims will be material. Refer to Note 16 for further discussion of RMT, including amounts Alliant Energy recorded to “Operating expenses” in the second quarter of 2015 related to certain warranty claims. Whiting Petroleum - In 2004, Alliant Energy sold its remaining interest in Whiting Petroleum. Whiting Petroleum is an independent oil and gas company. Alliant Energy continues to guarantee the obligations related to the abandonment of certain platforms off the coast of California and related onshore plant and equipment that were owned by Whiting Petroleum prior to Alliant Energy’s sale of Whiting Petroleum. The guarantee does not include a maximum limit. As of June 30, 2015 , the present value of the abandonment obligations is estimated at $36 million . Alliant Energy believes that no payments will be made under this guarantee. Alliant Energy has not recognized any material liabilities related to this guarantee as of June 30, 2015 . (e) Environmental Matters - MGP Sites - IPL and WPL have current or previous ownership interests in various sites that are previously associated with the production of gas for which IPL and WPL have, or may have in the future, liability for investigation, remediation and monitoring costs. IPL and WPL are working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around these former MGP sites in order to protect public health and the environment. IPL and WPL are currently monitoring and/or remediating 24 and 5 sites, respectively. No longer included in IPL’s sites is a Minnesota site for which responsibility of monitoring and/or remediating the site was transferred to the buyer as part of the sale of IPL’s Minnesota natural gas distribution assets completed in April 2015. Environmental liabilities related to the MGP sites are recorded based upon periodic studies. Such amounts are based on the best current estimate of the remaining amount to be incurred for investigation, remediation and monitoring costs for those sites where the investigation process has been or is substantially completed, and the minimum of the estimated cost range for those sites where the investigation is in its earlier stages. There are inherent uncertainties associated with the estimated remaining costs for MGP projects primarily due to unknown site conditions and potential changes in regulatory agency requirements. It is possible that future cost estimates will be greater than current estimates as the investigation process proceeds and as additional facts become known. The amounts recognized as liabilities are reduced for expenditures incurred and are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted. At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 WPL Consent Decree - In 2009, the EPA sent a notice of violation to WPL as an owner and the operator of Edgewater, Nelson Dewey and Columbia alleging that the owners of such EGUs failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin State Implementation Plan. In 2010, the Sierra Club filed complaints against WPL, as owner and operator of Nelson Dewey and Columbia, and separately as owner and operator of Edgewater, based on allegations that modifications were made at the facilities without complying with the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and state regulatory counterparts contained within the Wisconsin State Implementation Plan designed to implement the CAA. In April 2013, WPL, along with the other owners of Edgewater and Columbia, entered into a Consent Decree with the EPA and the Sierra Club to resolve the claims relating to Edgewater, Columbia and Nelson Dewey, while admitting no liability. In June 2013, the Consent Decree was approved by the U.S. District Court for the Western District of Wisconsin, thereby resolving all claims against WPL. Under the Consent Decree, WPL is required to install the following emission controls systems: • SCR system at Edgewater Unit 5 by May 1, 2013 (placed in service in 2012); • Scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 (placed in service in 2014); • Scrubber and baghouse at Edgewater Unit 5 by December 31, 2016; and • SCR system at Columbia Unit 2 by December 31, 2018. WPL is also required to fuel switch or retire Nelson Dewey Units 1 and 2 and Edgewater Unit 3 by December 31, 2015, and Edgewater Unit 4 by December 31, 2018. In addition, the Consent Decree establishes emission rate limits for SO2, NOx and particulate matter for Columbia Units 1 and 2, Nelson Dewey Units 1 and 2 and Edgewater Units 4 and 5. The Consent Decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia, Edgewater and Nelson Dewey. In addition, WPL will complete approximately $7 million in environmental mitigation projects. Final recovery of the costs expected to be incurred related to the Consent Decree will be decided by the PSCW in future rate cases or other proceedings. Alliant Energy and WPL currently expect to recover any material costs incurred by WPL related to compliance with the terms of the Consent Decree from WPL’s electric customers. Other Environmental Contingencies - In addition to the environmental liabilities discussed above, various environmental rules are monitored that may have a significant impact on future operations. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Given uncertainties regarding the outcome, timing and compliance plans for these environmental matters, the complete financial impact of each of these rules is not able to be determined; however future capital investments and/or modifications to EGUs to comply with certain of these rules could be significant. Specific current, proposed or potential environmental matters include, among others: Cross-State Air Pollution Rule, Clean Air Visibility Rule, Mercury and Air Toxic Standard Rule, Industrial Boiler and Process Heater Maximum Achievable Control Technology Rule, Ozone National Ambient Air Quality Standards Rule, SO2 National Ambient Air Quality Standards Rule, Federal Clean Water Act including Section 316(b), Effluent Limitation Guidelines, Hydroelectric Fish Passage Device, CCR Rule, and various legislation and EPA regulations to monitor and regulate the emission of greenhouse gases, including carbon emissions from new (CAA Section 111(b)) and existing (CAA Section 111(d)) fossil-fueled EGUs. Some recent developments concerning these environmental matters are included below: Air Quality - Clean Air Act Section 111(d) - In August 2015, the EPA issued final standards under Section 111(d) of the CAA, which establish guidelines for states to follow in developing plans to reduce carbon dioxide emissions from existing fossil-fueled EGUs. The final standards include an interim compliance period from 2022 through 2029 and a final compliance goal beginning in 2030. In August 2015, the EPA also issued a proposed federal plan that would be implemented in states that do not have a fully approved state plan. Clean Air Act Section 111(b) - In August 2015, the EPA issued final standards under Section 111(b) of the CAA, which establish carbon dioxide emissions limits for certain new fossil-fueled EGUs. Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these standards. Marshalltown is being constructed, and WPL’s proposed Riverside expansion is being designed, to achieve compliance with these standards. Land and Solid Waste - CCR Rule - Refer to Note 10 for discussion of the final CCR Rule, including additional AROs that were recognized in the second quarter of 2015 related to such rule. |
WPL [Member] | |
Commitments and Contingencies Disclosure | COMMITMENTS AND CONTINGENCIES (a) Capital Purchase Obligations - Various contractual obligations contain minimum future commitments related to capital expenditures for certain construction projects. WPL’s projects include the installation of a scrubber and baghouse at Edgewater Unit 5 to reduce SO2 and mercury emissions, and generation maintenance and performance improvements at Columbia Units 1 and 2. At June 30, 2015 , Alliant Energy’s and WPL’s minimum future commitments related to certain contractual obligations for these projects were $30 million . (b) Operating Expense Purchase Obligations - Various commodity supply, transportation and storage contracts help meet obligations to provide electricity and natural gas to utility customers. Other operating expense purchase obligations with various vendors provide other goods and services. At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . (c) Legal Proceedings - IPL Consent Decree - In July 2015, IPL entered into a Consent Decree with the EPA, the Sierra Club, the State of Iowa and Linn County in Iowa to resolve potential claims regarding CAA issues associated with emissions from IPL’s coal-fired generating facilities in Iowa, while admitting no liability. In July 2015, the Consent Decree was lodged with, and is subject to approval by, the U.S. District Court for the Northern District of Iowa. Under the Consent Decree, IPL is required to install the following emission control systems: • Scrubber and baghouse at the Ottumwa Generating Station by December 31, 2015 (placed in service in 2014); • Scrubber and baghouse at the Lansing Generating Station by December 31, 2016 (placed in service in June 2015 and in 2010, respectively); and • SCR system or equivalent NOx reduction system at the Ottumwa Generating Station by December 31, 2019. IPL is also required to fuel switch or retire the following EGUs: • M.L. Kapp Generating Station by August 31, 2015 (switched the fuel type from coal to natural gas in June 2015); • Prairie Creek Unit 4 by June 1, 2018; • Burlington Generating Station by December 31, 2021; and • Prairie Creek Units 1 and 3 by December 31, 2025. In addition, IPL is required to either install combined cycle technology at, or retire, the Dubuque and Sutherland Generation Stations by June 1, 2019. IPL previously switched the fuel type from coal to natural gas at these EGUs. The Consent Decree also establishes SO2, NOx and particulate matter emission rate limits with varying averaging times for the Burlington, Lansing, M.L. Kapp, Ottumwa and Prairie Creek Generating Stations. In addition, the Consent Decree includes calendar-year SO2 and NOx emission caps for the Prairie Creek Generating Station, and calendar-year SO2 and NOx emission caps in aggregate for the Burlington, Dubuque, Lansing, M.L. Kapp, Ottumwa, Prairie Creek and Sutherland Generating Stations. IPL will also pay a civil penalty of approximately $1 million and complete approximately $6 million in environmental mitigation projects. Alliant Energy and IPL currently expect to recover costs incurred by IPL related to the emission control systems and environmental mitigation projects from IPL’s electric customers. The recovery of such costs will be decided by IPL’s regulators in future rate cases or other proceedings. Alliant Energy and IPL currently do not expect to recover costs related to the civil penalty from IPL’s electric customers. Flood Damage Claims - In June 2013, several plaintiffs purporting to represent a class of residential and commercial property owners filed a complaint against CRANDIC, Alliant Energy and various other defendants in the Iowa District Court for Linn County. Plaintiffs assert claims of negligence and strict liability based on their allegations that CRANDIC (along with other defendants) caused or exacerbated flooding of the Cedar River in June 2008. In July 2013, the case was removed from state court to federal court based on federal jurisdiction. In September 2013, the U.S. District Court for the Northern District of Iowa dismissed the Plaintiffs’ claims and transferred the case for resolution to the Surface Transportation Board, the administrative agency that oversees the Interstate Commerce Commission Termination Act. In October 2013, the Plaintiffs appealed the federal court’s dismissal of the case to the Eighth Circuit Court of Appeals. In May 2015, the Eighth Circuit Court of Appeals vacated the U.S. District Court for the Northern District of Iowa’s decision and ordered the case remanded back to the Iowa District Court for Linn County. Alliant Energy and CRANDIC believe the case is without merit and will continue to vigorously contest the case. As a result, Alliant Energy does not currently believe any material losses from these claims are both probable and reasonably estimated, and therefore, has not recognized any material loss contingency amounts for this complaint as of June 30, 2015 . Due to the lack of specific damages identified and the procedural nature of the activity to date, Alliant Energy is currently unable to provide an estimate of potential loss or range of potential loss. (d) Guarantees and Indemnifications - RMT - In 2013, Alliant Energy sold RMT. RMT provided renewable energy services, including construction and high voltage connection services for wind and solar projects. As part of the sale, Alliant Energy indemnified the buyer for any claims, including claims of warranty under the project obligations that were commenced or are based on actions that occurred prior to the sale, except for liabilities already accounted for through adjustments to the purchase price. The indemnification obligations either cease to exist when the statute of limitation for such claims is met or, in the case of RMT’s projects, when the warranty period under the agreements expires. The contractual warranty periods for RMT’s projects generally range from 12 to 60 months with the latest expiring in 2016. Limited warranties may be extended in certain cases for warranty work performed. Alliant Energy also continues to guarantee RMT’s performance obligations related to certain of RMT’s projects that were commenced prior to Alliant Energy’s sale of RMT. As of June 30, 2015 , Alliant Energy had $198 million of performance guarantees outstanding, with $75 million , $48 million and $75 million currently expected to expire in 2015, 2016 and 2017, respectively. The expiration of these performance guarantees may be extended depending on when all valid warranty claims are resolved for the respective projects. Although Alliant Energy has received warranty claims related to certain of these projects, it does not currently believe that material losses are both probable and reasonably estimated, and therefore, has not recognized any material liabilities related to these matters as of June 30, 2015 . Alliant Energy does not currently believe that the range of future potential loss from any warranty claims will be material. Refer to Note 16 for further discussion of RMT, including amounts Alliant Energy recorded to “Operating expenses” in the second quarter of 2015 related to certain warranty claims. Whiting Petroleum - In 2004, Alliant Energy sold its remaining interest in Whiting Petroleum. Whiting Petroleum is an independent oil and gas company. Alliant Energy continues to guarantee the obligations related to the abandonment of certain platforms off the coast of California and related onshore plant and equipment that were owned by Whiting Petroleum prior to Alliant Energy’s sale of Whiting Petroleum. The guarantee does not include a maximum limit. As of June 30, 2015 , the present value of the abandonment obligations is estimated at $36 million . Alliant Energy believes that no payments will be made under this guarantee. Alliant Energy has not recognized any material liabilities related to this guarantee as of June 30, 2015 . (e) Environmental Matters - MGP Sites - IPL and WPL have current or previous ownership interests in various sites that are previously associated with the production of gas for which IPL and WPL have, or may have in the future, liability for investigation, remediation and monitoring costs. IPL and WPL are working pursuant to the requirements of various federal and state agencies to investigate, mitigate, prevent and remediate, where necessary, the environmental impacts to property, including natural resources, at and around these former MGP sites in order to protect public health and the environment. IPL and WPL are currently monitoring and/or remediating 24 and 5 sites, respectively. No longer included in IPL’s sites is a Minnesota site for which responsibility of monitoring and/or remediating the site was transferred to the buyer as part of the sale of IPL’s Minnesota natural gas distribution assets completed in April 2015. Environmental liabilities related to the MGP sites are recorded based upon periodic studies. Such amounts are based on the best current estimate of the remaining amount to be incurred for investigation, remediation and monitoring costs for those sites where the investigation process has been or is substantially completed, and the minimum of the estimated cost range for those sites where the investigation is in its earlier stages. There are inherent uncertainties associated with the estimated remaining costs for MGP projects primarily due to unknown site conditions and potential changes in regulatory agency requirements. It is possible that future cost estimates will be greater than current estimates as the investigation process proceeds and as additional facts become known. The amounts recognized as liabilities are reduced for expenditures incurred and are adjusted as further information develops or circumstances change. Costs of future expenditures for environmental remediation obligations are not discounted. At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 WPL Consent Decree - In 2009, the EPA sent a notice of violation to WPL as an owner and the operator of Edgewater, Nelson Dewey and Columbia alleging that the owners of such EGUs failed to comply with appropriate pre-construction review and permitting requirements and as a result violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and the Wisconsin State Implementation Plan. In 2010, the Sierra Club filed complaints against WPL, as owner and operator of Nelson Dewey and Columbia, and separately as owner and operator of Edgewater, based on allegations that modifications were made at the facilities without complying with the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA and state regulatory counterparts contained within the Wisconsin State Implementation Plan designed to implement the CAA. In April 2013, WPL, along with the other owners of Edgewater and Columbia, entered into a Consent Decree with the EPA and the Sierra Club to resolve the claims relating to Edgewater, Columbia and Nelson Dewey, while admitting no liability. In June 2013, the Consent Decree was approved by the U.S. District Court for the Western District of Wisconsin, thereby resolving all claims against WPL. Under the Consent Decree, WPL is required to install the following emission controls systems: • SCR system at Edgewater Unit 5 by May 1, 2013 (placed in service in 2012); • Scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014 (placed in service in 2014); • Scrubber and baghouse at Edgewater Unit 5 by December 31, 2016; and • SCR system at Columbia Unit 2 by December 31, 2018. WPL is also required to fuel switch or retire Nelson Dewey Units 1 and 2 and Edgewater Unit 3 by December 31, 2015, and Edgewater Unit 4 by December 31, 2018. In addition, the Consent Decree establishes emission rate limits for SO2, NOx and particulate matter for Columbia Units 1 and 2, Nelson Dewey Units 1 and 2 and Edgewater Units 4 and 5. The Consent Decree also includes annual plant-wide emission caps for SO2 and NOx for Columbia, Edgewater and Nelson Dewey. In addition, WPL will complete approximately $7 million in environmental mitigation projects. Final recovery of the costs expected to be incurred related to the Consent Decree will be decided by the PSCW in future rate cases or other proceedings. Alliant Energy and WPL currently expect to recover any material costs incurred by WPL related to compliance with the terms of the Consent Decree from WPL’s electric customers. Other Environmental Contingencies - In addition to the environmental liabilities discussed above, various environmental rules are monitored that may have a significant impact on future operations. Several of these environmental rules are subject to legal challenges, reconsideration and/or other uncertainties. Given uncertainties regarding the outcome, timing and compliance plans for these environmental matters, the complete financial impact of each of these rules is not able to be determined; however future capital investments and/or modifications to EGUs to comply with certain of these rules could be significant. Specific current, proposed or potential environmental matters include, among others: Cross-State Air Pollution Rule, Clean Air Visibility Rule, Mercury and Air Toxic Standard Rule, Industrial Boiler and Process Heater Maximum Achievable Control Technology Rule, Ozone National Ambient Air Quality Standards Rule, SO2 National Ambient Air Quality Standards Rule, Federal Clean Water Act including Section 316(b), Effluent Limitation Guidelines, Hydroelectric Fish Passage Device, CCR Rule, and various legislation and EPA regulations to monitor and regulate the emission of greenhouse gases, including carbon emissions from new (CAA Section 111(b)) and existing (CAA Section 111(d)) fossil-fueled EGUs. Some recent developments concerning these environmental matters are included below: Air Quality - Clean Air Act Section 111(d) - In August 2015, the EPA issued final standards under Section 111(d) of the CAA, which establish guidelines for states to follow in developing plans to reduce carbon dioxide emissions from existing fossil-fueled EGUs. The final standards include an interim compliance period from 2022 through 2029 and a final compliance goal beginning in 2030. In August 2015, the EPA also issued a proposed federal plan that would be implemented in states that do not have a fully approved state plan. Clean Air Act Section 111(b) - In August 2015, the EPA issued final standards under Section 111(b) of the CAA, which establish carbon dioxide emissions limits for certain new fossil-fueled EGUs. Marshalltown and WPL’s proposed Riverside expansion are expected to be impacted by these standards. Marshalltown is being constructed, and WPL’s proposed Riverside expansion is being designed, to achieve compliance with these standards. Land and Solid Waste - CCR Rule - Refer to Note 10 for discussion of the final CCR Rule, including additional AROs that were recognized in the second quarter of 2015 related to such rule. |
Segments Of Business
Segments Of Business | 6 Months Ended |
Jun. 30, 2015 | |
Segment Reporting Information [Line Items] | |
Segments Of Business | SEGMENTS OF BUSINESS Alliant Energy - Certain financial information relating to Alliant Energy’s business segments is as follows. Intersegment revenues were not material to Alliant Energy’s operations. Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Three Months Ended June 30, 2015 Operating revenues $640.4 $51.7 $14.8 $706.9 $10.3 $717.2 Operating income (loss) 100.9 (2.0 ) 3.2 102.1 6.9 109.0 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 55.7 13.2 68.9 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 55.7 11.9 67.6 Three Months Ended June 30, 2014 Operating revenues $643.9 $76.9 $15.6 $736.4 $13.9 $750.3 Operating income 89.1 2.7 2.2 94.0 9.3 103.3 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 53.0 9.1 62.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 53.0 8.8 61.8 Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Six Months Ended June 30, 2015 Operating revenues $1,311.7 $250.1 $31.2 $1,593.0 $21.6 $1,614.6 Operating income 205.6 34.3 8.5 248.4 13.5 261.9 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 148.1 17.4 165.5 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 148.1 16.1 164.2 Six Months Ended June 30, 2014 Operating revenues $1,319.7 $317.6 $38.4 $1,675.7 $27.4 $1,703.1 Operating income 183.4 45.7 10.1 239.2 18.3 257.5 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 151.2 18.9 170.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 151.2 18.6 169.8 IPL - Certain financial information relating to IPL’s business segments is as follows. Intersegment revenues were not material to IPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $339.4 $29.8 $13.0 $382.2 Operating income (loss) 33.9 (2.4 ) 2.3 33.8 Earnings available for common stock 16.7 Three Months Ended June 30, 2014 Operating revenues $354.6 $43.7 $13.6 $411.9 Operating income 29.0 1.6 3.4 34.0 Earnings available for common stock 18.4 Six Months Ended June 30, 2015 Operating revenues $702.0 $141.0 $28.2 $871.2 Operating income 74.2 18.2 6.9 99.3 Earnings available for common stock 64.5 Six Months Ended June 30, 2014 Operating revenues $728.8 $179.4 $32.6 $940.8 Operating income 55.5 24.9 11.1 91.5 Earnings available for common stock 61.8 WPL - Certain financial information relating to WPL’s business segments is as follows. Intersegment revenues were not material to WPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $301.0 $21.9 $1.8 $324.7 Operating income 67.0 0.4 0.9 68.3 Earnings available for common stock 39.0 Three Months Ended June 30, 2014 Operating revenues $289.3 $33.2 $2.0 $324.5 Operating income (loss) 60.1 1.1 (1.2 ) 60.0 Earnings available for common stock 34.6 Six Months Ended June 30, 2015 Operating revenues $609.7 $109.1 $3.0 $721.8 Operating income 131.4 16.1 1.6 149.1 Earnings available for common stock 83.6 Six Months Ended June 30, 2014 Operating revenues $590.9 $138.2 $5.8 $734.9 Operating income (loss) 127.9 20.8 (1.0 ) 147.7 Earnings available for common stock 89.4 |
IPL [Member] | |
Segment Reporting Information [Line Items] | |
Segments Of Business | SEGMENTS OF BUSINESS Alliant Energy - Certain financial information relating to Alliant Energy’s business segments is as follows. Intersegment revenues were not material to Alliant Energy’s operations. Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Three Months Ended June 30, 2015 Operating revenues $640.4 $51.7 $14.8 $706.9 $10.3 $717.2 Operating income (loss) 100.9 (2.0 ) 3.2 102.1 6.9 109.0 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 55.7 13.2 68.9 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 55.7 11.9 67.6 Three Months Ended June 30, 2014 Operating revenues $643.9 $76.9 $15.6 $736.4 $13.9 $750.3 Operating income 89.1 2.7 2.2 94.0 9.3 103.3 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 53.0 9.1 62.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 53.0 8.8 61.8 Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Six Months Ended June 30, 2015 Operating revenues $1,311.7 $250.1 $31.2 $1,593.0 $21.6 $1,614.6 Operating income 205.6 34.3 8.5 248.4 13.5 261.9 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 148.1 17.4 165.5 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 148.1 16.1 164.2 Six Months Ended June 30, 2014 Operating revenues $1,319.7 $317.6 $38.4 $1,675.7 $27.4 $1,703.1 Operating income 183.4 45.7 10.1 239.2 18.3 257.5 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 151.2 18.9 170.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 151.2 18.6 169.8 IPL - Certain financial information relating to IPL’s business segments is as follows. Intersegment revenues were not material to IPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $339.4 $29.8 $13.0 $382.2 Operating income (loss) 33.9 (2.4 ) 2.3 33.8 Earnings available for common stock 16.7 Three Months Ended June 30, 2014 Operating revenues $354.6 $43.7 $13.6 $411.9 Operating income 29.0 1.6 3.4 34.0 Earnings available for common stock 18.4 Six Months Ended June 30, 2015 Operating revenues $702.0 $141.0 $28.2 $871.2 Operating income 74.2 18.2 6.9 99.3 Earnings available for common stock 64.5 Six Months Ended June 30, 2014 Operating revenues $728.8 $179.4 $32.6 $940.8 Operating income 55.5 24.9 11.1 91.5 Earnings available for common stock 61.8 WPL - Certain financial information relating to WPL’s business segments is as follows. Intersegment revenues were not material to WPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $301.0 $21.9 $1.8 $324.7 Operating income 67.0 0.4 0.9 68.3 Earnings available for common stock 39.0 Three Months Ended June 30, 2014 Operating revenues $289.3 $33.2 $2.0 $324.5 Operating income (loss) 60.1 1.1 (1.2 ) 60.0 Earnings available for common stock 34.6 Six Months Ended June 30, 2015 Operating revenues $609.7 $109.1 $3.0 $721.8 Operating income 131.4 16.1 1.6 149.1 Earnings available for common stock 83.6 Six Months Ended June 30, 2014 Operating revenues $590.9 $138.2 $5.8 $734.9 Operating income (loss) 127.9 20.8 (1.0 ) 147.7 Earnings available for common stock 89.4 |
WPL [Member] | |
Segment Reporting Information [Line Items] | |
Segments Of Business | SEGMENTS OF BUSINESS Alliant Energy - Certain financial information relating to Alliant Energy’s business segments is as follows. Intersegment revenues were not material to Alliant Energy’s operations. Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Three Months Ended June 30, 2015 Operating revenues $640.4 $51.7 $14.8 $706.9 $10.3 $717.2 Operating income (loss) 100.9 (2.0 ) 3.2 102.1 6.9 109.0 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 55.7 13.2 68.9 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 55.7 11.9 67.6 Three Months Ended June 30, 2014 Operating revenues $643.9 $76.9 $15.6 $736.4 $13.9 $750.3 Operating income 89.1 2.7 2.2 94.0 9.3 103.3 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 53.0 9.1 62.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 53.0 8.8 61.8 Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Six Months Ended June 30, 2015 Operating revenues $1,311.7 $250.1 $31.2 $1,593.0 $21.6 $1,614.6 Operating income 205.6 34.3 8.5 248.4 13.5 261.9 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 148.1 17.4 165.5 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 148.1 16.1 164.2 Six Months Ended June 30, 2014 Operating revenues $1,319.7 $317.6 $38.4 $1,675.7 $27.4 $1,703.1 Operating income 183.4 45.7 10.1 239.2 18.3 257.5 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 151.2 18.9 170.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 151.2 18.6 169.8 IPL - Certain financial information relating to IPL’s business segments is as follows. Intersegment revenues were not material to IPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $339.4 $29.8 $13.0 $382.2 Operating income (loss) 33.9 (2.4 ) 2.3 33.8 Earnings available for common stock 16.7 Three Months Ended June 30, 2014 Operating revenues $354.6 $43.7 $13.6 $411.9 Operating income 29.0 1.6 3.4 34.0 Earnings available for common stock 18.4 Six Months Ended June 30, 2015 Operating revenues $702.0 $141.0 $28.2 $871.2 Operating income 74.2 18.2 6.9 99.3 Earnings available for common stock 64.5 Six Months Ended June 30, 2014 Operating revenues $728.8 $179.4 $32.6 $940.8 Operating income 55.5 24.9 11.1 91.5 Earnings available for common stock 61.8 WPL - Certain financial information relating to WPL’s business segments is as follows. Intersegment revenues were not material to WPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $301.0 $21.9 $1.8 $324.7 Operating income 67.0 0.4 0.9 68.3 Earnings available for common stock 39.0 Three Months Ended June 30, 2014 Operating revenues $289.3 $33.2 $2.0 $324.5 Operating income (loss) 60.1 1.1 (1.2 ) 60.0 Earnings available for common stock 34.6 Six Months Ended June 30, 2015 Operating revenues $609.7 $109.1 $3.0 $721.8 Operating income 131.4 16.1 1.6 149.1 Earnings available for common stock 83.6 Six Months Ended June 30, 2014 Operating revenues $590.9 $138.2 $5.8 $734.9 Operating income (loss) 127.9 20.8 (1.0 ) 147.7 Earnings available for common stock 89.4 |
Related Parties
Related Parties | 6 Months Ended |
Jun. 30, 2015 | |
Related Party Transactions [Line Items] | |
Related Parties | RELATED PARTIES Service Agreements - IPL and WPL are parties to service agreements with an affiliate, Corporate Services. Pursuant to these service agreements, IPL and WPL receive various administrative and general services. These services are billed to IPL and WPL at cost based on expenses incurred by Corporate Services for the benefit of IPL and WPL, respectively. These costs consisted primarily of employee compensation and benefits, fees associated with various professional services and a return on net assets. Corporate Services also acts as agent on behalf of IPL and WPL pursuant to the service agreements. As agent, Corporate Services enters into energy, capacity, ancillary services, and transmission sale and purchase transactions within MISO and PJM. Corporate Services assigns such sales and purchases among IPL and WPL based on statements received from MISO and PJM. The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 ATC - Pursuant to various agreements, WPL receives a range of transmission services from ATC. WPL provides operation, maintenance, and construction services to ATC. WPL and ATC also bill each other for use of shared facilities owned by each party. The related amounts billed between the parties for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 ATC billings to WPL $25 $24 $50 $48 WPL billings to ATC 3 1 5 4 WPL owed ATC net amounts of $8 million as of June 30, 2015 and $8 million as of December 31, 2014 . |
IPL [Member] | |
Related Party Transactions [Line Items] | |
Related Parties | RELATED PARTIES Service Agreements - IPL and WPL are parties to service agreements with an affiliate, Corporate Services. Pursuant to these service agreements, IPL and WPL receive various administrative and general services. These services are billed to IPL and WPL at cost based on expenses incurred by Corporate Services for the benefit of IPL and WPL, respectively. These costs consisted primarily of employee compensation and benefits, fees associated with various professional services and a return on net assets. Corporate Services also acts as agent on behalf of IPL and WPL pursuant to the service agreements. As agent, Corporate Services enters into energy, capacity, ancillary services, and transmission sale and purchase transactions within MISO and PJM. Corporate Services assigns such sales and purchases among IPL and WPL based on statements received from MISO and PJM. The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 |
WPL [Member] | |
Related Party Transactions [Line Items] | |
Related Parties | RELATED PARTIES Service Agreements - IPL and WPL are parties to service agreements with an affiliate, Corporate Services. Pursuant to these service agreements, IPL and WPL receive various administrative and general services. These services are billed to IPL and WPL at cost based on expenses incurred by Corporate Services for the benefit of IPL and WPL, respectively. These costs consisted primarily of employee compensation and benefits, fees associated with various professional services and a return on net assets. Corporate Services also acts as agent on behalf of IPL and WPL pursuant to the service agreements. As agent, Corporate Services enters into energy, capacity, ancillary services, and transmission sale and purchase transactions within MISO and PJM. Corporate Services assigns such sales and purchases among IPL and WPL based on statements received from MISO and PJM. The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 ATC - Pursuant to various agreements, WPL receives a range of transmission services from ATC. WPL provides operation, maintenance, and construction services to ATC. WPL and ATC also bill each other for use of shared facilities owned by each party. The related amounts billed between the parties for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 ATC billings to WPL $25 $24 $50 $48 WPL billings to ATC 3 1 5 4 WPL owed ATC net amounts of $8 million as of June 30, 2015 and $8 million as of December 31, 2014 . |
Discontinued Operations And Ass
Discontinued Operations And Assets And Liabilities Held For Sale | 6 Months Ended |
Jun. 30, 2015 | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |
Discontinued Operations and Assets and Liabilities Held For Sale | DISCONTINUED OPERATIONS AND ASSETS AND LIABILITIES HELD FOR SALE In 2013, Alliant Energy sold RMT to narrow its strategic focus and risk profile. The operating results of RMT have been separately classified and reported as discontinued operations in Alliant Energy’s income statements. A summary of the components of discontinued operations in Alliant Energy’s income statements for the three and six months ended June 30 was as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Operating expenses $2.0 $0.6 $2.0 $0.6 Loss before income taxes (2.0 ) (0.6 ) (2.0 ) (0.6 ) Income tax benefit (0.7 ) (0.3 ) (0.7 ) (0.3 ) Loss from discontinued operations, net of tax ($1.3 ) ($0.3 ) ($1.3 ) ($0.3 ) Refer to Note 13(d) for further discussion of warranty claims associated with RMT that have resulted in operating expenses subsequent to the sale. In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets, which qualified as held for sale as of December 31, 2014. In July 2015, IPL completed the sale of its Minnesota electric distribution assets, which qualified as held for sale as of June 30, 2015. Alliant Energy and IPL evaluated the sales of IPL’s Minnesota electric and natural gas distribution assets and believe such sales did not represent a strategic shift that has, or will have, a major effect on their operational and financial results. As a result, the operating results of IPL’s Minnesota electric and natural gas distribution assets have not been separately classified and reported as discontinued operations in Alliant Energy’s and IPL’s income statements. Alliant Energy’s and IPL’s balance sheets included assets held for sale recorded in “Other current assets” and liabilities held for sale recorded in “Other current liabilities” as follows (in millions): Electric Natural Gas Distribution Assets Distribution Assets June 30, 2015 December 31, 2014 Assets held for sale: Current assets $9.3 $1.1 Property, plant and equipment, net 125.0 11.0 Non-current regulatory assets 20.5 7.0 Carrying value adjustment of net assets sold (a) (8.8 ) — Total assets held for sale 146.0 19.1 Liabilities held for sale: Current liabilities 2.4 1.0 Other liabilities 12.6 7.1 Total liabilities held for sale 15.0 8.1 Net assets held for sale $131.0 $11.0 (a) The carrying value of IPL’s Minnesota electric distribution assets classified as held for sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy and IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets. Refer to Note 3 for further discussion of IPL’s sales of its Minnesota electric and natural gas distribution assets. |
IPL [Member] | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |
Discontinued Operations and Assets and Liabilities Held For Sale | DISCONTINUED OPERATIONS AND ASSETS AND LIABILITIES HELD FOR SALE In 2013, Alliant Energy sold RMT to narrow its strategic focus and risk profile. The operating results of RMT have been separately classified and reported as discontinued operations in Alliant Energy’s income statements. A summary of the components of discontinued operations in Alliant Energy’s income statements for the three and six months ended June 30 was as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Operating expenses $2.0 $0.6 $2.0 $0.6 Loss before income taxes (2.0 ) (0.6 ) (2.0 ) (0.6 ) Income tax benefit (0.7 ) (0.3 ) (0.7 ) (0.3 ) Loss from discontinued operations, net of tax ($1.3 ) ($0.3 ) ($1.3 ) ($0.3 ) Refer to Note 13(d) for further discussion of warranty claims associated with RMT that have resulted in operating expenses subsequent to the sale. In April 2015, IPL completed the sale of its Minnesota natural gas distribution assets, which qualified as held for sale as of December 31, 2014. In July 2015, IPL completed the sale of its Minnesota electric distribution assets, which qualified as held for sale as of June 30, 2015. Alliant Energy and IPL evaluated the sales of IPL’s Minnesota electric and natural gas distribution assets and believe such sales did not represent a strategic shift that has, or will have, a major effect on their operational and financial results. As a result, the operating results of IPL’s Minnesota electric and natural gas distribution assets have not been separately classified and reported as discontinued operations in Alliant Energy’s and IPL’s income statements. Alliant Energy’s and IPL’s balance sheets included assets held for sale recorded in “Other current assets” and liabilities held for sale recorded in “Other current liabilities” as follows (in millions): Electric Natural Gas Distribution Assets Distribution Assets June 30, 2015 December 31, 2014 Assets held for sale: Current assets $9.3 $1.1 Property, plant and equipment, net 125.0 11.0 Non-current regulatory assets 20.5 7.0 Carrying value adjustment of net assets sold (a) (8.8 ) — Total assets held for sale 146.0 19.1 Liabilities held for sale: Current liabilities 2.4 1.0 Other liabilities 12.6 7.1 Total liabilities held for sale 15.0 8.1 Net assets held for sale $131.0 $11.0 (a) The carrying value of IPL’s Minnesota electric distribution assets classified as held for sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy and IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets. Refer to Note 3 for further discussion of IPL’s sales of its Minnesota electric and natural gas distribution assets. |
Summary Of Significant Accoun22
Summary Of Significant Accounting Policies (Policy) | 6 Months Ended |
Jun. 30, 2015 | |
General, Basis of Accounting | The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. |
General, Use of Estimates | In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. |
General, Reclassification | Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. |
New Accounting Pronouncements | New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
IPL [Member] | |
General, Basis of Accounting | The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. |
General, Use of Estimates | In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. |
General, Reclassification | Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. |
New Accounting Pronouncements | New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
WPL [Member] | |
General, Basis of Accounting | The interim unaudited Financial Statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted, although management believes that the disclosures are adequate to make the information presented not misleading. These Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the latest combined Annual Report on Form 10-K. |
General, Use of Estimates | In the opinion of management, all adjustments, which unless otherwise noted are normal and recurring in nature, necessary for a fair presentation of the results of operations, financial position and cash flows have been made. Results for the six months ended June 30, 2015 are not necessarily indicative of results that may be expected for the year ending December 31, 2015 . A change in management’s estimates or assumptions could have a material impact on financial condition and results of operations during the period in which such change occurred. |
General, Reclassification | Certain prior period amounts in the Financial Statements and Notes have been reclassified to conform to the current period presentation for comparative purposes. Unless otherwise noted, the Notes herein exclude discontinued operations for all periods presented. In addition, the Notes herein exclude assets and liabilities held for sale. |
New Accounting Pronouncements | New Accounting Pronouncements - Revenue Recognition - In May 2014, the Financial Accounting Standards Board issued an accounting standard providing principles for recognizing revenue for the transfer of promised goods or services to customers with the consideration to which the entity expects to be entitled in exchange for those goods or services. This standard also requires disclosures about the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In July 2015, the Financial Accounting Standards Board deferred the effective date of this standard. As a result, Alliant Energy, IPL and WPL are now required to adopt this standard on January 1, 2018. Early adoption on January 1, 2017 is permitted. Alliant Energy, IPL and WPL are currently evaluating the impact of this standard on their financial condition and results of operations. Presentation of Debt Issuance Costs - In April 2015, the Financial Accounting Standards Board issued an accounting standard to simplify the presentation of debt issuance costs on the balance sheet. Under the new standard, debt issuance costs related to a recognized debt liability will be presented on the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Alliant Energy, IPL and WPL are required to adopt this standard by January 1, 2016. Debt issuance costs represent less than 1% of total long-term debt. |
Regulatory Matters (Tables)
Regulatory Matters (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Regulatory Assets [Line Items] | |
Regulatory Assets | Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 |
Regulatory Liabilities | Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 |
Tax Benefit Riders | For the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by $41 million as follows (in millions): Electric tax benefit rider credits $35 Gas tax benefit rider credits 6 $41 |
Customer Billing Credits | For the three and six months ended June 30 , IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Billing credits to reduce retail electric customers’ bills $6 $20 $12 $20 |
IPL [Member] | |
Regulatory Assets [Line Items] | |
Regulatory Assets | Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 |
Regulatory Liabilities | Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 |
Tax Benefit Riders | For the six months ended June 30 , 2015 , Alliant Energy’s and IPL’s “IPL’s tax benefit riders” regulatory liabilities decreased by $41 million as follows (in millions): Electric tax benefit rider credits $35 Gas tax benefit rider credits 6 $41 |
Customer Billing Credits | For the three and six months ended June 30 , IPL recorded billing credits to reduce retail electric customers’ bills as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Billing credits to reduce retail electric customers’ bills $6 $20 $12 $20 |
WPL [Member] | |
Regulatory Assets [Line Items] | |
Regulatory Assets | Regulatory assets were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Tax-related $961.1 $955.3 $932.8 $928.0 $28.3 $27.3 Pension and OPEB costs 555.7 570.2 281.8 287.9 273.9 282.3 AROs 77.9 73.7 44.1 41.4 33.8 32.3 Derivatives 54.1 46.9 26.1 28.0 28.0 18.9 Commodity cost recovery 32.3 31.1 0.5 0.4 31.8 30.7 Emission allowances 26.7 27.4 26.7 27.4 — — Other 70.1 79.1 38.7 44.8 31.4 34.3 $1,777.9 $1,783.7 $1,350.7 $1,357.9 $427.2 $425.8 |
Regulatory Liabilities | Regulatory liabilities were comprised of the following items (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Cost of removal obligations $410.6 $421.7 $266.6 $279.1 $144.0 $142.6 IPL’s tax benefit riders 201.9 243.0 201.9 243.0 — — Energy efficiency cost recovery 58.5 64.3 1.7 — 56.8 64.3 IPL’s electric transmission cost recovery 24.3 19.4 24.3 19.4 — — Commodity cost recovery 16.6 15.4 11.6 15.1 5.0 0.3 Other 58.2 57.4 25.9 26.9 32.3 30.5 $770.1 $821.2 $532.0 $583.5 $238.1 $237.7 |
Receivables (Tables)
Receivables (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Receivables [Line Items] | |
Maximum And Average Outstanding Cash Proceeds | IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Maximum outstanding aggregate cash proceeds (based on daily outstanding balances) $125.0 $75.0 $125.0 $75.0 Average outstanding aggregate cash proceeds (based on daily outstanding balances) 77.3 34.2 72.7 30.9 |
Receivables Sold Under The Receivables Agreement | The attributes of IPL’s receivables sold under the Receivables Agreement were as follows (in millions): June 30, 2015 December 31, 2014 Customer accounts receivable $100.4 $134.8 Unbilled utility revenues 77.2 69.7 Other receivables 0.2 0.1 Receivables sold to third party 177.8 204.6 Less: cash proceeds (a) 100.0 22.0 Deferred proceeds 77.8 182.6 Less: allowance for doubtful accounts 4.4 5.4 Fair value of deferred proceeds $73.4 $177.2 Outstanding receivables past due $14.0 $19.9 (a) Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. |
Additional Attributes Of Receivables Sold Under The Receivables Agreement | Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Collections reinvested in receivables $417.1 $475.8 $923.0 $1,017.2 Credit losses, net of recoveries 2.5 3.9 3.5 6.4 |
IPL [Member] | |
Receivables [Line Items] | |
Maximum And Average Outstanding Cash Proceeds | IPL’s maximum and average outstanding cash proceeds related to the sales of accounts receivable program for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Maximum outstanding aggregate cash proceeds (based on daily outstanding balances) $125.0 $75.0 $125.0 $75.0 Average outstanding aggregate cash proceeds (based on daily outstanding balances) 77.3 34.2 72.7 30.9 |
Receivables Sold Under The Receivables Agreement | The attributes of IPL’s receivables sold under the Receivables Agreement were as follows (in millions): June 30, 2015 December 31, 2014 Customer accounts receivable $100.4 $134.8 Unbilled utility revenues 77.2 69.7 Other receivables 0.2 0.1 Receivables sold to third party 177.8 204.6 Less: cash proceeds (a) 100.0 22.0 Deferred proceeds 77.8 182.6 Less: allowance for doubtful accounts 4.4 5.4 Fair value of deferred proceeds $73.4 $177.2 Outstanding receivables past due $14.0 $19.9 (a) Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. |
Additional Attributes Of Receivables Sold Under The Receivables Agreement | Additional attributes of IPL’s receivables sold under the Receivables Agreement for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Collections reinvested in receivables $417.1 $475.8 $923.0 $1,017.2 Credit losses, net of recoveries 2.5 3.9 3.5 6.4 |
Investments (Tables)
Investments (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Schedule of Investments [Line Items] | |
Unconsolidated Equity Investments | Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and six months ended June 30 was as follows (in millions): Alliant Energy WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 ATC ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) Other (0.4 ) (0.2 ) 0.9 (0.4 ) (0.4 ) (0.3 ) (0.4 ) (0.5 ) ($11.3 ) ($11.3 ) ($17.8 ) ($22.7 ) ($11.3 ) ($11.4 ) ($19.1 ) ($22.8 ) |
WPL [Member] | |
Schedule of Investments [Line Items] | |
Unconsolidated Equity Investments | Equity (income) loss from unconsolidated investments accounted for under the equity method of accounting for the three and six months ended June 30 was as follows (in millions): Alliant Energy WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 ATC ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) ($10.9 ) ($11.1 ) ($18.7 ) ($22.3 ) Other (0.4 ) (0.2 ) 0.9 (0.4 ) (0.4 ) (0.3 ) (0.4 ) (0.5 ) ($11.3 ) ($11.3 ) ($17.8 ) ($22.7 ) ($11.3 ) ($11.4 ) ($19.1 ) ($22.8 ) |
Common Equity (Tables)
Common Equity (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Stockholders' Equity Note [Abstract] | |
Common Share Activity | A summary of Alliant Energy’s common stock activity was as follows: Shares outstanding, January 1, 2015 110,935,680 At-the-market offering program 2,186,617 Shareowner Direct Plan 107,412 Equity-based compensation plans ( Note 9(b) ) 56,378 Other (22,463 ) Shares outstanding, June 30, 2015 113,263,624 |
Debt (Tables)
Debt (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Debt Disclosure [Line Items] | |
Other Short-Term Borrowings | Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. |
IPL [Member] | |
Debt Disclosure [Line Items] | |
Other Short-Term Borrowings | Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. |
WPL [Member] | |
Debt Disclosure [Line Items] | |
Other Short-Term Borrowings | Information regarding commercial paper classified as short-term debt and back-stopped by the credit facilities was as follows (dollars in millions): Alliant Energy Parent June 30, 2015 (Consolidated) Company IPL WPL Commercial paper: Amount outstanding $120.9 $120.9 $— $— Weighted average remaining maturity 6 days 6 days N/A N/A Weighted average interest rates 0.4% 0.4% N/A N/A Available credit facility capacity (a) $767.9 $179.1 $188.8 $400.0 Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Maximum amount outstanding (based on daily outstanding balances) $152.6 $311.6 $9.7 $6.0 $— $168.4 Average amount outstanding (based on daily outstanding balances) $93.2 $262.7 $0.1 $0.1 $— $141.8 Weighted average interest rates 0.5 % 0.2 % 0.5 % 0.2 % N/A 0.1 % Six Months Ended June 30 Maximum amount outstanding (based on daily outstanding balances) $152.6 $316.2 $9.7 $10.0 $— $204.7 Average amount outstanding (based on daily outstanding balances) $110.5 $269.1 $0.1 $0.2 $— $157.3 Weighted average interest rates 0.4 % 0.2 % 0.5 % 0.2 % N/A 0.1 % (a) Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015 . Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. |
Income Taxes (Tables)
Income Taxes (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Income Taxes [Line Items] | |
Schedule Of Effective Income Tax Rates | The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % |
Summary Of Tax Credit Carryforwards | At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
IPL [Member] | |
Income Taxes [Line Items] | |
Schedule Of Effective Income Tax Rates | The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % |
Summary Of Tax Credit Carryforwards | At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
WPL [Member] | |
Income Taxes [Line Items] | |
Schedule Of Effective Income Tax Rates | The overall income tax rates shown in the following table were computed by dividing income tax expense (benefit) by income from continuing operations before income taxes. Alliant Energy IPL WPL Three Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.6 ) (11.9 ) (25.3 ) (36.6 ) — — Effect of rate-making on property-related differences (8.4 ) (4.8 ) (22.3 ) (14.4 ) (0.7 ) (0.2 ) Production tax credits (6.5 ) (6.1 ) (7.2 ) (8.0 ) (6.7 ) (5.8 ) Other items, net 4.1 4.8 4.1 4.6 4.6 5.0 Overall income tax rate 13.6 % 17.0 % (15.7 %) (19.4 %) 32.2 % 34.0 % Alliant Energy IPL WPL Six Months Ended June 30 2015 2014 2015 2014 2015 2014 Statutory federal income tax rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % IPL’s tax benefit riders (10.2 ) (11.9 ) (25.2 ) (32.8 ) — — Effect of rate-making on property-related differences (7.0 ) (5.1 ) (16.6 ) (13.0 ) (0.6 ) (0.7 ) Production tax credits (6.4 ) (6.5 ) (7.2 ) (8.2 ) (6.4 ) (6.2 ) Other items, net 4.3 4.7 4.2 4.6 4.7 4.9 Overall income tax rate 15.7 % 16.2 % (9.8 %) (14.4 %) 32.7 % 33.0 % |
Summary Of Tax Credit Carryforwards | At June 30, 2015 , tax carryforwards and associated deferred tax assets and expiration dates were estimated as follows (dollars in millions): Alliant Energy Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $845 $290 2029 State net operating losses 860 44 2018 Federal tax credits 222 218 2022 $552 IPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $396 $136 2029 State net operating losses 265 14 2018 Federal tax credits 77 75 2022 $225 WPL Tax Carryforwards Deferred Tax Assets Earliest Expiration Date Federal net operating losses $342 $117 2029 State net operating losses 170 8 2018 Federal tax credits 86 85 2022 $210 |
Benefit Plans (Tables)
Benefit Plans (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Pension And Other Postretirement Benefits Plans | The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 |
Employees Participate In Defined Contribution Retirement Plans | For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. |
Recognized Compensation Expense And Income Tax Benefits | A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 |
Schedule Of Equity-based Compensation Plans Activity | Information related to fair values of nonvested performance shares and units at June 30, 2015 , by year of grant, was as follows: Performance Shares Performance Units 2015 Grant 2014 Grant 2013 Grant 2015 Grant 2014 Grant 2013 Grant Nonvested awards 45,403 49,719 49,093 17,504 19,440 21,380 Alliant Energy common stock closing price on June 30, 2015 $57.72 $57.72 $57.72 Alliant Energy common stock closing price on grant date $65.09 $53.77 $47.58 Estimated payout percentage based on performance criteria 100 % 133 % 180 % 100 % 133 % 180 % Fair values of each nonvested award $57.72 $76.77 $103.90 $65.09 $71.51 $85.64 |
Performance Shares [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule Of Equity-based Compensation Plans Activity | A summary of the performance shares activity was as follows: 2015 (a) 2014 (a) Nonvested shares, January 1 144,424 139,940 Granted 45,403 51,221 Vested (45,612 ) (45,235 ) Forfeited — (1,502 ) Nonvested shares, June 30 144,215 144,424 (a) Share amounts represent the target number of performance shares. During the six months ended June 30 , certain performance shares vested, resulting in payouts (a combination of cash and common stock) as follows: 2015 2014 2012 Grant 2011 Grant Performance shares vested 45,612 45,235 Percentage of target number of performance shares 167.5 % 147.5 % Aggregate payout value (in millions) $5.1 $3.4 Payout - cash (in millions) $3.2 $2.9 Payout - common stock shares issued 10,975 4,810 |
Performance Units [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule Of Equity-based Compensation Plans Activity | A summary of the performance units activity was as follows: 2015 (a) 2014 (a) Nonvested units, January 1 63,665 65,912 Granted 17,837 20,422 Vested (22,845 ) (20,751 ) Forfeited (333 ) (761 ) Nonvested units, June 30 58,324 64,822 (a) Unit amounts represent the target number of performance units. During the six months ended June 30 , certain performance units vested, resulting in cash payouts as follows: 2015 2014 2012 Grant 2011 Grant Performance units vested 22,845 20,751 Percentage of target number of performance units 167.5 % 147.5 % Payout value (in millions) $1.6 $1.2 |
Performance Contingent Restricted Stock [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule Of Equity-based Compensation Plans Activity | A summary of the performance contingent restricted stock activity was as follows: 2015 2014 Shares Weighted Average Fair Value Shares Weighted Average Fair Value Nonvested shares, January 1 98,812 $50.69 158,922 $42.71 Granted 45,403 65.09 51,221 53.77 Vested (a) (49,093 ) 47.58 (90,847 ) 40.91 Forfeited — — (20,484 ) 39.85 Nonvested shares, June 30 95,122 59.17 98,812 50.69 (a) In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met. |
Performance Contingent Cash Awards [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Schedule Of Equity-based Compensation Plans Activity | A summary of the performance contingent cash awards activity was as follows: 2015 2014 Nonvested awards, January 1 78,930 96,977 Granted 41,105 42,446 Vested (a) (37,332 ) (55,517 ) Forfeited (709 ) (4,098 ) Nonvested awards, June 30 81,994 79,808 (a) In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million . In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million , respectively. |
IPL [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Pension And Other Postretirement Benefits Plans | The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 |
Employees Participate In Defined Contribution Retirement Plans | For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. |
Recognized Compensation Expense And Income Tax Benefits | A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 |
WPL [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Defined Benefit Pension And Other Postretirement Benefits Plans | The components of net periodic benefit costs (credits) for sponsored defined benefit pension and OPEB plans for the three and six months ended June 30 are included in the tables below (in millions). In the “IPL” and “WPL” tables below, the defined benefit pension plans costs represent those respective costs for IPL’s and WPL’s bargaining unit employees covered under the qualified plans that are sponsored by IPL and WPL, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Alliant Energy and Corporate Services sponsored qualified and non-qualified defined benefit pension plans. In the “IPL” and “WPL” tables below, the OPEB plans costs (credits) represent costs (credits) for IPL and WPL employees, respectively, as well as amounts directly assigned to each of IPL and WPL related to their current and former non-bargaining employees who are participants in the Corporate Services sponsored OPEB plan. Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months Alliant Energy 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $3.9 $3.3 $7.9 $6.6 $1.4 $1.3 $2.8 $2.6 Interest cost 13.4 13.5 26.8 27.0 2.3 2.3 4.5 4.7 Expected return on plan assets (18.8 ) (18.8 ) (37.5 ) (37.5 ) (2.1 ) (2.0 ) (4.2 ) (4.1 ) Amortization of prior service credit — — (0.1 ) — (2.8 ) (2.9 ) (5.6 ) (5.9 ) Amortization of actuarial loss 8.9 5.0 17.7 9.8 1.2 0.6 2.4 1.2 Additional benefit costs 0.1 — 0.3 — — — — — $7.5 $3.0 $15.1 $5.9 $— ($0.7 ) ($0.1 ) ($1.5 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months IPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $2.2 $1.8 $4.4 $3.6 $0.6 $0.6 $1.2 $1.2 Interest cost 6.3 6.3 12.5 12.6 1.0 1.0 1.9 2.0 Expected return on plan assets (9.0 ) (8.9 ) (17.9 ) (17.9 ) (1.4 ) (1.4 ) (2.8 ) (2.9 ) Amortization of prior service credit (0.1 ) — (0.1 ) — (1.6 ) (1.5 ) (3.1 ) (3.1 ) Amortization of actuarial loss 3.9 2.0 7.7 4.0 0.5 0.2 1.1 0.5 $3.3 $1.2 $6.6 $2.3 ($0.9 ) ($1.1 ) ($1.7 ) ($2.3 ) Defined Benefit Pension Plans OPEB Plans Three Months Six Months Three Months Six Months WPL 2015 2014 2015 2014 2015 2014 2015 2014 Service cost $1.5 $1.2 $2.9 $2.4 $0.5 $0.5 $1.1 $1.0 Interest cost 5.7 5.6 11.3 11.3 0.9 0.9 1.8 1.9 Expected return on plan assets (8.1 ) (8.1 ) (16.2 ) (16.2 ) (0.4 ) (0.3 ) (0.8 ) (0.6 ) Amortization of prior service cost (credit) — 0.1 0.1 0.2 (0.8 ) (0.9 ) (1.7 ) (1.9 ) Amortization of actuarial loss 4.2 2.3 8.4 4.6 0.5 0.3 1.1 0.6 Additional benefit costs 0.1 — 0.3 — — — — — $3.4 $1.1 $6.8 $2.3 $0.7 $0.5 $1.5 $1.0 |
Employees Participate In Defined Contribution Retirement Plans | For the three and six months ended June 30 , costs related to the 401(k) savings plans, which are partially based on the participants’ contributions, were as follows (in millions): Alliant Energy IPL (a) WPL (a) Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 401(k) costs $5.6 $6.1 $12.3 $12.0 $2.9 $2.6 $6.3 $5.7 $2.6 $3.3 $5.5 $5.9 (a) IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. |
Recognized Compensation Expense And Income Tax Benefits | A summary of compensation expense (including amounts allocated to IPL and WPL) and the related income tax benefits recognized for share-based compensation awards for the three and six months ended June 30 was as follows (in millions): Alliant Energy IPL WPL Three Months Six Months Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 2015 2014 Compensation expense $2.3 $3.1 $5.5 $6.2 $1.2 $1.7 $2.9 $3.4 $1.0 $1.3 $2.4 $2.6 Income tax benefits 0.9 1.2 2.2 2.5 0.5 0.7 1.2 1.4 0.4 0.5 1.0 1.0 |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Schedule of Asset Retirement Obligations [Line Items] | |
Reconciliation Of Changes In Asset Retirement Obligations | A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
IPL [Member] | |
Schedule of Asset Retirement Obligations [Line Items] | |
Reconciliation Of Changes In Asset Retirement Obligations | A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
WPL [Member] | |
Schedule of Asset Retirement Obligations [Line Items] | |
Reconciliation Of Changes In Asset Retirement Obligations | A reconciliation of the changes in AROs associated with long-lived assets is as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Balance, January 1 $114.0 $109.7 $51.8 $47.9 $52.4 $52.4 Revisions in estimated cash flows (a) 2.1 — 0.9 — 1.2 — Liabilities settled (6.4 ) (0.7 ) (2.4 ) (0.4 ) (4.0 ) (0.3 ) Liabilities incurred (a) 72.3 16.5 56.1 16.3 16.2 0.2 Accretion expense 2.2 2.1 0.9 1.0 0.9 0.8 Balance, June 30 $184.2 $127.6 $107.3 $64.8 $66.7 $53.1 (a) In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million , $57 million and $17 million , respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Statement [Line Items] | |
Carrying Amount and Fair Value Of Financial Instruments | Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 |
Fair Value Measurements | Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 |
Fair Value Measurements Using Significant Unobservable Inputs | Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. |
Fair Value Of Net Derivative Assets (Liabilities) | The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
IPL [Member] | |
Statement [Line Items] | |
Carrying Amount and Fair Value Of Financial Instruments | Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 |
Fair Value Measurements | Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 |
Fair Value Measurements Using Significant Unobservable Inputs | Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. |
Fair Value Of Net Derivative Assets (Liabilities) | The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
WPL [Member] | |
Statement [Line Items] | |
Carrying Amount and Fair Value Of Financial Instruments | Carrying amounts and the related estimated fair values of other financial instruments were as follows (in millions): Alliant Energy IPL WPL June 30, 2015 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $35.0 $35.0 $30.7 $30.7 $4.3 $4.3 Deferred proceeds (sales of receivables) ( Note 4(a) ) 73.4 73.4 73.4 73.4 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,750.9 4,214.4 1,730.2 1,937.2 1,574.1 1,824.0 Cumulative preferred stock 200.0 198.9 200.0 198.9 — — Derivative liabilities ( Note 12 ) 47.0 47.0 20.7 20.7 26.3 26.3 Alliant Energy IPL WPL December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Carrying Amount Fair Value Assets: Derivative assets ( Note 12 ) $38.6 $38.6 $28.0 $28.0 $10.6 $10.6 Deferred proceeds (sales of receivables) ( Note 4(a) ) 177.2 177.2 177.2 177.2 — — Capitalization and liabilities: Long-term debt (including current maturities) ( Note 7(b) ) 3,789.7 4,418.2 1,768.7 2,053.0 1,573.9 1,908.9 Cumulative preferred stock 200.0 200.2 200.0 200.2 — — Derivative liabilities ( Note 12 ) 37.6 37.6 19.5 19.5 18.1 18.1 |
Fair Value Measurements | Items subject to fair value measurement disclosure requirements were as follows (in millions): Alliant Energy June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $35.0 $— $3.0 $32.0 $38.6 $— $2.6 $36.0 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 4,214.4 — 4,210.7 3.7 4,418.2 — 4,414.9 3.3 Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 47.0 — 15.6 31.4 37.6 — 19.5 18.1 IPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $30.7 $— $1.9 $28.8 $28.0 $— $2.4 $25.6 Deferred proceeds 73.4 — — 73.4 177.2 — — 177.2 Capitalization and liabilities: Long-term debt (including current maturities) 1,937.2 — 1,937.2 — 2,053.0 — 2,053.0 — Cumulative preferred stock 198.9 198.9 — — 200.2 200.2 — — Derivatives - commodity contracts 20.7 — 10.2 10.5 19.5 — 13.3 6.2 WPL June 30, 2015 December 31, 2014 Fair Level Level Level Fair Level Level Level Value 1 2 3 Value 1 2 3 Assets: Derivatives - commodity contracts $4.3 $— $1.1 $3.2 $10.6 $— $0.2 $10.4 Capitalization and liabilities: Long-term debt (including current maturities) 1,824.0 — 1,824.0 — 1,908.9 — 1,908.9 — Derivatives - commodity contracts 26.3 — 5.4 20.9 18.1 — 6.2 11.9 |
Fair Value Measurements Using Significant Unobservable Inputs | Information for fair value measurements using significant unobservable inputs (Level 3 inputs) was as follows (in millions): Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($13.1 ) $23.9 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (19.6 ) 16.9 — — Transfers out of Level 3 1.0 — — — Purchases 36.8 76.7 — — Sales (0.4 ) — — — Settlements (a) (4.1 ) (16.3 ) (44.3 ) 22.9 Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($17.7 ) $16.3 $— $— Alliant Energy Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $17.9 $4.4 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (36.8 ) 54.7 — — Transfers out of Level 3 0.6 — — — Purchases 36.8 76.7 — — Sales (1.2 ) — — — Settlements (a) (16.7 ) (34.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $0.6 $101.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($33.9 ) $46.0 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Three Months Ended June 30 2015 2014 2015 2014 Beginning balance, April 1 ($5.0 ) $7.8 $117.7 $170.8 Total net gains (losses) (realized/unrealized) included in changes in net assets (5.0 ) 0.6 — — Transfers out of Level 3 0.2 — — — Purchases 33.1 68.8 — — Sales (0.4 ) — — — Settlements (a) (4.6 ) (13.0 ) (44.3 ) 22.9 Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($4.2 ) $0.7 $— $— IPL Commodity Contract Derivative Assets and (Liabilities), net Deferred Proceeds Six Months Ended June 30 2015 2014 2015 2014 Beginning balance, January 1 $19.4 $14.6 $177.2 $203.5 Total net gains (losses) (realized/unrealized) included in changes in net assets (17.4 ) 4.4 — — Purchases 33.1 68.8 — — Sales (1.1 ) — — — Settlements (a) (15.7 ) (23.6 ) (103.8 ) (9.8 ) Ending balance, June 30 $18.3 $64.2 $73.4 $193.7 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($14.3 ) $3.7 $— $— WPL Commodity Contract Derivative Assets and (Liabilities), net Three Months Ended June 30 2015 2014 Beginning balance, April 1 ($8.1 ) $16.1 Total net gains (losses) (realized/unrealized) included in changes in net assets (14.6 ) 16.3 Transfers out of Level 3 0.8 — Purchases 3.7 7.9 Settlements 0.5 (3.3 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($13.5 ) $15.6 WPL Commodity Contract Derivative Assets and (Liabilities), net Six Months Ended June 30 2015 2014 Beginning balance, January 1 ($1.5 ) ($10.2 ) Total net gains (losses) (realized/unrealized) included in changes in net assets (19.4 ) 50.3 Transfers out of Level 3 0.6 — Purchases 3.7 7.9 Sales (0.1 ) — Settlements (1.0 ) (11.0 ) Ending balance, June 30 ($17.7 ) $37.0 The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 ($19.6 ) $42.3 (a) Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. |
Fair Value Of Net Derivative Assets (Liabilities) | The fair value of electric, natural gas and coal commodity contracts categorized as Level 3 was recognized as net derivative assets (liabilities) as follows (in millions): Alliant Energy IPL WPL Excluding FTRs FTRs Excluding FTRs FTRs Excluding FTRs FTRs June 30, 2015 ($28.3 ) $28.9 ($9.0 ) $27.3 ($19.3 ) $1.6 December 31, 2014 (7.0 ) 24.9 (3.2 ) 22.6 (3.8 ) 2.3 |
Derivative Instruments (Tables)
Derivative Instruments (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Derivative Instruments [Line Items] | |
Notional Amounts Of Derivative Instruments | As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 |
Fair Value Of Financial Instruments | The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 |
Gains And Losses From Derivative Instruments | Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 |
Credit Risk-related Contingent Features | The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 |
Balance Sheet Offsetting | The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 |
IPL [Member] | |
Derivative Instruments [Line Items] | |
Notional Amounts Of Derivative Instruments | As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 |
Fair Value Of Financial Instruments | The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 |
Gains And Losses From Derivative Instruments | Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 |
Credit Risk-related Contingent Features | The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 |
Balance Sheet Offsetting | The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 |
WPL [Member] | |
Derivative Instruments [Line Items] | |
Notional Amounts Of Derivative Instruments | As of June 30, 2015 , gross notional amounts by delivery year related to outstanding swap contracts, option contracts, physical forward contracts, FTRs and coal contracts that were accounted for as commodity derivative instruments were as follows (units in thousands): 2015 2016 2017 2018 Total Alliant Energy Electricity (MWhs) 2,432 3,240 1,314 1,314 8,300 FTRs (MWhs) 11,952 9,961 — — 21,913 Natural gas (Dths) 36,167 34,330 9,079 126 79,702 Coal (tons) 897 2,260 1,073 1,113 5,343 IPL Electricity (MWhs) 1,100 809 — — 1,909 FTRs (MWhs) 6,664 5,696 — — 12,360 Natural gas (Dths) 23,343 18,103 2,886 126 44,458 Coal (tons) 189 830 274 387 1,680 WPL Electricity (MWhs) 1,332 2,431 1,314 1,314 6,391 FTRs (MWhs) 5,288 4,265 — — 9,553 Natural gas (Dths) 12,824 16,227 6,193 — 35,244 Coal (tons) 708 1,430 799 726 3,663 |
Fair Value Of Financial Instruments | The fair values of current derivative assets are included in “Other current assets,” non-current derivative assets are included in “Deferred charges and other,” current derivative liabilities are included in “Other current liabilities” and non-current derivative liabilities are included in “Other liabilities” on the balance sheets as follows (in millions): Alliant Energy IPL WPL Commodity contracts June 30, December 31, June 30, December 31, June 30, December 31, Current derivative assets $34.2 $30.5 $30.0 $27.4 $4.2 $3.1 Non-current derivative assets 0.8 8.1 0.7 0.6 0.1 7.5 Current derivative liabilities 27.1 28.1 13.8 16.4 13.3 11.7 Non-current derivative liabilities 19.9 9.5 6.9 3.1 13.0 6.4 |
Gains And Losses From Derivative Instruments | Changes in unrealized gains (losses) from commodity derivative instruments were recorded with offsets to regulatory assets or regulatory liabilities on the balance sheets as follows (in millions): Alliant Energy IPL WPL 2015 2014 2015 2014 2015 2014 Three Months Ended June 30 Regulatory assets ($21.2 ) ($4.6 ) ($12.1 ) ($4.1 ) ($9.1 ) ($0.5 ) Regulatory liabilities (4.6 ) 21.3 3.6 3.8 (8.2 ) 17.5 Six Months Ended June 30 Regulatory assets (42.1 ) 5.5 (23.8 ) 1.4 (18.3 ) 4.1 Regulatory liabilities (2.4 ) 69.4 2.2 15.9 (4.6 ) 53.5 |
Credit Risk-related Contingent Features | The aggregate fair value of all derivative instruments with credit risk-related contingent features in a net liability position, as well as amounts that would be required to be posted as credit support to counterparties by Alliant Energy, IPL or WPL if the most restrictive credit risk-related contingent features for derivative agreements in a net liability position were triggered, were as follows (in millions): Alliant Energy IPL WPL June 30, December 31, June 30, December 31, June 30, December 31, Aggregate fair value $47.0 $37.6 $20.7 $19.5 $26.3 $18.1 Credit support to be posted if triggered 46.9 37.4 20.7 19.5 26.2 17.9 |
Balance Sheet Offsetting | The fair value amounts of derivative instruments subject to a master netting arrangement are not netted by counterparty on the balance sheets. However, if the fair value amounts of derivative instruments by counterparty were netted, derivative assets and derivative liabilities related to commodity contracts would have been presented on the balance sheets as follows (in millions): Alliant Energy IPL WPL Gross Gross Gross (as reported) Net (as reported) Net (as reported) Net June 30, 2015 Derivative assets $35.0 $32.0 $30.7 $29.3 $4.3 $2.7 Derivative liabilities 47.0 44.0 20.7 19.3 26.3 24.7 December 31, 2014 Derivative assets 38.6 33.0 28.0 24.7 10.6 8.3 Derivative liabilities 37.6 32.0 19.5 16.2 18.1 15.8 |
Commitments And Contingencies (
Commitments And Contingencies (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Commitments and Contingencies [Line Items] | |
Operating Expense Purchase Obligations | At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . |
MGP Site Estimated Future Costs And Recorded Liabilities | At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 |
IPL [Member] | |
Commitments and Contingencies [Line Items] | |
Operating Expense Purchase Obligations | At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . |
MGP Site Estimated Future Costs And Recorded Liabilities | At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 |
WPL [Member] | |
Commitments and Contingencies [Line Items] | |
Operating Expense Purchase Obligations | At June 30, 2015 , minimum future commitments related to these operating expense purchase obligations were as follows (in millions): Alliant Energy IPL WPL Purchased power (a): DAEC (IPL) $1,480 $1,480 $— Other 202 1 201 1,682 1,481 201 Natural gas 270 165 105 Coal (b) 279 114 165 SO2 emission allowances 22 22 — Other (c) 24 17 7 $2,277 $1,799 $478 (a) Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. (b) Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. (c) Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015 . |
MGP Site Estimated Future Costs And Recorded Liabilities | At June 30, 2015 , estimated future costs expected to be incurred for the investigation, remediation and monitoring of the MGP sites, as well as environmental liabilities recorded on the balance sheets for these sites, were as follows (in millions): Alliant Energy IPL WPL Range of estimated future costs $12 - $29 $10 - $26 $2 - $3 Current and non-current environmental liabilities 16 14 2 |
Segments Of Business (Tables)
Segments Of Business (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Segment Reporting Information [Line Items] | |
Schedule Of Segments Of Business | Certain financial information relating to Alliant Energy’s business segments is as follows. Intersegment revenues were not material to Alliant Energy’s operations. Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Three Months Ended June 30, 2015 Operating revenues $640.4 $51.7 $14.8 $706.9 $10.3 $717.2 Operating income (loss) 100.9 (2.0 ) 3.2 102.1 6.9 109.0 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 55.7 13.2 68.9 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 55.7 11.9 67.6 Three Months Ended June 30, 2014 Operating revenues $643.9 $76.9 $15.6 $736.4 $13.9 $750.3 Operating income 89.1 2.7 2.2 94.0 9.3 103.3 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 53.0 9.1 62.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 53.0 8.8 61.8 Utility Non-Regulated, Alliant Energy Electric Gas Other Total Parent and Other Consolidated (in millions) Six Months Ended June 30, 2015 Operating revenues $1,311.7 $250.1 $31.2 $1,593.0 $21.6 $1,614.6 Operating income 205.6 34.3 8.5 248.4 13.5 261.9 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 148.1 17.4 165.5 Loss from discontinued operations, net of tax — (1.3 ) (1.3 ) Net income 148.1 16.1 164.2 Six Months Ended June 30, 2014 Operating revenues $1,319.7 $317.6 $38.4 $1,675.7 $27.4 $1,703.1 Operating income 183.4 45.7 10.1 239.2 18.3 257.5 Amounts attributable to Alliant Energy common shareowners: Income from continuing operations, net of tax 151.2 18.9 170.1 Loss from discontinued operations, net of tax — (0.3 ) (0.3 ) Net income 151.2 18.6 169.8 |
IPL [Member] | |
Segment Reporting Information [Line Items] | |
Schedule Of Segments Of Business | Certain financial information relating to IPL’s business segments is as follows. Intersegment revenues were not material to IPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $339.4 $29.8 $13.0 $382.2 Operating income (loss) 33.9 (2.4 ) 2.3 33.8 Earnings available for common stock 16.7 Three Months Ended June 30, 2014 Operating revenues $354.6 $43.7 $13.6 $411.9 Operating income 29.0 1.6 3.4 34.0 Earnings available for common stock 18.4 Six Months Ended June 30, 2015 Operating revenues $702.0 $141.0 $28.2 $871.2 Operating income 74.2 18.2 6.9 99.3 Earnings available for common stock 64.5 Six Months Ended June 30, 2014 Operating revenues $728.8 $179.4 $32.6 $940.8 Operating income 55.5 24.9 11.1 91.5 Earnings available for common stock 61.8 |
WPL [Member] | |
Segment Reporting Information [Line Items] | |
Schedule Of Segments Of Business | Certain financial information relating to WPL’s business segments is as follows. Intersegment revenues were not material to WPL’s operations. Electric Gas Other Total (in millions) Three Months Ended June 30, 2015 Operating revenues $301.0 $21.9 $1.8 $324.7 Operating income 67.0 0.4 0.9 68.3 Earnings available for common stock 39.0 Three Months Ended June 30, 2014 Operating revenues $289.3 $33.2 $2.0 $324.5 Operating income (loss) 60.1 1.1 (1.2 ) 60.0 Earnings available for common stock 34.6 Six Months Ended June 30, 2015 Operating revenues $609.7 $109.1 $3.0 $721.8 Operating income 131.4 16.1 1.6 149.1 Earnings available for common stock 83.6 Six Months Ended June 30, 2014 Operating revenues $590.9 $138.2 $5.8 $734.9 Operating income (loss) 127.9 20.8 (1.0 ) 147.7 Earnings available for common stock 89.4 |
Related Parties (Tables)
Related Parties (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Related Party Transactions [Line Items] | |
Services Provided, Sales Credited And Purchases | The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 |
Net Intercompany Payables | Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 |
Related Amounts Billed Between Parties | The related amounts billed between the parties for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 ATC billings to WPL $25 $24 $50 $48 WPL billings to ATC 3 1 5 4 |
IPL [Member] | |
Related Party Transactions [Line Items] | |
Services Provided, Sales Credited And Purchases | The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 |
Net Intercompany Payables | Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 |
WPL [Member] | |
Related Party Transactions [Line Items] | |
Services Provided, Sales Credited And Purchases | The amounts billed for services provided, sales credited and purchases for the three and six months ended June 30 were as follows (in millions): IPL WPL Three Months Six Months Three Months Six Months 2015 2014 2015 2014 2015 2014 2015 2014 Corporate Services billings $40 $41 $76 $74 $32 $31 $60 $59 Sales credited 2 2 6 4 6 3 12 2 Purchases billed 89 108 168 207 19 28 33 58 |
Net Intercompany Payables | Net intercompany payables to Corporate Services were as follows (in millions): IPL WPL June 30, 2015 December 31, 2014 June 30, 2015 December 31, 2014 Net payables to Corporate Services $95 $84 $49 $58 |
Related Amounts Billed Between Parties | The related amounts billed between the parties for the three and six months ended June 30 were as follows (in millions): Three Months Six Months 2015 2014 2015 2014 ATC billings to WPL $25 $24 $50 $48 WPL billings to ATC 3 1 5 4 |
Discontinued Operations And A36
Discontinued Operations And Assets And Liabilities Held for Sale (Tables) | 6 Months Ended |
Jun. 30, 2015 | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |
Discontinued Operations on Income Statement | A summary of the components of discontinued operations in Alliant Energy’s income statements for the three and six months ended June 30 was as follows (in millions): Three Months Six Months 2015 2014 2015 2014 Operating expenses $2.0 $0.6 $2.0 $0.6 Loss before income taxes (2.0 ) (0.6 ) (2.0 ) (0.6 ) Income tax benefit (0.7 ) (0.3 ) (0.7 ) (0.3 ) Loss from discontinued operations, net of tax ($1.3 ) ($0.3 ) ($1.3 ) ($0.3 ) |
Assets And Liabilities Held For Sale on Balance Sheets | Alliant Energy’s and IPL’s balance sheets included assets held for sale recorded in “Other current assets” and liabilities held for sale recorded in “Other current liabilities” as follows (in millions): Electric Natural Gas Distribution Assets Distribution Assets June 30, 2015 December 31, 2014 Assets held for sale: Current assets $9.3 $1.1 Property, plant and equipment, net 125.0 11.0 Non-current regulatory assets 20.5 7.0 Carrying value adjustment of net assets sold (a) (8.8 ) — Total assets held for sale 146.0 19.1 Liabilities held for sale: Current liabilities 2.4 1.0 Other liabilities 12.6 7.1 Total liabilities held for sale 15.0 8.1 Net assets held for sale $131.0 $11.0 (a) The carrying value of IPL’s Minnesota electric distribution assets classified as held for sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy and IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets. |
IPL [Member] | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |
Assets And Liabilities Held For Sale on Balance Sheets | Alliant Energy’s and IPL’s balance sheets included assets held for sale recorded in “Other current assets” and liabilities held for sale recorded in “Other current liabilities” as follows (in millions): Electric Natural Gas Distribution Assets Distribution Assets June 30, 2015 December 31, 2014 Assets held for sale: Current assets $9.3 $1.1 Property, plant and equipment, net 125.0 11.0 Non-current regulatory assets 20.5 7.0 Carrying value adjustment of net assets sold (a) (8.8 ) — Total assets held for sale 146.0 19.1 Liabilities held for sale: Current liabilities 2.4 1.0 Other liabilities 12.6 7.1 Total liabilities held for sale 15.0 8.1 Net assets held for sale $131.0 $11.0 (a) The carrying value of IPL’s Minnesota electric distribution assets classified as held for sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy and IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets. |
Summary Of Significant Accoun37
Summary Of Significant Accounting Policies (Narrative) (Details) - Minimum [Member] | Jun. 30, 2015 |
New Accounting Pronouncements [Line Items] | |
Debt issuance costs percentage, on total long-term debt | 1.00% |
IPL [Member] | |
New Accounting Pronouncements [Line Items] | |
Debt issuance costs percentage, on total long-term debt | 1.00% |
WPL [Member] | |
New Accounting Pronouncements [Line Items] | |
Debt issuance costs percentage, on total long-term debt | 1.00% |
Regulatory Matters (Narrative)
Regulatory Matters (Narrative) (Details) - USD ($) $ in Millions | 6 Months Ended | 12 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Dec. 31, 2016 | Dec. 31, 2014 | |
Regulatory Matters [Line Items] | ||||
Decrease in regulatory liabilities | $ (40) | $ 45.2 | ||
Alliant Energy and IPL [Member] | Tax benefit riders [Member] | ||||
Regulatory Matters [Line Items] | ||||
Decrease in regulatory liabilities | 41 | |||
WPL [Member] | ||||
Regulatory Matters [Line Items] | ||||
Decrease in regulatory liabilities | (1.1) | $ 47.9 | ||
2014 Test Year Retail Electric Fuel Related [Member] | WPL [Member] | ||||
Regulatory Matters [Line Items] | ||||
Annual bandwidth for fuel-related costs | 2.00% | |||
2014 Test Year Retail Electric Fuel Related [Member] | Alliant Energy and WPL [Member] | ||||
Regulatory Matters [Line Items] | ||||
Under-collection of retail fuel-related costs | $ 33 | |||
Fuel-related costs | $ 28 | |||
Subsequent Event [Member] | 2016 Test Year Retail Electric Fuel Related [Member] | ||||
Regulatory Matters [Line Items] | ||||
Requested rate increase (decrease), amount | $ 15 | |||
Requested rate increase (decrease), percentage | 1.00% | |||
Subsequent Event [Member] | 2014 Test Year Retail Electric Fuel Related [Member] | ||||
Regulatory Matters [Line Items] | ||||
Approved rate increase (decrease), amount | $ 28 | |||
Approved rate increase (decrease), percentage | 3.00% |
Regulatory Matters (Regulatory
Regulatory Matters (Regulatory Assets) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Regulatory Assets [Line Items] | ||
Regulatory assets | $ 1,777.9 | $ 1,783.7 |
Tax-related [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 961.1 | 955.3 |
Pension and OPEB costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 555.7 | 570.2 |
AROs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 77.9 | 73.7 |
Derivatives [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 54.1 | 46.9 |
Commodity cost recovery [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 32.3 | 31.1 |
Emission allowances [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 26.7 | 27.4 |
Other [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 70.1 | 79.1 |
IPL [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 1,350.7 | 1,357.9 |
IPL [Member] | Tax-related [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 932.8 | 928 |
IPL [Member] | Pension and OPEB costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 281.8 | 287.9 |
IPL [Member] | AROs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 44.1 | 41.4 |
IPL [Member] | Derivatives [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 26.1 | 28 |
IPL [Member] | Commodity cost recovery [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 0.5 | 0.4 |
IPL [Member] | Emission allowances [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 26.7 | 27.4 |
IPL [Member] | Other [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 38.7 | 44.8 |
WPL [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 427.2 | 425.8 |
WPL [Member] | Tax-related [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 28.3 | 27.3 |
WPL [Member] | Pension and OPEB costs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 273.9 | 282.3 |
WPL [Member] | AROs [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 33.8 | 32.3 |
WPL [Member] | Derivatives [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 28 | 18.9 |
WPL [Member] | Commodity cost recovery [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | 31.8 | 30.7 |
WPL [Member] | Other [Member] | ||
Regulatory Assets [Line Items] | ||
Regulatory assets | $ 31.4 | $ 34.3 |
Regulatory Matters (Regulator40
Regulatory Matters (Regulatory Liabilities) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | $ 770.1 | $ 821.2 |
Cost of removal obligations [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 410.6 | 421.7 |
IPL's tax benefit riders [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 201.9 | 243 |
Energy efficiency cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 58.5 | 64.3 |
IPL's electric transmission cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 24.3 | 19.4 |
Commodity cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 16.6 | 15.4 |
Other [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 58.2 | 57.4 |
IPL [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 532 | 583.5 |
IPL [Member] | Cost of removal obligations [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 266.6 | 279.1 |
IPL [Member] | IPL's tax benefit riders [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 201.9 | 243 |
IPL [Member] | Energy efficiency cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 1.7 | 0 |
IPL [Member] | IPL's electric transmission cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 24.3 | 19.4 |
IPL [Member] | Commodity cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 11.6 | 15.1 |
IPL [Member] | Other [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 25.9 | 26.9 |
WPL [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 238.1 | 237.7 |
WPL [Member] | Cost of removal obligations [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 144 | 142.6 |
WPL [Member] | Energy efficiency cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 56.8 | 64.3 |
WPL [Member] | Commodity cost recovery [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | 5 | 0.3 |
WPL [Member] | Other [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities | $ 32.3 | $ 30.5 |
Regulatory Matters (Tax Benefit
Regulatory Matters (Tax Benefit Riders) (Details) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2015 | Jun. 30, 2014 | |
Regulatory Liabilities [Line Items] | ||
Decrease in regulatory liabilities | $ (40) | $ 45.2 |
Alliant Energy and IPL [Member] | Electric tax benefit rider [Member] | ||
Regulatory Liabilities [Line Items] | ||
Decrease in regulatory liabilities | 35 | |
Alliant Energy and IPL [Member] | Gas tax benefit rider [Member] | ||
Regulatory Liabilities [Line Items] | ||
Decrease in regulatory liabilities | 6 | |
Alliant Energy and IPL [Member] | Tax benefit riders [Member] | ||
Regulatory Liabilities [Line Items] | ||
Decrease in regulatory liabilities | $ 41 |
Regulatory Matters (Customer Bi
Regulatory Matters (Customer Billing Credits) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
IPL [Member] | ||||
Regulatory Liabilities [Line Items] | ||||
Customer billing credits | $ 6 | $ 20 | $ 12 | $ 20 |
Property, Plant and Equipment (
Property, Plant and Equipment (Narrative) (Details) $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | |||
Jul. 31, 2015USD ($) | Apr. 30, 2015USD ($) | Jun. 30, 2015USD ($) | Jun. 30, 2014USD ($) | Jun. 30, 2015USD ($)MW | Jun. 30, 2014USD ($) | Dec. 31, 2015USD ($) | |
Property, Plant and Equipment [Line Items] | |||||||
Allowance for funds used during construction | $ 8.6 | $ 8.4 | $ 15.4 | $ 17.5 | |||
IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Allowance for funds used during construction | 6.7 | $ 6 | 12 | $ 12 | |||
Edgewater Unit 5 [Member] | Alliant Energy and WPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Construction work in progress | 132 | 132 | |||||
Allowance for funds used during construction | $ 5 | ||||||
Marshalltown [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Fossil-fueled EGU capacity (in megawatts) | MW | 650 | ||||||
Marshalltown [Member] | Alliant Energy and IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Construction work in progress | 343 | $ 343 | |||||
Allowance for funds used during construction | 12 | ||||||
Gas distribution assets [Member] | Alliant Energy and IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Loss on sale of Minnesota distribution assets | 3 | 3 | |||||
Gas distribution assets [Member] | IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Proceeds from asset sales | $ 11 | ||||||
Receipt of promissory note | $ 2 | ||||||
Electric distribution assets [Member] | Alliant Energy and IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Loss on sale of Minnesota distribution assets | 9 | 9 | |||||
Customer Billing And Information System [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Capitalized expenditures | 79 | 79 | |||||
Capitalized interest | $ 2 | $ 2 | |||||
Subsequent Event [Member] | Electric distribution assets [Member] | IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Proceeds from asset sales | $ 127 | ||||||
Scenario, Forecast [Member] | Electric distribution assets [Member] | IPL [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Proceeds from asset sales | $ 130 |
Receivables (Narrative) (Detail
Receivables (Narrative) (Details) - USD ($) $ in Millions | 6 Months Ended | |||
Jun. 30, 2014 | Jun. 30, 2015 | Dec. 31, 2014 | ||
IPL [Member] | ||||
Receivables [Line Items] | ||||
Receivables sold to third party | $ 177.8 | |||
Whiting Petroleum Corporation [Member] | ||||
Receivables [Line Items] | ||||
Final payment of certain future tax benefits expected to be realized | $ 26 | |||
Receivables Sold [Member] | IPL [Member] | ||||
Receivables [Line Items] | ||||
Receivables sold to third party | 177.8 | $ 204.6 | ||
Cash proceeds of receivables sold | [1] | 100 | 22 | |
Deferred proceeds | $ 73.4 | $ 177.2 | ||
[1] | Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. |
Receivables (Maximum And Averag
Receivables (Maximum And Average Outstanding Cash Proceeds) (Details) - IPL [Member] - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Receivables [Line Items] | ||||
Outstanding aggregate cash proceeds (based on daily outstanding balances) | $ 77.3 | $ 34.2 | $ 72.7 | $ 30.9 |
Maximum [Member] | ||||
Receivables [Line Items] | ||||
Outstanding aggregate cash proceeds (based on daily outstanding balances) | $ 125 | $ 75 | $ 125 | $ 75 |
Receivables (Receivables Sold U
Receivables (Receivables Sold Under The Agreement) (Details) - IPL [Member] - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 | |
Receivables [Line Items] | |||
Receivables sold to third party | $ 177.8 | ||
Receivables Sold [Member] | |||
Receivables [Line Items] | |||
Customer accounts receivable | 100.4 | $ 134.8 | |
Unbilled utility revenues | 77.2 | 69.7 | |
Other receivables | 0.2 | 0.1 | |
Receivables sold to third party | 177.8 | 204.6 | |
Less: cash proceeds | [1] | 100 | 22 |
Deferred proceeds | 77.8 | 182.6 | |
Less: allowance for doubtful accounts | 4.4 | 5.4 | |
Fair value of deferred proceeds | 73.4 | 177.2 | |
Outstanding receivables past due | $ 14 | $ 19.9 | |
[1] | Changes in cash proceeds are presented in “Sales of accounts receivable” in operating activities in Alliant Energy’s and IPL’s cash flows statements. |
Receivables (Additional Attribu
Receivables (Additional Attributes Of Receivables Sold Under The Agreement) (Details) - IPL [Member] - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Receivables [Line Items] | ||||
Collections reinvested in receivables | $ 417.1 | $ 475.8 | $ 923 | $ 1,017.2 |
Credit losses, net of recoveries | $ 2.5 | $ 3.9 | $ 3.5 | $ 6.4 |
Investments (Unconsolidated Equ
Investments (Unconsolidated Equity Investments) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | $ (11.3) | $ (11.3) | $ (17.8) | $ (22.7) |
WPL [Member] | ||||
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | (11.3) | (11.4) | (19.1) | (22.8) |
ATC [Member] | ||||
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | (10.9) | (11.1) | (18.7) | (22.3) |
ATC [Member] | WPL [Member] | ||||
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | (10.9) | (11.1) | (18.7) | (22.3) |
Other [Member] | ||||
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | (0.4) | (0.2) | 0.9 | (0.4) |
Other [Member] | WPL [Member] | ||||
Schedule of Investments [Line Items] | ||||
Equity (income) loss from unconsolidated investments, net | $ (0.4) | $ (0.3) | $ (0.4) | $ (0.5) |
Common Equity (Narrative) (Deta
Common Equity (Narrative) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | 12 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | Dec. 31, 2015 | |
Common Equity [Line Items] | |||||
Proceeds from issuance of common stock, net | $ 139.5 | $ 0 | |||
Other comprehensive income | $ 0 | $ 0 | 0 | 0 | |
IPL [Member] | |||||
Common Equity [Line Items] | |||||
Retained earnings free of dividend restrictions | 533 | 533 | |||
Restricted net assets of subsidiaries | 1,400 | 1,400 | |||
Capital contributions from parent | 100 | 60 | |||
Common stock dividends to parent | 69.9 | ||||
Other comprehensive income | 0 | 0 | 0 | 0 | |
WPL [Member] | |||||
Common Equity [Line Items] | |||||
Retained earnings free of dividend restrictions | 64 | 64 | |||
Restricted net assets of subsidiaries | 1,700 | 1,700 | |||
Common stock dividends to parent | 63.5 | ||||
Other comprehensive income | $ 0 | $ 0 | $ 0 | $ 0 | |
At The Market Offering Program [Member] | |||||
Common Equity [Line Items] | |||||
New shares of common stock issued, At-the-market offering program (in shares) | 2,186,617 | ||||
Proceeds from issuance of common stock, net | $ 133 | ||||
Fees and commissions from issuance of common stock | $ 2 | ||||
At The Market Offering Program [Member] | Subsequent Event [Member] | |||||
Common Equity [Line Items] | |||||
Maximum aggregate gross sales price of common stock that can be offered and sold | $ 150 |
Common Equity (Common Share Act
Common Equity (Common Share Activity) (Details) | 6 Months Ended |
Jun. 30, 2015shares | |
Common Stock Oustanding [Roll Forward] | |
Shares outstanding, January 1, 2015 (in shares) | 110,935,680 |
New shares of stock issued, Shareowner Direct Plan (in shares) | 107,412 |
Equity-based compensation plans (in shares) | 56,378 |
Other (in shares) | (22,463) |
Shares outstanding, June 30, 2015 (in shares) | 113,263,624 |
At The Market Offering Program [Member] | |
Common Stock Oustanding [Roll Forward] | |
New shares of common stock issued, At-the-market offering program (in shares) | 2,186,617 |
Debt (Narrative) (Details)
Debt (Narrative) (Details) - Jun. 30, 2015 - USD ($) $ in Millions | Total | Total |
Debt [Line Items] | ||
Commercial paper, long-term | $ 111.2 | $ 111.2 |
Senior Debentures [Member] | 3.3% senior debenture, due 2015 [Member] | ||
Debt [Line Items] | ||
Payments to retire long-term debt | $ 150 | |
Interest rate | 3.30% | 3.30% |
Commercial Paper [Member] | ||
Debt [Line Items] | ||
Interest rate | 0.50% | 0.50% |
Weighted average remaining maturity, long-term debt (in days) | 6 days |
Debt (Credit Facilities) (Detai
Debt (Credit Facilities) (Details) - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Dec. 31, 2014 | ||
Commercial paper: | |||
Amount outstanding | $ 120.9 | $ 141.3 | |
Weighted average remaining maturity (in days) | 6 days | ||
Weighted average interest rates | 0.40% | ||
Available credit facility capacity | [1] | $ 767.9 | |
Commercial paper, long-term | 111.2 | ||
Parent Company [Member] | |||
Commercial paper: | |||
Amount outstanding | $ 120.9 | ||
Weighted average remaining maturity (in days) | 6 days | ||
Weighted average interest rates | 0.40% | ||
Available credit facility capacity | [1] | $ 179.1 | |
IPL [Member] | |||
Commercial paper: | |||
Amount outstanding | 0 | ||
Available credit facility capacity | [1] | 188.8 | |
WPL [Member] | |||
Commercial paper: | |||
Amount outstanding | 0 | ||
Available credit facility capacity | [1] | $ 400 | |
[1] | Alliant Energy’s and IPL’s available credit facility capacities reflect outstanding commercial paper classified as both short- and long-term debt at June 30, 2015. Refer to Note 7(b) for further discussion of $111.2 million of commercial paper outstanding at June 30, 2015 classified as long-term debt on Alliant Energy’s and IPL’s balance sheets. |
Debt (Other Short-Term Borrowin
Debt (Other Short-Term Borrowings) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Debt [Line Items] | ||||
Maximum amount outstanding (based on daily outstanding balances) | $ 152.6 | $ 311.6 | $ 152.6 | $ 316.2 |
Average amount outstanding (based on daily outstanding balances) | $ 93.2 | $ 262.7 | $ 110.5 | $ 269.1 |
Weighted average interest rates | 0.50% | 0.20% | 0.40% | 0.20% |
IPL [Member] | ||||
Debt [Line Items] | ||||
Maximum amount outstanding (based on daily outstanding balances) | $ 9.7 | $ 6 | $ 9.7 | $ 10 |
Average amount outstanding (based on daily outstanding balances) | $ 0.1 | $ 0.1 | $ 0.1 | $ 0.2 |
Weighted average interest rates | 0.50% | 0.20% | 0.50% | 0.20% |
WPL [Member] | ||||
Debt [Line Items] | ||||
Maximum amount outstanding (based on daily outstanding balances) | $ 0 | $ 168.4 | $ 0 | $ 204.7 |
Average amount outstanding (based on daily outstanding balances) | $ 0 | $ 141.8 | $ 0 | $ 157.3 |
Weighted average interest rates | 0.10% | 0.10% |
Income Taxes (Narrative) (Detai
Income Taxes (Narrative) (Details) $ in Millions | 6 Months Ended |
Jun. 30, 2015USD ($) | |
Income Taxes [Line Items] | |
Increase (decrease) non-current deferred tax liabilities | $ 128 |
IPL [Member] | |
Income Taxes [Line Items] | |
Increase (decrease) non-current deferred tax liabilities | 77.4 |
WPL [Member] | |
Income Taxes [Line Items] | |
Increase (decrease) non-current deferred tax liabilities | $ 44.9 |
Income Taxes (Schedule Of Effec
Income Taxes (Schedule Of Effective Income Tax Rates) (Details) | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Effective Tax Rate [Line Items] | ||||
Statutory federal income tax rate | 35.00% | 35.00% | 35.00% | 35.00% |
IPL's tax benefit riders | (10.60%) | (11.90%) | (10.20%) | (11.90%) |
Effect of rate-making on property-related differences | (8.40%) | (4.80%) | (7.00%) | (5.10%) |
Production tax credits | (6.50%) | (6.10%) | (6.40%) | (6.50%) |
Other items, net | 4.10% | 4.80% | 4.30% | 4.70% |
Overall income tax rate | 13.60% | 17.00% | 15.70% | 16.20% |
IPL [Member] | ||||
Effective Tax Rate [Line Items] | ||||
Statutory federal income tax rate | 35.00% | 35.00% | 35.00% | 35.00% |
IPL's tax benefit riders | (25.30%) | (36.60%) | (25.20%) | (32.80%) |
Effect of rate-making on property-related differences | (22.30%) | (14.40%) | (16.60%) | (13.00%) |
Production tax credits | (7.20%) | (8.00%) | (7.20%) | (8.20%) |
Other items, net | 4.10% | 4.60% | 4.20% | 4.60% |
Overall income tax rate | (15.70%) | (19.40%) | (9.80%) | (14.40%) |
WPL [Member] | ||||
Effective Tax Rate [Line Items] | ||||
Statutory federal income tax rate | 35.00% | 35.00% | 35.00% | 35.00% |
Effect of rate-making on property-related differences | (0.70%) | (0.20%) | (0.60%) | (0.70%) |
Production tax credits | (6.70%) | (5.80%) | (6.40%) | (6.20%) |
Other items, net | 4.60% | 5.00% | 4.70% | 4.90% |
Overall income tax rate | 32.20% | 34.00% | 32.70% | 33.00% |
Income Taxes (Summary Of Tax Cr
Income Taxes (Summary Of Tax Credit Carryforwards) (Details) $ in Millions | Jun. 30, 2015USD ($) |
Carryforwards [Line Items] | |
Net operating losses, deferred tax assets | $ 552 |
IPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, deferred tax assets | 225 |
WPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, deferred tax assets | 210 |
Federal [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 845 |
Net operating losses, deferred tax assets | 290 |
Tax credits, carryforward amount | 222 |
Tax credits, deferred tax assets | 218 |
Federal [Member] | IPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 396 |
Net operating losses, deferred tax assets | 136 |
Tax credits, carryforward amount | 77 |
Tax credits, deferred tax assets | 75 |
Federal [Member] | WPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 342 |
Net operating losses, deferred tax assets | 117 |
Tax credits, carryforward amount | 86 |
Tax credits, deferred tax assets | 85 |
State [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 860 |
Net operating losses, deferred tax assets | 44 |
State [Member] | IPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 265 |
Net operating losses, deferred tax assets | 14 |
State [Member] | WPL [Member] | |
Carryforwards [Line Items] | |
Net operating losses, carryforward amount | 170 |
Net operating losses, deferred tax assets | $ 8 |
Benefit Plans (Narrative) (Deta
Benefit Plans (Narrative) (Details) - Jun. 30, 2015 - USD ($) $ in Millions | Total |
Defined Benefit Plan Disclosure [Line Items] | |
Unrecognized compensation cost | $ 9.6 |
Minimum [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Unrecognized compensation cost recognized over a weighted average period | 1 year |
Maximum [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Unrecognized compensation cost recognized over a weighted average period | 2 years |
Benefit Plans (Defined Benefit
Benefit Plans (Defined Benefit Pension And Other Postretirement Benefits Plans) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Defined benefit pension plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | $ 3.9 | $ 3.3 | $ 7.9 | $ 6.6 |
Interest cost | 13.4 | 13.5 | 26.8 | 27 |
Expected return on plan assets | (18.8) | (18.8) | (37.5) | (37.5) |
Amortization of prior service cost (credit) | 0 | 0 | (0.1) | 0 |
Amortization of actuarial loss | 8.9 | 5 | 17.7 | 9.8 |
Additional benefit costs | 0.1 | 0 | 0.3 | 0 |
Total | 7.5 | 3 | 15.1 | 5.9 |
OPEB Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 1.4 | 1.3 | 2.8 | 2.6 |
Interest cost | 2.3 | 2.3 | 4.5 | 4.7 |
Expected return on plan assets | (2.1) | (2) | (4.2) | (4.1) |
Amortization of prior service cost (credit) | (2.8) | (2.9) | (5.6) | (5.9) |
Amortization of actuarial loss | 1.2 | 0.6 | 2.4 | 1.2 |
Additional benefit costs | 0 | 0 | 0 | 0 |
Total | 0 | (0.7) | (0.1) | (1.5) |
IPL [Member] | Defined benefit pension plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 2.2 | 1.8 | 4.4 | 3.6 |
Interest cost | 6.3 | 6.3 | 12.5 | 12.6 |
Expected return on plan assets | (9) | (8.9) | (17.9) | (17.9) |
Amortization of prior service cost (credit) | (0.1) | 0 | (0.1) | 0 |
Amortization of actuarial loss | 3.9 | 2 | 7.7 | 4 |
Total | 3.3 | 1.2 | 6.6 | 2.3 |
IPL [Member] | OPEB Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 0.6 | 0.6 | 1.2 | 1.2 |
Interest cost | 1 | 1 | 1.9 | 2 |
Expected return on plan assets | (1.4) | (1.4) | (2.8) | (2.9) |
Amortization of prior service cost (credit) | (1.6) | (1.5) | (3.1) | (3.1) |
Amortization of actuarial loss | 0.5 | 0.2 | 1.1 | 0.5 |
Total | (0.9) | (1.1) | (1.7) | (2.3) |
WPL [Member] | Defined benefit pension plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 1.5 | 1.2 | 2.9 | 2.4 |
Interest cost | 5.7 | 5.6 | 11.3 | 11.3 |
Expected return on plan assets | (8.1) | (8.1) | (16.2) | (16.2) |
Amortization of prior service cost (credit) | 0 | 0.1 | 0.1 | 0.2 |
Amortization of actuarial loss | 4.2 | 2.3 | 8.4 | 4.6 |
Additional benefit costs | 0.1 | 0 | 0.3 | 0 |
Total | 3.4 | 1.1 | 6.8 | 2.3 |
WPL [Member] | OPEB Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 0.5 | 0.5 | 1.1 | 1 |
Interest cost | 0.9 | 0.9 | 1.8 | 1.9 |
Expected return on plan assets | (0.4) | (0.3) | (0.8) | (0.6) |
Amortization of prior service cost (credit) | (0.8) | (0.9) | (1.7) | (1.9) |
Amortization of actuarial loss | 0.5 | 0.3 | 1.1 | 0.6 |
Additional benefit costs | 0 | 0 | 0 | 0 |
Total | $ 0.7 | $ 0.5 | $ 1.5 | $ 1 |
Benefit Plans (Defined Contribu
Benefit Plans (Defined Contribution Retirement Plans) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
401(k) costs | $ 5.6 | $ 6.1 | $ 12.3 | $ 12 | |
IPL [Member] | |||||
401(k) costs | [1] | 2.9 | 2.6 | 6.3 | 5.7 |
WPL [Member] | |||||
401(k) costs | [1] | $ 2.6 | $ 3.3 | $ 5.5 | $ 5.9 |
[1] | IPL’s and WPL’s amounts include allocated costs associated with Corporate Services employees. |
Benefit Plans (Recognized Compe
Benefit Plans (Recognized Compensation Expense And Income Tax Benefits) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Compensation expense | $ 2.3 | $ 3.1 | $ 5.5 | $ 6.2 |
Income tax benefits | 0.9 | 1.2 | 2.2 | 2.5 |
IPL [Member] | ||||
Compensation expense | 1.2 | 1.7 | 2.9 | 3.4 |
Income tax benefits | 0.5 | 0.7 | 1.2 | 1.4 |
WPL [Member] | ||||
Compensation expense | 1 | 1.3 | 2.4 | 2.6 |
Income tax benefits | $ 0.4 | $ 0.5 | $ 1 | $ 1 |
Benefit Plans (Summary Of Perfo
Benefit Plans (Summary Of Performance Shares Activity) (Details) - Performance Shares [Member] - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Nonvested, January 1 (in shares/awards) | [1] | 144,424 | 139,940 |
Granted (in shares/awards) | [1] | 45,403 | 51,221 |
Vested (in shares/awards) | [1] | (45,612) | (45,235) |
Forfeited (in shares/awards) | [1] | 0 | (1,502) |
Nonvested, June 30 (in shares/awards) | [1] | 144,215 | 144,424 |
2012 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | (45,612) | ||
Vested percentage of the target | 167.50% | ||
Aggregate payout value | $ 5.1 | ||
Payout - cash | $ 3.2 | ||
Payout - common stock shares issued (in shares) | 10,975 | ||
2011 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | (45,235) | ||
Vested percentage of the target | 147.50% | ||
Aggregate payout value | $ 3.4 | ||
Payout - cash | $ 2.9 | ||
Payout - common stock shares issued (in shares) | 4,810 | ||
[1] | Share amounts represent the target number of performance shares. |
Benefit Plans (Summary Of Per62
Benefit Plans (Summary Of Performance Unit Activity) (Details) - Performance Units [Member] - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Nonvested, January 1 (in shares/awards) | [1] | 63,665 | 65,912 |
Granted (in shares/awards) | [1] | 17,837 | 20,422 |
Vested (in shares/awards) | [1] | (22,845) | (20,751) |
Forfeited (in shares/awards) | [1] | (333) | (761) |
Nonvested, June 30 (in shares/awards) | [1] | 58,324 | 64,822 |
2012 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | (22,845) | ||
Vested percentage of the target | 167.50% | ||
Aggregate payout value | $ 1.6 | ||
2011 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | (20,751) | ||
Vested percentage of the target | 147.50% | ||
Aggregate payout value | $ 1.2 | ||
[1] | Unit amounts represent the target number of performance units. |
Benefit Plans (Fair Values Of N
Benefit Plans (Fair Values Of Nonvested Performance Shares And Units) (Details) - $ / shares | 6 Months Ended | ||||
Jun. 30, 2015 | Dec. 31, 2014 | Jun. 30, 2014 | Dec. 31, 2013 | ||
Performance Shares [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | [1] | 144,215 | 144,424 | 144,424 | 139,940 |
Performance Units [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | [2] | 58,324 | 63,665 | 64,822 | 65,912 |
2015 Grant [Member] | Performance Shares [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 45,403 | ||||
Alliant Energy common stock closing price on June 30, 2015 (in dollars per share) | $ 57.72 | ||||
Estimated payout percentage based on performance criteria | 100.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 57.72 | ||||
2015 Grant [Member] | Performance Units [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 17,504 | ||||
Alliant Energy common stock closing price on grant date (in dollars per share) | $ 65.09 | ||||
Estimated payout percentage based on performance criteria | 100.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 65.09 | ||||
2014 Grant [Member] | Performance Shares [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 49,719 | ||||
Alliant Energy common stock closing price on June 30, 2015 (in dollars per share) | $ 57.72 | ||||
Estimated payout percentage based on performance criteria | 133.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 76.77 | ||||
2014 Grant [Member] | Performance Units [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 19,440 | ||||
Alliant Energy common stock closing price on grant date (in dollars per share) | $ 53.77 | ||||
Estimated payout percentage based on performance criteria | 133.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 71.51 | ||||
2013 Grant [Member] | Performance Shares [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 49,093 | ||||
Alliant Energy common stock closing price on June 30, 2015 (in dollars per share) | $ 57.72 | ||||
Estimated payout percentage based on performance criteria | 180.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 103.90 | ||||
2013 Grant [Member] | Performance Units [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Nonvested awards (in shares/awards) | 21,380 | ||||
Alliant Energy common stock closing price on grant date (in dollars per share) | $ 47.58 | ||||
Estimated payout percentage based on performance criteria | 180.00% | ||||
Fair values of each nonvested award (in dollars per share) | $ 85.64 | ||||
[1] | Share amounts represent the target number of performance shares. | ||||
[2] | Unit amounts represent the target number of performance units. |
Benefit Plans (Summary Of Restr
Benefit Plans (Summary Of Restricted Stock Activity) (Details) - Performance Contingent Restricted Stock [Member] - $ / shares | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Nonvested, January 1 (in shares/awards) | 98,812 | 158,922 | |
Nonvested, January 1, weighted average fair value (in dollars per share) | $ 50.69 | $ 42.71 | |
Granted (in shares/awards) | 45,403 | 51,221 | |
Granted, weighted average fair value (in dollars per share) | $ 65.09 | $ 53.77 | |
Vested (in shares/awards) | [1] | (49,093) | (90,847) |
Vested, weighted average fair value (in dollars per share) | [1] | $ 47.58 | $ 40.91 |
Forfeited (in shares/awards) | 0 | (20,484) | |
Forfeited, weighted average fair value (in dollars per share) | $ 0 | $ 39.85 | |
Nonvested, June 30 (in shares/awards) | 95,122 | 98,812 | |
Nonvested, June 30, weighted average fair value (in dollars per share) | $ 59.17 | $ 50.69 | |
2013 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (49,093) | |
2012 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (45,612) | |
2011 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (45,235) | |
[1] | In 2015, 49,093 performance contingent restricted shares granted in 2013 vested because the specified performance criteria for such shares were met. In 2014, 45,612 and 45,235 performance contingent restricted shares granted in 2012 and 2011, respectively, vested because the specified performance criteria for such shares were met. |
Benefit Plans (Summary Of Per65
Benefit Plans (Summary Of Performance Contingent Cash Awards Activity) (Details) - Performance Contingent Cash Awards [Member] - USD ($) $ in Millions | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Nonvested, January 1 (in shares/awards) | 78,930 | 96,977 | |
Granted (in shares/awards) | 41,105 | 42,446 | |
Vested (in shares/awards) | [1] | (37,332) | (55,517) |
Forfeited (in shares/awards) | (709) | (4,098) | |
Nonvested, June 30 (in shares/awards) | 81,994 | 79,808 | |
2013 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (37,332) | |
Cash payout value | [1] | $ 2.4 | |
2012 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (34,766) | |
Cash payout value | [1] | $ 1.9 | |
2011 Grant [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward] | |||
Vested (in shares/awards) | [1] | (20,751) | |
Cash payout value | [1] | $ 1.1 | |
[1] | In 2015, 37,332 performance contingent cash awards granted in 2013 vested, resulting in cash payouts valued at $2.4 million. In 2014, 34,766 and 20,751 performance contingent cash awards granted in 2012 and 2011 vested, resulting in cash payouts valued at $1.9 million and $1.1 million, respectively. |
Asset Retirement Obligations (R
Asset Retirement Obligations (Reconciliation Of Changes In Asset Retirement Obligations) (Details) $ in Millions | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2015USD ($) | Jun. 30, 2015USD ($) | Jun. 30, 2014USD ($) | ||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||||
Balance, January 1 | $ 114 | $ 109.7 | ||||
Revisions in estimated cash flows | [1] | 2.1 | 0 | |||
Liabilities settled | (6.4) | (0.7) | ||||
Liabilities incurred | $ 74 | 72.3 | [1] | 16.5 | [1] | |
Accretion expense | 2.2 | 2.1 | ||||
Balance, June 30 | 184.2 | 184.2 | 127.6 | |||
IPL [Member] | ||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||||
Balance, January 1 | 51.8 | 47.9 | ||||
Revisions in estimated cash flows | [1] | 0.9 | 0 | |||
Liabilities settled | (2.4) | (0.4) | ||||
Liabilities incurred | 57 | 56.1 | [1] | 16.3 | [1] | |
Accretion expense | 0.9 | 1 | ||||
Balance, June 30 | $ 107.3 | $ 107.3 | 64.8 | |||
Electric generating units with coal ash ponds (in number of electric generating units) | 9 | 9 | ||||
Active coal combustion residuals landfills (in number of landfills) | 4 | 4 | ||||
WPL [Member] | ||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||||
Balance, January 1 | $ 52.4 | 52.4 | ||||
Revisions in estimated cash flows | [1] | 1.2 | 0 | |||
Liabilities settled | (4) | (0.3) | ||||
Liabilities incurred | $ 17 | 16.2 | [1] | 0.2 | [1] | |
Accretion expense | 0.9 | 0.8 | ||||
Balance, June 30 | $ 66.7 | $ 66.7 | $ 53.1 | |||
Electric generating units with coal ash ponds (in number of electric generating units) | 3 | 3 | ||||
Active coal combustion residuals landfills (in number of landfills) | 2 | 2 | ||||
[1] | In April 2015, the EPA published the final CCR Rule, which regulates CCR as a non-hazardous waste and is effective October 2015. IPL and WPL have nine and three coal-fired EGUs, respectively, with coal ash ponds that are impacted by this rule. In addition, IPL and WPL have four and two active CCR landfills, respectively, that are impacted by this rule. In the second quarter of 2015, Alliant Energy, IPL and WPL recognized additional AROs of $74 million, $57 million and $17 million, respectively, as a result of the final CCR Rule. The increases in AROs resulted in corresponding increases in “Property, plant and equipment, net” on the respective balance sheets. Actual costs resulting from the CCR rule may be different than the amounts recorded in the second quarter of 2015 due to potential changes in compliance strategies that will be used, as well as other potential cost estimate changes. Expenditures incurred by IPL and WPL to comply with the CCR Rule are anticipated to be recovered in rates from their customers. |
Fair Value Measurements (Narrat
Fair Value Measurements (Narrative) (Details) | 6 Months Ended |
Jun. 30, 2015 | |
IPL [Member] | |
Cumulative preferred stock rate | 5.10% |
Fair Value Measurements (Fair V
Fair Value Measurements (Fair Value Of Financial Instruments) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Assets: | ||
Derivative assets | $ 35 | $ 38.6 |
Capitalization and liabilities: | ||
Derivative liabilities | 47 | 37.6 |
IPL [Member] | ||
Assets: | ||
Derivative assets | 30.7 | 28 |
Capitalization and liabilities: | ||
Derivative liabilities | 20.7 | 19.5 |
WPL [Member] | ||
Assets: | ||
Derivative assets | 4.3 | 10.6 |
Capitalization and liabilities: | ||
Derivative liabilities | 26.3 | 18.1 |
Carrying Amount [Member] | ||
Assets: | ||
Derivative assets | 35 | 38.6 |
Deferred proceeds (sales of receivables) | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 3,750.9 | 3,789.7 |
Cumulative preferred stock | 200 | 200 |
Derivative liabilities | 47 | 37.6 |
Carrying Amount [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 30.7 | 28 |
Deferred proceeds (sales of receivables) | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,730.2 | 1,768.7 |
Cumulative preferred stock | 200 | 200 |
Derivative liabilities | 20.7 | 19.5 |
Carrying Amount [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 4.3 | 10.6 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,574.1 | 1,573.9 |
Derivative liabilities | 26.3 | 18.1 |
Fair Value [Member] | ||
Assets: | ||
Derivative assets | 35 | 38.6 |
Deferred proceeds (sales of receivables) | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 4,214.4 | 4,418.2 |
Cumulative preferred stock | 198.9 | 200.2 |
Derivative liabilities | 47 | 37.6 |
Fair Value [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 30.7 | 28 |
Deferred proceeds (sales of receivables) | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,937.2 | 2,053 |
Cumulative preferred stock | 198.9 | 200.2 |
Derivative liabilities | 20.7 | 19.5 |
Fair Value [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 4.3 | 10.6 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,824 | 1,908.9 |
Derivative liabilities | $ 26.3 | $ 18.1 |
Fair Value Measurements (Fair69
Fair Value Measurements (Fair Value Measurements) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Assets: | ||
Derivative assets | $ 32 | $ 33 |
Capitalization and liabilities: | ||
Derivative liabilities | 44 | 32 |
IPL [Member] | ||
Assets: | ||
Derivative assets | 29.3 | 24.7 |
Capitalization and liabilities: | ||
Derivative liabilities | 19.3 | 16.2 |
WPL [Member] | ||
Assets: | ||
Derivative assets | 2.7 | 8.3 |
Capitalization and liabilities: | ||
Derivative liabilities | 24.7 | 15.8 |
Level 1 [Member] | ||
Assets: | ||
Deferred proceeds | 0 | 0 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 0 | 0 |
Cumulative preferred stock | 198.9 | 200.2 |
Level 1 [Member] | IPL [Member] | ||
Assets: | ||
Deferred proceeds | 0 | 0 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 0 | 0 |
Cumulative preferred stock | 198.9 | 200.2 |
Level 1 [Member] | WPL [Member] | ||
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 0 | 0 |
Level 1 [Member] | Commodity Contracts [Member] | ||
Assets: | ||
Derivative assets | 0 | 0 |
Capitalization and liabilities: | ||
Derivative liabilities | 0 | 0 |
Level 1 [Member] | Commodity Contracts [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 0 | 0 |
Capitalization and liabilities: | ||
Derivative liabilities | 0 | 0 |
Level 1 [Member] | Commodity Contracts [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 0 | 0 |
Capitalization and liabilities: | ||
Derivative liabilities | 0 | 0 |
Level 2 [Member] | ||
Assets: | ||
Deferred proceeds | 0 | 0 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 4,210.7 | 4,414.9 |
Cumulative preferred stock | 0 | 0 |
Level 2 [Member] | IPL [Member] | ||
Assets: | ||
Deferred proceeds | 0 | 0 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,937.2 | 2,053 |
Cumulative preferred stock | 0 | 0 |
Level 2 [Member] | WPL [Member] | ||
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,824 | 1,908.9 |
Level 2 [Member] | Commodity Contracts [Member] | ||
Assets: | ||
Derivative assets | 3 | 2.6 |
Capitalization and liabilities: | ||
Derivative liabilities | 15.6 | 19.5 |
Level 2 [Member] | Commodity Contracts [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 1.9 | 2.4 |
Capitalization and liabilities: | ||
Derivative liabilities | 10.2 | 13.3 |
Level 2 [Member] | Commodity Contracts [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 1.1 | 0.2 |
Capitalization and liabilities: | ||
Derivative liabilities | 5.4 | 6.2 |
Level 3 [Member] | ||
Assets: | ||
Deferred proceeds | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 3.7 | 3.3 |
Cumulative preferred stock | 0 | 0 |
Level 3 [Member] | IPL [Member] | ||
Assets: | ||
Deferred proceeds | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 0 | 0 |
Cumulative preferred stock | 0 | 0 |
Level 3 [Member] | WPL [Member] | ||
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 0 | 0 |
Level 3 [Member] | Commodity Contracts [Member] | ||
Assets: | ||
Derivative assets | 32 | 36 |
Capitalization and liabilities: | ||
Derivative liabilities | 31.4 | 18.1 |
Level 3 [Member] | Commodity Contracts [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 28.8 | 25.6 |
Capitalization and liabilities: | ||
Derivative liabilities | 10.5 | 6.2 |
Level 3 [Member] | Commodity Contracts [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 3.2 | 10.4 |
Capitalization and liabilities: | ||
Derivative liabilities | 20.9 | 11.9 |
Fair Value [Member] | ||
Assets: | ||
Deferred proceeds | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 4,214.4 | 4,418.2 |
Cumulative preferred stock | 198.9 | 200.2 |
Fair Value [Member] | IPL [Member] | ||
Assets: | ||
Deferred proceeds | 73.4 | 177.2 |
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,937.2 | 2,053 |
Cumulative preferred stock | 198.9 | 200.2 |
Fair Value [Member] | WPL [Member] | ||
Capitalization and liabilities: | ||
Long-term debt (including current maturities) | 1,824 | 1,908.9 |
Fair Value [Member] | Commodity Contracts [Member] | ||
Assets: | ||
Derivative assets | 35 | 38.6 |
Capitalization and liabilities: | ||
Derivative liabilities | 47 | 37.6 |
Fair Value [Member] | Commodity Contracts [Member] | IPL [Member] | ||
Assets: | ||
Derivative assets | 30.7 | 28 |
Capitalization and liabilities: | ||
Derivative liabilities | 20.7 | 19.5 |
Fair Value [Member] | Commodity Contracts [Member] | WPL [Member] | ||
Assets: | ||
Derivative assets | 4.3 | 10.6 |
Capitalization and liabilities: | ||
Derivative liabilities | $ 26.3 | $ 18.1 |
Fair Value Measurements (Fair70
Fair Value Measurements (Fair Value Measurements Using Significant Unobservable Inputs) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | ||
Commodity Contracts [Member] | |||||
Fair Value, Assets and Liabilities, Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||
Beginning balance | $ (13.1) | $ 23.9 | $ 17.9 | $ 4.4 | |
Total net gains (losses) (realized/unrealized) included in changes in net assets | (19.6) | 16.9 | (36.8) | 54.7 | |
Transfers out of Level 3 | 1 | 0 | 0.6 | 0 | |
Purchases | 36.8 | 76.7 | 36.8 | 76.7 | |
Sales | (0.4) | 0 | (1.2) | 0 | |
Settlements | [1] | (4.1) | (16.3) | (16.7) | (34.6) |
Ending balance | 0.6 | 101.2 | 0.6 | 101.2 | |
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 | (17.7) | 16.3 | (33.9) | 46 | |
Commodity Contracts [Member] | IPL [Member] | |||||
Fair Value, Assets and Liabilities, Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||
Beginning balance | (5) | 7.8 | 19.4 | 14.6 | |
Total net gains (losses) (realized/unrealized) included in changes in net assets | (5) | 0.6 | (17.4) | 4.4 | |
Transfers out of Level 3 | 0.2 | 0 | |||
Purchases | 33.1 | 68.8 | 33.1 | 68.8 | |
Sales | (0.4) | 0 | (1.1) | 0 | |
Settlements | [1] | (4.6) | (13) | (15.7) | (23.6) |
Ending balance | 18.3 | 64.2 | 18.3 | 64.2 | |
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 | (4.2) | 0.7 | (14.3) | 3.7 | |
Commodity Contracts [Member] | WPL [Member] | |||||
Fair Value, Assets and Liabilities, Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||
Beginning balance | (8.1) | 16.1 | (1.5) | (10.2) | |
Total net gains (losses) (realized/unrealized) included in changes in net assets | (14.6) | 16.3 | (19.4) | 50.3 | |
Transfers out of Level 3 | 0.8 | 0 | 0.6 | 0 | |
Purchases | 3.7 | 7.9 | 3.7 | 7.9 | |
Sales | (0.1) | 0 | |||
Settlements | 0.5 | (3.3) | (1) | (11) | |
Ending balance | (17.7) | 37 | (17.7) | 37 | |
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 | (13.5) | 15.6 | (19.6) | 42.3 | |
Deferred Proceeds [Member] | |||||
Fair Value, Assets and Liabilities, Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||
Beginning balance | 117.7 | 170.8 | 177.2 | 203.5 | |
Total net gains (losses) (realized/unrealized) included in changes in net assets | 0 | 0 | 0 | 0 | |
Transfers out of Level 3 | 0 | 0 | 0 | 0 | |
Purchases | 0 | 0 | 0 | 0 | |
Sales | 0 | 0 | 0 | 0 | |
Settlements | [1] | (44.3) | 22.9 | (103.8) | (9.8) |
Ending balance | 73.4 | 193.7 | 73.4 | 193.7 | |
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 | 0 | 0 | 0 | 0 | |
Deferred Proceeds [Member] | IPL [Member] | |||||
Fair Value, Assets and Liabilities, Net, Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward] | |||||
Beginning balance | 117.7 | 170.8 | 177.2 | 203.5 | |
Total net gains (losses) (realized/unrealized) included in changes in net assets | 0 | 0 | 0 | 0 | |
Transfers out of Level 3 | 0 | 0 | |||
Purchases | 0 | 0 | 0 | 0 | |
Sales | 0 | 0 | 0 | 0 | |
Settlements | [1] | (44.3) | 22.9 | (103.8) | (9.8) |
Ending balance | 73.4 | 193.7 | 73.4 | 193.7 | |
The amount of total net gains (losses) for the period included in changes in net assets attributable to the change in unrealized gains (losses) relating to assets and liabilities held at June 30 | $ 0 | $ 0 | $ 0 | $ 0 | |
[1] | Settlements related to deferred proceeds are due to the change in the carrying amount of receivables sold less the allowance for doubtful accounts associated with the receivables sold and cash proceeds received from the receivables sold. |
Fair Value Measurements (Fair71
Fair Value Measurements (Fair Value Of Net Derivative Assets (Liabilities)) (Details) - Commodity Contracts [Member] - USD ($) $ in Millions | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Jun. 30, 2014 | Mar. 31, 2014 | Dec. 31, 2013 |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | $ 0.6 | $ (13.1) | $ 17.9 | $ 101.2 | $ 23.9 | $ 4.4 |
Excluding Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative liabilities | (28.3) | (7) | ||||
Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | 28.9 | 24.9 | ||||
IPL [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | 18.3 | (5) | 19.4 | 64.2 | 7.8 | 14.6 |
IPL [Member] | Excluding Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative liabilities | (9) | (3.2) | ||||
IPL [Member] | Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | 27.3 | 22.6 | ||||
WPL [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | (17.7) | $ (8.1) | (1.5) | $ 37 | $ 16.1 | $ (10.2) |
WPL [Member] | Excluding Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative liabilities | (19.3) | (3.8) | ||||
WPL [Member] | Financial Transmission Rights [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair value, net derivative assets | $ 1.6 | $ 2.3 |
Derivative Instruments (Notiona
Derivative Instruments (Notional Amounts Of Derivative Instruments) (Details) - Jun. 30, 2015 - Commodity [Member] Tons in Thousands, MWh in Thousands, Dekatherms in Thousands | TonsDekathermsMWh |
Electricity (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 8,300 |
Electricity (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,909 |
Electricity (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 6,391 |
FTRs (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 21,913 |
FTRs (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 12,360 |
FTRs (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 9,553 |
Natural Gas (Dths) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 79,702 |
Natural Gas (Dths) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 44,458 |
Natural Gas (Dths) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 35,244 |
Coal (Tons) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 5,343 |
Coal (Tons) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 1,680 |
Coal (Tons) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 3,663 |
2015 [Member] | Electricity (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 2,432 |
2015 [Member] | Electricity (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,100 |
2015 [Member] | Electricity (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,332 |
2015 [Member] | FTRs (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 11,952 |
2015 [Member] | FTRs (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 6,664 |
2015 [Member] | FTRs (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 5,288 |
2015 [Member] | Natural Gas (Dths) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 36,167 |
2015 [Member] | Natural Gas (Dths) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 23,343 |
2015 [Member] | Natural Gas (Dths) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 12,824 |
2015 [Member] | Coal (Tons) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 897 |
2015 [Member] | Coal (Tons) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 189 |
2015 [Member] | Coal (Tons) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 708 |
2016 [Member] | Electricity (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 3,240 |
2016 [Member] | Electricity (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 809 |
2016 [Member] | Electricity (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 2,431 |
2016 [Member] | FTRs (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 9,961 |
2016 [Member] | FTRs (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 5,696 |
2016 [Member] | FTRs (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 4,265 |
2016 [Member] | Natural Gas (Dths) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 34,330 |
2016 [Member] | Natural Gas (Dths) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 18,103 |
2016 [Member] | Natural Gas (Dths) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 16,227 |
2016 [Member] | Coal (Tons) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 2,260 |
2016 [Member] | Coal (Tons) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 830 |
2016 [Member] | Coal (Tons) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 1,430 |
2017 [Member] | Electricity (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,314 |
2017 [Member] | Electricity (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2017 [Member] | Electricity (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,314 |
2017 [Member] | FTRs (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2017 [Member] | FTRs (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2017 [Member] | FTRs (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2017 [Member] | Natural Gas (Dths) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 9,079 |
2017 [Member] | Natural Gas (Dths) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 2,886 |
2017 [Member] | Natural Gas (Dths) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 6,193 |
2017 [Member] | Coal (Tons) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 1,073 |
2017 [Member] | Coal (Tons) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 274 |
2017 [Member] | Coal (Tons) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 799 |
2018 [Member] | Electricity (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,314 |
2018 [Member] | Electricity (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2018 [Member] | Electricity (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 1,314 |
2018 [Member] | FTRs (MWhs) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2018 [Member] | FTRs (MWhs) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2018 [Member] | FTRs (MWhs) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | 0 |
2018 [Member] | Natural Gas (Dths) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 126 |
2018 [Member] | Natural Gas (Dths) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 126 |
2018 [Member] | Natural Gas (Dths) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Dekatherms | 0 |
2018 [Member] | Coal (Tons) [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 1,113 |
2018 [Member] | Coal (Tons) [Member] | IPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 387 |
2018 [Member] | Coal (Tons) [Member] | WPL [Member] | |
Notional Amount of Derivatives [Line Items] | |
Notional unit amount of derivatives (in MWhs/Dths/Tons) | Tons | 726 |
Derivative Instruments (Fair Va
Derivative Instruments (Fair Value Of Financial Instruments) (Details) - Commodity Contracts [Member] - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Derivatives, Fair Value [Line Items] | ||
Current derivative assets | $ 34.2 | $ 30.5 |
Non-current derivative assets | 0.8 | 8.1 |
Current derivative liabilities | 27.1 | 28.1 |
Non-current derivative liabilities | 19.9 | 9.5 |
IPL [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Current derivative assets | 30 | 27.4 |
Non-current derivative assets | 0.7 | 0.6 |
Current derivative liabilities | 13.8 | 16.4 |
Non-current derivative liabilities | 6.9 | 3.1 |
WPL [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Current derivative assets | 4.2 | 3.1 |
Non-current derivative assets | 0.1 | 7.5 |
Current derivative liabilities | 13.3 | 11.7 |
Non-current derivative liabilities | $ 13 | $ 6.4 |
Derivative Instruments (Gains A
Derivative Instruments (Gains And Losses From Derivative Instruments) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Regulatory Assets [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | $ (21.2) | $ (4.6) | $ (42.1) | $ 5.5 |
Regulatory Assets [Member] | IPL [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | (12.1) | (4.1) | (23.8) | 1.4 |
Regulatory Assets [Member] | WPL [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | (9.1) | (0.5) | (18.3) | 4.1 |
Regulatory Liabilities [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | (4.6) | 21.3 | (2.4) | 69.4 |
Regulatory Liabilities [Member] | IPL [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | 3.6 | 3.8 | 2.2 | 15.9 |
Regulatory Liabilities [Member] | WPL [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gains (losses) from commodity derivative instruments | $ (8.2) | $ 17.5 | $ (4.6) | $ 53.5 |
Derivative Instruments (Credit
Derivative Instruments (Credit Risk-related Contingent Features) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Derivative Instruments [Line Items] | ||
Aggregate fair value | $ 47 | $ 37.6 |
Credit support to be posted if triggered | 46.9 | 37.4 |
IPL [Member] | ||
Derivative Instruments [Line Items] | ||
Aggregate fair value | 20.7 | 19.5 |
Credit support to be posted if triggered | 20.7 | 19.5 |
WPL [Member] | ||
Derivative Instruments [Line Items] | ||
Aggregate fair value | 26.3 | 18.1 |
Credit support to be posted if triggered | $ 26.2 | $ 17.9 |
Derivative Instruments (Balance
Derivative Instruments (Balance Sheet Offsetting) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
Derivative Instruments [Line Items] | ||
Derivative assets, Gross (as reported) | $ 35 | $ 38.6 |
Derivative assets, Net | 32 | 33 |
Derivative liabilities, Gross (as reported) | 47 | 37.6 |
Derivative liabilities, Net | 44 | 32 |
IPL [Member] | ||
Derivative Instruments [Line Items] | ||
Derivative assets, Gross (as reported) | 30.7 | 28 |
Derivative assets, Net | 29.3 | 24.7 |
Derivative liabilities, Gross (as reported) | 20.7 | 19.5 |
Derivative liabilities, Net | 19.3 | 16.2 |
WPL [Member] | ||
Derivative Instruments [Line Items] | ||
Derivative assets, Gross (as reported) | 4.3 | 10.6 |
Derivative assets, Net | 2.7 | 8.3 |
Derivative liabilities, Gross (as reported) | 26.3 | 18.1 |
Derivative liabilities, Net | $ 24.7 | $ 15.8 |
Commitments And Contingencies77
Commitments And Contingencies (Narrative) (Details) - Jun. 30, 2015 $ in Millions | USD ($)site |
Commitments and Contingencies [Line Items] | |
Minimum future commitments | $ 2,277 |
Performance guarantees outstanding | 198 |
Present value abandonment obligation | 36 |
IPL [Member] | |
Commitments and Contingencies [Line Items] | |
Minimum future commitments | $ 1,799 |
Number of sites monitoring and remediating (in sites) | site | 24 |
WPL [Member] | |
Commitments and Contingencies [Line Items] | |
Minimum future commitments | $ 478 |
Number of sites monitoring and remediating (in sites) | site | 5 |
Capital Purchase Obligation [Member] | Alliant Energy and WPL [Member] | |
Commitments and Contingencies [Line Items] | |
Minimum future commitments | $ 30 |
Performance guarantees outstanding, 2015 [Member] | |
Commitments and Contingencies [Line Items] | |
Performance guarantees outstanding | 75 |
Performance guarantees outstanding, 2016 [Member] | |
Commitments and Contingencies [Line Items] | |
Performance guarantees outstanding | 48 |
Performance guarantees outstanding, 2017 [Member] | |
Commitments and Contingencies [Line Items] | |
Performance guarantees outstanding | 75 |
Civil Penalty [Member] | IPL [Member] | |
Commitments and Contingencies [Line Items] | |
Environmental mitigation projects to be completed, value | 1 |
Environmental Issue [Member] | IPL [Member] | |
Commitments and Contingencies [Line Items] | |
Environmental mitigation projects to be completed, value | 6 |
Environmental Issue [Member] | WPL [Member] | |
Commitments and Contingencies [Line Items] | |
Environmental mitigation projects to be completed, value | $ 7 |
Minimum [Member] | |
Commitments and Contingencies [Line Items] | |
Warranty period | 12 months |
Maximum [Member] | |
Commitments and Contingencies [Line Items] | |
Warranty period | 60 months |
Commitments And Contingencies78
Commitments And Contingencies (Operating Expense Purchase Obligations) (Details) - Jun. 30, 2015 - USD ($) $ in Millions | Total | |
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | $ 2,277 | |
Individual commitments incurred | 1 | |
IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 1,799 | |
Individual commitments incurred | 1 | |
WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 478 | |
Individual commitments incurred | 1 | |
DAEC (IPL) [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 1,480 |
DAEC (IPL) [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 1,480 |
DAEC (IPL) [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 0 |
Other [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 202 |
Other [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 1 |
Other [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 201 |
Purchased Power [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 1,682 |
Purchased Power [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 1,481 |
Purchased Power [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [1] | 201 |
Natural Gas [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 270 | |
Natural Gas [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 165 | |
Natural Gas [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 105 | |
Coal [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [2] | 279 |
Coal [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [2] | 114 |
Coal [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [2] | 165 |
SO2 emission allowances [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 22 | |
SO2 emission allowances [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 22 | |
SO2 emission allowances [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | 0 | |
Other [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [3] | 24 |
Other [Member] | IPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [3] | 17 |
Other [Member] | WPL [Member] | ||
Commitments and Contingencies [Line Items] | ||
Minimum future commitments | [3] | $ 7 |
[1] | Includes payments required by PPAs for capacity rights and minimum quantities of MWhs required to be purchased. | |
[2] | Corporate Services entered into system-wide coal contracts on behalf of IPL and WPL that include minimum future commitments. These commitments were assigned to IPL and WPL based on information available as of June 30, 2015 regarding expected future usage, which is subject to change. | |
[3] | Includes individual commitments incurred during the normal course of business that exceeded $1 million at June 30, 2015. |
Commitments And Contingencies79
Commitments And Contingencies (MPG Site Estimated Future Costs And Recorded Liabilities) (Details) - Jun. 30, 2015 - Manufactured Gas Plant Sites [Member] - USD ($) $ in Millions | Total |
Commitments and Contingencies [Line Items] | |
Minimum range of estimated future costs | $ 12 |
Maximum range of estimated future costs | 29 |
Current and non-current environmental liabilities | 16 |
IPL [Member] | |
Commitments and Contingencies [Line Items] | |
Minimum range of estimated future costs | 10 |
Maximum range of estimated future costs | 26 |
Current and non-current environmental liabilities | 14 |
WPL [Member] | |
Commitments and Contingencies [Line Items] | |
Minimum range of estimated future costs | 2 |
Maximum range of estimated future costs | 3 |
Current and non-current environmental liabilities | $ 2 |
Segments Of Business (Schedule
Segments Of Business (Schedule Of Segments Of Business) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Segment Reporting Information [Line Items] | ||||
Operating revenues | $ 717.2 | $ 750.3 | $ 1,614.6 | $ 1,703.1 |
Operating income (loss) | 109 | 103.3 | 261.9 | 257.5 |
Income from continuing operations, net of tax | 68.9 | 62.1 | 165.5 | 170.1 |
Loss from discontinued operations, net of tax | (1.3) | (0.3) | (1.3) | (0.3) |
Net income (loss) attributable to common shareowners | 67.6 | 61.8 | 164.2 | 169.8 |
IPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 382.2 | 411.9 | 871.2 | 940.8 |
Operating income (loss) | 33.8 | 34 | 99.3 | 91.5 |
Net income (loss) attributable to common shareowners | 16.7 | 18.4 | 64.5 | 61.8 |
WPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 324.7 | 324.5 | 721.8 | 734.9 |
Operating income (loss) | 68.3 | 60 | 149.1 | 147.7 |
Net income (loss) attributable to common shareowners | 39 | 34.6 | 83.6 | 89.4 |
Electric [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 640.4 | 643.9 | 1,311.7 | 1,319.7 |
Operating income (loss) | 100.9 | 89.1 | 205.6 | 183.4 |
Electric [Member] | IPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 339.4 | 354.6 | 702 | 728.8 |
Operating income (loss) | 33.9 | 29 | 74.2 | 55.5 |
Electric [Member] | WPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 301 | 289.3 | 609.7 | 590.9 |
Operating income (loss) | 67 | 60.1 | 131.4 | 127.9 |
Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 51.7 | 76.9 | 250.1 | 317.6 |
Operating income (loss) | (2) | 2.7 | 34.3 | 45.7 |
Gas [Member] | IPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 29.8 | 43.7 | 141 | 179.4 |
Operating income (loss) | (2.4) | 1.6 | 18.2 | 24.9 |
Gas [Member] | WPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 21.9 | 33.2 | 109.1 | 138.2 |
Operating income (loss) | 0.4 | 1.1 | 16.1 | 20.8 |
Other Utilities [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 14.8 | 15.6 | 31.2 | 38.4 |
Operating income (loss) | 3.2 | 2.2 | 8.5 | 10.1 |
Other Utilities [Member] | IPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 13 | 13.6 | 28.2 | 32.6 |
Operating income (loss) | 2.3 | 3.4 | 6.9 | 11.1 |
Other Utilities [Member] | WPL [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 1.8 | 2 | 3 | 5.8 |
Operating income (loss) | 0.9 | (1.2) | 1.6 | (1) |
Utilities Business [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 706.9 | 736.4 | 1,593 | 1,675.7 |
Operating income (loss) | 102.1 | 94 | 248.4 | 239.2 |
Income from continuing operations, net of tax | 55.7 | 53 | 148.1 | 151.2 |
Loss from discontinued operations, net of tax | 0 | 0 | 0 | 0 |
Net income (loss) attributable to common shareowners | 55.7 | 53 | 148.1 | 151.2 |
Non-Regulated [Member] | Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues | 10.3 | 13.9 | 21.6 | 27.4 |
Operating income (loss) | 6.9 | 9.3 | 13.5 | 18.3 |
Income from continuing operations, net of tax | 13.2 | 9.1 | 17.4 | 18.9 |
Loss from discontinued operations, net of tax | (1.3) | (0.3) | (1.3) | (0.3) |
Net income (loss) attributable to common shareowners | $ 11.9 | $ 8.8 | $ 16.1 | $ 18.6 |
Related Parties (Narrative) (De
Related Parties (Narrative) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
IPL [Member] | ||
Related Party Transactions [Line Items] | ||
Net amounts due from (to) related party | $ (95) | $ (84) |
WPL [Member] | ||
Related Party Transactions [Line Items] | ||
Net amounts due from (to) related party | (49) | (58) |
WPL [Member] | WPL Owed ATC [Member] | ||
Related Party Transactions [Line Items] | ||
Net amounts due from (to) related party | $ (8) | $ (8) |
Related Parties (Service Agreem
Related Parties (Service Agreements) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Corporate Services Billings [Member] | IPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | $ 40 | $ 41 | $ 76 | $ 74 |
Corporate Services Billings [Member] | WPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | 32 | 31 | 60 | 59 |
Sales Credited [Member] | IPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | 2 | 2 | 6 | 4 |
Sales Credited [Member] | WPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | 6 | 3 | 12 | 2 |
Purchases Billed [Member] | IPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | 89 | 108 | 168 | 207 |
Purchases Billed [Member] | WPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | $ 19 | $ 28 | $ 33 | $ 58 |
Related Parties (Net Intercompa
Related Parties (Net Intercompany Payables) (Details) - USD ($) $ in Millions | Jun. 30, 2015 | Dec. 31, 2014 |
IPL [Member] | ||
Related Party Transactions [Line Items] | ||
Net amounts due from (to) related party | $ (95) | $ (84) |
WPL [Member] | ||
Related Party Transactions [Line Items] | ||
Net amounts due from (to) related party | $ (49) | $ (58) |
Related Parties (Amounts Billed
Related Parties (Amounts Billed Between Parties) (Details) - WPL [Member] - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
ATC Billings To WPL [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | $ 25 | $ 24 | $ 50 | $ 48 |
WPL Billings To ATC [Member] | ||||
Related Party Transactions [Line Items] | ||||
Amounts billed between related parties | $ 3 | $ 1 | $ 5 | $ 4 |
Discontinued Operations And A85
Discontinued Operations And Assets And Liabilities Held For Sale (Components Of Discontinued Operations In Consolidated Statements Of Income (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2014 | Jun. 30, 2015 | Jun. 30, 2014 | |
Discontinued Operations and Disposal Groups [Abstract] | ||||
Operating expenses | $ 2 | $ 0.6 | $ 2 | $ 0.6 |
Loss before income taxes | (2) | (0.6) | (2) | (0.6) |
Income tax benefit | (0.7) | (0.3) | (0.7) | (0.3) |
Loss from discontinued operations, net of tax | $ (1.3) | $ (0.3) | $ (1.3) | $ (0.3) |
Discontinued Operations And A86
Discontinued Operations And Assets And Liabilities Held For Sale (Components Of Assets And Liabilities Held For Sale In Consolidated Balance Sheets) (Details) - Alliant Energy and IPL [Member] - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2015 | Jun. 30, 2015 | Dec. 31, 2014 | ||
Electric distribution assets [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Current assets | $ 9.3 | $ 9.3 | ||
Property, plant and equipment, net | 125 | 125 | ||
Non-current regulatory assets | 20.5 | 20.5 | ||
Carrying value adjustment of net assets sold | [1] | (8.8) | (8.8) | |
Total assets held for sale | 146 | 146 | ||
Current liabilities | 2.4 | 2.4 | ||
Other liabilities | 12.6 | 12.6 | ||
Total liabilities held for sale | 15 | 15 | ||
Net assets held for sale | 131 | 131 | ||
Loss on sale of Minnesota distribution assets | $ 9 | $ 9 | ||
Gas distribution assets [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Current assets | $ 1.1 | |||
Property, plant and equipment, net | 11 | |||
Non-current regulatory assets | 7 | |||
Carrying value adjustment of net assets sold | [1] | 0 | ||
Total assets held for sale | 19.1 | |||
Current liabilities | 1 | |||
Other liabilities | 7.1 | |||
Total liabilities held for sale | 8.1 | |||
Net assets held for sale | $ 11 | |||
[1] | The carrying value of IPL’s Minnesota electric distribution assets classified as held for sale exceeded the expected proceeds, less costs to sell. As a result, Alliant Energy and IPL recorded a pre-tax charge of $9 million in the second quarter of 2015 related to the Minnesota electric distribution assets. |