Document and Entity Information
Document and Entity Information - USD ($) | 12 Months Ended | ||
Sep. 30, 2016 | Nov. 11, 2016 | Mar. 31, 2016 | |
Entity Information [Line Items] | |||
Entity Registrant Name | SPIRE INC | ||
Entity Central Index Key | 1,126,956 | ||
Current Fiscal Year End Date | --09-30 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Public Float | $ 2,843,343,450 | ||
Entity Common Stock, Shares Outstanding | 45,656,218 | ||
Document Fiscal Year Focus | 2,016 | ||
Document Fiscal Period Focus | FY | ||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Sep. 30, 2016 | ||
Laclede Gas | |||
Entity Information [Line Items] | |||
Entity Registrant Name | LACLEDE GAS CO | ||
Entity Central Index Key | 57,183 | ||
Current Fiscal Year End Date | --09-30 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Public Float | 0 | ||
Entity Common Stock, Shares Outstanding | 24,577 | ||
Document Fiscal Year Focus | 2,016 | ||
Document Fiscal Period Focus | FY | ||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Sep. 30, 2016 | ||
Alagasco | |||
Entity Information [Line Items] | |||
Entity Registrant Name | ALABAMA GAS CORP | ||
Entity Central Index Key | 3,146 | ||
Current Fiscal Year End Date | --09-30 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Public Float | $ 0 | ||
Entity Common Stock, Shares Outstanding | 1,972,052 | ||
Document Fiscal Year Focus | 2,016 | ||
Document Fiscal Period Focus | FY | ||
Document Type | 10-K | ||
Amendment Flag | false | ||
Document Period End Date | Sep. 30, 2016 |
CONSOLIDATED STATEMENTS OF INCO
CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Operating Revenues: | ||||
Gas Utility | $ 1,457.2 | $ 1,891.8 | $ 1,462.6 | |
Gas Marketing and other | 80.1 | 84.6 | 164.6 | |
Total Operating Revenues | 1,537.3 | 1,976.4 | 1,627.2 | |
Gas Utility | ||||
Natural and propane gas | 492.2 | 882.4 | 731.7 | |
Other operation and maintenance expenses | 377.5 | 390.6 | 287.8 | |
Depreciation and amortization | 136.9 | 129.9 | 82.4 | |
Taxes, other than income taxes | 125.2 | 142.1 | 112 | |
Total Gas Utility Operating Expenses | 1,131.8 | 1,545 | 1,213.9 | |
Gas Marketing and other | 123.2 | 158.9 | 246.9 | |
Total Operating Expenses | 1,255 | 1,703.9 | 1,460.8 | |
Operating Income | 282.3 | 272.5 | 166.4 | |
Other Income and (Income Deductions) – Net | 8.6 | 1.2 | (3.3) | |
Interest Charges: | ||||
Interest on long-term debt | 67.6 | 66.6 | 39.3 | |
Other interest charges | 9.6 | 8 | 6.9 | |
Total Interest Charges | 77.2 | 74.6 | 46.2 | |
Income Before Income Taxes | 213.7 | 199.1 | 116.9 | |
Income Tax Expense | 69.5 | 62.2 | 32.3 | |
Net Income | $ 144.2 | $ 136.9 | $ 84.6 | |
Weighted Average Number of Common Shares Outstanding: | ||||
Basic (in shares) | 44.1 | 43.2 | 35.8 | |
Diluted (in shares) | 44.3 | 43.3 | 35.9 | |
Basic Earnings Per Share of Common Stock (in dollars per share) | $ 3.26 | $ 3.16 | $ 2.36 | |
Diluted Earnings Per Share of Common Stock (in dollars per share) | $ 3.24 | $ 3.16 | $ 2.35 | |
Laclede Gas | ||||
Operating Revenues: | ||||
Gas Utility | $ 1,087.5 | $ 1,416.6 | $ 1,448.1 | |
Other | 0 | 0 | 0.1 | |
Total Operating Revenues | 1,087.5 | 1,416.6 | 1,448.2 | |
Gas Utility | ||||
Natural and propane gas | 471.3 | 786.1 | 816.9 | |
Other operation and maintenance expenses | 244.4 | 253.6 | 276.4 | |
Depreciation and amortization | 88.6 | 82.6 | 78.5 | |
Taxes, other than income taxes | 96.3 | 108.9 | 110.1 | |
Total Gas Utility Operating Expenses | 900.6 | 1,231.2 | 1,281.9 | |
Gas Marketing and other | 0 | 0 | (0.1) | |
Total Operating Expenses | 900.6 | 1,231.2 | 1,281.8 | |
Operating Income | 186.9 | 185.4 | 166.4 | |
Other Income and (Income Deductions) – Net | 1.8 | (0.5) | (3.4) | |
Interest Charges: | ||||
Interest on long-term debt | 32.9 | 33.1 | 34.4 | |
Other interest charges | 4.5 | 3.3 | 3 | |
Total Interest Charges | 37.4 | 36.4 | 37.4 | |
Income Before Income Taxes | 151.3 | 148.5 | 125.6 | |
Income Tax Expense | 45.4 | 43.2 | 35.5 | |
Net Income | 105.9 | 105.3 | $ 90.1 | |
Alagasco | ||||
Operating Revenues: | ||||
Gas Utility | $ 417.2 | 368.5 | 479.2 | |
Total Operating Revenues | 417.2 | 368.5 | 479.2 | |
Gas Utility | ||||
Natural and propane gas | 184.5 | 67.3 | 171.5 | |
Other operation and maintenance expenses | 107.5 | 133.5 | 138 | |
Depreciation and amortization | 34.4 | 47.8 | 47.3 | |
Taxes, other than income taxes | 28.6 | 28.4 | 33.2 | |
Total Operating Expenses | 355 | 277 | 390 | |
Operating Income | 62.2 | 91.5 | 89.2 | |
Other Income and (Income Deductions) – Net | 2.2 | 7.9 | 2 | |
Interest Charges: | ||||
Interest on long-term debt | 10.1 | 11.4 | 11.6 | |
Other interest charges | 1.4 | 2.4 | 2.3 | |
Total Interest Charges | 11.5 | 13.8 | 13.9 | |
Income Before Income Taxes | 52.9 | 85.6 | 77.3 | |
Income Tax Expense | 19.9 | 32.4 | 29.3 | |
Net Income | $ 33 | $ 53.2 | $ 48 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Net income | $ 144.2 | $ 136.9 | $ 84.6 |
Cash flow hedging derivative instruments: | |||
Net hedging loss arising during the period | (4) | (5.5) | (4.5) |
Reclassification adjustment for loss included in net income | 1.1 | 4.4 | 2.5 |
Net unrealized loss on cash flow hedging derivative instruments | (2.9) | (1.1) | (2) |
Defined benefit pension and other postretirement benefit plans: | |||
Net actuarial gain arising during the period | 0 | 0.1 | 0 |
Amortization of actuarial (gain) loss included in net periodic pension and postretirement benefit cost | (0.3) | 0.4 | 0.5 |
Net defined benefit pension and other postretirement benefit plans | (0.3) | 0.5 | 0.5 |
Other Comprehensive Loss, Before Tax | (3.2) | (0.6) | (1.5) |
Income Tax Benefit Related to Items of Other Comprehensive Loss | (1) | (0.3) | (0.6) |
Other Comprehensive Loss, Net of Tax | (2.2) | (0.3) | (0.9) |
Comprehensive Income | 142 | 136.6 | 83.7 |
Laclede Gas | |||
Net income | 105.9 | 105.3 | 90.1 |
Cash flow hedging derivative instruments: | |||
Net hedging loss arising during the period | 0 | (1.2) | 0.1 |
Reclassification adjustment for loss included in net income | 0.5 | 0.9 | (0.2) |
Net unrealized loss on cash flow hedging derivative instruments | 0.5 | (0.3) | (0.1) |
Defined benefit pension and other postretirement benefit plans: | |||
Net actuarial gain arising during the period | 0 | 0.1 | 0 |
Amortization of actuarial (gain) loss included in net periodic pension and postretirement benefit cost | (0.3) | 0.4 | 0.4 |
Net defined benefit pension and other postretirement benefit plans | (0.3) | 0.5 | 0.4 |
Loss on available for sale securities | (0.1) | 0 | 0 |
Other Comprehensive Loss, Before Tax | 0.1 | 0.2 | 0.3 |
Income Tax Benefit Related to Items of Other Comprehensive Loss | 0.2 | 0 | 0.1 |
Other Comprehensive Loss, Net of Tax | (0.1) | 0.2 | 0.2 |
Comprehensive Income | $ 105.8 | $ 105.5 | $ 90.3 |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
ASSETS | ||
Utility Plant | $ 4,793.6 | $ 4,234.5 |
Less: Accumulated depreciation and amortization | 1,506.4 | 1,307 |
Net Utility Plant | 3,287.2 | 2,927.5 |
Non-utility property (net of accumulated depreciation and amortization, $8.1 and $7.5 at September 30, 2016 and 2015, respectively) | 13.7 | 13.7 |
Goodwill | 1,164.9 | 946 |
Other investments | 62.1 | 59.9 |
Other Property and Investments | 1,240.7 | 1,019.6 |
Current Assets: | ||
Cash and cash equivalents | 5.2 | 13.8 |
Accounts receivable: | ||
Utility | 127.8 | 138.1 |
Other | 113.4 | 86.7 |
Allowance for doubtful accounts | (20.5) | (14.2) |
Delayed customer billings | 1.6 | 2.6 |
Inventories: | ||
Natural gas | 174 | 188.6 |
Propane gas | 12 | 12 |
Materials and supplies | 16.3 | 14.8 |
Natural gas receivable | 9.7 | 17.3 |
Derivative instrument assets | 11.4 | 4.6 |
Unamortized purchased gas adjustments | 49.7 | 12.9 |
Other regulatory assets | 44.2 | 27.6 |
Deferred income tax | 0 | 5.8 |
Prepayments and other | 24.8 | 25.3 |
Total Current Assets | 569.6 | 530.1 |
Deferred Charges: | ||
Regulatory assets | 838 | 737.6 |
Other | 141.9 | 75.4 |
Total Deferred Charges | 979.9 | 813 |
Total Assets | 6,077.4 | 5,290.2 |
Capitalization: | ||
Common stock equity | 1,768.2 | 1,573.6 |
Long-term debt | 1,833.7 | 1,771.5 |
Total Capitalization | 3,601.9 | 3,345.1 |
Current Liabilities: | ||
Current portion of long-term debt | 250 | 80 |
Notes payable | 398.7 | 338 |
Accounts payable | 210.9 | 146.5 |
Advance customer billings | 70.2 | 44.3 |
Wages and compensation accrued | 39.8 | 32.7 |
Dividends payable | 23.5 | 21.1 |
Customer deposits | 34.9 | 32.1 |
Interest accrued | 14.8 | 14.3 |
Unamortized purchased gas adjustments | 1.7 | 28.2 |
Taxes accrued | 55.2 | 51.7 |
Other regulatory liabilities | 28.9 | 32.4 |
Other | 32.7 | 32.5 |
Total Current Liabilities | 1,161.3 | 853.8 |
Deferred Credits and Other Liabilities: | ||
Deferred income taxes | 607.3 | |
Deferred income taxes | 482.1 | |
Pension and postretirement benefit costs | 303.7 | 253.4 |
Asset retirement obligations | 206.4 | 159.2 |
Regulatory liabilities | 130.7 | 119.3 |
Other | 66.1 | 77.3 |
Total Deferred Credits and Other Liabilities | 1,314.2 | 1,091.3 |
Commitments and Contingencies | ||
Total Capitalization and Liabilities | 6,077.4 | 5,290.2 |
Laclede Gas | ||
ASSETS | ||
Utility Plant | 2,718.5 | 2,579.1 |
Less: Accumulated depreciation and amortization | 604.5 | 590 |
Net Utility Plant | 2,114 | 1,989.1 |
Goodwill | 210.2 | 210.2 |
Other investments | 57.3 | 55.3 |
Other Property and Investments | 267.5 | 265.5 |
Current Assets: | ||
Cash and cash equivalents | 2.1 | 1.7 |
Accounts receivable: | ||
Utility | 87.9 | 103.4 |
Other | 11.4 | 25.2 |
Allowance for doubtful accounts | (16.1) | (10) |
Delayed customer billings | 1.6 | 2.6 |
Receivables from associated companies | 2.2 | 2.5 |
Inventories: | ||
Natural gas | 127.3 | 138.2 |
Propane gas | 12 | 12 |
Materials and supplies | 9.2 | 9.3 |
Derivative instrument assets | 4.9 | 0 |
Unamortized purchased gas adjustments | 43.1 | 12.9 |
Other regulatory assets | 23.9 | 16.2 |
Deferred income tax | 0 | 0.4 |
Prepayments and other | 14.5 | 12.5 |
Total Current Assets | 324 | 326.5 |
Deferred Charges: | ||
Regulatory assets | 589.8 | 573.6 |
Other | 5.3 | 12.8 |
Total Deferred Charges | 595.1 | 586.4 |
Total Assets | 3,300.6 | 3,167.5 |
Capitalization: | ||
Common stock equity | 1,068.5 | 1,037.8 |
Long-term debt | 808.3 | 808.1 |
Total Capitalization | 1,876.8 | 1,845.9 |
Current Liabilities: | ||
Notes payable | 243.7 | 233 |
Accounts payable | 67.6 | 61.5 |
Accounts payable to associated companies | 5.4 | 5.5 |
Advance customer billings | 49.1 | 25.2 |
Wages and compensation accrued | 29.9 | 26.8 |
Dividends payable | 14 | 19.9 |
Customer deposits | 13.5 | 13 |
Interest accrued | 7.7 | 7.6 |
Taxes accrued | 29.1 | 25.4 |
Other regulatory liabilities | 1.3 | 0.6 |
Other | 9.9 | 18.5 |
Total Current Liabilities | 471.2 | 437 |
Deferred Credits and Other Liabilities: | ||
Deferred income taxes | 556.9 | |
Deferred income taxes | 485.2 | |
Pension and postretirement benefit costs | 211.8 | 207.8 |
Asset retirement obligations | 75.2 | 72.4 |
Regulatory liabilities | 67.3 | 70.6 |
Other | 41.4 | 48.6 |
Total Deferred Credits and Other Liabilities | 952.6 | 884.6 |
Commitments and Contingencies | ||
Total Capitalization and Liabilities | 3,300.6 | 3,167.5 |
Alagasco | ||
ASSETS | ||
Utility Plant | 1,729.6 | 1,655.4 |
Less: Accumulated depreciation and amortization | 756.6 | 717 |
Net Utility Plant | 973 | 938.4 |
Current Assets: | ||
Cash and cash equivalents | 0 | 7.2 |
Accounts receivable: | ||
Utility | 34 | 34.7 |
Other | 7.2 | 5.2 |
Allowance for doubtful accounts | (3.3) | (4.2) |
Inventories: | ||
Natural gas | 34.6 | 40.4 |
Materials and supplies | 5.9 | 5.4 |
Unamortized purchased gas adjustments | 5.6 | 0 |
Other regulatory assets | 14.9 | 11.4 |
Deferred income tax | 0 | 6.2 |
Prepayments and other | 5.1 | 4.6 |
Total Current Assets | 104 | 110.9 |
Deferred Charges: | ||
Regulatory assets | 230.7 | 163.6 |
Deferred income tax | 221.4 | |
Deferred income tax | 248.4 | |
Other | 63.2 | 57.7 |
Total Deferred Charges | 515.3 | 469.7 |
Total Assets | 1,592.3 | 1,519 |
Capitalization: | ||
Common stock equity | 867.3 | 874.6 |
Long-term debt | 250 | 170 |
Total Capitalization | 1,117.3 | 1,044.6 |
Current Liabilities: | ||
Current portion of long-term debt | 0 | 80 |
Notes payable | 82 | 31 |
Accounts payable | 34.3 | 21.8 |
Accounts payable to associated companies | 0.4 | 0.2 |
Advance customer billings | 21.1 | 19.1 |
Wages and compensation accrued | 7.8 | 5.8 |
Customer deposits | 18.2 | 19.1 |
Interest accrued | 3.3 | 3.5 |
Unamortized purchased gas adjustments | 0 | 28.2 |
Taxes accrued | 21.6 | 26 |
Other regulatory liabilities | 22.7 | 31.8 |
Other | 6.3 | 5.4 |
Total Current Liabilities | 217.7 | 271.9 |
Deferred Credits and Other Liabilities: | ||
Pension and postretirement benefit costs | 74.3 | 45.6 |
Asset retirement obligations | 120.1 | 86.6 |
Regulatory liabilities | 41.7 | 48.7 |
Other | 21.2 | 21.6 |
Total Deferred Credits and Other Liabilities | 257.3 | 202.5 |
Total Capitalization and Liabilities | $ 1,592.3 | $ 1,519 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Assets | ||
Non-utility property, accumulated depreciation and amortization | $ 8.1 | $ 7.5 |
CONSOLIDATED STATEMENTS OF CAPI
CONSOLIDATED STATEMENTS OF CAPITALIZATION - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Common Stock Equity: | ||
Common stock, par value $1 per share | $ 45.6 | $ 43.3 |
Paid-in capital | 1,175.9 | 1,038.1 |
Retained earnings | 550.9 | 494.2 |
Accumulated other comprehensive loss | (4.2) | (2) |
Total Common Stock Equity | 1,768.2 | 1,573.6 |
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 1,835.8 | 1,773.8 |
Unamortized discounts on long-term debt | (2.1) | (2.3) |
Total Long-Term Debt | 1,833.7 | 1,771.5 |
Total Capitalization | 3,601.9 | 3,345.1 |
Spire | Floating Rate Senior Notes, due August 15, 2017 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 0 | 250 |
Spire | 2.55% Senior Notes, due August 15, 2019 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 125 | 125 |
Spire | 2.52% Senior Notes, due September 1, 2021 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 35 | 0 |
Spire | 2.0% Series A Remarketable Subordinated Notes, due April 1, 2022 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 143.8 | 143.8 |
Spire | 3.31% Notes Payable, due December 15, 2022 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 25 | 25 |
Spire | 3.13% Senior Notes, due September 1, 2026 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 130 | 0 |
Spire | 4.70% Senior Notes, due August 15, 2044 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 250 | 250 |
Laclede Gas | ||
Common Stock Equity: | ||
Common stock, par value $1 per share | 0.1 | 0.1 |
Paid-in capital | 751.9 | 748.2 |
Retained earnings | 318.3 | 291.2 |
Accumulated other comprehensive loss | (1.8) | (1.7) |
Total Common Stock Equity | 1,068.5 | 1,037.8 |
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 810 | 810 |
Unamortized discounts on long-term debt | (1.7) | (1.9) |
Total Long-Term Debt | 808.3 | 808.1 |
Total Capitalization | 1,876.8 | 1,845.9 |
Laclede Gas | 2.0% Series, due August 15, 2018 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 100 | 100 |
Laclede Gas | 5.5% Series, due May 1, 2019 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 50 | 50 |
Laclede Gas | 3.0% Series, due March 15, 2023 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 55 | 55 |
Laclede Gas | 3.4% Series, due August 15, 2023 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 250 | 250 |
Laclede Gas | 3.4% Series, due March 15, 2028 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 45 | 45 |
Laclede Gas | 7.0% Series, due June 1, 2029 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 25 | 25 |
Laclede Gas | 7.9% Series, due September 15, 2030 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 30 | 30 |
Laclede Gas | 6.0% Series, due May 1, 2034 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 100 | 100 |
Laclede Gas | 6.15% Series, due June 1, 2036 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 55 | 55 |
Laclede Gas | 4.625% Series, due August 15, 2043 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 100 | 100 |
Alagasco | ||
Common Stock Equity: | ||
Common stock, par value $1 per share, and paid-in capital | 451.9 | 480.9 |
Retained earnings | 415.4 | 393.7 |
Total Common Stock Equity | 867.3 | 874.6 |
Long-Term Debt - Laclede Gas: | ||
Total Long-Term Debt | 250 | 170 |
Total Capitalization | 1,117.3 | 1,044.6 |
Alagasco | 5.2% Notes, due January 15, 2020 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 40 | 40 |
Alagasco | 3.86% Notes, due December 23, 2021 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 50 | 50 |
Alagasco | 3.21% Notes, due September 15, 2025 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 35 | 35 |
Alagasco | 5.9% Notes, due January 15, 2037 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 45 | 45 |
Alagasco | 4.31% Notes, due December 1, 2045 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 80 | 0 |
Other | 3.10%, due December 30, 2018 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 5 | 0 |
Other | 4.14%, due September 30, 2021 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | 20 | 0 |
Other | 5.00%, due September 30, 2031 | ||
Long-Term Debt - Laclede Gas: | ||
Debt instrument, principal outstanding | $ 42 | $ 0 |
CONSOLIDATED STATEMENTS OF CAP7
CONSOLIDATED STATEMENTS OF CAPITALIZATION (Parenthetical) - $ / shares | Sep. 30, 2016 | Sep. 30, 2015 |
Long - Term Debt - Laclede Gas: | ||
Common stock, par value (in dollars per share) | $ 1 | $ 1 |
Common stock, authorized (in shares) | 70,000,000 | 70,000,000 |
Common stock, outstanding (in shares) | 45,650,642 | 43,335,012 |
Spire | 2.55% Senior Notes, due August 15, 2019 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 2.55% | 2.55% |
Spire | 2.52% Senior Notes, due September 1, 2021 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 2.52% | 2.52% |
Spire | 3.31% Notes Payable, due December 15, 2022 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.31% | 3.31% |
Spire | 2.0% Series A Remarketable Subordinated Notes, due April 1, 2022 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 2.00% | 2.00% |
Spire | 3.13% Senior Notes, due September 1, 2026 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.13% | 3.13% |
Spire | 4.70% Senior Notes, due August 15, 2044 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 4.70% | 4.70% |
Laclede Gas | ||
Long - Term Debt - Laclede Gas: | ||
Common stock, par value (in dollars per share) | $ 1 | $ 1 |
Common stock, authorized (in shares) | 50,000,000 | 50,000,000 |
Common stock, outstanding (in shares) | 24,577 | 24,577 |
Laclede Gas | 2.0% Series, due August 15, 2018 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 2.00% | 2.00% |
Laclede Gas | 5.5% Series, due May 1, 2019 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 5.50% | 5.50% |
Laclede Gas | 3.0% Series, due March 15, 2023 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.00% | 3.00% |
Laclede Gas | 3.4% Series, due August 15, 2023 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.40% | 3.40% |
Laclede Gas | 3.4% Series, due March 15, 2028 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.40% | 3.40% |
Laclede Gas | 7.0% Series, due June 1, 2029 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 7.00% | 7.00% |
Laclede Gas | 7.9% Series, due September 15, 2030 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 7.90% | 7.90% |
Laclede Gas | 6.0% Series, due May 1, 2034 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 6.00% | 6.00% |
Laclede Gas | 6.15% Series, due June 1, 2036 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 6.15% | 6.15% |
Laclede Gas | 4.625% Series, due August 15, 2043 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 4.625% | 4.625% |
Alagasco | ||
Long - Term Debt - Laclede Gas: | ||
Common stock, par value (in dollars per share) | $ 0.01 | $ 0.01 |
Common stock, authorized (in shares) | 3,000,000 | 3,000,000 |
Common stock, outstanding (in shares) | 1,972,052 | 1,972,052 |
Alagasco | 5.2% Notes, due January 15, 2020 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 5.20% | 5.20% |
Alagasco | 3.86% Notes, due December 23, 2021 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.86% | 3.86% |
Alagasco | 3.21% Notes, due September 15, 2025 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.21% | 3.21% |
Alagasco | 5.9% Notes, due January 15, 2037 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 5.90% | 5.90% |
Alagasco | 4.31% Notes, due December 1, 2045 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 4.31% | 4.31% |
Other | 3.10%, due December 30, 2018 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 3.10% | 3.10% |
Other | 4.14%, due September 30, 2021 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 4.14% | 4.14% |
Other | 5.00%, due September 30, 2031 | ||
Long - Term Debt - Laclede Gas: | ||
Debt instrument, interest rate, stated percentage | 5.00% | 5.00% |
CONSOLIDATED STATEMENTS OF COMM
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY - USD ($) $ in Millions | Total | Common Stock Outstanding | Paid-in Capital | Retained Earnings | AOCI | Laclede Gas | Laclede GasCommon Stock Outstanding | Laclede GasPaid-in Capital | Laclede GasRetained Earnings | Laclede GasAOCI | Alagasco | AlagascoCommon Stock Outstanding | AlagascoPaid-in Capital | AlagascoRetained Earnings |
BALANCE (in shares) at Sep. 30, 2013 | 32,696,836 | 24,549 | ||||||||||||
BALANCE at Sep. 30, 2013 | $ 1,046.3 | $ 32.7 | $ 594.3 | $ 420.1 | $ (0.8) | $ 973.9 | $ 0.1 | $ 738.1 | $ 237.8 | $ (2.1) | ||||
Stockholders' Equity Rollforward | ||||||||||||||
Net income | 84.6 | 84.6 | 90.1 | 90.1 | ||||||||||
Common stock offering (in shares) | 10,350,000 | 28 | ||||||||||||
Common stock offering | 456.8 | $ 10.4 | 446.4 | 1.1 | 1.1 | |||||||||
Equity units offering | (19.7) | (19.7) | ||||||||||||
Dividend reinvestment plan (in shares) | 33,667 | |||||||||||||
Dividend reinvestment plan | 1.5 | $ 0 | 1.5 | |||||||||||
Stock-based compensation costs | 5.8 | 5.8 | 4.2 | 4.2 | ||||||||||
Equity Incentive Plan (in shares) | 97,902 | |||||||||||||
Equity Incentive Plan | 1.7 | $ 0.1 | 1.6 | |||||||||||
Employees’ taxes paid associated with restricted shares withheld upon vesting | (1.1) | (1.1) | ||||||||||||
Tax benefit - stock compensation | 0.6 | 0.6 | 0.6 | 0.6 | ||||||||||
Dividends declared on common stock | (67.2) | (67.2) | (62.3) | (62.3) | ||||||||||
Other comprehensive loss, net of tax | (0.9) | (0.9) | 0.2 | 0.2 | ||||||||||
BALANCE (in shares) at Sep. 30, 2014 | 43,178,405 | 24,577 | 1,972,052 | |||||||||||
BALANCE at Sep. 30, 2014 | 1,508.4 | $ 43.2 | 1,029.4 | 437.5 | (1.7) | 1,007.8 | $ 0.1 | 744 | 265.6 | (1.9) | $ 849.6 | $ 0 | $ 503.9 | $ 345.7 |
BALANCE (in shares) at Dec. 31, 2013 | 1,972,052 | |||||||||||||
BALANCE at Dec. 31, 2013 | 384.6 | $ 0 | 34.5 | 350.1 | ||||||||||
Stockholders' Equity Rollforward | ||||||||||||||
Net income | 33 | 33 | ||||||||||||
Purchase accounting adjustments | 469.4 | 469.4 | ||||||||||||
Dividends declared on common stock | (37.4) | (37.4) | ||||||||||||
BALANCE (in shares) at Sep. 30, 2014 | 43,178,405 | 24,577 | 1,972,052 | |||||||||||
BALANCE at Sep. 30, 2014 | 1,508.4 | $ 43.2 | 1,029.4 | 437.5 | (1.7) | 1,007.8 | $ 0.1 | 744 | 265.6 | (1.9) | 849.6 | $ 0 | 503.9 | 345.7 |
Stockholders' Equity Rollforward | ||||||||||||||
Net income | 136.9 | 136.9 | 105.3 | 105.3 | 48 | 48 | ||||||||
Purchase accounting adjustments | 4 | 4 | ||||||||||||
Dividend reinvestment plan (in shares) | 31,166 | |||||||||||||
Dividend reinvestment plan | 1.6 | 1.6 | ||||||||||||
Stock-based compensation costs | 3 | 3 | 3.7 | 3.7 | ||||||||||
Equity Incentive Plan (in shares) | 125,441 | |||||||||||||
Equity Incentive Plan | 5.1 | $ 0.1 | 5 | |||||||||||
Employees’ taxes paid associated with restricted shares withheld upon vesting | (1.6) | (1.6) | ||||||||||||
Tax benefit - stock compensation | 0.7 | 0.7 | 0.5 | 0.5 | ||||||||||
Dividends declared on common stock | (80.2) | (80.2) | (79.7) | (79.7) | ||||||||||
Return of capital to Spire | (27) | (27) | ||||||||||||
Other comprehensive loss, net of tax | (0.3) | (0.3) | 0.2 | 0.2 | ||||||||||
BALANCE (in shares) at Sep. 30, 2015 | 43,335,012 | 24,577 | 1,972,052 | |||||||||||
BALANCE at Sep. 30, 2015 | 1,573.6 | $ 43.3 | 1,038.1 | 494.2 | (2) | 1,037.8 | $ 0.1 | 748.2 | 291.2 | (1.7) | 874.6 | $ 0 | 480.9 | 393.7 |
Stockholders' Equity Rollforward | ||||||||||||||
Net income | 144.2 | 144.2 | 105.9 | 105.9 | 53.2 | 53.2 | ||||||||
Common stock offering (in shares) | 2,185,000 | |||||||||||||
Common stock offering | 133.2 | $ 2.2 | 131 | |||||||||||
Dividend reinvestment plan (in shares) | 22,878 | |||||||||||||
Dividend reinvestment plan | 1.4 | 1.4 | ||||||||||||
Stock-based compensation costs | 2.2 | 2.2 | 3.7 | 3.7 | ||||||||||
Equity Incentive Plan (in shares) | 107,752 | |||||||||||||
Equity Incentive Plan | 5.1 | $ 0.1 | 5 | |||||||||||
Employees’ taxes paid associated with restricted shares withheld upon vesting | (1.8) | (1.8) | ||||||||||||
Dividends declared on common stock | (87.5) | (87.5) | (78.8) | (78.8) | (31.5) | (31.5) | ||||||||
Return of capital to Spire | (29) | (29) | ||||||||||||
Other comprehensive loss, net of tax | (2.2) | (2.2) | (0.1) | (0.1) | ||||||||||
BALANCE (in shares) at Sep. 30, 2016 | 45,650,642 | 24,577 | 1,972,052 | |||||||||||
BALANCE at Sep. 30, 2016 | $ 1,768.2 | $ 45.6 | $ 1,175.9 | $ 550.9 | $ (4.2) | $ 1,068.5 | $ 0.1 | $ 751.9 | $ 318.3 | $ (1.8) | $ 867.3 | $ 0 | $ 451.9 | $ 415.4 |
CONSOLIDATED STATEMENTS OF COM9
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Statement of Stockholders' Equity [Abstract] | |||
Dividends declared, common stock (in dollars per share) | $ 1.96 | $ 1.84 | $ 1.76 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Operating Activities: | ||||
Net income | $ 144.2 | $ 136.9 | $ 84.6 | |
Adjustments to reconcile net income to net cash provided by (used in) operating activities: | ||||
Depreciation, amortization and accretion | 137.5 | 130.8 | 83.3 | |
Deferred income taxes and investment tax credits | 68.8 | 65.5 | 31.4 | |
Changes in assets and liabilities: | ||||
Accounts receivable – net | (12.3) | (4.8) | (5.3) | |
Unamortized purchased gas adjustments | (64.3) | 46.9 | (36.4) | |
Deferred purchased gas costs | 11.5 | (19.8) | 13.9 | |
Accounts payable | 30 | (30) | 8.6 | |
Delayed / advance customer billings – net | 26.9 | 20.3 | (19.1) | |
Taxes accrued | (0.4) | (17) | (0.8) | |
Inventories | 16.5 | 54.8 | (15.5) | |
Other assets and liabilities | (35) | (67.6) | (27.5) | |
Other | 4.9 | 6.4 | 5.4 | |
Net cash provided by operating activities | 328.3 | 322.4 | 122.6 | |
Investing Activities: | ||||
Capital expenditures | (293.3) | (289.8) | (171) | |
Acquisition of EnergySouth (net of $2.0 cash acquired) | (317.7) | 0 | 0 | |
Acquisition of Alagasco (net of $12.1 cash acquired in 2014) | 0 | (8.2) | (1,305.2) | |
Acquisition of MGE | 0 | 0 | 23.9 | |
Proceeds from sale of right to acquire New England Gas Company | 0 | 0 | 11 | |
Other | (1.7) | (0.7) | 3.7 | |
Net cash used in investing activities | (612.7) | (298.7) | (1,437.6) | |
Financing Activities: | ||||
Issuance of long-term debt | 245 | 35 | 768.8 | |
Repayment of long-term debt | (80) | (34.8) | (80) | |
Issuance of short-term debt - net | 60.7 | 50.8 | 198.1 | |
Issuance of common stock | 137.1 | 3.1 | 460 | |
Dividends paid | (85.2) | (79) | (61.9) | |
Other | (1.8) | (1.1) | (6.9) | |
Net cash provided by (used in) financing activities | 275.8 | (26) | 1,278.1 | |
Net Decrease in Cash and Cash Equivalents | (8.6) | (2.3) | (36.9) | |
Cash and Cash Equivalents at Beginning of Year | 13.8 | 16.1 | 53 | |
Cash and Cash Equivalents at End of Year | $ 16.1 | 5.2 | 13.8 | 16.1 |
Supplemental disclosure of cash (paid) refunded for: | ||||
Interest | (72.5) | (65.3) | (40.6) | |
Income taxes | 2.9 | 1.3 | (3.4) | |
Laclede Gas | ||||
Operating Activities: | ||||
Net income | 105.9 | 105.3 | 90.1 | |
Adjustments to reconcile net income to net cash provided by (used in) operating activities: | ||||
Depreciation, amortization and accretion | 88.6 | 82.6 | 78.5 | |
Deferred income taxes and investment tax credits | 45.3 | 45.4 | 35.6 | |
Changes in assets and liabilities: | ||||
Accounts receivable – net | 35.7 | 9.9 | (21.5) | |
Unamortized purchased gas adjustments | (30.2) | 41.1 | (36.4) | |
Deferred purchased gas costs | 11.5 | (19.8) | 13.9 | |
Accounts payable | 0.9 | (11.4) | 6.8 | |
Delayed / advance customer billings – net | 24.9 | 17.9 | (19.1) | |
Taxes accrued | 4.9 | (14.6) | 10 | |
Inventories | 11 | 51.2 | (26.4) | |
Other assets and liabilities | (29.6) | (32.8) | (3.3) | |
Other | 2.3 | 2.8 | 2.8 | |
Net cash provided by operating activities | 271.2 | 277.6 | 131 | |
Investing Activities: | ||||
Capital expenditures | (197.8) | (198.6) | (163) | |
Acquisition of MGE | 0 | 0 | 23.9 | |
Other | 1.1 | 2.9 | 4.1 | |
Net cash used in investing activities | (196.7) | (195.7) | (135) | |
Financing Activities: | ||||
Repayment of long-term debt | 0 | 0 | (80) | |
Issuance of short-term debt - net | 10.7 | (5.7) | 164.6 | |
Borrowings from Spire | 0 | 18.4 | 276.1 | |
Repayment of borrowings from Spire | 0 | (18.4) | (322.7) | |
Issuance of common stock | 0 | 0 | 1.2 | |
Dividends paid | (84.8) | (78.7) | (57.2) | |
Other | 0 | 0.5 | 1.8 | |
Net cash provided by (used in) financing activities | (74.1) | (83.9) | (16.2) | |
Net Decrease in Cash and Cash Equivalents | 0.4 | (2) | (20.2) | |
Cash and Cash Equivalents at Beginning of Year | 1.7 | 3.7 | 23.9 | |
Cash and Cash Equivalents at End of Year | 3.7 | 2.1 | 1.7 | 3.7 |
Supplemental disclosure of cash (paid) refunded for: | ||||
Interest | (35.7) | (31) | (36.4) | |
Income taxes | 2.1 | 0.7 | (0.2) | |
Alagasco | ||||
Operating Activities: | ||||
Net income | 33 | 53.2 | 48 | |
Adjustments to reconcile net income to net cash provided by (used in) operating activities: | ||||
Depreciation, amortization and accretion | 34.4 | 47.8 | 47.3 | |
Deferred income taxes and investment tax credits | 4 | 33.2 | 29.2 | |
Changes in assets and liabilities: | ||||
Accounts receivable – net | 26.4 | (11.1) | (9.1) | |
Unamortized purchased gas adjustments | 24.8 | (33.8) | 5.8 | |
Accounts payable | (11.5) | 9.1 | (10.4) | |
Delayed / advance customer billings – net | (0.3) | 2 | 2.4 | |
Taxes accrued | 1.9 | (5.2) | (4) | |
Inventories | (11.8) | 5.3 | 7.2 | |
Other assets and liabilities | 17.1 | (3.2) | (18) | |
Other | (3) | 0.9 | 2 | |
Net cash provided by operating activities | 115 | 98.2 | 100.4 | |
Investing Activities: | ||||
Capital expenditures | (46.2) | (93.4) | (85.8) | (46.2) |
Proceeds from the sale of assets | 0.8 | 0 | 0 | |
Other | 0 | (2.5) | (1) | |
Net cash used in investing activities | (45.4) | (95.9) | (86.8) | |
Financing Activities: | ||||
Issuance of long-term debt | 0 | 80 | 35 | |
Repayment of long-term debt | 0 | (80) | (34.8) | |
Issuance of short-term debt - net | (34) | 51 | 15 | |
Return of capital to Spire | 0 | (29) | (27) | |
Dividends paid | (37.4) | (31.5) | 0 | |
Other | 4.4 | 0 | (0.2) | |
Net cash provided by (used in) financing activities | (67) | (9.5) | (12) | |
Net Decrease in Cash and Cash Equivalents | 2.6 | (7.2) | 1.6 | |
Cash and Cash Equivalents at Beginning of Year | 3 | 7.2 | 5.6 | |
Cash and Cash Equivalents at End of Year | 5.6 | 0 | 7.2 | $ 5.6 |
Supplemental disclosure of cash (paid) refunded for: | ||||
Interest | (9.6) | (12.4) | (12.3) | |
Income taxes | $ (20.4) | $ 0.8 | $ 0 |
CONSOLIDATED STATEMENTS OF CA11
CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2014 | |
Statement of Cash Flows [Abstract] | ||
Cash acquired from acquisition | $ 2 | $ 12.1 |
SUMMARY OF SIGNIFICANT ACCOUNTI
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | 12 Months Ended |
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES | SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES BASIS OF PRESENTATION – These notes are an integral part of the accompanying audited financial statements of Spire Inc. (Spire or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, Inc. (EnergySouth) are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas and Oil Company (Willmut Gas). The accompanying audited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). The consolidated financial position, results of operations, and cash flows of Spire are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between Laclede Gas and Alagasco and their affiliates, as well as intercompany balances on their balance sheets, have not been eliminated from their separate financial statements. The Company’s September 12, 2016 acquisition of EnergySouth and the August 31, 2014 acquisition of Alagasco are included in the results of operations since their acquisition dates and impact the comparability of the financial statement periods presented for the Company. For a further discussion of the acquisitions, see Note 2 , Acquisitions. The Utilities are regulated natural gas distribution utilities. Due to the seasonal nature of the Utilities, the earnings of Spire, Laclede Gas and Alagasco are typically concentrated during the heating season of November through April each fiscal year. Effective September 2, 2014, Alagasco amended its bylaws to change Alagasco’s fiscal year from beginning January 1 and ending on December 31, to beginning October 1 and ending September 30. As a result, the financial statements covering the nine-month period from January 1, 2014 through September 30, 2014 (the “transition period”) were included in Alagasco’s transition report on Form 10-K/T for such period and are presented in the financial statements and notes herein. NATURE OF OPERATIONS – Spire Inc. (NYSE: SR), headquartered in St. Louis, Missouri, is a public utility holding company. The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment consists of the regulated natural gas distribution operations of the Company and is the core business segment of Spire in terms of revenue and earnings generation. The Gas Utility segment is comprised of the operations of the Missouri Utilities, serving St. Louis and eastern Missouri, Kansas City and western Missouri (through MGE), Alagasco serving central and northern Alabama, and the subsidiaries of EnergySouth, serving southern Alabama and south-central Mississippi. Spire’s primary non-utility business, Laclede Energy Resources, Inc. (LER), included in the Gas Marketing segment, provides non-regulated natural gas services. The activities of other subsidiaries are described in Note 14 , Information by Operating Segment, and are reported as Other. Laclede Gas and Alagasco each have a single reportable segment. USE OF ESTIMATES – The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. SYSTEM OF ACCOUNTS – The accounts of the Utilities are maintained in accordance with the Uniform System of Accounts prescribed by the applicable state public service commissions, which systems substantially conform to that prescribed by the Federal Energy Regulatory Commission (FERC). UTILITY PLANT, DEPRECIATION AND AMORTIZATION – Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses. For Laclede Gas, utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal years 2016 , 2015 and 2014 , annual depreciation and amortization expense averaged 3.0% of the original cost of depreciable and amortizable property. Laclede Gas’ capital expenditures were $197.8 , $198.6 and $163.0 for fiscal years 2016 , 2015 , and 2014 , respectively. Additionally, Laclede Gas had recorded accruals for capital expenditures totaling $14.8 at September 30, 2016 , $9.6 at September 30, 2015 , and $3.0 at September 30, 2014 . For Alagasco, depreciation is provided using the composite method of depreciation on a straight-line basis over the estimated useful lives of utility property at rates approved by the Alabama Public Service Commission (APSC). On June 28, 2010, the APSC approved a reduction in depreciation rates, effective June 1, 2010, for Alagasco with the revised prospective composite depreciation rate approximating 3.1% . As required by the APSC, Alagasco performed another depreciation study in 2015. The composite depreciation rate from this study was also approximately 3.1% . Alagasco anticipates refunding approximately $9.3 of refundable negative salvage costs through lower tariff rates over the next twelve months. Related to the lower depreciation rates, an estimated $18.7 of refundable negative salvage costs will be refunded to eligible customers on a declining basis through lower tariff rates over a three year period through 2019. Alagasco’s capital expenditures were $93.4 , $85.8 and $46.2 for fiscal years 2016 , 2015 , and 2014 , respectively. Additionally, Alagasco recorded accruals for capital expenditures totaling $6.8 at September 30, 2016 , $3.1 at September 30, 2015 and $5.0 at September 30, 2014 . Accrued capital expenditures are excluded from the capital expenditures included in the statements of cash flows of the Company, Laclede Gas and Alagasco. ASSET RETIREMENT OBLIGATIONS – Spire, Laclede Gas, and Alagasco record legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Company, Laclede Gas and Alagasco record asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of Laclede Gas’, Alagasco’s and Mobile Gas’ distribution systems and general plant. Asset retirement obligations recorded by Spire’s other subsidiaries are not material. As authorized by the Missouri Public Service Commission (MoPSC) and APSC, Laclede Gas, Alagasco and Mobile Gas accrue future asset removal costs associated with their property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities or assets. When those utilities retire depreciable utility plant and equipment, they charge the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities or assets. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities or assets. In the rate setting process, the regulatory liability or asset is excluded from the rate base upon which those utilities have the opportunity to earn their allowed rates of return. The costs associated with asset retirement obligations of Laclede Gas, Alagasco and Mobile Gas are either currently being recovered in rates or are probable of recovery in future rates. The following table presents a reconciliation of the beginning and ending balances of asset retirement obligations at September 30, as reported in the balance sheets. Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Asset retirement obligations, beginning of year $ 159.2 $ 99.2 $ 72.4 $ 71.2 $ 86.6 $ 27.7 Liabilities incurred during the period 4.1 2.3 1.2 0.6 2.9 1.7 Liabilities settled during the period (9.5 ) (2.0 ) (1.9 ) (1.9 ) (6.8 ) (0.1 ) Accretion 13.2 4.5 3.5 3.4 9.7 1.1 Revisions in estimated cash flows 27.5 55.2 — (0.9 ) 27.7 56.2 Addition of EnergySouth asset retirement obligations 11.9 — — — — — Asset retirement obligations, end of year $ 206.4 $ 159.2 $ 75.2 $ 72.4 $ 120.1 $ 86.6 REGULATED OPERATIONS – The Utilities account for their regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. In addition, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. See additional discussion on regulated operations in Note 15 , Regulatory Matters. As discussed below for Laclede Gas and Alagasco, the Purchased Gas Adjustment (PGA) clauses and Gas Supply Adjustment (GSA) riders allow the Utilities to pass through to customers the cost of purchased gas supplies. Regulatory assets and liabilities related to the PGA clauses and the GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. Laclede Gas As authorized by the MoPSC, the PGA clause allows Laclede Gas to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, Laclede Gas is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Certain provisions of the PGA clause are included below: • Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism. • The tariffs allow Laclede Gas flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months . • Laclede Gas is authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits. Laclede Gas’ eastern Missouri service territory is also authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. • The MoPSC approved a plan applicable to Laclede Gas’ gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level. This gas supply cost management program allows Laclede Gas to retain 10% of cost savings, up to a maximum of $3.0 annually. Laclede Gas did not record any income under the plan during the three fiscal years reported. Income recorded under the plan, if any, is included in Gas Utility Operating Revenues on the Consolidated Statements of Income and under Operating Revenues on Laclede Gas’ Statements of Income. Pursuant to the provisions of the PGA clause, the difference between actual costs incurred and costs recovered through the application of the PGA clause are reflected as a deferred charge or credit at the end of the fiscal year. These costs include costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs, amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Company’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA clause also provides for the treatment of income from off-system sales and capacity release revenues. Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November. The customer share of such income is determined in accordance with the following tables, shown for each service territory for which the PGA clauses were approved by the MoPSC. Customer Share Company Share Eastern Missouri First $2.0* 100% —% Next $2.0 80% 20% Next $2.0 75% 25% Amounts exceeding $6.0 70% 30% * Customer share reverts to 85% and company share reverts to 15% in 2017. Western Missouri First $1.2 85% 15% Next $1.2 80% 20% Next $1.2 75% 25% Amounts exceeding $3.6 70% 30% Alagasco Alagasco’s rate schedules for natural gas distribution charges contain a GSA rider, established in 1993, which permits the pass-through to customers of changes in the cost of gas supply. Alagasco’s tariff provides a temperature adjustment mechanism, also included in the GSA rider, which is designed to moderate the impact of departures from normal temperatures on Alagasco’s earnings. The temperature adjustment applies primarily to residential, small commercial and small industrial customers. Other non-temperature weather-related conditions that may affect customer usage are not included in the temperature adjustment. NATURAL GAS AND PROPANE GAS – For Laclede Gas’ eastern Missouri utility, inventory of natural gas in storage is priced on a last in, first out (LIFO) basis and inventory of propane gas in storage is priced on a first in, first out (FIFO) basis. For the rest of the Gas Utility segment, inventory of natural gas in storage is priced on the weighted average cost basis. The replacement cost of Laclede Gas’ natural gas for current use in eastern Missouri at September 30, 2016 and September 30, 2015 was less than the LIFO cost by $11.4 and $20.4 , respectively. The carrying value of Laclede Gas’ inventory is not adjusted to the lower of cost or market prices because, pursuant to the Missouri Utilities’ PGA clauses, actual gas costs are recovered in customer rates. Natural gas and propane gas storage inventory in Spire’s other operating segments is recorded at the lower of average cost or market. BUSINESS COMBINATIONS – The EnergySouth and Alagasco acquisitions are accounted for by Spire using business combination accounting. Under this method, the purchase price paid by the acquirer is allocated to the assets acquired and liabilities assumed as of the acquisition date based on their fair value. For additional information on the acquisition of EnergySouth and Alagasco, refer to Note 2 , Acquisitions. GOODWILL – Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. Spire and Laclede Gas evaluate goodwill for impairment as of July 1st of each year, or more frequently if events and circumstances indicate that goodwill might be impaired. At July 1, 2016, 2015 and 2014, Spire and Laclede Gas each applied a quantitative goodwill evaluation model to their reporting units and concluded goodwill was not impaired because the fair value exceeded the carrying amount. The changes in the carrying amount of goodwill by reportable segment were as follows: Gas Utility Gas Marketing Other Total Balance as of September 30, 2013 $ 247.1 $ — $ — $ 247.1 Adjustments to finalize the 2013 acquisition of MGE (36.9 ) — — (36.9 ) Acquisition of Alagasco — — 727.6 727.6 Balance as of September 30, 2014 210.2 — 727.6 937.8 Adjustments to finalize the acquisition of Alagasco — — 8.2 8.2 Balance as of September 30, 2015 210.2 — 735.8 946.0 Acquisition of EnergySouth — — 218.9 218.9 Balance as of September 30, 2016 $ 210.2 $ — $ 954.7 $ 1,164.9 IMPAIRMENT OF LONG-LIVED ASSETS – Long-lived assets classified as held and used are evaluated for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Whether impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets with the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, the Company recognizes an impairment charge equal to the amount of the carrying value that exceeds the estimated fair value of the assets. In the period in which the Company determines an asset meets held-for-sale criteria, an impairment charge is recorded to the extent the book value exceeds its fair value less cost to sell. REVENUE RECOGNITION – The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues for Laclede Gas at September 30, 2016 and 2015 were $26.1 and $27.6 , respectively. Alagasco records natural gas distribution revenues in accordance with the tariff established by the APSC. The amount of accrued unbilled revenues, which are not recorded as revenues until billed, for Alagasco at September 30, 2016 and 2015 were $5.9 and $6.4 , respectively. All related costs and margins are also deferred. The subsidiaries of EnergySouth record natural gas revenues in accordance with tariffs established by the APSC and MSPSC. Unbilled revenues are accrued and related costs and margins are also deferred. Spire’s other subsidiaries, including LER, record revenues when earned, either when the product is delivered or when services are performed. In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. Certain of its derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815, “Derivatives and Hedging.” Those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues and expenses from such contracts are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. For additional information on derivative instruments, refer to Note 10 , Derivative Instruments and Hedging Activities. Certain of LER’s wholesale purchase and sale transactions are classified as trading activities for financial reporting purposes. Under GAAP, revenues and expenses associated with trading activities are presented on a net basis in Gas Marketing operating revenues (or expenses, if negative) in the Consolidated Statements of Income. This net presentation has no effect on operating income or net income. INCOME TAXES – Spire and its subsidiaries account for income taxes under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amount of existing assets and liabilities and the respective tax basis and for tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effects on deferred tax assets and liabilities of a change in enacted tax rates is recognized in income or loss for a non-regulated company, and in a regulatory asset or regulatory liability for a regulated company. A valuation allowance is established when it is more likely than not that some portion or all of the deferred tax assets will not be realized. The Company accounts for uncertain tax positions in accordance with authoritative guidance. The authoritative guidance addresses the determination of whether tax benefits claimed, or expected to be claimed, on a tax return should be recorded in the financial statements. Spire may recognize the tax benefit from an uncertain tax position only if it is more likely than not that the position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Tax-related interest and penalties, if any, are classified as a liability on the balance sheets. CASH AND CASH EQUIVALENTS – All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Company’s and Utilities’ bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the balance sheets. Changes in book overdrafts are reflected as Operating Activities in the statements of cash flows. NATURAL GAS RECEIVABLE – LER enters into natural gas transactions with natural gas pipeline companies known as park and loan arrangements. Under the terms of the arrangements, LER purchases natural gas from a third party and delivers that natural gas to the pipeline company for the right to receive the same quantity of natural gas from the pipeline company at the same location in a future period. These arrangements are accounted for as non-monetary transactions under GAAP and are recorded at the carrying amount. As such, natural gas receivables are reflected on the Consolidated Balance Sheets at cost, which includes related pipeline fees associated with the transactions. In the period that the natural gas is returned to LER, concurrent with the sale of the natural gas to a third party, the related natural gas receivable is expensed in the Consolidated Statements of Income. In conjunction with these transactions, LER usually enters into New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE) natural gas futures, options, and swap contracts or fixed price sales agreements to protect against market changes in future sales prices. EARNINGS PER COMMON SHARE – GAAP requires dual presentation of basic and diluted earnings per share (EPS). EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareholders. Certain of the Company’s stock-based compensation awards pay non-forfeitable dividends to the participants during the vesting period and, as such, are deemed participating securities. Basic EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding that are increased for additional shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares, pursuant to the treasury stock method. Shares attributable to equity units, non-participating stock options and time-vested restricted stock/units are excluded from the calculation of diluted earnings per share if the effect would be antidilutive. Shares attributable to non-participating performance-contingent restricted stock awards are only included in the calculation of diluted earnings per share to the extent the underlying performance and/or market conditions are satisfied (a) prior to the end of the reporting period or (b) would be satisfied if the end of the reporting period were the end of the related contingency period and the result would be dilutive. The Company’s EPS computations are presented in Note 4 , Earnings Per Common Share. GROSS RECEIPTS AND SALES TAXES – Gross receipts taxes associated with the Company’s natural gas utility services are imposed on the Company, Laclede Gas, and Alagasco and billed to its customers. The revenue and expense amounts are recorded gross in the “Operating Revenues” and “Taxes, other than income taxes” lines, respectively, in the statements of income. The following table presents gross receipts taxes recorded: 2016 2015 2014 Spire $ 75.5 $ 97.3 $ 77.5 Laclede Gas 57.4 74.5 76.3 Alagasco 17.9 22.6 20.6 Sales taxes imposed on applicable Alagasco and Laclede Gas sales are billed to customers. These amounts are not recorded in the statements of income but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the balance sheets. TRANSACTIONS WITH AFFILIATES – Transactions between affiliates of the Company have been eliminated from the consolidated financial statements of Spire. Other than borrowings from Spire reflected in Alagasco’s Balance Sheets and Statements of Cash Flows and normal intercompany shared services transactions, there were no transactions between Alagasco and affiliates. Laclede Gas had the following transactions with affiliates: 2016 2015 2014 Purchases of natural gas from LER $ 46.3 $ 74.1 $ 89.1 Sales of natural gas to LER 1.9 4.0 5.1 Services received from Laclede Insurance Risk Services, Inc. 1.8 1.0 0.6 ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectability of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. Spire’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses for Laclede Gas and Alagasco, as approved by the MoPSC and the APSC. FINANCE RECEIVABLES – Alagasco finances third party contractor sales of merchandise including gas furnaces and appliances. At September 30, 2016 and September 30, 2015 , the Company’s finance receivable totaled approximately $11.8 and $11.2 , respectively. Financing is available only to qualified customers who meet creditworthiness thresholds for customer payment history and external agency credit reports. Alagasco relies upon ongoing payments as the primary indicator of credit quality during the term of each contract. The allowance for credit losses is recognized using an estimate of write-off percentages based on historical experience applied to an aging of the finance receivable balance. Delinquent accounts are evaluated on a case-by-case basis and, absent evidence of debt repayment after 90 days, are due in full and assigned to a third party collection agency. The remaining finance receivable is written off approximately 12 months after being assigned to the third party collection agency. Alagasco had finance receivables past due 90 days or more of $0.4 at September 30, 2016 and September 30, 2015 . Alagasco recorded an allowance for credit losses at September 30, 2016 and September 30, 2015 of $0.4 . GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES – The Company self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting. FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below: • Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities. • Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data. • Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability. Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. Additional information about fair value measurements is provided in Note 8 , Fair Value of Financial Instruments, Note 9 , Fair Value Measurements, and Note 13 , Pension Plans and Other Postretirement Benefits. STOCK-BASED COMPENSATION – The Company measures stock-based compensation awards at fair value at the date of grant and recognizes the compensation cost of the awards over the requisite service period. Forfeitures are estimated at the time of grant and revised, if necessary, in subsequent periods if the actual forfeitures differ from those estimates. Refer to Note 3 , Stock-Based Compensation, for further discussion of the accounting for the Company’s stock-based compensation plans. REVISIONS TO PRIOR FINANCIAL STATEMENTS - Certain amounts in the prior period have been adjusted to conform with the current period presentation for Spire and Laclede Gas. The adjustment was related to the presentation of categories of deferred tax assets in Note 12 , Income Taxes. NEW ACCOUNTING PRONOUNCEMENTS – In May 2014, the FASB issued |
ACQUISITIONS
ACQUISITIONS | 12 Months Ended |
Sep. 30, 2016 | |
Business Combinations [Abstract] | |
ACQUISITIONS | ACQUISITIONS Spire’s recent acquisitions are described below. The following table summarizes the consideration paid and the amounts of the assets acquired and liabilities assumed at the acquisition dates. Measurement period adjustments were immaterial. Alagasco EnergySouth Recognized amounts of identifiable assets acquired and liabilities assumed: Utility plant $ 892.7 $ 199.5 Cash 12.1 2.0 Other current assets 99.4 17.5 Deferred tax assets 282.0 — Other assets 143.4 79.8 Long-term debt (249.8 ) (67.0 ) Current portion of long-term debt (15.0 ) — Other current liabilities (173.4 ) (42.7 ) Deferred tax liabilities — (35.5 ) Other liabilities (130.4 ) (52.8 ) Total identifiable net assets 861.0 100.8 Goodwill 735.8 218.9 Deferred tax elimination (Spire) (271.3 ) — Consideration (cash) $ 1,325.5 $ 319.7 Acquisition of Alagasco Spire completed the acquisition of 100% of the common stock of Alagasco from Energen effective on August 31, 2014. Total cash consideration paid at closing, net of cash acquired and debt assumed was $1,305.2 . Subsequently, the Company and Energen agreed to a final reconciliation of net assets, and $8.2 was paid by the Company to Energen on January 6, 2015, effectively increasing the total net consideration to $1,313.4 . The goodwill of $735.8 arising from this acquisition, $717.6 of which is expected to be deductible for tax purposes, is attributable to Alagasco’s assembled workforce and the expected cost efficiencies and strategic benefits of the transaction. The acquisition was supportive of the strategic focus on growing the Company’s regulated footprint and created geographic and regulatory diversity. The Company determined that the Alagasco acquisition met the scope exceptions for pushdown accounting; therefore, the goodwill was recorded on the Spire parent company balance sheet rather than the Alagasco subsidiary balance sheet and included in disclosures of segment assets under Other rather than the Gas Utility segment. The Company and Energen made an election under Section 338(h)(10) of the Internal Revenue Code of 1986, as amended, to treat the Alagasco acquisition as a deemed purchase and sale of assets for tax purposes. As a result of the election, goodwill was generated for tax purposes at Alagasco. For book purposes, as noted above, goodwill was recorded on the Spire parent entity and not pushed down to Alagasco. Consequently, a deferred tax asset (DTA) was recorded at Alagasco related to the excess of tax deductible goodwill over book goodwill for the stand-alone entity. That initial goodwill DTA is eliminated (along with the investment in subsidiary and Alagasco’s equity) in the Spire consolidated balance sheet because, at that consolidated level, there is no excess of tax deductible goodwill over book goodwill. As the tax goodwill is amortized and deducted for tax purposes, the DTA at Alagasco is reduced, and for Spire, a deferred tax liability (DTL) is created. For both Alagasco and consolidated Spire, the changes to the goodwill DTA/DTL are reported as a component of deferred tax expense in the income statement. Because the deferred tax expense impact will be offset by an opposite current tax expense impact, there will be no significant impact on the effective tax rate of the Company. Acquisition of EnergySouth Effective September 12, 2016, Spire completed the acquisition of 100% of the common stock of EnergySouth, the parent company of Mobile Gas and Willmut Gas, serving natural gas utility customers in Alabama and Mississippi. This acquisition is supportive of the strategic focus on growing Spire’s gas utility business and creating geographic and regulatory diversity. Total cash consideration paid at closing, net of cash acquired and debt assumed was $317.7 . The goodwill of $218.9 arising from this acquisition, which is not deductible for tax purposes, is attributable to the assembled workforce and the expected cost efficiencies and strategic benefits of the transaction. The Company did not elect pushdown accounting, so the goodwill was recorded on the Spire parent company balance sheet rather than the EnergySouth subsidiary balance sheet and is included in disclosures of segment assets under Other. Because the acquisition occurred near the end of the fiscal year and certain assessments are still in progress, the assignment of goodwill to reporting units has not yet been completed. Similarly, the recorded values of some of the assets acquired and liabilities assumed, such as those related to income taxes and contingencies, are provisional pending completion of analyses of those items. Actual and Pro Forma Results The results of operations of each of the acquisitions are included in the Spire statements of income from the date of acquisition, as shown in the following table. Alagasco EnergySouth 2016 2015 2014 2016 Total Operating Revenues $ 368.5 $ 479.2 $ 19.7 $ 3.3 Net Income (Loss) 53.2 48.0 (2.9 ) (0.2 ) Earnings (Loss) Per Share $ 1.20 $ 1.11 $ (0.08 ) $ — The following unaudited pro forma financial information presents Spire’s combined results of operations as though the EnergySouth acquisition had occurred as of the beginning of fiscal year 2015 and the Alagasco acquisition had occurred as of the beginning of fiscal year 2013. The unaudited pro forma financial information is not necessarily indicative of either future results of operations or results that would have been achieved if the acquisitions had occurred as of those earlier dates. It does not reflect the costs of any integration activities. It includes estimates and assumptions which management believes are reasonable. 2016 2015 2014 Total Operating Revenues $ 1,632.4 $ 2,081.6 $ 2,187.1 Net Income 153.9 143.6 133.5 Basic Earnings Per Share $ 3.48 $ 3.32 $ 3.11 Diluted Earnings Per Share 3.46 3.31 3.10 |
STOCK-BASED COMPENSATION
STOCK-BASED COMPENSATION | 12 Months Ended |
Sep. 30, 2016 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
STOCK-BASED COMPENSATION | STOCK-BASED COMPENSATION Spire’s 2015 incentive plan, The Laclede Group 2015 Equity Incentive Plan (the 2015 Plan), was approved at the annual meeting of shareholders of Spire on January 29, 2015. The purpose of the 2015 Plan is to encourage directors, officers, and employees of the Company and its subsidiaries to contribute to the Company’s success and align their interests with that of shareholders. To accomplish this purpose, the Compensation Committee (Committee) of the Board of Directors may grant awards under the 2015 Plan that may be earned by achieving performance objectives and/or other criteria as determined by the Committee. Under the terms of the 2015 Plan, officers and employees of the Company and its subsidiaries, as determined by the Committee, are eligible to be selected for awards. The 2015 Plan provides for restricted stock, restricted stock units, qualified and non-qualified stock options, stock appreciation rights, and performance shares payable in stock, cash, or a combination of both. The 2015 Plan generally provides a minimum vesting period of at least three years for each type of award, with pro rata vesting permitted during the minimum three -year vesting period. The maximum number of shares reserved for issuance under the 2015 Plan is 1,000,000 . The 2015 Plan replaced The Laclede Group 2006 Equity Incentive Plan (the 2006 Plan), which in turn replaced The Laclede Group, Inc. 2002 Equity Incentive Plan (the 2002 Plan). Shares reserved under the 2006 Plan and the 2002 Plan, other than those needed for currently outstanding awards, were canceled upon shareholder approval of the 2015 Plan. The Company issues new shares to satisfy employee restricted stock awards and stock option exercises. Restricted Stock Awards During fiscal year 2016 , the Company granted 199,140 performance-contingent restricted share units to executive officers and key employees at a weighted average grant date fair value of $45.95 per share. This number represents the maximum shares that can be earned pursuant to the terms of the awards. The share units have a performance period ending September 30, 2018. While the participants have no interim voting rights on these share units, dividends accrue during the performance period and are paid to the participants upon vesting, but are subject to forfeiture if the underlying share units do not vest. The number of share units that will ultimately vest is dependent upon the attainment of certain levels of earnings and other strategic goals, as well as the Company’s level of total shareholder return (TSR) during the performance period relative to a comparator group of companies. This TSR provision is considered a market condition under GAAP and is discussed further below. The weighted average grant date fair value of performance-contingent restricted shares and share units granted during fiscal years 2015 and 2014 was $36.69 and $37.21 per share, respectively. Fiscal year 2016 activity of restricted stock and restricted stock units subject to performance and/or market conditions is presented below: Shares/ Units Weighted Average Grant Date Fair Value Per Share Nonvested at September 30, 2015 397,270 $ 36.28 Granted (maximum shares that can be earned) 199,140 $ 45.95 Vested (62,593 ) $ 35.29 Forfeited (23,234 ) $ 30.96 Nonvested at September 30, 2016 510,583 $ 40.37 During fiscal year 2016 , the Company granted 35,210 shares of time-vested restricted stock to executive officers and key employees at a weighted average grant date fair value of $59.40 per share. These shares were awarded between December 2015 and September 2016 and vest between December 2018 and September 2019 based on terms of the agreements. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture. The weighted average grant date fair value of time-vested restricted stock and restricted stock units awarded to employees during fiscal year 2015 and 2014 was $50.90 and $45.66 per share, respectively. During fiscal year 2016 , the Company granted 13,520 shares of time-vested restricted stock to non-employee directors at a weighted average grant date fair value of $63.93 per share. The weighted average grant date fair value of restricted stock awarded to non-employee directors during fiscal years 2015 and 2014 was $54.66 and $46.02 per share, respectively. Time-vested restricted stock and stock unit activity for fiscal year 2016 is presented below: Shares/ Units Weighted Average Grant Date Fair Value Per Share Nonvested at September 30, 2015 129,304 $ 44.89 Granted 48,730 $ 60.65 Vested (44,645 ) $ 47.30 Forfeited (610 ) $ 53.12 Nonvested at September 30, 2016 132,779 $ 49.83 During fiscal year 2016, 107,238 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on October 1, 2012, December 3, 2012, February 1, 2013, June 3, 2013, and August 1, 2013 vested. The Company withheld 30,712 of the vested shares at a weighted average price of $57.29 per share pursuant to elections by employees to satisfy tax withholding obligations. During fiscal year 2015, 128,135 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on December 1, 2011, May 1, 2012, December 2, 2013 and January 1, 2014 vested. The Company withheld 31,688 of the vested shares at a weighted average price of $50.65 per share pursuant to elections by employees to satisfy tax withholding obligations. During fiscal year 2014, 88,533 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on December 1, 2010, September 1, 2011, October 1, 2012, January 30, 2014 and February 21, 2014 vested. The Company withheld 23,776 of these vested shares at a weighted average price of $45.96 per share pursuant to elections by employees to satisfy tax withholding obligations. The total fair value of restricted stock (performance-contingent and time-vested) vested during fiscal years 2016 , 2015 , and 2014 was $6.3 , $6.4 , and $4.1 , respectively, and the related tax benefit was $2.4 , $2.4 and $1.6 , respectively. None of the tax benefits have been realized. Stock Option Awards No stock options were granted during fiscal years 2016 , 2015 , and 2014 . Stock option activity for fiscal year 2016 is presented below: Stock Options Weighted Average Exercise Price Per Share Outstanding at September 30, 2015 28,500 $ 33.65 Exercised (27,750 ) $ 33.66 Forfeited (750 ) $ 33.45 Outstanding at September 30, 2016 — $ — During fiscal year 2016 , cash received from the exercise of stock options was $0.7 and the related intrinsic value was $0.7 . During fiscal year 2015 , cash received from the exercise of stock options was $1.5 and the related intrinsic value was $0.9 . During fiscal year 2014 , cash received from the exercise of stock options was $1.7 and the related intrinsic value was $0.9 . Related tax benefits were not material in any of those years. The closing price of the Company’s common stock was $63.74 per share at September 30, 2016 . Equity Compensation Costs Compensation cost for performance-contingent restricted stock and stock unit awards is based upon the probable outcome of the performance conditions. For shares or units that do not vest or that are not expected to vest due to the outcome of the performance conditions (excluding market conditions), no compensation cost is recognized and any previously recognized compensation cost is reversed. The fair value of awards of performance-contingent and time-vested restricted stock and restricted stock units, not subject to the TSR provision, are estimated using the closing price of the Company’s stock on the date of the grant. For those awards that do not pay dividends during the vesting period, the estimate of fair value is reduced by the present value of the dividends expected to be paid on the Company’s common stock during the performance period, discounted using an appropriate US Treasury yield. For shares subject to the TSR provision, the estimated impact of this market condition is reflected in the grant date fair value per share of the awards. Accordingly, compensation cost is not reversed to reflect any actual reductions in the awards that may result from the TSR provision. However, if the Company’s TSR during the performance period ranks below the level specified in the award agreements, relative to a comparator group of companies, and the Committee elects not to reduce the award (or reduce by a lesser amount), this election would be accounted for as a modification of the original award and additional compensation cost would be recognized at that time. The grant date fair value of the awards subject to the TSR provision awarded during fiscal years 2016 , 2015 , and 2014 was valued by a Monte Carlo simulation model that assessed the probabilities of various TSR outcomes. The significant assumptions used in the Monte Carlo simulations are as follows: 2016 2015 2014 Risk free interest rate 1.14% 0.83% 0.53% Expected dividend yield of stock — — — Expected volatility of stock 15.0% 14.0% 18.0% Vesting period 2.8 years 2.8 years 2.8 years The risk free interest rate was based on the yield on US Treasury securities matching the vesting period. A zero percent dividend yield was used, which is mathematically equivalent to the assumption that dividends are reinvested as they are paid. The expected volatility is based on the historical volatility of the Company’s stock. Volatility assumptions were also made for each of the companies included in the comparator group. The vesting period is equal to the performance period set forth in the terms of the award. The amounts of compensation cost recognized for share-based compensation arrangements are presented below: 2016 2015 2014 Total equity compensation cost $ 6.7 $ 6.7 $ 5.8 Compensation cost capitalized (2.2 ) (1.8 ) (1.8 ) Compensation cost recognized in net income $ 4.5 $ 4.9 $ 4.0 Income tax benefit recognized in net income (1.7 ) (1.9 ) (1.5 ) Compensation cost recognized in net income, net of income tax $ 2.8 $ 3.0 $ 2.5 As of September 30, 2016 , there was $9.2 of total unrecognized compensation cost related to non-vested share-based compensation arrangements. That cost is expected to be recognized over a weighted average period of 1.8 years . |
EARNINGS PER COMMON SHARE
EARNINGS PER COMMON SHARE | 12 Months Ended |
Sep. 30, 2016 | |
Earnings Per Share [Abstract] | |
EARNINGS PER COMMON SHARE | EARNINGS PER COMMON SHARE 2016 2015 2014 Basic EPS: Net Income $ 144.2 $ 136.9 $ 84.6 Less: Income allocated to participating securities 0.5 0.5 0.3 Net Income Available to Common Shareholders $ 143.7 $ 136.4 $ 84.3 Weighted Average Shares Outstanding (millions) 44.1 43.2 35.8 Earnings Per Share of Common Stock $ 3.26 $ 3.16 $ 2.36 Diluted EPS: Net Income $ 144.2 $ 136.9 $ 84.6 Less: Income allocated to participating securities 0.5 0.5 0.3 Net Income Available to Common Shareholders $ 143.7 $ 136.4 $ 84.3 Weighted Average Shares Outstanding (millions) 44.1 43.2 35.8 Dilutive Effect of Stock Options, Restricted Stock, and Restricted Stock Units (millions) 0.2 0.1 0.1 Weighted Average Diluted Shares (millions) 44.3 43.3 35.9 Earnings Per Share of Common Stock $ 3.24 $ 3.16 $ 2.35 Outstanding Shares (in millions) Excluded from the Calculation of Diluted EPS Attributable to: Restricted stock and stock units subject to performance and/or market conditions 0.3 0.3 0.3 Spire’s 2014 2.0% Series Equity Units issued in June 2014 are potentially dilutive securities, but were excluded from the calculation of diluted EPS for the years ended September 30, 2016 , 2015 and 2014. The potential shares were not included in the outstanding shares excluded from the calculation of Diluted EPS in the table above. See Note 5 for more information. |
STOCKHOLDERS' EQUITY
STOCKHOLDERS' EQUITY | 12 Months Ended |
Sep. 30, 2016 | |
Stockholders' Equity Note [Abstract] | |
STOCKHOLDERS' EQUITY | STOCKHOLDERS’ EQUITY Equity Units In June 2014, Spire issued 2.875 million equity units, initially consisting of Corporate Units, for an aggregate stated amount of approximately $143.8 . Each Corporate Unit has a stated amount of fifty dollars and consists of (i) a stock purchase contract obligating the holder to purchase shares of Spire’s common stock, par value $1.00 per share, and (ii) a 1/20, or 5% , undivided beneficial ownership interest in one thousand dollars principal amount of Spire’s 2014 Series A 2.00% Remarketable Junior Subordinated Notes due 2022 (RSNs). The stock purchase contracts obligate the holders to purchase shares of common stock at a future settlement date prior to the relevant RSN maturity date. The purchase price to be paid under the stock purchase contracts is fifty dollars per Corporate Unit and the number of shares to be purchased will be determined as follows: If the applicable market value per share of Spire common stock is: Number of shares to be purchased per purchase contract is: Equal to or greater than $57.8125 0.8649 Less than $57.8125, but greater than $46.25 $50 ÷ applicable market value Less than or equal to $46.25 1.0811 The RSNs are pledged as collateral to secure the purchase of Spire’s common stock under the related stock purchase contracts. The Company makes quarterly interest payments on the RSNs and quarterly contract adjustment payments on the stock purchase contracts, at the rates described below. The Company may defer payments on the stock purchase contracts and the RSNs for one or more consecutive periods but generally not beyond the purchase contract settlement date. If payments are deferred, interest on the RSNs and contract adjustment payments will compound on each respective payment date in which the payment was deferred. Also, during the deferral period, the Company may not make any cash distributions related to its capital stock, including dividends, redemptions, repurchases, liquidation payments or guarantee payments. Additionally, the Company may not make any payments on or redeem or repurchase any debt securities that are equal in right of payment with, or subordinated to, the RSNs during the deferral period. The Company has recorded the present value of the stock purchase contract payments as a liability offset by a charge to additional paid-in capital in equity. Interest payments on the RSNs are recorded as interest expense and stock purchase contract payments are charged against the liability. Accretion of the stock purchase contract liability is recorded as imputed interest expense. In calculating diluted EPS, the Company applies the treasury stock method to the Corporate Units. These securities did not have an effect on diluted EPS for the years ended September 30, 2016 and 2015. Under the terms of the stock purchase contracts, assuming no anti-dilution or other adjustments, Spire will issue between approximately 2.5 million and 3.1 million shares of its common stock in April 2017. A total of approximately 4.2 million shares of common stock have been reserved for issuance in connection with the stock purchase contracts. The stock purchase contracts obligate the holders to purchase shares of common stock at a future settlement date (April 1, 2017, or if such day is not a business day, the following business day) prior to the relevant RSN maturity date. Selected information about the Company’s equity units is presented below: Issuance Date Units Issued (Millions) Total Net Proceeds Total Long-term Debt RSN Annual Interest Rate Stock Purchase Contract Annual Rate Stock Purchase Contract Liability 6/11/2014 2.875 $139.4 $143.8 2.00% 4.75% $19.7 Other Stock Information Spire On June 20, 2014, Spire filed a registration statement on Form S-3 for the issuance and sale of up to 168,698 shares of its common stock under its Dividend Reinvestment and Stock Purchase Program. There were 106,535 and 101,439 shares at September 30, 2016 and November 11, 2016 , respectively, remaining available for issuance under this Form S-3. On May 17, 2016, Spire completed a public offering of 2,185,000 shares of its common stock, generating $133.2 of proceeds net of issuance costs. On September 23, 2016, Spire and Laclede Gas filed with the SEC a joint shelf registration statement on Form S-3 for issuance of various types of debt and equity securities, which registration statement will expire September 22, 2019. The amount, timing, and type of additional financing to be issued under this shelf registration statement will depend on cash requirements and market conditions. At September 30, 2016 and 2015 , Spire had authorized 5,000,000 shares of preferred stock, but none were issued and outstanding. Laclede Gas Laclede Gas periodically sells shares of its stock to Spire at prices per share equal to book value on the last day of the quarter preceding each sale. There was no sale of shares to Spire during fiscal years 2016 or 2015. Laclede Gas sold 28 shares to Spire for $1.1 during fiscal year 2014. Exemption from registration for all of the sales was claimed under section 4(a)(2) of the Securities Act of 1933, as amended. Substantially all of Laclede Gas plant is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock or to make loans to its parent company. These mortgage restrictions are applicable regardless of whether the stock is publicly held or held solely by Laclede Gas’ parent company. Under the most restrictive of these provisions, no cash dividend may be declared or paid if, after the dividend, the aggregate net amount spent for all dividends after September 30, 1953 would exceed a maximum amount determined by a formula set out in the mortgage. Under that formula, the maximum amount is the sum of $8.0 plus earnings applicable to common stock (adjusted for stock repurchases and issuances) for the period from September 30, 1953 to the last day of the quarter before the declaration or payment date for the dividends. As of September 30, 2016 and 2015 , the amount under the mortgage’s formula that was available to pay dividends was $916.8 and $891.7 , respectively. Thus, all of Laclede Gas’ retained earnings were free from such dividend restrictions as of those dates. On September 23, 2016, Spire and Laclede Gas filed with the SEC a joint shelf registration statement on Form S-3 for issuance of various types of debt and equity securities, which registration statement will expire September 22, 2019. The amount, timing, and type of additional financing to be issued under this shelf registration statement will depend on cash requirements and market conditions, as well as future MoPSC authorizations. Laclede Gas has authority from the MoPSC to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in capital, and enter into capital lease agreements, all for a total of up to $300.0 . Laclede Gas has issued no securities under this authorization. At September 30, 2016 and 2015 , Laclede Gas had authorized 1,480,000 shares of preferred stock, but none were issued and outstanding. Alagasco At September 30, 2016 and 2015 , Alagasco has authorized 120,000 shares of preferred stock, but none were issued and outstanding. Other Comprehensive Income The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the balance sheets at September 30 were as follows: Net Unrealized Gains (Losses) on Cash Flow Hedges Defined Benefit Pension and Other Postretirement Benefit Plans Net Unrealized Losses on Available for Sale Securities Total Spire Balance at September 30, 2014 $ 0.2 $ (1.9 ) $ — $ (1.7 ) Other comprehensive (loss) income (0.6 ) 0.4 (0.1 ) (0.3 ) Balance at September 30, 2015 (0.4 ) (1.5 ) (0.1 ) (2.0 ) Other comprehensive (loss) income (1.9 ) (0.3 ) — (2.2 ) Balance at September 30, 2016 $ (2.3 ) $ (1.8 ) $ (0.1 ) $ (4.2 ) Laclede Gas Balance at September 30, 2014 $ — $ (1.9 ) $ — $ (1.9 ) Other comprehensive (loss) income (0.2 ) 0.4 — 0.2 Balance at September 30, 2015 (0.2 ) (1.5 ) — (1.7 ) Other comprehensive income (loss) 0.3 (0.3 ) (0.1 ) (0.1 ) Balance at September 30, 2016 $ 0.1 $ (1.8 ) $ (0.1 ) $ (1.8 ) Income tax expense (benefit) recorded for items of other comprehensive income (loss) reported in the statements of comprehensive income is calculated by applying statutory federal, state, and local income tax rates applicable to ordinary income. The tax rates applied to individual items of other comprehensive income are similar within each reporting period. For the periods presented, Alagasco had no accumulated other comprehensive income (loss) balances. |
LONG-TERM DEBT
LONG-TERM DEBT | 12 Months Ended |
Sep. 30, 2016 | |
Debt Disclosure [Abstract] | |
LONG-TERM DEBT | LONG-TERM DEBT Composition of long-term debt for Spire, Laclede Gas and Alagasco are shown in each registrant’s statements of capitalization as part of the financial statements. Maturities of long-term debt for Spire, Laclede Gas and Alagasco for the five fiscal years subsequent to September 30, 2016 are as follows: Spire Laclede Gas Alagasco 2017 $ 250.0 $ — $ — 2018 100.0 100.0 — 2019 180.0 50.0 — 2020 40.0 — 40.0 2021 55.0 — — Spire’s, Laclede Gas’ and Alagasco’s short-term credit facilities and long-term debt agreements contain customary covenants and default provisions. As of September 30, 2016 , there were no events of default under these covenants. The Company’s, Laclede Gas’, and Alagasco’s access to capital markets, including the commercial paper market, and their respective financing costs, may depend on the credit rating of the entity that is accessing the capital markets. The credit ratings of the Company, Laclede Gas and Alagasco remain at investment grade, but are subject to review and change by the rating agencies. It is management’s view that the Company, Laclede Gas and Alagasco have adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements, which primarily include capital expenditures, interest payments on long-term debt, scheduled maturities of long-term debt, short-term seasonal needs, and dividends. Spire Spire entered into a master note purchase agreement on June 20, 2016, with certain institutional purchasers pursuant to which Spire issued a total of $165.0 unsecured notes in the private placement market. These notes were issued on September 9, 2016 to fund a portion of the purchase price for the EnergySouth acquisition and consisted of $35 million in aggregate principal amount of its unsecured Series 2016 Senior Notes, Tranche A, due September 1, 2021 (Tranche A Notes) and $130 million in aggregate principal amount of its unsecured Series 2016 Senior Notes, Tranche B, due September 1, 2026 (Tranche B Notes). Tranche A Notes and Tranche B Notes bear interest at a rate per annum of 2.52% and 3.13% , respectively. At September 30, 2016 , including the current portion but excluding unamortized discounts and net hedging gains, Spire had long-term debt totaling $2,085.8 , of which $810.0 was issued by Laclede Gas, $250.0 was issued by Alagasco, and $67.0 was issued by other subsidiaries. With the exception of $250.0 floating rate senior notes issued by Spire, all long-term debt bears fixed rates and is subject to changes in fair value as market interest rates change. However, increases and decreases in fair value would impact earnings and cash flows only if the Company were to reacquire any of these issues in the open market prior to maturity. Under GAAP applicable to the Utilities’ regulated operations, losses or gains on early redemption of long-term debt typically would be deferred as regulatory assets or liabilities and amortized over a future period. Of the Company’s $1,942.0 senior long-term debt (including the current portion) , $25.0 have no call options, $937.0 have make-whole call options, $250.0 is callable currently, and $730.0 are callable at par between one to six months prior to maturity. The remainder of the Company’s long-term debt is $143.8 of 2% Remarketable Junior Subordinated Notes due in 2022. None of the debt has put options. Spire has a shelf registration statement on Form S-3 on file with the SEC for the issuance and sale of up to 168,698 shares of common stock under its Dividend Reinvestment and Direct Stock Purchase Plan. There were 106,535 and 101,439 at September 30, 2016 and November 11, 2016, respectively, remaining available for issuance under this Form S-3. Spire also has a shelf registration statement on Form S-3 on file with the SEC for the issuance of equity and debt securities. The Company’s capitalization at September 30, 2016 consisted of 49.1% of Spire common stock equity and 50.9% long-term debt, compared to 47.0% of Spire common stock equity and 53.0% of long-term debt at September 30, 2015 . The decline in the proportion of long-term debt is due primarily to the reclassification of $250.0 of Spire’s long-term debt to “current.” Laclede Gas At September 30, 2016 , Laclede Gas had fixed-rate long-term debt, including the current portion, totaling $810.0 . While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. Of Laclede Gas’ $810.0 in long-term debt, $25.0 have no call options, $435.0 have make-whole call options and $350.0 are callable at par three to six months prior to maturity. None of the debt has any put options. Laclede Gas has authority from the MoPSC to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in-capital, and enter into capital lease agreements, all for a total of up to $300.0 for financings placed any time before September 30, 2018. On March 31, 2016, Laclede Gas filed an appeal with Missouri’s Western District Court of Appeals challenging the level of authority. On July 20, 2016, Laclede Gas filed its initial brief in the appeal. Oral arguments are scheduled for November 17, 2016. During the year ended September 30, 2016 , Laclede Gas issued no securities under this authorization, so that as of November 11, 2016, $300.0 remains available to be issued. On September 23, 2016, Laclede Gas filed a shelf registration on Form S-3 with the SEC for issuance of first mortgage bonds, unsecured debt, and preferred stock, which expires on September 22, 2019. The amount, timing, and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions, as well as future MoPSC authorizations. This authorization is more fully described in Note 5 , Stockholders’ Equity. Laclede Gas’ capitalization at September 30, 2016 consisted of 56.9% of Laclede Gas common stock equity and 43.1% long-term debt compared to 56.2% of Laclede Gas common stock equity and 43.8% of long-term debt at September 30, 2015 . Substantially all of Laclede Gas’ plant is subject to the liens of its first mortgage bonds. The mortgage contains several restrictions on Laclede Gas’ ability to pay cash dividends on its common stock, which are described more fully in Note 5 , Stockholders’ Equity. Alagasco Because Alagasco has no standing authority to issue long-term debt, it must petition the APSC for each planned issuance. On November 3, 2014, Alagasco received authorization and approval from the APSC to borrow $35.0 for the purpose of redeeming, without penalty, $34.8 in existing long-term, callable debt financed at 5.7% . Pursuant to a call notice issued on December 15, 2014, Alagasco redeemed $34.8 of debt effective January 15, 2015. On February 3, 2015, Alagasco received authorization and approval from the APSC to borrow $80.0 for the purpose of refinancing the scheduled maturity on December 1, 2015 of $80.0 of existing debt. Pursuant to these authorizations, Alagasco committed to issue $115.0 unsecured notes in the private placement market: $35.0 at a rate of 3.21% for 10 years issued on September 15, 2015, and $80.0 at a rate of 4.31% for 30 years issued on December 1, 2015. The Notes are senior unsecured obligations of Alagasco and rank equal in right to payment with all other senior unsecured indebtedness. Alagasco used the proceeds from the sale of the Notes to refinance existing indebtedness and for general corporate purposes. At September 30, 2016 , Alagasco had fixed-rate long-term debt totaling $250.0 . While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. All of Alagasco’s $250.0 long-term debt has make-whole call options. Alagasco’s capitalization at September 30, 2016 consisted of 77.6% of Alagasco common stock equity and 22.4% long-term debt compared to 83.7% of Alagasco common stock equity and 16.3% of long-term debt at September 30, 2015 . |
NOTES PAYABLE AND CREDIT AGREEM
NOTES PAYABLE AND CREDIT AGREEMENTS | 12 Months Ended |
Sep. 30, 2016 | |
Short-term Debt [Abstract] | |
NOTES PAYABLE AND CREDIT AGREEMENTS | NOTES PAYABLE AND CREDIT AGREEMENTS Short-term cash requirements outside of the Utilities have generally been funded by Spire or met with internally generated funds. At September 30, 2016 , Spire had a $150.0 syndicated line of credit from nine banks maturing on September 3, 2019, with the largest portion provided by a single bank being 15.6% . The line of credit has a covenant limiting the total debt of the consolidated Spire to no more than 70% of the Company’s total capitalization. As defined in the line of credit, this ratio was 58.5% on September 30, 2016 . Spire’s line may be used to provide for the funding needs of various subsidiaries. The maturity date of the loan agreement is September 3, 2019. The Utilities’ short-term borrowing requirements typically peak during the colder months while the Company’s needs are less seasonal. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. At September 30, 2016 , Laclede Gas had a syndicated line of credit of $450.0 in place from ten banks. The largest portion provided by a single bank is 15.6% . Laclede Gas’ line of credit includes a covenant limiting total debt, including short-term debt, to no more than 70% of total capitalization. As defined in the line of credit, on September 30, 2016 total debt was 49.7% of total capitalization. Laclede Gas’ commercial paper program is backed by the line of credit. The maturity date of the line of credit is September 3, 2019. On September 2, 2014, Alagasco entered into a new $150.0 syndicated line of credit with twelve banks and extinguished the line that was in place prior to its acquisition by Spire. The largest portion provided by a single bank is 10% . The line of credit, which matures on September 2, 2019, has a covenant limiting total debt to no more than 70% of Alagasco’s total capitalization. As defined in the line of credit, this ratio stood at 27.8% on September 30, 2016 . Spire Information about Spire’s short-term borrowings (excluding intercompany borrowings) during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Laclede Gas Commercial Paper Borrowings Spire Bank Line Borrowings* Alagasco Bank Line Borrowings Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $201.0 $42.7 $30.2 $273.9 Weighted average interest rate 0.7% 1.6% 1.4% 0.9% Range of borrowings outstanding $43.0 - $307.2 $0.0 - $82.0 $0.0 - $82.0 $73.1 - $427.2 As of September 30, 2016 Borrowings outstanding at end of period $243.7 $73.0 $82.0 $398.7 Weighted average interest rate 0.8% 1.8% 1.5% 1.1% Year Ended September 30, 2015 Weighted average borrowings outstanding $212.7 $65.6 $22.3 $300.6 Weighted average interest rate 0.4% 1.4% 1.1% 0.7% Range of borrowings outstanding $ 102.1 - $341.0 $32.5 - $80.0 $0.0 - $69.5 $180.1 - $488.5 As of September 30, 2015 Borrowings outstanding at end of period $233.0 $74.0 $31.0 $338.0 Weighted average interest rate 0.5% 1.5% 1.2% 0.8% * Spire Inc., excluding its wholly owned subsidiaries. Based on average short-term borrowings for the twelve months ended September 30, 2016 , an increase in the average interest rate of 100 basis points would decrease Spire’s pre-tax earnings and cash flows by approximately $2.7 on an annual basis, portions of which may be offset through the application of PGA or GSA carrying costs. Laclede Gas Information about Laclede Gas’ short-term borrowings during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Commercial Paper Borrowings Borrowings from Spire Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $201.0 $14.7 $215.7 Weighted average interest rate 0.7% 0.8% 0.7% Range of borrowings outstanding $43.0 - $307.2 $0.0 - $114.2 $127.8 - $ 307.2 As of September 30, 2016 Borrowings outstanding at end of period $243.7 $— $243.7 Weighted average interest rate 0.8% —% 0.8% Year Ended September 30, 2015 Weighted average borrowings outstanding $212.7 $0.3 $213.0 Weighted average interest rate 0.4% 0.5% 0.4% Range of borrowings outstanding $102.1 - $341.0 $0.0 - $10.4 $104.2 - $ 341.0 As of September 30, 2015 Borrowings outstanding at end of period $233.0 $— $233.0 Weighted average interest rate 0.5% —% 0.5% Based on average short-term borrowings for the twelve months ended September 30, 2016 , an increase in the average interest rate of 100 basis points would decrease Laclede Gas’ pre-tax earnings and cash flows by approximately $2.2 on an annual basis, portions of which may be offset through the application of PGA carrying costs. Alagasco Information about Alagasco’s short-term borrowings during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Bank Line Borrowings Borrowings from Spire Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $30.2 $12.4 $42.6 Weighted average interest rate 1.4% 1.4% 1.4% Range of borrowings outstanding $0.0 - $82 $0.0 - $61.9 $19.0 - $82.0 As of September 30, 2016 Borrowings outstanding at end of period $82.0 $— $82.0 Weighted average interest rate 1.5% —% 1.5% Year Ended September 30, 2015 Weighted average borrowings outstanding $22.3 $— $22.3 Weighted average interest rate 1.1% —% 1.1% Range of borrowings outstanding $0.0 - $69.5 0 $0.0- $69.5 As of September 30, 2015 Borrowings outstanding at end of period $31.0 $— $31.0 Weighted average interest rate 1.2% —% 1.2% Based on average short-term borrowings for the twelve months ended September 30, 2016 , an increase in the average interest rate of 100 basis points would decrease Alagasco’s pre-tax earnings and cash flows by approximately $0.4 on an annual basis, portions of which may be offset through the application of GSA carrying costs. |
FAIR VALUE OF FINANCIAL INSTRUM
FAIR VALUE OF FINANCIAL INSTRUMENTS | 12 Months Ended |
Sep. 30, 2016 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE OF FINANCIAL INSTRUMENTS | FAIR VALUE OF FINANCIAL INSTRUMENTS Spire The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for the Company are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ 5.2 $ 5.2 $ 5.2 $ — $ — Short-term debt 398.7 398.7 — 398.7 — Long-term debt, including current portion 2,083.7 2,257.1 — 2,257.1 — As of September 30, 2015 Cash and cash equivalents $ 13.8 $ 13.8 $ 13.8 $ — $ — Short-term debt 338.0 338.0 — 338.0 — Long-term debt, including current portion 1,851.5 1,944.2 — 1,944.2 — Laclede Gas The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for Laclede Gas are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ 2.1 $ 2.1 $ 2.1 $ — $ — Short-term debt 243.7 243.7 — 243.7 — Long-term debt 808.3 900.4 — 900.4 — As of September 30, 2015 Cash and cash equivalents $ 1.7 $ 1.7 $ 1.7 $ — $ — Short-term debt 233.0 233.0 — 233.0 — Long-term debt 808.1 880.2 — 880.2 — Alagasco The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for Alagasco are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ — $ — $ — $ — $ — Short-term debt 82.0 82.0 — 82.0 — Long-term debt 250.0 275.5 — 275.5 — As of September 30, 2015 Cash and cash equivalents $ 7.2 $ 7.2 $ 7.2 $ — $ — Short-term debt 31.0 31.0 — 31.0 — Long-term debt, including current portion 250.0 263.2 — 263.2 — The carrying amounts for cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. Refer to Note 9 , Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis. |
FAIR VALUE MEASUREMENTS
FAIR VALUE MEASUREMENTS | 12 Months Ended |
Sep. 30, 2016 | |
Fair Value Disclosures [Abstract] | |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTS Spire The information presented below categorizes the assets and liabilities in the balance sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition. The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. The mutual funds included in Level 2 are valued based on the closing net asset value per unit. Derivative instruments included in Level 1 are valued using quoted market prices on the NYMEX. Derivative instruments classified as Level 2 include physical commodity derivatives that are valued using Over-the-Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. There were no material Level 3 balances as of September 30, 2016 or 2015 . The Company’s and the Utilities’ policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer. The mutual funds are included in the “Other investments” line of the balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exist between the Company or Laclede Gas and the counterparty to the derivative contract. For additional information on derivative instruments, see Note 10 , Derivative Instruments and Hedging Activities. Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Effects of Netting and Cash Margin Receivables /Payables Total As of September 30, 2016 ASSETS Gas Utility US stock/bond mutual funds $ 16.8 $ 4.1 $ — $ — $ 20.9 NYMEX/ICE natural gas contracts 5.3 — — (0.4 ) 4.9 Gasoline and heating oil contracts 0.4 — — (0.3 ) 0.1 Subtotal 22.5 4.1 — (0.7 ) 25.9 Gas Marketing NYMEX/ICE natural gas contracts 0.4 3.4 — (3.4 ) 0.4 Natural gas commodity contracts — 8.7 0.2 (0.9 ) 8.0 Total $ 22.9 $ 16.2 $ 0.2 $ (5.0 ) $ 34.3 LIABILITIES Gas Utility NYMEX/ICE natural gas contracts $ 1.6 $ — $ — $ (1.6 ) $ — OTCBB natural gas contracts — 0.2 — — 0.2 Subtotal 1.6 0.2 — (1.6 ) 0.2 Gas Marketing NYMEX/ICE natural gas contracts 3.5 1.6 — (5.1 ) — Natural gas commodity contracts — 2.6 — (0.9 ) 1.7 Other Interest rate swaps — 3.0 — — 3.0 Total $ 5.1 $ 7.4 $ — $ (7.6 ) $ 4.9 As of September 30, 2015 ASSETS Gas Utility US stock/bond mutual funds $ 15.5 $ 4.0 $ — $ — $ 19.5 NYMEX/ICE natural gas contracts 1.3 — — (1.3 ) — Subtotal 16.8 4.0 — (1.3 ) 19.5 Gas Marketing NYMEX natural gas contracts 6.3 4.3 — (6.6 ) 4.0 Natural gas commodity contracts — 1.5 0.2 (0.5 ) 1.2 Total $ 23.1 $ 9.8 $ 0.2 $ (8.4 ) $ 24.7 LIABILITIES Gas Utility NYMEX/ICE natural gas contracts $ 16.4 $ — $ — $ (16.4 ) $ — OTCBB natural gas contracts — 5.9 — — 5.9 NYMEX gasoline and heating oil contracts 0.3 — — (0.3 ) — Subtotal 16.7 5.9 — (16.7 ) 5.9 Gas Marketing NYMEX/ICE natural gas contracts 1.2 3.9 — (5.1 ) — Natural gas commodity contracts — 2.2 — (0.5 ) 1.7 Total $ 17.9 $ 12.0 $ — $ (22.3 ) $ 7.6 Laclede Gas Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Effects of Netting and Cash Margin Receivables /Payables Total As of September 30, 2016 ASSETS US stock/bond mutual funds $ 16.8 $ 4.1 $ — $ — $ 20.9 NYMEX/ICE natural gas contracts 5.3 — — (0.4 ) 4.9 Gasoline and heating oil contracts 0.3 — — (0.3 ) — Total $ 22.4 $ 4.1 $ — $ (0.7 ) $ 25.8 LIABILITIES NYMEX/ICE natural gas contracts $ 1.6 $ — $ — $ (1.6 ) $ — OTCBB natural gas contracts — 0.2 — — 0.2 Total $ 1.6 $ 0.2 $ — $ (1.6 ) $ 0.2 As of September 30, 2015 ASSETS US stock/bond mutual funds $ 15.5 $ 4.0 $ — $ — $ 19.5 NYMEX/ICE natural gas contracts 1.3 — — (1.3 ) — Total $ 16.8 $ 4.0 $ — $ (1.3 ) $ 19.5 LIABILITIES NYMEX/ICE natural gas contracts $ 16.4 $ — $ — $ (16.4 ) $ — OTCBB natural gas contracts — 5.9 — — 5.9 NYMEX gasoline and heating oil contracts 0.3 — — (0.3 ) — Total $ 16.7 $ 5.9 $ — $ (16.7 ) $ 5.9 Alagasco During the fiscal second quarter of 2016 Alagasco commenced a gasoline derivative program to stabilize the cost of fuel used in operations. As of September 30, 2016, the fair value of related gasoline contracts was not significant. |
DERIVATIVE INSTRUMENTS AND HEDG
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES | 12 Months Ended |
Sep. 30, 2016 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES | DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Spire Laclede Gas has a risk management policy to utilize various derivatives, including futures contracts, exchange-traded options, swaps and over-the-counter instruments for the explicit purpose of managing price risk associated with purchasing and delivering natural gas on a regular basis to customers in accordance with its tariffs. The objective of this policy is to limit Laclede Gas’ exposure to natural gas price volatility and to manage, hedge and mitigate substantial price risk. Further discussion of this policy can be found in the Laclede Gas section. From time to time Laclede Gas and Alagasco purchase NYMEX futures and options contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of their business. Further information on these derivatives can be found in the Laclede Gas and Alagasco sections, respectively. In the course of its business, Spire’s gas marketing subsidiary, LER, which includes its wholly owned subsidiary LER Storage Services, Inc., enters into commitments associated with the purchase or sale of natural gas. Certain of LER’s derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815 and are accounted for as executory contracts on an accrual basis. Any of LER’s derivative natural gas contracts that are not designated as normal purchases or normal sales are accounted for at fair value. At September 30, 2016 , the fair values of 122.7 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet. Of these contracts, 110.8 million MMBtu will settle during fiscal year 2017 , and 11.4 million MMBtu, 0.2 million MMBtu, and 0.3 million MMBtu will settle during 2018 , 2019 , and 2020 , respectively. These contracts have not been designated as hedges; therefore, changes in the fair value of these contracts are reported in earnings each period. Furthermore, LER manages the price risk associated with its fixed-priced commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of NYMEX or ICE futures, swap, and option contracts to lock in margins. At September 30, 2016 , LER’s unmatched fixed-price positions were not material to Spire’s financial position or results of operations. LER’s NYMEX and ICE natural gas futures, swap, and option contracts used to lock in margins may be designated as cash flow hedges of forecasted transactions for financial reporting purposes. On April 14, 2014, as amended on July 8, 2014, Spire entered into certain interest rate swap agreements, with a notional amount $375.0 , to effectively lock in interest rates on a portion of the long-term debt it anticipated issuing to finance its acquisition of Alagasco. These derivative instruments were designated as cash flow hedges of forecasted transactions. These forward starting swaps involved the payment of a fixed interest rate and the receipt of a floating interest rate (the London Interbank Offered Rate, also known as LIBOR) over the terms specified in the contracts. On August 6, 2014, the interest rate swap agreements were terminated and the settlement resulted in a $19.0 loss by Spire, which assigned the loss as a regulatory asset since the interest rate swaps were entered into to hedge the interest payments on the $625.0 of long-term debt issued on August 19, 2014 by Spire. During the second quarter of fiscal year 2015, Alagasco entered into certain interest rate swap transactions to protect itself against adverse movement in interest rates in anticipation of its issuance of $115.0 of long-term debt. Alagasco received prior approval from the APSC to enter into these hedges. The notional amount of interest rate swaps outstanding was $80.5 with stated maturities ranging from 2025 to 2045 and fixed interest rates ranging between 2.18% and 2.85% . In April 2015, Alagasco entered into an additional hedge with a notional amount of $24.0 and terms within the same range. These derivative instruments were designated as cash flow hedges of forecasted transactions. These forward starting swaps involved the payment of a fixed interest rate and the receipt of LIBOR over the terms specified in the contracts. On May 21, 2015, the interest rate swap agreements were terminated and the settlement resulted in a $2.7 gain which was recorded as a regulatory liability. Of the total issuance of long-term debt, $35.0 was issued on September 15, 2015 and the remaining $80.0 was issued on December 1, 2015. During the second quarter of fiscal 2016, Spire entered into five -year interest rate swap transactions with a fixed interest rate of 1.776% and a notional amount of $105.0 to protect itself against adverse movement in interest rates in anticipation of the issuance of long-term debt in 2017. During the third quarter of 2016, the Company entered into seven -year swap transactions with an average fixed interest rate of 1.501% and a notional amount of $120.0 to hedge against additional debt expected to be issued in 2017 or early 2018. As a result, a $1.0 mark-to-market gain and $3.0 mark-to-market losses were recognized for the three and twelve months ended September 30, 2016, respectively. On May 5, 2016, Spire entered into certain interest rate swap agreements, with a notional amount of $85.0 , to effectively lock in interest rates on a portion of the long-term debt it anticipated issuing to finance its acquisition of EnergySouth. These derivative instruments were designated as cash flow hedges of forecasted transactions. On June 3, 2016, the interest rate swap agreements were terminated and the settlement resulted in a $0.4 payment recorded in accumulated other comprehensive loss to be amortized over the life of the related debt issuances. The Company’s and Laclede Gas’ exchange-traded/cleared derivative instruments consist primarily of NYMEX, OTCBB, and ICE positions. The NYMEX and OTCBB is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX/ICE and OTCBB natural gas futures and swap positions at September 30, 2016 were as follows: Gas Utility Gas Marketing MMBtu (millions) Avg. Price Per MMBtu MMBtu (millions) Avg. Price Per MMBtu NYMEX/ICE Open short futures positions Fiscal 2017 — $ — 12.20 $ 2.86 Fiscal 2018 — — 1.27 2.95 NYMEX/ICE Open long futures/swap positions Fiscal 2017 18.43 2.95 4.62 3.12 Fiscal 2018 0.33 2.83 0.45 3.02 Fiscal 2019 — — 0.04 2.89 ICE Open long basis swap positions Fiscal 2017 — — 16.62 0.34 Fiscal 2018 — — 2.01 0.43 Fiscal 2019 — — 0.08 0.40 ICE Open short basis swap positions Fiscal 2017 — — 11.88 0.19 Fiscal 2018 — — 0.93 0.27 Fiscal 2019 — — 2.27 0.13 OTC Open long futures/swap positions Fiscal 2017 0.32 3.64 — — At September 30, 2016 , Laclede Gas also had 19.8 million MMBtu of other price mitigation in place through the use of NYMEX and OTCBB natural gas option-based strategies while LER had none. Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the balance sheets of the Company at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income or loss (OCI). Accumulated other comprehensive income or loss (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at September 30, 2016 , it is expected that an immaterial amount of unrealized gains will be reclassified into the Consolidated Statements of Income of the Company during the next twelve months. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the Consolidated Statements of Cash Flows. Effect of Derivative Instruments on the Consolidated Statements of Income and Consolidated Statements of Comprehensive Income Location of Gain (Loss) Recorded in Income 2016 2015 2014 Derivatives in Cash Flow Hedging Relationships Effective portion of gain (loss) recognized in OCI on derivatives: Gas Marketing natural gas contracts $ (0.6 ) $ (4.3 ) $ (4.6 ) Gas Utility gasoline and heating oil contracts — (1.2 ) 0.1 Interest Rate Swaps (3.4 ) — — Total $ (4.0 ) $ (5.5 ) $ (4.5 ) Effective portion of gain (loss) reclassified from AOCI to income: Natural gas contracts Gas Marketing Operating Revenues $ 4.3 $ 1.7 $ 4.2 Gas Marketing Operating Expenses (4.9 ) (5.2 ) (1.5 ) Subtotal (0.6 ) (3.5 ) 2.7 Gasoline and heating oil contracts Gas Utility Other Operating Expenses (0.5 ) (0.9 ) (0.2 ) Total $ (1.1 ) $ (4.4 ) $ 2.5 Ineffective portion of gain (loss) on derivatives recognized in income: Natural gas contracts Gas Marketing Operating Revenues $ 0.1 $ — $ (0.1 ) Gas Marketing Operating Expenses 0.1 (0.5 ) 0.1 Subtotal 0.2 (0.5 ) — Gasoline and heating oil contracts Gas Utility Other Operating Expenses 0.1 0.1 (0.2 ) Total $ 0.3 $ (0.4 ) $ (0.2 ) Derivatives Not Designated as Hedging Instruments* Gain (loss) recognized in income on derivatives: Natural gas commodity contracts Gas Marketing Operating Revenues $ 12.3 $ (1.3 ) $ (8.7 ) NYMEX / ICE natural gas contracts Gas Marketing Operating Revenues (1.7 ) (9.6 ) 3.0 Gasoline and heating oil contracts Other Income and (Income Deductions) - Net — (0.2 ) — Total $ 10.6 $ (11.1 ) $ (5.7 ) * Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Missouri Utilities’ PGA clauses and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the statements of income. Such amounts are recognized in the statements of income as a component of Regulated Gas Distribution Natural and Propane Gas operating expenses when they are recovered through the PGA clause and reflected in customer billings. Fair Value of Derivative Instruments in the Consolidated Balance Sheet Asset Derivatives* Liability Derivatives* September 30, 2016 Balance Sheet Location Fair Value Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gas Utility: Gasoline and heating oil contracts Derivative Instrument Assets $ 0.3 Derivative Instrument Assets $ — Gas Marketing: Natural gas contracts Derivative Instrument Assets 2.5 Derivative Instrument Assets 0.8 Deferred Charges – Other 0.4 Deferred Charges – Other 0.1 Other: Interest swaps Derivative Instrument Assets — Derivative Instrument Assets 3.0 Subtotal 3.2 3.9 Derivatives not designated as hedging instruments Gas Utility: Natural gas contracts Accounts Receivable – Other 5.4 Accounts Receivable – Other 1.6 Derivative Instrument Assets — Derivative Instrument Assets 0.2 Gas Marketing: NYMEX / ICE natural gas contracts Derivative Instrument Assets 0.8 Derivative Instrument Assets 4.1 Deferred Charges – Other — Deferred Charges – Other 0.1 Natural gas commodity Derivative Instrument Assets 6.5 Derivative Instrument Assets 0.2 Other Deferred Charges 2.1 Other Deferred Charges 0.3 Current Liabilities – Other 0.2 Current Liabilities – Other 2.0 Deferred Credits – Other 0.2 Deferred Credits – Other 0.1 Subtotal 15.2 8.6 Total derivatives $ 18.4 $ 12.5 September 30, 2015 Derivatives designated as hedging instruments Gas Utility: Gasoline and heating oil contracts Accounts Receivable – Other $ — Accounts Receivable – Other $ 0.3 Gas Marketing: Natural gas contracts Derivative Instrument Assets 4.1 Derivative Instrument Assets 3.2 Deferred Charges – Other 1.1 Deferred Charges – Other 0.5 Subtotal 5.2 4.0 Derivatives not designated as hedging instruments Gas Utility: Natural gas contracts Accounts Receivable – Other 1.2 Accounts Receivable – Other 16.4 Derivative Instrument Assets — Derivative Instrument Assets 5.7 Deferred Charges – Other — Deferred Charges – Other 0.2 Gas Marketing: NYMEX / ICE natural gas contracts Derivative Instrument Assets 4.7 Derivative Instrument Assets 0.6 Deferred Charges – Other 0.7 Deferred Charges – Other 0.7 Natural gas commodity Derivative Instrument Assets 1.4 Derivative Instrument Assets 0.1 Current Liabilities – Other 0.2 Current Liabilities – Other 1.4 Deferred Credits – Other 0.1 Deferred Credits – Other 0.7 Subtotal 8.3 25.8 Total derivatives $ 13.5 $ 29.8 * The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the balance sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 9 , Fair Value Measurements, for information on the valuation of derivative instruments. Following is a reconciliation of the amounts in the tables above to the amounts presented in the Consolidated Balance Sheets: 2016 2015 Fair value of asset derivatives presented above $ 18.4 $ 13.5 Fair value of cash margin receivables offset with derivatives 2.5 13.9 Netting of assets and liabilities with the same counterparty (7.6 ) (22.2 ) Total $ 13.3 $ 5.2 Derivative Instrument Assets, per Consolidated Balance Sheets: Derivative instrument assets $ 11.4 $ 4.6 Deferred Charges – Other 1.9 0.6 Total $ 13.3 $ 5.2 Fair value of liability derivatives presented above $ 12.5 $ 29.8 Netting of assets and liabilities with the same counterparty (7.6 ) (22.2 ) Total $ 4.9 $ 7.6 Derivative Instrument Liabilities, per Consolidated Balance Sheets: Current Liabilities – Other $ 4.8 $ 6.8 Deferred Credits – Other 0.1 0.8 Total $ 4.9 $ 7.6 Additionally, at September 30, 2016 and 2015 , the Company had $2.9 and $5.9 , respectively, in cash margin receivables not offset with derivatives, which are presented in Accounts Receivable – Other. Laclede Gas Laclede Gas has a risk management policy to utilize various derivatives, including futures contracts, exchange-traded options, swaps and over-the-counter instruments for the explicit purpose of managing price risk associated with purchasing and delivering natural gas on a regular basis to customers in accordance with its tariffs. The objective of this policy is to limit Laclede Gas’ exposure to natural gas price volatility and to manage, hedge and mitigate substantial price risk. This policy strictly prohibits speculation and permits Laclede Gas to hedge current physical natural gas purchase commitments or forecasted or anticipated future peak (maximum) physical need for natural gas delivered. Costs and cost reductions, including carrying costs, associated with Laclede Gas’ use of natural gas derivative instruments are allowed to be passed on to Laclede Gas customers through the operation of its PGA clause, through which the MoPSC allows Laclede Gas to recover gas supply costs, subject to prudence review by the MoPSC. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. Laclede Gas does not designate these instruments as hedging instruments for financial reporting purposes because gains or losses associated with the use of these derivative instruments are deferred and recorded as regulatory assets or regulatory liabilities pursuant to ASC Topic 980, “Regulated Operations,” and, as a result, have no direct impact on the statements of income. The timing of the operation of the PGA clause may cause interim variations in short-term cash flows, because Laclede Gas is subject to cash margin requirements associated with changes in the values of these instruments. Nevertheless, carrying costs associated with such requirements are recovered through the PGA clause. From time to time, Laclede Gas purchases NYMEX futures and options contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At September 30, 2016 , Laclede Gas held 1.8 million gallons of gasoline futures contracts at an average price of $1.37 per gallon. Most of these contracts, the longest of which extends to December 2016, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815, “Derivatives and Hedging.” The gains or losses on these derivative instruments are not subject to Laclede Gas’ PGA clause. Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the balance sheets at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in OCI. AOCI is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at September 30, 2016 , it is expected that an immaterial amount of pre-tax gains will be reclassified into the statements of income during fiscal year 2016. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the statements of cash flows. Laclede Gas’ derivative instruments consist primarily of NYMEX and OTCBB positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX and OTCBB natural gas futures positions at September 30, 2016 were as follows: MMBtu (millions) Avg. Price Per MMBtu NYMEX/ICE Open long futures/swap positions Fiscal 2017 18.43 $ 2.95 Fiscal 2018 0.33 2.83 OTC Open long futures/swap positions Fiscal 2017 0.32 $ 3.64 At September 30, 2016 , Laclede Gas also had 19.8 million MMBtu of other price mitigation in place through the use of NYMEX and OTCBB natural gas option-based strategies. Effect of Derivative Instruments on the Statements of Income and Statements of Comprehensive Income Location of Gain (Loss) Recorded in Income 2016 2015 2014 Derivatives in Cash Flow Hedging Relationships Effective portion of gain (loss) recognized in OCI on derivatives: Gasoline and heating oil contracts $ — $ (1.2 ) $ 0.1 Effective portion of gain (loss) reclassified from AOCI to income: Gasoline and heating oil contracts Gas Utility Other Operating Expenses $ (0.5 ) $ (0.9 ) $ (0.2 ) Ineffective portion of gain (loss) on derivatives recognized in income: Gasoline and heating oil contracts Gas Utility Other Operating Expenses $ 0.1 $ 0.1 $ (0.2 ) Derivatives Not Designated as Hedging Instruments* Gain (loss) recognized in income on derivatives: Gasoline and heating oil contracts Other Income and (Income Deductions) - Net $ — $ (0.2 ) $ — * Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Laclede Gas’ PGA clauses and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Income. Such amounts are recognized in the Statements of Income as a component of Regulated Gas Distribution Natural and Propane Gas operating expenses when they are recovered through the PGA clause and reflected in customer billings. Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2016 Asset Derivatives* Liability Derivatives* Balance Sheet Location Fair Value Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gasoline and heating oil contracts Derivative Instrument Assets $ 0.3 Derivative Instrument Assets $ — Subtotal 0.3 — Derivatives not designated as hedging instruments Natural gas contracts Accounts Receivable – Other 5.4 Accounts Receivable – Other 1.6 OTCBB natural gas contracts Derivative Instrument Assets — Derivative Instrument Assets 0.2 Subtotal 5.4 1.8 Total derivatives $ 5.7 $ 1.8 Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2015 Asset Derivatives Liability Derivatives* Balance Sheet Location Fair Value * Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gasoline and heating oil contracts Accounts Receivable – Other $ — Accounts Receivable – Other $ 0.3 Subtotal — 0.3 Derivatives not designated as hedging instruments Natural gas contracts Accounts Receivable – Other 1.2 Accounts Receivable – Other 16.4 Derivative Instrument Assets — Derivative Instrument Assets 5.7 Deferred Charges - Other — Deferred Charges - Other 0.2 Subtotal 1.2 22.3 Total derivatives $ 1.2 $ 22.6 * The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Balance Sheets. As such, the gross balances presented in the table above are not indicative of Laclede Gas’ net economic exposure. Refer to Note 9 , Fair Value Measurements, for information on the valuation of derivative instruments. Following is a reconciliation of the amounts in the tables above to the amounts presented in Laclede Gas’ Balance Sheets: 2016 2015 Fair value of asset derivatives presented above $ 5.7 $ 1.2 Fair value of cash margin receivables offset with derivatives 0.8 15.5 Netting of assets and liabilities with the same counterparty (1.6 ) (16.7 ) Total $ 4.9 $ — Derivative Instrument Assets, per Balance Sheets: Derivative instrument assets $ 4.9 $ — Total $ 4.9 $ — Fair value of liability derivatives presented above $ 1.8 $ 22.6 Netting of assets and liabilities with the same counterparty (1.6 ) (16.7 ) Total $ 0.2 $ 5.9 Derivative Instrument Liabilities, per Balance Sheets: Current Liabilities – Other $ 0.2 $ 5.7 Deferred Credits – Other — 0.2 Total $ 0.2 $ 5.9 Additionally, at September 30, 2016 and 2015, Laclede Gas had $0.5 and $5.9 , respectively, in cash margin receivables not offset with derivatives, which are presented in Accounts Receivable – Other. Alagasco In prior years, Alagasco entered into cash flow derivative commodity instruments to hedge its exposure to price fluctuations on its gas supply. Alagasco recognizes all derivatives at fair value as either assets or liabilities on the balance sheet. Any realized gains or losses are passed through to customers using the mechanisms of the GSA rider in accordance with Alagasco’s APSC approved tariff. During the second quarter of fiscal year 2015, Alagasco entered into certain interest rate swap transactions to protect itself against adverse movement in interest rates in anticipation of its issuance of $115.0 of long-term debt. Alagasco received prior approval from the APSC to enter into these hedges. The notional amount of interest rate swaps outstanding was $80.5 with stated maturities ranging from 2025 to 2045 and fixed interest rates ranging between 2.18% and 2.85% . In April 2015, Alagasco entered into an additional hedge with a notional amount of $24.0 and terms within the same range. These derivative instruments were designated as cash flow hedges of forecasted transactions. These forward starting swaps involved the payment of a fixed interest rate and the receipt of LIBOR over the terms specified in the contracts. On May 21, 2015, the interest rate swap agreements were terminated and the settlement resulted in a $2.7 gain which was recorded as a regulatory liability. Of the total issuance of long-term debt, $35.0 was issued on September 15, 2015 and the remaining $80.0 was issued on December 1, 2015. During the fiscal second quarter of 2016, Alagasco commenced a gasoline derivative program to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At September 30, 2016 , Alagasco held 0.6 million gallons of gasoline futures contracts at an average price of $1.53 per gallon. Most of these contracts, the longest of which extends to December 2017, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815, “Derivatives and Hedging.” The gains or losses on these derivative instruments are not subject to Alagasco’s GSA clause. As of September 30, 2016, the fair value of related gasoline contracts was not significant. |
CONCENTRATIONS OF CREDIT RISK
CONCENTRATIONS OF CREDIT RISK | 12 Months Ended |
Sep. 30, 2016 | |
Risks and Uncertainties [Abstract] | |
CONCENTRATIONS OF CREDIT RISK | CONCENTRATIONS OF CREDIT RISK Other than in LER (the Gas Marketing segment), Spire has no significant concentration of credit risk. A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of transactions with these counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, LER has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, LER may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, LER may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry from which LER both sells and purchases natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in accounts receivable attributable to energy producers and their marketing affiliates amounted to $15.8 at September 30, 2016 ( $12.4 reflecting netting arrangements). LER’s accounts receivable attributable to utility companies and their marketing affiliates comprised $52.8 of total accounts receivable at September 30, 2016 ( $50.5 reflecting netting arrangements). LER also has concentrations of credit risk with certain individually significant counterparties and with pipeline companies associated with its natural gas receivable amount. At September 30, 2016 , the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure) totaled $31.2 ( $27.2 reflecting netting arrangements). These five counterparties are either investment-grade rated or owned by investment-grade rated companies. |
INCOME TAXES
INCOME TAXES | 12 Months Ended |
Sep. 30, 2016 | |
Income Tax Disclosure [Abstract] | |
INCOME TAXES | INCOME TAXES Spire The Company’s provision for income taxes charged during the fiscal years ended September 30, 2016 , 2015 , and 2014 are as follows: 2016 2015 2014 Federal Current $ 0.1 $ (3.3 ) $ 0.3 Deferred 62.0 58.8 30.6 Investment tax credits (0.2 ) (0.2 ) (0.2 ) State and local Current 0.6 — 0.6 Deferred 7.0 6.9 1.0 Total income tax expense $ 69.5 $ 62.2 $ 32.3 The Company’s effective income tax rate varied from the federal statutory income tax rate for each year due to the following: 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 3.0 1.8 Certain expenses capitalized on books and deducted on tax return (3.4 ) (3.7 ) (4.9 ) Taxes related to prior years (0.2 ) (0.6 ) (0.7 ) Other items – net * (1.7 ) (2.5 ) (3.6 ) Effective income tax rate 32.5 % 31.2 % 27.6 % * Other consists primarily of property adjustments. The Company’s significant items comprising the net deferred tax liability recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 21.3 $ 14.8 Pension and other postretirement benefits 68.3 62.5 Operating losses 102.3 47.3 Other — 1.5 Deferred tax assets 191.9 126.1 Less: valuation allowance 0.9 — Total deferred tax assets 191.0 126.1 Deferred tax liabilities: Relating to property 623.1 472.1 Regulatory pension and other postretirement benefits 106.8 110.6 Deferred gas costs 20.0 8.1 Other 48.4 11.6 Total deferred tax liabilities 798.3 602.4 Net deferred tax liability 607.3 476.3 Net deferred tax asset – current — 5.8 Net deferred tax liability – noncurrent $ 607.3 $ 482.1 In assessing whether deferred tax assets are realizable, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. Management considers all significant available positive and negative evidence, including the existence of losses in recent years, the timing of deferred tax liability reversals, projected future taxable income, taxable income in carryback years, and tax planning strategies to assess the need for a valuation allowance. Based upon this evidence, management believes it is more likely than not the Company will realize the benefits of these deferred tax assets. The Company has federal and state loss carryforwards of approximately $297.0 at September 30, 2016 . The Company also has contribution carryforwards of approximately $12.2 at September 30, 2016 . The loss carryforwards begin to expire in the fiscal year ending 2030 for certain state purposes and 2035 for federal and other states purposes. The contribution carryforwards begin to expire in fiscal year 2017. The Company has established a valuation allowance of $0.9 during the fiscal year as a portion of the charitable contribution carryforward will not be realized prior to its expiration. The Company also has various tax credit carryforwards of approximately $3.5 that begin to expire in 2017. The Company recognizes the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The Company records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are reported as a reduction of a deferred tax asset for an operating loss carryforward. The following table presents a reconciliation of the beginning and ending balances of the Company’s unrecognized tax benefits: 2016 2015 2014 Unrecognized tax benefits, beginning of year $ 7.1 $ 4.6 $ 2.4 Increases related to tax positions taken in current year 3.4 2.9 2.6 Reductions due to lapse of applicable statute of limitations (0.5 ) (0.4 ) (0.4 ) Unrecognized tax benefits, end of year $ 10.0 $ 7.1 $ 4.6 The amount of unrecognized tax benefits which, if recognized, would affect the Company’s effective tax rate were $3.3 and $3.1 as of September 30, 2016 and 2015 , respectively. It is reasonably possible that events will occur in the next 12 months that could increase or decrease the amount of the Company’s unrecognized tax benefits. The Company does not expect that any such change will be significant to the Consolidated Balance Sheets. As of September 30, 2016 and 2015 , interest accrued associated with the Company’s uncertain tax positions was de minimis, and no penalties were accrued as of September 30, 2016 . The Company is subject to US federal income tax as well as income tax in various state and local jurisdictions. The Company is no longer subject to examination for fiscal years prior to 2013. Regarding the Company’s recent EnergySouth acquisition, tax returns for the calendar years 2013 through 2015 remain open and subject to examination by the Internal Revenue Service and state taxing jurisdictions. These returns cover periods during which EnergySouth was owned by Sempra Global. The impact of any adjustments made to these returns by the relevant taxing authorities would be addressed by the indemnification provisions of the stock purchase agreement with Sempra Global. Laclede Gas Laclede Gas’ provision for income taxes charged during the fiscal years ended September 30, 2016 , 2015 , and 2014 are as follows: 2016 2015 2014 Federal Current $ — $ (2.1 ) $ (0.1 ) Deferred 37.5 40.9 34.3 Investment tax credits (0.2 ) (0.2 ) (0.2 ) State and local Current 0.1 (0.1 ) — Deferred 8.0 4.7 1.5 Total income tax expense $ 45.4 $ 43.2 $ 35.5 Laclede Gas’ effective income tax rate varied from the federal statutory income tax rate for each year due to the following: 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 2.8 1.8 Certain expenses capitalized on books and deducted on tax return (4.8 ) (4.9 ) (4.5 ) Taxes related to prior years (0.2 ) (0.8 ) (0.7 ) Other items – net * (2.8 ) (3.0 ) (3.3 ) Effective income tax rate 30.0 % 29.1 % 28.3 % * Other consists primarily of property adjustments. Laclede Gas’ significant items comprising the net deferred tax liability reported in the Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 14.9 $ 15.4 Pension and other postretirement benefits 56.9 62.5 Operating losses 29.9 3.7 Other — 1.5 Deferred tax assets 101.7 83.1 Less: valuation allowance 0.9 — Total deferred tax assets 100.8 83.1 Deferred tax liabilities: Relating to utility property 497.0 425.0 Regulatory pension and other postretirement benefits 106.8 120.2 Deferred gas costs 20.0 8.2 Other 33.9 14.5 Total deferred tax liabilities 657.7 567.9 Net deferred tax liability 556.9 484.8 Net deferred tax asset – current — 0.4 Net deferred tax liability – noncurrent $ 556.9 $ 485.2 Spire files a consolidated federal return and various state income tax returns and allocates income taxes to Laclede Gas and its other subsidiaries as if each entity were a separate taxpayer. In assessing whether deferred tax assets are realizable, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. Management considers all significant available positive and negative evidence, including the existence of losses in recent years, the timing of deferred tax liability reversals, projected future taxable income, taxable income in carryback years, and tax planning strategies to assess the need for a valuation allowance. Based upon this evidence, management believes it is more likely than not that Laclede Gas will realize the benefits of these deferred tax assets. Laclede Gas has state and federal loss carryforwards of approximately $105.0 , at September 30, 2016 , based on a separate company basis. For federal tax purposes, these loss carryforwards may be utilized against income from another member of the consolidated group. Laclede Gas also has contribution carryforwards of approximately $12.0 at September 30, 2016 . The loss carryforwards begin to expire in the fiscal year ending 2035 for federal and state purposes. The contribution carryforwards begin to expire in fiscal year ending 2017. Laclede Gas has established a valuation allowance of $0.9 during the fiscal year as a portion of the charitable contribution carryforward will not be realized prior to its expiration. Laclede Gas also has approximately $2.0 of various tax credit carryforwards with expiration dates which begin to expire in 2017. Laclede Gas recognizes the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. Laclede Gas records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are reported as a reduction of a deferred tax asset for an operating loss carryforward. The following table presents a reconciliation of the beginning and ending balances of Laclede Gas unrecognized tax benefits: 2016 2015 2014 Unrecognized tax benefits, beginning of year $ 6.9 $ 4.2 $ 2.0 Increases related to tax positions taken in current year 3.3 2.9 2.5 Reductions due to lapse of applicable statute of limitations (0.5 ) (0.2 ) (0.3 ) Unrecognized tax benefits, end of year $ 9.7 $ 6.9 $ 4.2 The amount of unrecognized tax benefits, which, if recognized, would affect Laclede Gas’ effective tax rate were $3.1 and $2.9 as of September 30, 2016 and 2015 , respectively. It is reasonably possible that events will occur in the next 12 months that could increase or decrease the amount of Laclede Gas’ unrecognized tax benefits. Laclede Gas does not expect that any such change will be significant to Laclede Gas’ Balance Sheets. As of September 30, 2016 and 2015 , interest accrued associated with Laclede Gas’ uncertain tax positions was de minimis, and no penalties were accrued. Laclede Gas is subject to US federal income tax as well as income tax in various state and local jurisdictions, and is no longer subject to examination for fiscal years prior to 2013. Alagasco Alagasco’s provision for income taxes charged during the fiscal years ended September 30, 2016 and 2015 , and the nine months ended September 30, 2014 , are as follows: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Federal Current $ (0.8 ) $ — $ 14.1 Deferred 29.4 25.9 3.5 State and local Current — 0.1 1.8 Deferred 3.8 3.3 0.5 Total income tax expense $ 32.4 $ 29.3 $ 19.9 Alagasco’s effective income tax rate varied from the federal statutory income tax rate for each year due to the following: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 2.8 2.8 Other items – net 0.1 0.1 (0.2 ) Effective income tax rate 37.9 % 37.9 % 37.6 % Alagasco’s significant items comprising the net deferred tax asset reported in the Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 6.3 $ 7.0 Pension and other postretirement benefits 11.4 9.6 Goodwill 233.4 251.5 Operating losses 60.2 32.4 Other — 1.4 Total deferred tax assets 311.3 301.9 Deferred tax liabilities: Relating to utility property 87.6 45.1 Other 2.3 2.2 Total deferred tax liabilities 89.9 47.3 Net deferred tax asset 221.4 254.6 Net deferred tax asset – current — 6.2 Net deferred tax asset – noncurrent $ 221.4 $ 248.4 Spire files a consolidated federal return and various state income tax returns and allocates income taxes to Alagasco and its other subsidiaries as if each entity were a separate taxpayer. In assessing whether deferred tax assets are realizable, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. Management considers all significant available positive and negative evidence, including the existence of losses in recent years, the timing of deferred tax liability reversals, projected future taxable income, taxable income in carryback years, and tax planning strategies to assess the need for a valuation allowance. Based upon this evidence, management believes it is more likely than not that Alagasco will realize the benefits of these deferred tax assets. On a separate company basis, Alagasco has state and federal loss carryforwards of approximately $159.0 , at September 30, 2016 generated since the acquisition. The loss carryforwards begin to expire in the fiscal year ending 2030 for state purposes and 2035 for federal purposes. For federal tax purposes, these loss carryforwards may be utilized against income from another member of the consolidated group. Alagasco recognizes the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. Alagasco records potential interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Alagasco has reported no unrecognized tax benefits since the acquisition by Spire in August 2014. The following table presents a reconciliation of the beginning and ending balances of Alagasco’s unrecognized tax benefits: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Unrecognized tax benefits, beginning of period $ — $ — $ 0.3 Reduction for transfer of balance to Energen — — (0.3 ) Unrecognized tax benefits, end of period $ — $ — $ — Alagasco is subject to US federal income tax as well as income tax in various state and local jurisdictions. Alagasco’s tax returns for the periods after 2012 remain open and subject to examination by the Internal Revenue Service and state taxing jurisdictions. The returns covering 2013 and 2014 include periods during which Alagasco was owned by Energen. The impact of any adjustments made to those returns by the relevant taxing authorities would be addressed by the indemnification provisions of the stock purchase agreement with Energen. |
PENSION PLANS AND OTHER POSTRET
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS | 12 Months Ended |
Sep. 30, 2016 | |
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract] | |
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS | PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS The Spire information in this note reflects all plans of the Company, including information for plans of EnergySouth since September 12, 2016 and Alagasco since August 31, 2014 . The net pension and postretirement obligations were re-measured at those acquisition dates as well as at the fiscal year end. Pension Plans The pension plans of Spire consist of plans for employees at the Missouri Utilities, plans covering the employees of Alagasco, and plans covering employees for EnergySouth. The Missouri Utilities have non-contributory, defined benefit, trusteed forms of pension plans covering the majority of their employees. Plan assets consist primarily of corporate and US government obligations and a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments and investments in diversified mutual funds. Alagasco has non-contributory, defined benefit, trusteed forms of pension plans covering the majority of its employees. Qualified plan assets are comprised of United States equities consisting of mutual and commingled funds with varying strategies, global equities consisting of mutual funds, alternative investments of limited partnerships and commingled and mutual funds, and fixed income investments. The net periodic pension costs include the following components: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Service cost – benefits earned during the period $ 15.3 $ 17.3 $ 10.2 $ 10.0 $ 11.5 $ 9.7 $ 5.3 $ 5.8 $ 5.1 Interest cost on projected benefit obligation 28.0 29.5 24.5 21.7 23.3 24.0 6.3 6.2 4.1 Expected return on plan assets (34.9 ) (37.4 ) (27.2 ) (26.7 ) (29.2 ) (26.5 ) (8.2 ) (8.2 ) (5.2 ) Amortization of other comprehensive income — — 0.4 — — — — — — Amortization of prior service cost 0.4 0.5 0.5 0.4 0.5 0.5 — — 0.1 Amortization of actuarial loss 8.0 7.5 7.1 7.9 7.5 7.1 0.1 — 2.2 Loss on lump-sum settlements 3.3 19.6 1.5 — 18.0 1.5 3.3 1.6 10.1 Special termination benefits 1.6 — — 1.6 — — — — — Subtotal 21.7 37.0 17.0 14.9 31.6 16.3 6.8 5.4 16.4 Regulatory adjustment 17.8 (2.1 ) 10.4 11.7 (5.2 ) 10.4 6.1 3.1 0.4 Net pension cost $ 39.5 $ 34.9 $ 27.4 $ 26.6 $ 26.4 $ 26.7 $ 12.9 $ 8.5 $ 16.8 * Nine months ended September 30 Other changes in plan assets and pension benefit obligations recognized in other comprehensive income or loss (OCI) include the following: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Current year actuarial loss $ 46.8 $ 48.3 $ 15.7 $ 21.6 $ 26.0 $ 14.2 $ 25.2 $ 22.3 $ 1.5 Amortization of actuarial loss (8.0 ) (7.5 ) (7.1 ) (7.9 ) (7.5 ) (7.1 ) (0.1 ) — — Acceleration of loss recognized due to settlement (3.3 ) (19.6 ) (1.5 ) — (18.0 ) (1.5 ) (3.3 ) (1.6 ) — Amortization of current year service cost 5.0 — — 5.0 — — — — — Amortization of prior service cost (0.4 ) (0.5 ) (0.5 ) (0.4 ) (0.5 ) (0.5 ) — — — Subtotal 40.1 20.7 6.6 18.3 — 5.1 21.8 20.7 1.5 Regulatory adjustment (39.8 ) (21.2 ) (6.1 ) (18.0 ) (0.5 ) (4.7 ) (21.8 ) (20.7 ) (1.5 ) Total recognized in OCI $ 0.3 $ (0.5 ) $ 0.5 $ 0.3 $ (0.5 ) $ 0.4 $ — $ — $ — * Nine months ended September 30 Spire pension obligations are driven by separate plan and regulatory provisions governing Laclede Gas, Alagasco and EnergySouth pension plans. Pursuant to the provisions of the Missouri Utilities’ and Alagasco’s pension plans, pension obligations may be satisfied by lump-sum cash payments. Lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs in a specific year. Special termination benefits, when offered, are also recognized as settlements which can result in gains or losses. Two Alagasco plans and one Laclede plan met the criteria for settlement recognition in the fiscal year ended September 30, 2016 , requiring re-measurement of the obligation under those plans using updated census data and assumptions for discount rate and mortality. Lump-sum payments recognized as settlements during fiscal year 2016 , 2015 , and 2014 were $16.6 (attributable to Alagasco), $71.1 , and $22.1 , respectively. Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four -year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for Laclede Gas’ eastern Missouri qualified pension plan is based on an annual allowance of $15.5 effective January 1, 2011. The recovery in rates for MGE’s qualified pension plan is based on an annual allowance of $10 effective February 20, 2010. The difference between these amounts and pension expense as calculated pursuant to the above and that otherwise would be included in the statements of income and statements of comprehensive income is deferred as a regulatory asset or regulatory liability. The following table shows the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Benefit obligation, beginning of year $ 652.3 $ 692.4 $ 497.6 $ 543.6 $ 154.7 $ 148.8 Service cost 15.3 17.3 10.0 11.5 5.3 5.8 Interest cost 28.0 29.5 21.7 23.3 6.3 6.2 Actuarial loss (gain) 85.8 (12.8 ) 59.2 (20.7 ) 26.6 7.9 Plan amendments 5.1 — 5.1 — — — EnergySouth acquisition 60.4 — — — — — Settlement loss 1.1 16.5 — 14.5 1.1 2.0 Special termination benefits 1.6 — 1.6 — — — Settlement benefits paid (16.6 ) (71.1 ) — (58.2 ) (16.6 ) (12.9 ) Regular benefits paid (38.3 ) (19.5 ) (35.2 ) (16.4 ) (3.1 ) (3.1 ) Benefit obligation, end of year $ 794.7 $ 652.3 $ 560.0 $ 497.6 $ 174.3 $ 154.7 Accumulated benefit obligation, end of year 724.5 $ 591.4 517.7 $ 456.9 149.8 $ 134.5 The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Fair value of plan assets, beginning of year $ 448.9 $ 506.6 $ 339.9 $ 387.4 $ 109.0 $ 119.2 Actual return on plan assets 75.1 (7.2 ) 64.4 (3.0 ) 10.7 (4.2 ) Employer contributions 26.6 40.1 26.6 30.1 — 10.0 EnergySouth acquisition 44.8 — — — — — Settlement benefits paid (16.6 ) (71.1 ) — (58.2 ) (16.6 ) (12.9 ) Regular benefits paid (38.3 ) (19.5 ) (35.2 ) (16.4 ) (3.1 ) (3.1 ) Fair value of plan assets, end of year $ 540.5 $ 448.9 $ 395.7 $ 339.9 $ 100.0 $ 109.0 Funded status of plans, end of year $ (254.2 ) $ (203.4 ) $ (164.3 ) $ (157.7 ) $ (74.3 ) $ (45.7 ) The following table sets forth the amounts recognized in the balance sheets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Current liabilities $ (0.6 ) $ (0.5 ) $ (0.6 ) $ (0.5 ) $ — $ — Noncurrent liabilities (253.6 ) (202.9 ) (163.7 ) (157.2 ) (74.3 ) (45.7 ) Total $ (254.2 ) $ (203.4 ) $ (164.3 ) $ (157.7 ) $ (74.3 ) $ (45.7 ) Pre-tax amounts recognized in accumulated other comprehensive loss not yet recognized as components of net periodic pension cost consist of: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Net actuarial loss $ 179.4 $ 143.9 $ 135.5 $ 121.9 $ 43.9 $ 22.0 Prior service costs 8.2 3.5 8.2 3.5 — — Subtotal 187.6 147.4 143.7 125.4 43.9 22.0 Adjustments for amounts included in regulatory assets (184.8 ) (144.9 ) (140.9 ) (122.9 ) (43.9 ) (22.0 ) Total $ 2.8 $ 2.5 $ 2.8 $ 2.5 $ — $ — At September 30, 2016 , the following pre-tax amounts are expected to be amortized from accumulated other comprehensive loss into net periodic pension cost during fiscal year 2017 : Spire Laclede Gas Alagasco Amortization of net actuarial loss $ 13.5 $ 11.6 $ 1.9 Amortization of prior service cost 1.0 1.0 — Subtotal 14.5 12.6 1.9 Regulatory adjustment (14.2 ) (12.3 ) (1.9 ) Total $ 0.3 $ 0.3 $ — The assumptions used to calculate net periodic pension costs for Laclede Gas are as follows: 2016 2015 2014 Weighted average discount rate - Laclede Gas division plans 4.40% 4.30% 4.70% Weighted average discount rate - MGE division plans 4.50% 4.45% 5.00% Weighted average rate of future compensation increase * 3.00% 3.00% 3.00% Expected long-term rate of return on plan assets * 7.75% 7.75% 7.75% * Assumptions for weighted average rate of future compensation increase and expected long-term rate of return on plan assets are the same for both Laclede Gas and MGE plans. The assumptions used to calculate net periodic pension costs for Alagasco are as follows: 2016 2015 2014* Weighted average discount rate 4.25% /4.30% 4.15% /4.25% 4.00% / 4.05% Weighted average rate of future compensation increase 3.00% 2.92% 2.92% Expected long-term rate of return on plan assets 7.50% 7.00% / 7.25% 7.00% / 7.25% * Nine-month transition period ended September 30 The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The assumptions used to calculate the benefit obligations are as follows: 2016 2015 Weighted average discount rate - Laclede Gas division 3.50% 4.40% Weighted average discount rate - MGE division 3.50% 4.50% Weighted average discount rate - Alagasco 3.45%/3.50% 4.25%/4.30% Weighted average rate of future compensation increase - Laclede Gas, Alagasco and MGE 3.00% 3.00% Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Projected benefit obligation $ 794.8 $ 652.3 $ 560.0 $ 497.6 $ 174.3 $ 154.7 Accumulated benefit obligation 724.5 591.4 517.7 456.9 149.8 134.5 Fair value of plan assets 540.5 448.9 395.7 339.9 100.0 109.0 Following are the targeted and actual plan assets by category as of September 30 of each year for Laclede Gas and Alagasco: Laclede Gas 2016 Target 2016 Actual 2015 Target 2015 Actual Equity markets 56.2 % 56.9 % 52.0 % 48.4 % Debt securities 43.8 % 43.1 % 48.0 % 50.1 % Other* — % — % — % 1.5 % Total 100.0 % 100.0 % 100.0 % 100.0 % * Other investments in 2016 and 2015 consisted of cash equivalents. Alagasco 2016 Target 2016 Actual 2015 Target 2015 Actual Equity markets 60.0 % 59.2 % 60.0 % 52.9 % Debt securities 29.0 % 28.8 % 29.0 % 27.9 % Other* 11.0 % 12.0 % 11.0 % 19.2 % Total 100.0 % 100.0 % 100.0 % 100.0 % * Other investments in 2016 included cash, real estate, commodities, natural resources and TIPS. In 2015, this included cash and cash equivalents, hedge funds, real estate, and all asset funds, which can invest in equities or fixed income. Laclede Gas’ investment policies are designed to maximize, to the extent possible, the funded status of the plan over time, and minimize volatility of funding and costs. The policy seeks to maximize investment returns consistent with these objectives and Laclede Gas’ tolerance for risk. The duration of plan liabilities and the impact of potential changes in asset values on the funded status are fundamental considerations in the selection of plan assets. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with the policy. The policy seeks to avoid significant concentrations of risk by investing in a diversified portfolio of assets. Investments in corporate, US government and agencies, and, to a lesser extent, international debt securities seek to provide duration matching with plan liabilities, and typically have investment grade ratings and reflect allocations across various entities and industries. There are also exposures to additional asset types in the target portfolio: commodities, real estate and inflation-indexed securities. During 2015, the target portfolio was rebalanced to include a higher weighting for the growth (equity) component and a lower weighting to the liability-driven (debt) component. The investment policy permits the use of derivative instruments, which may be used to achieve the desired market exposure of an index, adjust portfolio duration, or rebalance the total portfolio to the target asset allocation. The Growth Strategy utilizes a combination of derivative instruments and debt securities to achieve diversified exposure to equity and other markets while generating returns from the fixed-income investments and providing further duration matching with the liabilities. Performance and compliance with the guidelines is regularly monitored. The policy calls for increased allocations to debt securities as the funded status improves. Alagasco employs a total return investment approach whereby a mix of equities and fixed income investments are used to maximize the long-term return of plan assets with a prudent level of risk. Risk tolerance is established through consideration of plan liabilities, plan funded status, corporate financial condition and market conditions. Alagasco has developed an investment strategy that focuses on asset allocation, diversification and quality guidelines. The investment goals are to obtain an adequate level of return to meet future obligations of the plan by providing above average risk-adjusted returns with a risk exposure in the mid-range of comparable funds. Investment managers are retained by Alagasco to manage separate pools of assets. Funds are allocated to such managers in order to achieve an appropriate, diversified, and balanced asset mix. Comparative market and peer group benchmarks are utilized to ensure that investment managers are performing satisfactorily. Alagasco seeks to maintain an appropriate level of diversification to minimize the risk of large losses in a single asset class. Accordingly, plan assets for the pension plans do not have a concentration of assets in a single entity, industry, country, commodity or class of investment fund. Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter, for Spire, Laclede Gas, and Alagasco: 2017 2018 2019 2020 2021 2022- 2026 Spire $ 61.3 $ 56.2 $ 57.1 $ 56.6 $ 56.8 $ 286.3 Laclede Gas 48.2 43.3 43.5 42.2 40.4 196.6 Alagasco 10.9 10.6 11.2 11.9 13.7 74.5 The funding policy of Laclede Gas and Alagasco is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Laclede Gas contributions to the pension plans in fiscal year 2017 are anticipated to be $29.0 into the qualified trusts, and $0.6 into the non-qualified plans. Alagasco has no required contributions to the qualified pension plans during 2017. Additionally, it is not anticipated that the funded status of the qualified pension plans will fall below statutory thresholds requiring accelerated funding or constraints on benefit levels or plan administration. During fiscal 2017, Alagasco may make additional discretionary contributions to the qualified pension plans depending on the amount and timing of employee retirements and market conditions. Postretirement Benefits The Utilities provide certain life insurance benefits at retirement. Laclede Gas plans provide for medical insurance after early retirement until age 65 . For retirements prior to January 1, 2015, the MGE plans provided medical insurance after retirement until death. For retirements after January 1, 2015, the MGE plans provide medical insurance after early retirement until age 65 . Under the Alagasco plans, medical insurance is currently available upon retirement until death for certain retirees depending on the type of employee and the date the employee was originally hired. Net periodic postretirement benefit costs consist of the following components: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Service cost – benefits earned during the period $ 10.9 $ 12.8 $ 11.3 $ 10.6 $ 12.3 $ 11.2 $ 0.3 $ 0.5 $ 0.4 Interest cost on accumulated postretirement benefit obligation 10.2 11.2 8.9 8.1 8.6 8.7 2.1 2.6 1.9 Expected return on plan assets (13.5 ) (13.2 ) (7.3 ) (8.5 ) (8.1 ) (6.8 ) (5.0 ) (5.1 ) (3.6 ) Amortization of prior other comprehensive loss — — (0.2 ) — — — — — — Amortization of prior service cost 0.3 0.8 — 0.3 0.8 — — — — Amortization of actuarial loss (gain) 3.6 5.1 6.0 3.8 5.1 6.0 (0.2 ) — (1.0 ) Special termination benefits 2.6 — — 2.6 — — — — — Subtotal 14.1 16.7 18.7 16.9 18.7 19.1 (2.8 ) (2.0 ) (2.3 ) Regulatory adjustment (6.6 ) (11.0 ) (9.6 ) (4.8 ) (9.2 ) (9.6 ) (1.8 ) (1.8 ) (0.2 ) Net postretirement benefit cost $ 7.5 $ 5.7 $ 9.1 $ 12.1 $ 9.5 $ 9.5 $ (4.6 ) $ (3.8 ) $ (2.5 ) * Nine months ended September 30 Other changes in plan assets and postretirement benefit obligations recognized in OCI include the following: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Current year actuarial loss (gain) $ 0.8 $ (8.5 ) $ (3.1 ) $ 1.4 $ (2.4 ) $ (4.2 ) $ (0.6 ) $ (6.1 ) $ 1.1 Amortization of actuarial (loss) gain (3.6 ) (5.1 ) (6.0 ) (3.8 ) (5.1 ) (6.0 ) 0.2 — — Amortization of prior service (cost) credit (0.3 ) (0.8 ) 2.5 (0.3 ) (0.8 ) 2.5 — — — Current year prior service credit (1.8 ) (4.9 ) — — (4.9 ) — (1.8 ) — — Subtotal (4.9 ) (19.3 ) (6.6 ) (2.7 ) (13.2 ) (7.7 ) (2.2 ) (6.1 ) 1.1 Regulatory adjustment 4.9 19.3 6.6 2.7 13.2 7.7 2.2 6.1 (1.1 ) Total recognized in OCI $ — $ — $ — $ — $ — $ — $ — $ — $ — * Nine months ended September 30 Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four -year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for Laclede Gas’ postretirement benefit plans is based on an annual allowance of $9.5 effective January 1, 2011. The difference between these amounts and postretirement benefit cost based on the above and that otherwise would be included in the statements of income and statements of comprehensive income is deferred as a regulatory asset or regulatory liability. The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Benefit obligation, beginning of year $ 239.2 $ 258.5 $ 191.9 $ 197.9 $ 47.3 $ 60.6 Service cost 10.9 12.8 10.6 12.3 0.3 0.5 Interest cost 10.2 11.2 8.1 8.6 2.1 2.6 Actuarial loss (gain) 7.1 (23.7 ) 6.7 (10.9 ) 0.4 (12.8 ) Plan amendments (1.8 ) (4.9 ) — (4.9 ) (1.8 ) — EnergySouth acquisition 5.9 — — — — — Special termination benefits 2.6 — 2.6 — — — Retiree drug subsidy program 0.2 0.4 — — 0.2 0.4 Gross benefits paid (15.1 ) (15.1 ) (12.0 ) (11.1 ) (3.1 ) (4.0 ) Benefit obligation, end of year $ 259.2 $ 239.2 $ 207.9 $ 191.9 $ 45.4 $ 47.3 The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Fair value of plan assets at beginning of year $ 223.3 $ 222.5 $ 143.6 $ 137.2 $ 79.7 $ 85.3 Actual return on plan assets 19.9 (2.0 ) 13.8 (0.4 ) 6.2 (1.6 ) Employer contributions 14.3 17.9 14.3 17.9 — — EnergySouth acquisition 4.0 — — — — — Gross benefits paid (15.1 ) (15.1 ) (12.0 ) (11.1 ) (3.1 ) (4.0 ) Fair value of plan assets, end of year $ 246.4 $ 223.3 $ 159.7 $ 143.6 $ 82.8 $ 79.7 Funded status of plans, end of year $ (12.8 ) $ (15.9 ) $ (48.2 ) $ (48.3 ) $ 37.4 $ 32.4 The following table sets forth the amounts recognized in the balance sheets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Current assets $ 0.3 $ — $ 0.3 $ — $ — $ — Noncurrent assets 37.4 35.5 — 3.1 37.4 32.4 Current liabilities (0.4 ) (0.3 ) (0.4 ) (0.3 ) — — Noncurrent liabilities (50.1 ) (51.1 ) (48.1 ) (51.1 ) — — Total $ (12.8 ) $ (15.9 ) $ (48.2 ) $ (48.3 ) $ 37.4 $ 32.4 Pre-tax amounts recognized in accumulated other comprehensive loss not yet recognized as components of net periodic postretirement benefit cost consist of: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Net actuarial loss $ 38.0 $ 40.8 $ 43.4 $ 45.8 $ (5.4 ) $ (5.0 ) Prior service credit (5.2 ) (3.1 ) (3.4 ) (3.1 ) (1.8 ) — Subtotal 32.8 37.7 40.0 42.7 (7.2 ) (5.0 ) Adjustments for amounts included in regulatory assets (32.8 ) (37.7 ) (40.0 ) (42.7 ) 7.2 5.0 Total $ — $ — $ — $ — $ — $ — At September 30, 2016 , the following pre-tax amounts are expected to be amortized from accumulated other comprehensive loss into net periodic postretirement benefit cost during fiscal year 2017: Spire Laclede Gas Alagasco Amortization of net actuarial loss (gain) $ 2.4 $ 2.5 $ (0.1 ) Amortization of prior service cost 0.1 0.3 (0.2 ) Subtotal 2.5 2.8 (0.3 ) Regulatory adjustment (2.5 ) (2.8 ) 0.3 Total $ — $ — $ — The assumptions used to calculate net periodic postretirement benefit costs for Laclede Gas are as follows: 2016 2015 2014 Weighted average discount rate Laclede Gas division plans 4.00 % 4.15 % 4.60 % Weighted average discount rate MGE division plans 4.30 % 4.40 % 4.95 % Weighted average rate of future compensation increase - Laclede Gas plans 3.00 % 3.00 % 3.00 % Expected long-term rate of return on plan assets - Laclede Gas division plans 6.00% / 7.75% 6.25% / 7.75% 6.25% / 7.75% Expected long-term rate of return on plan assets - MGE division plans 4.75 % 5.00 % 3.75% / 5.75% The assumptions used to calculate net periodic postretirement benefit costs for Alagasco are as follows: 2016 2015 2014 Weighted average discount rate 4.50 % 4.40 % 4.25 % Weighted average rate of future compensation increase n/a n/a 2.92 % Expected long-term rate of return on plan assets 4.50% / 7.25% 4.75% / 7.50% 4.75% / 7.25% The weighted average discount rate is based on long-term, high quality bond indices at the measurement date. The expected long-term rate of return on plan assets is based on historical and projected rates of return for current and planned asset classes in the investment portfolio. Assumed projected rates of return for each asset class were selected after analyzing historical experience and future expectations of the returns. The overall expected rate of return for the portfolio was developed based on the target allocation for each class. The assumptions used to calculate the accumulated postretirement benefit obligations for Laclede Gas are as follows: 2016 2015 Weighted average discount rate - Laclede Gas division plans 3.15 % 4.00 % Weighted average discount rate - MGE division plans 3.45 % 4.30 % Weighted average rate of future compensation increase 3.00 % 3.00 % The assumptions used to calculate the accumulated postretirement benefit obligations for Alagasco are as follows: 2016 2015 Weighted average discount rate 3.60 % 4.50 % Weighted average rate of future compensation increase n/a n/a The assumed medical cost trend rates at September 30 are as follows: 2016 2015 Medical cost trend assumed for next year - Laclede Gas 7.50 % 7.00 % Medical cost trend assumed for next year - Alagasco 7.50 % 7.00 % Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate) 5.00 % 5.00 % Year the rate reaches the ultimate trend 2023 2020 The following table presents the effects of an assumed 1% change in the assumed medical cost trend rate: Spire Laclede Gas Alagasco 1% Increase 1% Decrease 1% Increase 1% Decrease 1% Increase 1% Decrease Net periodic postretirement benefit cost $ 1.5 $ (1.4 ) $ 1.5 $ (1.4 ) $ — $ — Accumulated postretirement benefit obligation 11.0 (10.2 ) 9.0 (8.4 ) 1.3 (1.2 ) Following are the targeted and actual plan assets by category as of September 30 of each year for Laclede Gas and Alagasco: Laclede Gas Target 2016 Actual 2015 Actual Equity securities 60.0 % 59.1 % 59.6 % Debt securities 40.0 % 39.4 % 39.7 % Other (cash and cash equivalents) — % 1.5 % 0.7 % Total 100.0 % 100.0 % 100.0 % Alagasco Target 2016 Actual 2015 Actual Equity securities 60.0 % 60.5 % 59.7 % Debt securities 40.0 % 39.5 % 40.3 % Total 100.0 % 100.0 % 100.0 % Missouri state law provides for the recovery in rates of costs accrued pursuant to GAAP provided that such costs are funded through an independent, external funding mechanism. Laclede Gas established Voluntary Employees’ Beneficiary Association and Rabbi Trusts as its external funding mechanisms. Laclede Gas’ investment policy seeks to maximize investment returns consistent with Laclede Gas’ tolerance for risk. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with policy. Performance and compliance with the guidelines is regularly monitored. Laclede Gas’ current investment policy targets an asset allocation of 60% to equity securities and 40% to debt securities, excluding cash held in short-term debt securities for the purpose of making benefit payments. Laclede Gas currently invests in a mutual fund which is rebalanced on an ongoing basis to the target allocation. The mutual fund is diversified across US stock and bond markets. Alagasco established Voluntary Employees’ Beneficiary Association accounts as its external funding mechanisms for post-retirement benefit costs. Alagasco’s investment policy seeks to maximize investment returns consistent with its tolerance for risk. Outside investment management specialists are utilized in each asset class. Such specialists are provided with guidelines, where appropriate, designed to ensure that the investment portfolio is managed in accordance with policy. Performance and compliance with the guidelines is regularly monitored. Alagasco’s current investment policy targets an asset allocation of 60% to equity securities and 40% to debt securities. Alagasco currently invests in several mutual funds which are rebalanced periodically to the target allocation. The mutual funds are diversified across US and international stock markets and the US bond market. Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter for Spire, Laclede Gas, and Alagasco: 2017 2018 2019 2020 2021 2022- 2026 Spire $ 15.4 $ 16.7 $ 17.9 $ 19.1 $ 20.1 $ 108.6 Laclede Gas 12.3 13.7 14.8 15.8 16.8 92.5 Alagasco 2.9 2.8 2.8 2.9 2.9 14.1 Laclede Gas’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Contributions to the postretirement plans in fiscal year 2017 are anticipated to be $10.3 to the qualified trusts and $0.4 paid directly to participants from Laclede Gas funds. Alagasco’s funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. In fiscal 2017 , it is not anticipated that contributions will be made to the postretirement plans. Other Plans Laclede Gas and Alagasco sponsor 401(k) plans that cover substantially all employees. The plans allow employees to contribute a portion of their base pay in accordance with specific guidelines. Laclede Gas provides a match of such contributions within specific limits. The cost of the defined contribution plans of Laclede Gas amounted to $8.2 , $8.0 , and $6.7 for fiscal years 2016 , 2015 , and 2014 , respectively. Alagasco also provides a match of employee contributions within specific limits. The cost of the defined contribution plans of Alagasco amounted to $2.3 , $3.0 , and $4.7 for fiscal years 2016 and 2015 , and the nine months ended September 30, 2014, respectively. Fair Value Measurements of Pension and Other Postretirement Plan Assets Spire The table below categorizes the fair value measurements of the Spire pension plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 51.2 $ — $ — $ 51.2 Stock/bond mutual fund 99.3 26.7 0.1 126.1 Debt Securities US bond mutual funds 23.0 126.0 — 149.0 US government 42.1 3.0 — 45.1 US corporate 137.4 — — 137.4 US municipal 6.3 — — 6.3 International 25.3 — — 25.3 Derivatives and margin (payable) (1.0 ) 1.1 — 0.1 Total $ 383.6 $ 156.8 $ 0.1 $ 540.5 As of September 30, 2015 Cash and cash equivalents $ 43.4 $ 0.2 $ — $ 43.6 Stock/bond mutual fund 46.4 74.6 9.6 130.6 Debt Securities US bond mutual funds — 9.3 — 9.3 US government 58.7 — — 58.7 US corporate 123.7 42.9 — 166.6 US municipal — 5.9 — 5.9 International — 31.3 — 31.3 Derivative instruments — 2.9 — 2.9 Total $ 272.2 $ 167.1 $ 9.6 $ 448.9 The table below categorizes the fair value measurements of Spire’s postretirement plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 4.8 $ — $ — $ 4.8 US stock/bond mutual fund 157.9 68.5 — 226.4 International fund 0.9 14.3 — 15.2 Total $ 163.6 $ 82.8 $ — $ 246.4 As of September 30, 2015 Cash and cash equivalents $ 1.6 $ — $ — $ 1.6 US stock/bond mutual fund 115.5 92.8 — 208.3 International fund — 13.4 — 13.4 Total $ 117.1 $ 106.2 $ — $ 223.3 Cash and cash equivalents include money market mutual funds valued based on quoted market prices. Fair values of derivative instruments are calculated by investment managers who use valuation models that incorporate observable market inputs. Debt securities are valued based on broker/dealer quotations or by using observable market inputs. The stock and bond mutual funds are valued at the quoted market price of the identical securities. Laclede Gas The table below categorizes the fair value measurements of Laclede Gas’ pension plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 46.5 $ — $ — $ 46.5 Stock/bond mutual fund — 14.8 0.1 14.9 Debt Securities US bond mutual funds — 120.2 — 120.2 US government 42.1 3.0 — 45.1 US corporate 137.4 — — 137.4 US municipal 6.3 — — 6.3 International 25.2 — — 25.2 Derivatives and margin (payable) (1.0 ) 1.1 — 0.1 Total $ 256.5 $ 139.1 $ 0.1 $ 395.7 As of September 30, 2015 Cash and cash equivalents $ 31.8 $ — $ — $ 31.8 Stock/bond mutual funds — 67.6 0.1 67.7 Debt Securities US government 37.7 — — 37.7 US corporate 123.7 42.9 — 166.6 US municipal — 5.9 — 5.9 International — 27.3 — 27.3 Derivative instruments — 2.9 — 2.9 Total $ 193.2 $ 146.6 $ 0.1 $ 339.9 The table below categorizes the fair value measurements of Laclede Gas’ postretirement plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 4.6 $ — $ — $ 4.6 US stock/bond mutual funds 155.1 — — 155.1 Total $ 159.7 $ — $ — $ 159.7 As of September 30, 2015 Cash and cash equivalents $ 1.6 $ — $ — $ 1.6 US stock/bond mutual funds 115.5 26.5 — 142.0 Total $ 117.1 $ 26.5 $ — $ 143.6 Cash and cash equivalents include money market mutual funds valued based on quoted market prices. Fair values of derivative instruments are calculated by investment managers who use valuation models that incorporate observable market inputs. Debt securities are valued based on broker/dealer quotations or by using observable market inputs. The stock and bond mutual funds are valued at the quoted market price of the identical securities. Alagasco The table below categorizes the fair value measurements of Alagasco’s pension plan assets: Quoted Prices in Activ |
INFORMATION BY OPERATING SEGMEN
INFORMATION BY OPERATING SEGMENT | 12 Months Ended |
Sep. 30, 2016 | |
Segment Reporting [Abstract] | |
INFORMATION BY OPERATING SEGMENT | INFORMATION BY OPERATING SEGMENT Spire The Company has two reportable segments: Gas Utility and Gas Marketing. The Gas Utility segment is the aggregation of the regulated operations of the Utilities. The Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas and related activities, and LER Storage Services, Inc., which utilizes natural gas storage contracts for providing natural gas sales. Other includes: • unallocated corporate items, including certain debt and associated interest costs, • Laclede Pipeline Company, a subsidiary of Spire which operates a propane pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction, • Spire STL Pipeline, a subsidiary of Spire planning construction of a 70-mile FERC-regulated pipeline to deliver natural gas into eastern Missouri, and • Spire’s subsidiaries that are engaged in compression of natural gas and risk management, among other activities. All subsidiaries are wholly owned. Accounting policies are described in Note 1 , Summary of Significant Accounting Policies. Intersegment transactions include sales of natural gas from LER to Laclede Gas, sales of natural gas from Laclede Gas to LER, risk management services provided by Laclede Insurance Risk Services, Inc. to Laclede Gas, propane transportation services provided by Laclede Pipeline Company to Laclede Gas, and propane storage services provided by Laclede Gas to Laclede Pipeline Company. Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings also exclude the after-tax impacts related to acquisition, divestiture, and restructuring activities. Gas Utility Gas Marketing Other Eliminations Consolidated 2016 Revenues from external customers $ 1,457.2 $ 78.5 $ 1.6 $ — $ 1,537.3 Intersegment revenues 2.2 — 3.2 (5.4 ) — Total Operating Revenues 1,459.4 78.5 4.8 (5.4 ) 1,537.3 Operating Expenses Gas Utility Natural and propane gas 539.7 — — (47.5 ) 492.2 Other operation and maintenance 379.3 — — (1.8 ) 377.5 Depreciation and amortization 136.9 — — — 136.9 Taxes, other than income taxes 125.2 — — — 125.2 Total Gas Utility Operating Expenses 1,181.1 — — (49.3 ) 1,131.8 Gas Marketing and Other — 66.7 (a) 12.6 (b) 43.9 123.2 Total Operating Expenses 1,181.1 66.7 12.6 (5.4 ) 1,255.0 Operating Income (Loss) 278.3 11.8 (7.8 ) — 282.3 Net Economic Earnings (Loss) 160.3 6.4 (17.6 ) — 149.1 Capital Expenditures 291.7 — 1.6 — 293.3 Gas Utility Gas Marketing Other Eliminations Consolidated 2015 Revenues from external customers $ 1,891.8 $ 82.9 $ 1.7 $ — $ 1,976.4 Intersegment revenues 4.0 70.5 2.0 (76.5 ) — Total Operating Revenues 1,895.8 153.4 3.7 (76.5 ) 1,976.4 Operating Expenses Gas Utility Natural and propane gas 957.6 — — (75.2 ) 882.4 Other operation and maintenance 391.6 — — (1.0 ) 390.6 Depreciation and amortization 129.9 — — — 129.9 Taxes, other than income taxes 142.1 — — — 142.1 Total Gas Utility Operating Expenses 1,621.2 — — (76.2 ) 1,545.0 Gas Marketing and Other — 146.6 (a) 12.6 (b) (0.3 ) 158.9 Total Operating Expenses 1,621.2 146.6 12.6 (76.5 ) 1,703.9 Operating Income (Loss) 274.6 6.8 (8.9 ) — 272.5 Net Economic Earnings (Loss) 150.4 4.2 (16.3 ) — 138.3 Capital Expenditures 284.4 — 5.4 — 289.8 Gas Utility Gas Marketing Other Eliminations Consolidated 2014 Revenues from external customers $ 1,462.6 $ 162.6 $ 2.0 $ — $ 1,627.2 Intersegment revenues 5.2 84.0 1.8 (91.0 ) — Total Operating Revenues 1,467.8 246.6 3.8 (91.0 ) 1,627.2 Operating Expenses Gas Utility Natural and propane gas 821.8 — — (90.1 ) 731.7 Other operation and maintenance 288.7 — — (0.9 ) 287.8 Depreciation and amortization 82.4 — — — 82.4 Taxes, other than income taxes 112.0 — — — 112.0 Total Gas Utility Operating Expenses 1,304.9 — — (91.0 ) 1,213.9 Gas Marketing and Other — 226.4 (a) 20.5 (b) — 246.9 Total Operating Expenses 1,304.9 226.4 20.5 (91.0 ) 1,460.8 Operating Income (Loss) 162.9 20.2 (16.7 ) — 166.4 Net Economic Earnings (Loss) 92.8 10.2 (2.9 ) — 100.1 Capital Expenditures 168.6 — 2.4 — 171.0 (a) Depreciation and amortization for Gas Marketing are included in Gas Marketing Expenses on the Consolidated Statements of Income ( $0.1 for 2016 , $0.3 for 2015 , and $0.4 for 2014 ). (b) Depreciation, amortization, and accretion for Other are included in the Other Operating Expenses on the Consolidated Statements of Income ( $0.5 for 2016 , $0.6 for 2015 , and $0.5 for 2014 ). Total Assets at End of Year 2016 2015 2014 Gas Utility $ 5,191.9 $ 4,686.2 $ 4,520.0 Gas Marketing 205.0 160.6 156.7 Other 1,842.4 1,560.2 1,575.7 Eliminations (1,161.9 ) (1,116.8 ) (1,178.4 ) Total Assets $ 6,077.4 $ 5,290.2 $ 5,074.0 Reconciliation of Consolidated Net Income to Consolidated Net Economic Earnings 2016 2015 2014 Net Income (GAAP) $ 144.2 $ 136.9 $ 84.6 Unrealized gain on energy-related derivatives (0.1 ) (2.8 ) (1.6 ) Lower of cost or market inventory adjustments 0.2 0.4 (1.1 ) Realized (gain) loss on economic hedges prior to the sale of the physical commodity (1.6 ) 2.4 (0.4 ) Acquisition, divestiture and restructuring activities 9.2 9.8 29.5 Gain on sale of property — (7.6 ) — Income tax effect of adjustments (2.8 ) (0.8 ) (10.9 ) Net Economic Earnings $ 149.1 $ 138.3 $ 100.1 |
REGULATORY MATTERS
REGULATORY MATTERS | 12 Months Ended |
Sep. 30, 2016 | |
Regulated Operations [Abstract] | |
REGULATORY MATTERS | REGULATORY MATTERS The Utilities account for regulated operations in accordance with ASC Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). The following regulatory assets and regulatory liabilities were reflected in the Balance Sheets as of September 30, 2016 and 2015 . Unamortized Purchased Gas Adjustments are also included below, which are reported separately in the current assets and liabilities sections of each balance sheet. Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Regulatory Assets: Current: Pension and postretirement benefit costs $ 27.0 $ 22.0 $ 20.2 $ 15.5 $ 6.8 $ 6.5 Unamortized purchased gas adjustments 49.7 12.9 43.1 12.9 5.6 — Other 17.2 5.6 3.7 0.7 8.1 4.9 Total Current Regulatory Assets 93.9 40.5 67.0 29.1 20.5 11.4 Noncurrent: Future income taxes due from customers 151.3 134.5 151.3 134.5 — — Pension and postretirement benefit costs 487.9 448.7 375.7 368.0 98.9 80.7 Cost of removal 130.6 78.9 — — 130.6 78.9 Purchased gas costs 12.6 24.1 12.6 24.1 — — Energy efficiency 25.5 22.3 25.5 22.3 — — Other 30.1 29.1 24.7 24.7 1.2 4.0 Total Noncurrent Regulatory Assets 838.0 737.6 589.8 573.6 230.7 163.6 Total Regulatory Assets $ 931.9 $ 778.1 $ 656.8 $ 602.7 $ 251.2 $ 175.0 Regulatory Liabilities: Current: RSE adjustment $ 7.5 $ 12.2 $ — $ — $ 5.0 $ 12.2 Unbilled service margin 5.9 6.4 — — 5.9 6.4 Refundable negative salvage 9.3 10.8 — — 9.3 10.8 Unamortized purchased gas adjustments 1.7 28.2 — — — 28.2 Other 6.2 3.0 1.3 0.6 2.5 2.4 Total Current Regulatory Liabilities 30.6 60.6 1.3 0.6 22.7 60.0 Noncurrent: Postretirement liabilities 28.9 28.9 — — 28.9 28.9 Refundable negative salvage 9.4 16.2 — — 9.4 16.2 Accrued cost of removal 74.8 58.7 55.1 58.7 — — Other 17.6 15.5 12.2 11.9 3.4 3.6 Total Noncurrent Regulatory Liabilities 130.7 119.3 67.3 70.6 41.7 48.7 Total Regulatory Liabilities $ 161.3 $ 179.9 $ 68.6 $ 71.2 $ 64.4 $ 108.7 Regulatory assets are expected to be recovered in rates charged to customers. A portion of the Company’s regulatory assets are not earning a return and are shown in the schedule below: Spire Laclede Gas 2016 2015 2016 2015 Future income taxes due from customers $ 151.3 $ 134.5 $ 151.3 $ 134.5 Pension and postretirement benefit costs 240.6 223.7 240.6 223.7 Compensated absences — — — — Other 12.9 14.2 12.9 14.2 Total Regulatory Assets Not Earning a Return $ 404.8 $ 372.4 $ 404.8 $ 372.4 All of Alagasco’s regulatory assets currently earn a return. These regulatory assets are expected to be recovered from customers in future rates. Excluding deferred income taxes and purchased gas adjustment items, as of September 30, 2016 and 2015 , approximately $404.8 and $372.4 , respectively, of regulatory assets were not earning a rate of return. The Company expects these items to be recovered over a period not to exceed 15 years consistent with precedent set by the MoPSC. The portion of the regulatory asset related to pensions and other postemployment benefits that relates to unfunded differences between the projected benefit obligation and plan assets also does not earn a rate of return. Laclede Gas On November 12, 2015, the MoPSC approved an incremental Infrastructure System Replacement Surcharge (ISRS) amount of $4.4 for Laclede Gas’ eastern Missouri service territory and $1.9 for MGE, effective December 1, 2015, bringing total annualized ISRS revenue to $19.6 for Laclede Gas’ eastern Missouri service territory and $6.7 for MGE’s service territory. On January 15, 2016, the Missouri Office of the Public Counsel (OPC) filed an appeal to Missouri’s Western District Court of Appeals of the MoPSC’s decision permitting Laclede Gas to update its ISRS applications during the pendency of the case. On September 27, 2016, the Western District affirmed the report and order of the MoPSC. On May 19, 2016, the MoPSC approved an incremental ISRS amount of $5.4 for Laclede Gas’ eastern Missouri service territory and $3.6 for MGE, effective May 31, 2016, bringing total annualized ISRS revenue to $25.0 for Laclede Gas’ eastern Missouri service territory and $10.3 for MGE’s service territory. On June 30, 2016, the OPC again filed an appeal to Missouri’s Western District Court of Appeals of the MoPSC’s decision permitting Laclede Gas to update its ISRS applications during the pendency of the case. Laclede Gas believes the MoPSC’s decision was lawful and reasonable, and believes the updating process will again be upheld by the Western District and intends to vigorously oppose the appeal. On September 30, 2016 Laclede Gas filed to increase its ISRS revenues by $5.0 for Laclede Gas’ eastern Missouri service territory and $3.4 for MGE, related to ISRS investments from March 2016 through October 2016. The MoPSC suspended the tariff until January 28, 2017 and directed the MoPSC Staff (Staff) to file a recommendation no later than November 29, 2016. Laclede Gas previously had authority from the MoPSC to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in capital, and enter into capital lease agreements, all for a total of up to $518.0 . This authority was scheduled to expire June 30, 2015. On April 15, 2015, Laclede Gas applied to the MoPSC for a new financing authorization in the amount of $550.0 , and on June 24, 2015, the MoPSC granted an extension of the current authorization until the pending application was resolved. On February 10, 2016, the MoPSC issued an order, by a 3-2 vote, authorizing Laclede financing authority for $300.0 for financings placed any time before September 30, 2018. Laclede Gas filed an application for rehearing, which was denied on March 9, 2016. On March 31, 2016, Laclede Gas filed an appeal with the Western District Court of Appeals concerning this matter. On July 20, 2016, Laclede Gas filed its initial brief before the Court. The MoPSC filed its reply brief on September 19, 2016. Laclede Gas filed its final brief on October 4, 2016. Oral arguments are scheduled for November 17, 2016. Laclede Gas issued no securities under this authorization since the decision and $300.0 remained available for issuance as of November 11, 2016. Alagasco Alagasco is subject to regulation by the APSC which established the Rate Stabilization and Equalization (RSE) rate-setting process in 1983. Alagasco’s current RSE order has a term extending beyond September 30, 2018, unless the APSC enters an order to the contrary in a manner consistent with law. In the event of unforeseen circumstances, whether physical or economic, of the nature of force majeure and including a change in control, the APSC and Alagasco will consult in good faith with respect to modifications, if any. Effective January 1, 2014, Alagasco’s allowed range of return on average common equity is 10.5% to 10.95% with an adjusting point of 10.8% . Alagasco is eligible to receive a performance-based adjustment of 5 basis points to the return on equity adjusting point, based on meeting certain customer satisfaction criteria. Under RSE, the APSC conducts quarterly reviews to determine whether Alagasco’s return on average common equity at the end of the rate year will be within the allowed range of return. Reductions in rates can be made quarterly to bring the projected return within the allowed range; increases, however, are allowed only once each rate year, effective December 1, and cannot exceed 4% of prior-year revenues. There was no RSE reduction for the January 31, 2016 quarterly point of test. Related to the April 30, 2016 quarterly point of test, Alagasco recorded a $5.8 RSE reduction to operating revenues, which the APSC directed, by order dated June 20, 2016, be applied to the Gas Supply Adjustment (GSA) balance. The RSE reduction for the July 31, 2016 quarterly point of test was $4.8 . As of September 30, 2016, Alagasco recorded a $2.7 RSE reduction to operating revenues to bring the expected rate of return on average common equity at the end of the year to within the allowed range of return. The quarterly point of test reductions from rate year 2016 went into effect October 1, 2016 for $4.8 and will go into effect December 1, 2016 for $2.7 . On October 26, 2016, as part of their annual update for RSE, Alagasco filed a $1.3 reduction for rate year 2017, which is subject to review by APSC Staff and becomes effective December 1, 2016 unless otherwise ordered by the APSC. The inflation-based Cost Control Mechanism (CCM), established by the APSC, allows for annual increases to operations and maintenance (O&M) expense. The CCM range is Alagasco’s 2007 actual rate year O&M expense (Base Year) inflation-adjusted using the June Consumer Price Index For All Urban Consumers each rate year plus or minus 1.75% (Index Range). If rate year O&M expense falls within the Index Range, no adjustment is required. If rate year O&M expense exceeds the Index Range, three-quarters of the difference is returned to customers through future rate adjustments. To the extent that rate year O&M is less than the Index Range, Alagasco benefits by one-half of the difference through future rate adjustments. Certain items that fluctuate based on situations demonstrated to be beyond Alagasco’s control may be excluded from the CCM calculation. A CCM benefit to the company for such cost saving of $7.8 related to 2016 will be reflected in rates effective December 1, 2016. The CCM benefit was $4.7 for 2015. |
COMMITMENTS AND CONTINGENCIES
COMMITMENTS AND CONTINGENCIES | 12 Months Ended |
Sep. 30, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
COMMITMENTS AND CONTINGENCIES | COMMITMENTS AND CONTINGENCIES Commitments The Company and the Utilities have entered into contracts with various counterparties, expiring on dates through 2031, for the storage, transportation, and supply of natural gas. Minimum payments required by the Company under the contracts in place at September 30, 2016 are estimated at $1,647.8 . Minimum payments required for Laclede Gas and Alagasco under the contracts are estimated at $1,227.6 and $352.7 , respectively. Additional contracts are generally entered into prior to or during the heating season of November through April. The Missouri Utilities recover their costs from customers in accordance with their PGA clause and Alagasco recovers its cost through its GSA rider. Alagasco’s long-term contracts associated with the delivery and storage of natural gas include fixed charges of approximately $352.7 through August 2020. Alagasco also is committed to purchase minimum quantities of gas at market-related prices or to pay certain costs in the event the minimum quantities are not taken. These purchase commitments are approximately 93 Bcf through August 2020. Laclede Pipeline Company (Pipeline), a wholly owned subsidiary of Spire, is providing liquid propane transportation service to Laclede Gas pursuant to an approved FERC tariff and a contractual arrangement between Pipeline and Laclede Gas. In accordance with the terms of that agreement, Laclede Gas is obligated to pay Pipeline approximately $1.0 annually, at current rates. The agreement renews at the end of each contract year, unless terminated by either party upon provision of at least six months’ notice. Leases and Guarantees Aggregate rental expense and annual minimum rental commitments under all leases having an initial or remaining non-cancelable term of more than one year are shown below: Aggregate Rental Expense Minimum Rental Commitments 2016 2015 2014 2017 2018 2019 2020 2021 Later Total Spire $ 11.9 $ 14.1 $ 6.7 $ 10.5 $ 7.5 $ 7.3 $ 6.2 $ 6.0 $ 53.4 $ 90.9 Laclede Gas 4.3 7.6 6.3 2.5 0.9 0.9 0.3 0.1 — 4.7 Alagasco 3.7 4.0 2.0 3.9 2.5 2.5 2.1 2.1 4.9 18.0 The lease agreement covering the primary office space of Spire and its Missouri Utilities extends through February 2035. Laclede Gas has entered into various operating lease agreements for the rental of vehicles and power operated equipment. The lease agreement covering the primary office space of Alagasco extends through February 2018. Alagasco has an operating lease for additional office space that extends to January 31, 2024. Alagasco has subleased all of this office space to Energen pursuant to a sublease that expires on December 31, 2019 with an option to extend through January 31, 2024. Amounts in the table above have not been reduced for sublease rentals. For Alagasco and Spire, sublease rentals were $2.1 , $2.1 , and $0.2 for fiscal years 2016, 2015, and 2014, and minimum future rentals to be received in fiscal years 2017, 2018, 2019, and 2020 are $2.1 , $2.1 , $2.1 , and $0.5 , respectively. Laclede Gas, Alagasco and LER have other relatively minor rental arrangements that provide for minimum rental payments. A consolidated subsidiary is a general partner in an unconsolidated partnership that invests in real estate partnerships. The subsidiary and third parties are jointly and severally liable for the payment of mortgage loans in the aggregate outstanding amount of approximately $1.4 incurred in connection with various real estate ventures. Spire has no reason to believe that the other principal liable parties will not be able to meet their proportionate share of these obligations. Spire further believes that the asset values of the real estate properties are sufficient to support these mortgage loans. Contingencies The Company and Utilities account for environmental liabilities and other contingencies in accordance with accounting standards under the loss contingency guidance of ASC Topic 450, “Contingencies,” when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company and the Utilities own and operate natural gas distribution, transmission, and storage facilities, the operations of which are subject to various environmental laws, regulations, and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Utilities’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, the Company or the Utilities may incur additional environmental liabilities that may result in additional costs. In addition to matters noted below, the Company, Laclede Gas, and Alagasco are involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the consolidated statements of income, balance sheets, and statements of cash flows of the Company, Laclede Gas, or Alagasco. However, there is uncertainty in the valuation of pending claims and prediction of litigation results. In the natural gas industry, many gas distribution companies have incurred environmental liabilities associated with sites they or their predecessor companies formerly owned or operated where manufactured gas operations took place. The Utilities each have former manufactured gas plant (MGP) operations in their respective service territories. Laclede Gas Laclede Gas has identified three former MGP sites in eastern Missouri where costs have been incurred and claims have been asserted: one in Shrewsbury, Missouri and two in the City of St. Louis, Missouri. Laclede Gas has enrolled the two sites in the City of St. Louis in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP). In Laclede Gas’ western service area, MGE has enrolled all of its owned former MGP sites in the BVCP. With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, Environmental Protection Agency (EPA) Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after this termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs. In conjunction with redevelopment of one of the sites located in the City of St. Louis, Laclede Gas and another former owner of the site entered into an agreement (Remediation Agreement) with the City development agencies, the developer, and an environmental consultant that obligates one of the City agencies and the environmental consultant to remediate the site and obtain a No Further Action letter from the Missouri Department of Natural Resources (MDNR). The Remediation Agreement also provides for a release of Laclede Gas and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance coverage, including remediation cost containment, premises pollution liability, and professional liability. The operative provisions of the Remediation Agreement were triggered on December 20, 2010, on which date Laclede Gas and the other former site owner, as full consideration under the Remediation Agreement, paid a small percentage of the cost of remediation of the site. The amount paid by Laclede Gas did not materially impact the financial condition, results of operations, or cash flows of the Company. Laclede Gas has not owned the other site located in the City of St. Louis for many years. In a letter dated June 29, 2011, the Attorney General for the state of Missouri informed Laclede Gas that the MDNR had completed an investigation of the site. The Attorney General requested that Laclede Gas participate in the follow up investigations of the site. In a letter dated January 10, 2012, Laclede Gas stated that it would participate in future environmental response activities at the site in conjunction with other potentially responsible parties (PRPs) that are willing to contribute to such efforts in a meaningful and equitable fashion. Accordingly, Laclede Gas entered into a cost sharing agreement for remedial investigation with other PRPs. Pending MDNR approval which has not occurred as of the date of filing, the remedial investigation of the site will begin. Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them. On March 10, 2015, Laclede Gas received a Section 104(e) information request from EPA Region VII regarding the former Thompson Chemical/Superior Solvents site in St. Louis, Missouri. In turn, Laclede Gas issued a Freedom of Information Act (FOIA) request to the EPA on April 3, 2015, in an effort to identify the basis of the inquiry. The FOIA response from the EPA was received on July 15, 2015 and a response was provided to the EPA on August 15, 2015. MGE has seven owned MGP sites enrolled in the BVCP, including Joplin MGP #1, St. Joseph MGP #1, Kansas City Coal Gas Station B, Kansas City Station A Railroad area, Kansas City Coal Gas Station A North, Kansas City Coal Gas Station A South, and Independence MGP #2. Source removal has been conducted at all of the owned sites since 2003 with the exception of Joplin. On September 15, 2016, a request was made with the MDNR for a restrictive covenant use limitation with respect to Joplin. Remediation efforts at the seven sites are at various stages of completion, ranging from groundwater monitoring and sampling following source removal activities to the aforementioned request in respect to Joplin. As part of its participation in the BVCP, MGE communicates regularly with the MDNR with respect to its remediation efforts and monitoring activities at these sites. On May 11, 2015, MDNR approved the next phase of investigation at the Kansas City Station A North and Railroad area. To date, costs incurred for all Missouri Utilities’ MGP sites for investigation, remediation and monitoring these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. The actual future costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remediation actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and government regulations, the ultimate ability of other potential responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries. In 2013, Laclede Gas retained an outside consultant to conduct probabilistic cost modeling of 19 former MGP sites owned or operated by Laclede Gas in eastern Missouri or MGE in western Missouri. The purpose of this analysis was to develop an estimated range of probabilistic future liability for each site. That analysis, completed in August 2014, provided a range of demonstrated possible future expenditures to investigate, monitor and remediate all 19 MGP sites. Laclede Gas has recorded its best estimate of the probable expenditures that relate to these matters. The amount is not material. Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable. To the extent such costs (less any amounts received from insurance proceeds or as contributions from other PRP’s), are incurred prior to a rate case, Laclede Gas would request from the MoPSC authority to defer such costs and collect them in the next rate case. Laclede Gas and the Company do not expect potential liabilities that may arise from remediating these sites to have a material impact on their future financial condition or results of operations. Alagasco Alagasco is in the chain of title of nine former MGP sites, four of which it still owns, and five former manufactured gas distribution sites, one of which it still owns. As of September 30, 2016, Alagasco does not foresee a probable or reasonably estimable loss associated with these nine sites. Alagasco and the Company do not expect potential liabilities that may arise from remediating these sites to have a material impact on their future financial conditions or results of operations. In 2012, Alagasco responded to an EPA Request for Information Pursuant to Section 104 of the Comprehensive Environment Response, Compensation, and Liability Act (CERCLA) relating to the 35th Avenue Superfund Site located in North Birmingham, Jefferson County, Alabama. Alagasco was identified as a PRP under CERCLA for the cleanup of the site or costs the EPA incurs in cleaning up the site. At this point, Alagasco has not been provided information that would allow it to determine the extent, if any, of its potential liability with respect to the 35th Avenue Superfund Site and vigorously denies its inclusion as a PRP. On December 17, 2013, an incident occurred at a Housing Authority apartment complex in Birmingham, Alabama which resulted in one fatality, personal injuries and property damage. Alagasco cooperated with the National Transportation Safety Board (NTSB) which investigated the incident. The NTSB report of findings was issued on March 30, 2016 and no safety recommendations, fines, or penalties were contained therein. Alagasco has been named as a defendant in several lawsuits arising from the incident, and additional lawsuits and claims may be filed against Alagasco. Mobile Gas Mobile Gas is in the chain of title of one former MGP site which it still owns in Mobile, Alabama. On September 15, 2010, Mobile Gas filed an application to enroll the site into the Alabama Department of Environmental Management’s (ADEM) Voluntary Cleanup Program (VCP). This application was accepted by ADEM on November 16, 2010. Investigation and testing have been completed. As of September 30, 2016, Mobile Gas has an approved remediation plan from ADEM which is currently in the process of being executed. Mobile Gas and the Company do not expect potential liabilities that may arise from remediating this site to have a material impact on their future financial conditions or results of operations. Since April 2012, a total of 14 lawsuits have been filed against Mobile Gas in Mobile County Circuit Court alleging that in the first half of 2008, Mobile Gas spilled tert-butyl mercaptan, an odorant added to natural gas for safety reasons, in Eight Mile, Alabama. Eleven of the lawsuits have been settled. The remaining three lawsuits, which include approximately 270 individual plaintiffs, allege nuisance, fraud and negligence causes of actions, and seek unspecified compensatory and punitive damages. A claim has been made against the insurance carriers for Mobile Gas requesting reimbursement for costs accrued in respect to this spill. Mobile Gas and the Company do not expect potential liabilities that may arise from these lawsuits to have a material impact on their future financial conditions or results of operations. |
INTERIM FINANCIAL INFORMATION (
INTERIM FINANCIAL INFORMATION (UNAUDITED) | 12 Months Ended |
Sep. 30, 2016 | |
Quarterly Financial Information Disclosure [Abstract] | |
INTERIM FINANCIAL INFORMATION (UNAUDITED) | INTERIM FINANCIAL INFORMATION (UNAUDITED) Spire In the opinion of Spire, the quarterly information presented below for fiscal years 2016 and 2015 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in consolidated operations reported on a quarterly basis primarily reflect the seasonal nature of the business of the Utilities. Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 399.4 $ 609.3 $ 249.3 $ 279.3 Operating Income (Loss) 87.0 167.7 35.3 (7.7 ) Net Income (Loss) 46.9 100.8 10.7 (14.2 ) Basic Earnings (Loss) Per Share of Common Stock $ 1.08 $ 2.32 $ 0.24 $ (0.31 ) Diluted Earnings (Loss) Per Share of Common Stock $ 1.08 $ 2.31 $ 0.24 $ (0.31 ) Fiscal Year 2015 Total Operating Revenues $ 619.6 $ 877.4 $ 275.2 $ 204.2 Operating Income (Loss) 87.3 157.7 36.0 (8.5 ) Net Income (Loss) 47.1 94.4 14.1 (18.7 ) Basic Earnings (Loss) Per Share of Common Stock $ 1.09 $ 2.18 $ 0.32 $ (0.43 ) Diluted Earnings (Loss) Per Share of Common Stock $ 1.09 $ 2.18 $ 0.32 $ (0.43 ) Laclede Gas In the opinion of Laclede Gas, the quarterly information presented below for fiscal years 2016 and 2015 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in operations reported on a quarterly basis primarily reflect their seasonal nature. Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 317.2 $ 446.7 $ 179.3 $ 144.3 Operating Income 65.1 87.0 29.4 5.4 Net Income (Loss) 39.4 54.3 13.9 (1.7 ) Fiscal Year 2015 Total Operating Revenues $ 462.4 $ 615.7 $ 187.5 $ 151.0 Operating Income 64.8 80.6 34.5 5.5 Net Income (Loss) 39.0 49.9 20.0 (3.6 ) Alagasco In the opinion of Alagasco, the quarterly information presented below for fiscal years 2016 and 2015 includes all adjustments (consisting of only normal recurring accruals) necessary for a fair statement of the results of operations for such periods. Variations in operations reported on a quarterly basis primarily reflect their seasonal nature. Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 82.3 $ 166.0 $ 74.0 $ 46.2 Operating Income (Loss) 18.9 80.4 9.3 (17.1 ) Net Income (Loss) 9.9 48.1 4.0 (8.8 ) Fiscal Year 2015 Total Operating Revenues $ 120.0 $ 233.3 $ 73.7 $ 52.2 Operating Income (Loss) 20.4 77.4 3.9 (12.5 ) Net Income (Loss) 10.6 46.3 0.7 (9.6 ) |
SUMMARY OF SIGNIFICANT ACCOUN29
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies) | 12 Months Ended |
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
BASIS OF PRESENTATION | BASIS OF PRESENTATION – These notes are an integral part of the accompanying audited financial statements of Spire Inc. (Spire or the Company), as well as Laclede Gas Company (Laclede Gas or the Missouri Utilities) and Alabama Gas Corporation (Alagasco). Laclede Gas, which includes the operations of Missouri Gas Energy (MGE), and Alagasco are wholly owned subsidiaries of the Company. Laclede Gas, Alagasco and the subsidiaries of EnergySouth, Inc. (EnergySouth) are collectively referred to as the Utilities. The subsidiaries of EnergySouth are Mobile Gas Service Corporation (Mobile Gas) and Willmut Gas and Oil Company (Willmut Gas). The accompanying audited financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). The consolidated financial position, results of operations, and cash flows of Spire are primarily derived from the financial position, results of operations, and cash flows of the Utilities. In compliance with GAAP, transactions between Laclede Gas and Alagasco and their affiliates, as well as intercompany balances on their balance sheets, have not been eliminated from their separate financial statements. The Company’s September 12, 2016 acquisition of EnergySouth and the August 31, 2014 acquisition of Alagasco are included in the results of operations since their acquisition dates and impact the comparability of the financial statement periods presented for the Company. For a further discussion of the acquisitions, see Note 2 , Acquisitions. The Utilities are regulated natural gas distribution utilities. Due to the seasonal nature of the Utilities, the earnings of Spire, Laclede Gas and Alagasco are typically concentrated during the heating season of November through April each fiscal year. Effective September 2, 2014, Alagasco amended its bylaws to change Alagasco’s fiscal year from beginning January 1 and ending on December 31, to beginning October 1 and ending September 30. As a result, the financial statements covering the nine-month period from January 1, 2014 through September 30, 2014 (the “transition period”) were included in Alagasco’s transition report on Form 10-K/T for such period and are presented in the financial statements and notes herein. |
USE OF ESTIMATES | USE OF ESTIMATES – The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates. |
SYSTEM OF ACCOUNTS | SYSTEM OF ACCOUNTS – The accounts of the Utilities are maintained in accordance with the Uniform System of Accounts prescribed by the applicable state public service commissions, which systems substantially conform to that prescribed by the Federal Energy Regulatory Commission (FERC). |
UTILITY PLANT, DEPRECIATION AND AMORTIZATION | UTILITY PLANT, DEPRECIATION AND AMORTIZATION – Utility plant is stated at original cost. The cost of additions to utility plant includes contracted work, direct labor and materials, allocable overheads, and an allowance for funds used during construction. The costs of units of property retired, replaced, or renewed are removed from utility plant and are charged to accumulated depreciation. Maintenance and repairs of property and replacement and renewal of items determined to be less than units of property are charged to maintenance expenses. For Laclede Gas, utility plant is depreciated on a straight-line basis at rates based on estimated service lives of the various classes of property. In fiscal years 2016 , 2015 and 2014 , annual depreciation and amortization expense averaged 3.0% of the original cost of depreciable and amortizable property. Laclede Gas’ capital expenditures were $197.8 , $198.6 and $163.0 for fiscal years 2016 , 2015 , and 2014 , respectively. Additionally, Laclede Gas had recorded accruals for capital expenditures totaling $14.8 at September 30, 2016 , $9.6 at September 30, 2015 , and $3.0 at September 30, 2014 . For Alagasco, depreciation is provided using the composite method of depreciation on a straight-line basis over the estimated useful lives of utility property at rates approved by the Alabama Public Service Commission (APSC). |
ASSET RETIREMENT OBLIGATIONS | ASSET RETIREMENT OBLIGATIONS – Spire, Laclede Gas, and Alagasco record legal obligations associated with the retirement of long-lived assets in the period in which the obligations are incurred, if sufficient information exists to reasonably estimate the fair value of the obligations. Obligations are recorded as both a cost of the related long-lived asset and as a corresponding liability. Subsequently, the asset retirement costs are depreciated over the life of the asset and the asset retirement obligations are accreted to the expected settlement amounts. The Company, Laclede Gas and Alagasco record asset retirement obligations associated with certain safety requirements to purge and seal gas distribution mains upon retirement, the plugging and abandonment of storage wells and other storage facilities, specific service line obligations, and certain removal and disposal obligations related to components of Laclede Gas’, Alagasco’s and Mobile Gas’ distribution systems and general plant. Asset retirement obligations recorded by Spire’s other subsidiaries are not material. As authorized by the Missouri Public Service Commission (MoPSC) and APSC, Laclede Gas, Alagasco and Mobile Gas accrue future asset removal costs associated with their property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation expense and are recorded with corresponding credits to regulatory liabilities or assets. When those utilities retire depreciable utility plant and equipment, they charge the associated original costs to accumulated depreciation and amortization, and any related removal costs incurred are charged to regulatory liabilities or assets. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognized for financial reporting purposes is a timing difference between recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred as regulatory liabilities or assets. In the rate setting process, the regulatory liability or asset is excluded from the rate base upon which those utilities have the opportunity to earn their allowed rates of return. The costs associated with asset retirement obligations of Laclede Gas, Alagasco and Mobile Gas are either currently being recovered in rates or are probable of recovery in future rates. |
REGULATED OPERATIONS | REGULATED OPERATIONS – The Utilities account for their regulated operations in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. In addition, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. See additional discussion on regulated operations in Note 15 , Regulatory Matters. As discussed below for Laclede Gas and Alagasco, the Purchased Gas Adjustment (PGA) clauses and Gas Supply Adjustment (GSA) riders allow the Utilities to pass through to customers the cost of purchased gas supplies. Regulatory assets and liabilities related to the PGA clauses and the GSA rider are both labeled Unamortized Purchased Gas Adjustments herein. Laclede Gas As authorized by the MoPSC, the PGA clause allows Laclede Gas to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. To better match customer billings with market natural gas prices, Laclede Gas is allowed to file to modify, on a periodic basis, the level of gas costs in its PGA. Certain provisions of the PGA clause are included below: • Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. The MoPSC clarified that costs, cost reductions, and carrying costs associated with the Utility’s use of natural gas derivative instruments are gas costs recoverable through the PGA mechanism. • The tariffs allow Laclede Gas flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months . • Laclede Gas is authorized to apply carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, including cash payments for margin deposits. Laclede Gas’ eastern Missouri service territory is also authorized to recover gas inventory carrying costs through its PGA rates to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. • The MoPSC approved a plan applicable to Laclede Gas’ gas supply commodity costs under which it retains a portion of cost savings associated with the acquisition of natural gas below an established benchmark level. This gas supply cost management program allows Laclede Gas to retain 10% of cost savings, up to a maximum of $3.0 annually. Laclede Gas did not record any income under the plan during the three fiscal years reported. Income recorded under the plan, if any, is included in Gas Utility Operating Revenues on the Consolidated Statements of Income and under Operating Revenues on Laclede Gas’ Statements of Income. Pursuant to the provisions of the PGA clause, the difference between actual costs incurred and costs recovered through the application of the PGA clause are reflected as a deferred charge or credit at the end of the fiscal year. These costs include costs and cost reductions associated with the use of derivative instruments and gas inventory carrying costs, amounts due to or from customers related to operation of the gas supply cost management program, refunds received from the Company’s suppliers in connection with gas supply, transportation, and storage services, and carrying costs on such over- or under-recoveries. At that time, the balance is classified as a current asset or current liability and recovered from, or credited to, customers over an annual period commencing in November. The balance in the current account is amortized as amounts are reflected in customer billings. The PGA clause also provides for the treatment of income from off-system sales and capacity release revenues. Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November. The customer share of such income is determined in accordance with the following tables, shown for each service territory for which the PGA clauses were approved by the MoPSC. Customer Share Company Share Eastern Missouri First $2.0* 100% —% Next $2.0 80% 20% Next $2.0 75% 25% Amounts exceeding $6.0 70% 30% * Customer share reverts to 85% and company share reverts to 15% in 2017. Western Missouri First $1.2 85% 15% Next $1.2 80% 20% Next $1.2 75% 25% Amounts exceeding $3.6 70% 30% Alagasco Alagasco’s rate schedules for natural gas distribution charges contain a GSA rider, established in 1993, which permits the pass-through to customers of changes in the cost of gas supply. Alagasco’s tariff provides a temperature adjustment mechanism, also included in the GSA rider, which is designed to moderate the impact of departures from normal temperatures on Alagasco’s earnings. The temperature adjustment applies primarily to residential, small commercial and small industrial customers. Other non-temperature weather-related conditions that may affect customer usage are not included in the temperature adjustment. |
NATURAL GAS AND PROPANE GAS | NATURAL GAS AND PROPANE GAS – For Laclede Gas’ eastern Missouri utility, inventory of natural gas in storage is priced on a last in, first out (LIFO) basis and inventory of propane gas in storage is priced on a first in, first out (FIFO) basis. For the rest of the Gas Utility segment, inventory of natural gas in storage is priced on the weighted average cost basis. The replacement cost of Laclede Gas’ natural gas for current use in eastern Missouri at September 30, 2016 and September 30, 2015 was less than the LIFO cost by $11.4 and $20.4 , respectively. The carrying value of Laclede Gas’ inventory is not adjusted to the lower of cost or market prices because, pursuant to the Missouri Utilities’ PGA clauses, actual gas costs are recovered in customer rates. Natural gas and propane gas storage inventory in Spire’s other operating segments is recorded at the lower of average cost or market. |
BUSINESS COMBINATIONS | BUSINESS COMBINATIONS – The EnergySouth and Alagasco acquisitions are accounted for by Spire using business combination accounting. Under this method, the purchase price paid by the acquirer is allocated to the assets acquired and liabilities assumed as of the acquisition date based on their fair value. |
GOODWILL | GOODWILL – Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. Spire and Laclede Gas evaluate goodwill for impairment as of July 1st of each year, or more frequently if events and circumstances indicate that goodwill might be impaired. At July 1, 2016, 2015 and 2014, Spire and Laclede Gas each applied a quantitative goodwill evaluation model to their reporting units and concluded goodwill was not impaired because the fair value exceeded the carrying amount. |
IMPAIRMENT OF LONG-LIVED ASSETS | IMPAIRMENT OF LONG-LIVED ASSETS – Long-lived assets classified as held and used are evaluated for impairment when events or changes in circumstances indicate that the carrying value of such assets may not be recoverable. Whether impairment has occurred is determined by comparing the estimated undiscounted cash flows attributable to the assets with the carrying value of the assets. If the carrying value exceeds the undiscounted cash flows, the Company recognizes an impairment charge equal to the amount of the carrying value that exceeds the estimated fair value of the assets. In the period in which the Company determines an asset meets held-for-sale criteria, an impairment charge is recorded to the extent the book value exceeds its fair value less cost to sell. |
REVENUE RECOGNITION | REVENUE RECOGNITION – The Utilities read meters and bill customers on monthly cycles. The Missouri Utilities record their gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues for Laclede Gas at September 30, 2016 and 2015 were $26.1 and $27.6 , respectively. Alagasco records natural gas distribution revenues in accordance with the tariff established by the APSC. The amount of accrued unbilled revenues, which are not recorded as revenues until billed, for Alagasco at September 30, 2016 and 2015 were $5.9 and $6.4 , respectively. All related costs and margins are also deferred. The subsidiaries of EnergySouth record natural gas revenues in accordance with tariffs established by the APSC and MSPSC. Unbilled revenues are accrued and related costs and margins are also deferred. Spire’s other subsidiaries, including LER, record revenues when earned, either when the product is delivered or when services are performed. In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. Certain of its derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815, “Derivatives and Hedging.” Those contracts are accounted for as executory contracts and recorded on an accrual basis. Revenues and expenses from such contracts are recorded using a gross presentation. Contracts not designated as normal purchases or normal sales are recorded as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. For additional information on derivative instruments, refer to Note 10 , Derivative Instruments and Hedging Activities. Certain of LER’s wholesale purchase and sale transactions are classified as trading activities for financial reporting purposes. Under GAAP, revenues and expenses associated with trading activities are presented on a net basis in Gas Marketing operating revenues (or expenses, if negative) in the Consolidated Statements of Income. This net presentation has no effect on operating income or net income. |
INCOME TAXES | INCOME TAXES – Spire and its subsidiaries account for income taxes under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amount of existing assets and liabilities and the respective tax basis and for tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effects on deferred tax assets and liabilities of a change in enacted tax rates is recognized in income or loss for a non-regulated company, and in a regulatory asset or regulatory liability for a regulated company. A valuation allowance is established when it is more likely than not that some portion or all of the deferred tax assets will not be realized. The Company accounts for uncertain tax positions in accordance with authoritative guidance. The authoritative guidance addresses the determination of whether tax benefits claimed, or expected to be claimed, on a tax return should be recorded in the financial statements. Spire may recognize the tax benefit from an uncertain tax position only if it is more likely than not that the position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Tax-related interest and penalties, if any, are classified as a liability on the balance sheets. |
CASH AND CASH EQUIVALENTS | CASH AND CASH EQUIVALENTS – All highly liquid debt instruments purchased with original maturities of three months or less are considered to be cash equivalents. Such instruments are carried at cost, which approximates market value. Outstanding checks on the Company’s and Utilities’ bank accounts in excess of funds on deposit create book overdrafts (which are funded at the time checks are presented for payment) and are classified as Other in the Current Liabilities section of the balance sheets. Changes in book overdrafts are reflected as Operating Activities in the statements of cash flows. |
NATURAL GAS RECEIVABLE | ACCOUNTS RECEIVABLE AND ALLOWANCE FOR DOUBTFUL ACCOUNTS – Trade accounts receivable are recorded at the amounts due from customers, including unbilled amounts. Estimates of the collectability of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. Accounts receivable are written off against the allowance for doubtful accounts when they are deemed to be uncollectible. Spire’s provision for uncollectible accounts includes the amortization of previously deferred uncollectible expenses for Laclede Gas and Alagasco, as approved by the MoPSC and the APSC. NATURAL GAS RECEIVABLE – LER enters into natural gas transactions with natural gas pipeline companies known as park and loan arrangements. Under the terms of the arrangements, LER purchases natural gas from a third party and delivers that natural gas to the pipeline company for the right to receive the same quantity of natural gas from the pipeline company at the same location in a future period. These arrangements are accounted for as non-monetary transactions under GAAP and are recorded at the carrying amount. As such, natural gas receivables are reflected on the Consolidated Balance Sheets at cost, which includes related pipeline fees associated with the transactions. In the period that the natural gas is returned to LER, concurrent with the sale of the natural gas to a third party, the related natural gas receivable is expensed in the Consolidated Statements of Income. In conjunction with these transactions, LER usually enters into New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE) natural gas futures, options, and swap contracts or fixed price sales agreements to protect against market changes in future sales prices. |
EARNINGS PER COMMON SHARE | EARNINGS PER COMMON SHARE – GAAP requires dual presentation of basic and diluted earnings per share (EPS). EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareholders. Certain of the Company’s stock-based compensation awards pay non-forfeitable dividends to the participants during the vesting period and, as such, are deemed participating securities. Basic EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding during the period. Diluted EPS is computed by dividing net income available to common shareholders by the weighted average number of common shares outstanding that are increased for additional shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares, pursuant to the treasury stock method. Shares attributable to equity units, non-participating stock options and time-vested restricted stock/units are excluded from the calculation of diluted earnings per share if the effect would be antidilutive. Shares attributable to non-participating performance-contingent restricted stock awards are only included in the calculation of diluted earnings per share to the extent the underlying performance and/or market conditions are satisfied (a) prior to the end of the reporting period or (b) would be satisfied if the end of the reporting period were the end of the related contingency period and the result would be dilutive. |
GROSS RECEIPTS AND SALES TAXES | GROSS RECEIPTS AND SALES TAXES – Gross receipts taxes associated with the Company’s natural gas utility services are imposed on the Company, Laclede Gas, and Alagasco and billed to its customers. The revenue and expense amounts are recorded gross in the “Operating Revenues” and “Taxes, other than income taxes” lines, respectively, in the statements of income. The following table presents gross receipts taxes recorded: 2016 2015 2014 Spire $ 75.5 $ 97.3 $ 77.5 Laclede Gas 57.4 74.5 76.3 Alagasco 17.9 22.6 20.6 Sales taxes imposed on applicable Alagasco and Laclede Gas sales are billed to customers. These amounts are not recorded in the statements of income but are recorded as tax collections payable and included in the Other line of the Current Liabilities section of the balance sheets. |
TRANSACTIONS WITH AFFILIATES | TRANSACTIONS WITH AFFILIATES – Transactions between affiliates of the Company have been eliminated from the consolidated financial statements of Spire. |
GROUP MEDICAL AND WORKERS' COMPENSATION RESERVES | GROUP MEDICAL AND WORKERS’ COMPENSATION RESERVES – The Company self-insures its group medical and workers’ compensation costs and carries stop-loss coverage in relation to medical claims and workers’ compensation claims. Reserves for amounts incurred but not reported are established based on historical cost levels and lags between occurrences and reporting. |
FAIR VALUE MEASUREMENTS | FAIR VALUE MEASUREMENTS – Certain assets and liabilities are recognized or disclosed at fair value, which is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). GAAP establishes a fair value hierarchy that prioritizes the inputs used to measure fair value. The levels of the hierarchy are described below: • Level 1 – Unadjusted quoted prices in active markets for identical assets or liabilities. • Level 2 – Pricing inputs other than quoted prices included within Level 1, which are either directly or indirectly observable for the asset or liability as of the reporting date. These inputs are derived principally from, or corroborated by, observable market data. • Level 3 – Pricing that is based upon inputs that are generally unobservable that are based on the best information available and reflect management’s assumptions about how market participants would price the asset or liability. Assessment of the significance of a particular input to the fair value measurements may require judgment and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. |
STOCK-BASED COMPENSATION | STOCK-BASED COMPENSATION – The Company measures stock-based compensation awards at fair value at the date of grant and recognizes the compensation cost of the awards over the requisite service period. Forfeitures are estimated at the time of grant and revised, if necessary, in subsequent periods if the actual forfeitures differ from those estimates. |
NEW ACCOUNTING STANDARDS | NEW ACCOUNTING PRONOUNCEMENTS – In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. The core principle of the standard is when an entity transfers goods or services to customers it will recognize revenue in an amount that reflects the consideration the entity expects to be entitled to for those goods or services. ASU No. 2014-09 also requires disclosures that will enable users of financial statements to understand the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which made the guidance in ASU No. 2014-09 effective for fiscal years beginning after December 15, 2017 and interim periods within those years, but companies may choose to adopt it one year earlier. In 2016, the FASB issued related ASU Nos. 2016-08, 2016-10, 2016-11 and 2016-12, which further modified the standards for accounting for revenue. The Company, Laclede Gas and Alagasco are currently assessing the available transition methods and the potential impacts of the updates, which must be adopted by the first quarter of fiscal year 2019. In April 2015, the FASB issued ASU No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs. Currently, debt issuance costs are recorded as a deferred charge (asset), while debt discount and debt premium costs are recorded as a liability adjustment. This amendment will require debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. ASU No. 2015-15 clarified that ASU No. 2015-03 does not address the presentation of debt issuance costs related to line-of-credit arrangements, and the Company intends to continue to report such costs as deferred charges. The new guidance is effective for the Company, Laclede Gas and Alagasco beginning in the first quarter of fiscal 2017. The application of this standard will be retrospective, wherein each balance sheet presented will be adjusted to reflect the impacts of applying the new guidance. If this ASU had been adopted as of September 30, 2016, the amounts reclassified from other deferred charges to reduce long-term debt at September 30, 2016 and 2015, respectively, would have been $13.2 and $13.0 for Spire, $4.2 and $4.8 for Laclede Gas, and $2.6 and $2.4 for Alagasco. In November 2015, the FASB issued ASU No. 2015-17, Income Taxes: Balance Sheet classification of Deferred Taxes, to require that deferred tax liabilities and assets be classified entirely as noncurrent. This was part of the FASB’s simplification initiative intended to reduce cost and complexity in financial reporting while improving or maintaining the usefulness of the information reported to investors. The Company, Laclede Gas and Alagasco adopted this ASU in the fourth quarter of fiscal 2016. Prior periods were not retrospectively adjusted. The adoption of this accounting standard was not material to the financial statements. In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments – Overall: Recognition and Measurement of Financial Assets and Financial Liabilities, which provides revised guidance concerning certain matters involving the recognition, measurement, and disclosure of financial instruments. It is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2019. In February 2016, the FASB issued ASU No. 2016-02, Leases. The new standard requires lessees to recognize a right-of-use asset and lease liability for almost all lease contracts based on the present value of lease payments. There is an exemption for short-term leases. The ASU provides new guidelines for identifying and classifying a lease, and classification affects the pattern and income statement line item for the related expense. The ASU is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2020. In March 2016, the FASB issued ASU No. 2016-09, Compensation – Stock Compensation: Improvements to Employee Share-Based Payment Accounting. The standard is intended to simplify several areas of accounting for share-based compensation arrangements, including the income tax impact, classification on the statement of cash flows and forfeitures. The ASU is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2018. On June 16, 2016, the FASB issued ASU 2016-13, Financial Instruments – Credit Losses: Measurement of Credit Losses on Financial Instruments. The standard introduces new guidance for the accounting for credit losses on instruments within its scope, including trade receivables. It is effective for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years, but may be adopted up to two years earlier. The Company, Laclede Gas and Alagasco are currently assessing the timing and impacts of adopting this standard, which must be adopted by the first quarter of fiscal year 2021. |
SUMMARY OF SIGNIFICANT ACCOUN30
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
Asset retirement obligations | The following table presents a reconciliation of the beginning and ending balances of asset retirement obligations at September 30, as reported in the balance sheets. Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Asset retirement obligations, beginning of year $ 159.2 $ 99.2 $ 72.4 $ 71.2 $ 86.6 $ 27.7 Liabilities incurred during the period 4.1 2.3 1.2 0.6 2.9 1.7 Liabilities settled during the period (9.5 ) (2.0 ) (1.9 ) (1.9 ) (6.8 ) (0.1 ) Accretion 13.2 4.5 3.5 3.4 9.7 1.1 Revisions in estimated cash flows 27.5 55.2 — (0.9 ) 27.7 56.2 Addition of EnergySouth asset retirement obligations 11.9 — — — — — Asset retirement obligations, end of year $ 206.4 $ 159.2 $ 75.2 $ 72.4 $ 120.1 $ 86.6 |
Off-system sales | Pre-tax income from off-system sales and capacity release revenues is shared with customers, with an estimated amount assumed in PGA rates. The difference between the actual amount allocated to customers for each fiscal year and the estimated amount assumed in PGA rates is recovered from, or credited to, customers over an annual period commencing in the subsequent November. The customer share of such income is determined in accordance with the following tables, shown for each service territory for which the PGA clauses were approved by the MoPSC. Customer Share Company Share Eastern Missouri First $2.0* 100% —% Next $2.0 80% 20% Next $2.0 75% 25% Amounts exceeding $6.0 70% 30% * Customer share reverts to 85% and company share reverts to 15% in 2017. Western Missouri First $1.2 85% 15% Next $1.2 80% 20% Next $1.2 75% 25% Amounts exceeding $3.6 70% 30% |
Changes in the carrying amount of goodwill by reportable segment | The changes in the carrying amount of goodwill by reportable segment were as follows: Gas Utility Gas Marketing Other Total Balance as of September 30, 2013 $ 247.1 $ — $ — $ 247.1 Adjustments to finalize the 2013 acquisition of MGE (36.9 ) — — (36.9 ) Acquisition of Alagasco — — 727.6 727.6 Balance as of September 30, 2014 210.2 — 727.6 937.8 Adjustments to finalize the acquisition of Alagasco — — 8.2 8.2 Balance as of September 30, 2015 210.2 — 735.8 946.0 Acquisition of EnergySouth — — 218.9 218.9 Balance as of September 30, 2016 $ 210.2 $ — $ 954.7 $ 1,164.9 |
Schedule of gross receipts taxes | The following table presents gross receipts taxes recorded: 2016 2015 2014 Spire $ 75.5 $ 97.3 $ 77.5 Laclede Gas 57.4 74.5 76.3 Alagasco 17.9 22.6 20.6 |
Schedule of inter-company transactions | Laclede Gas had the following transactions with affiliates: 2016 2015 2014 Purchases of natural gas from LER $ 46.3 $ 74.1 $ 89.1 Sales of natural gas to LER 1.9 4.0 5.1 Services received from Laclede Insurance Risk Services, Inc. 1.8 1.0 0.6 |
ACQUISITIONS (Tables)
ACQUISITIONS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Business Combinations [Abstract] | |
Schedule of consideration paid and amounts of assets acquired and liabilities assumed | The following table summarizes the consideration paid and the amounts of the assets acquired and liabilities assumed at the acquisition dates. Measurement period adjustments were immaterial. Alagasco EnergySouth Recognized amounts of identifiable assets acquired and liabilities assumed: Utility plant $ 892.7 $ 199.5 Cash 12.1 2.0 Other current assets 99.4 17.5 Deferred tax assets 282.0 — Other assets 143.4 79.8 Long-term debt (249.8 ) (67.0 ) Current portion of long-term debt (15.0 ) — Other current liabilities (173.4 ) (42.7 ) Deferred tax liabilities — (35.5 ) Other liabilities (130.4 ) (52.8 ) Total identifiable net assets 861.0 100.8 Goodwill 735.8 218.9 Deferred tax elimination (Spire) (271.3 ) — Consideration (cash) $ 1,325.5 $ 319.7 |
Schedule of Pro Forma Information | The results of operations of each of the acquisitions are included in the Spire statements of income from the date of acquisition, as shown in the following table. Alagasco EnergySouth 2016 2015 2014 2016 Total Operating Revenues $ 368.5 $ 479.2 $ 19.7 $ 3.3 Net Income (Loss) 53.2 48.0 (2.9 ) (0.2 ) Earnings (Loss) Per Share $ 1.20 $ 1.11 $ (0.08 ) $ — The following unaudited pro forma financial information presents Spire’s combined results of operations as though the EnergySouth acquisition had occurred as of the beginning of fiscal year 2015 and the Alagasco acquisition had occurred as of the beginning of fiscal year 2013. The unaudited pro forma financial information is not necessarily indicative of either future results of operations or results that would have been achieved if the acquisitions had occurred as of those earlier dates. It does not reflect the costs of any integration activities. It includes estimates and assumptions which management believes are reasonable. 2016 2015 2014 Total Operating Revenues $ 1,632.4 $ 2,081.6 $ 2,187.1 Net Income 153.9 143.6 133.5 Basic Earnings Per Share $ 3.48 $ 3.32 $ 3.11 Diluted Earnings Per Share 3.46 3.31 3.10 |
STOCK-BASED COMPENSATION (Table
STOCK-BASED COMPENSATION (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Restricted stock and restricted stock unit activity | Fiscal year 2016 activity of restricted stock and restricted stock units subject to performance and/or market conditions is presented below: Shares/ Units Weighted Average Grant Date Fair Value Per Share Nonvested at September 30, 2015 397,270 $ 36.28 Granted (maximum shares that can be earned) 199,140 $ 45.95 Vested (62,593 ) $ 35.29 Forfeited (23,234 ) $ 30.96 Nonvested at September 30, 2016 510,583 $ 40.37 Time-vested restricted stock and stock unit activity for fiscal year 2016 is presented below: Shares/ Units Weighted Average Grant Date Fair Value Per Share Nonvested at September 30, 2015 129,304 $ 44.89 Granted 48,730 $ 60.65 Vested (44,645 ) $ 47.30 Forfeited (610 ) $ 53.12 Nonvested at September 30, 2016 132,779 $ 49.83 |
Stock option awards activity | No stock options were granted during fiscal years 2016 , 2015 , and 2014 . Stock option activity for fiscal year 2016 is presented below: Stock Options Weighted Average Exercise Price Per Share Outstanding at September 30, 2015 28,500 $ 33.65 Exercised (27,750 ) $ 33.66 Forfeited (750 ) $ 33.45 Outstanding at September 30, 2016 — $ — |
Significant assumptions used in the Monte Carlo simulations | The significant assumptions used in the Monte Carlo simulations are as follows: 2016 2015 2014 Risk free interest rate 1.14% 0.83% 0.53% Expected dividend yield of stock — — — Expected volatility of stock 15.0% 14.0% 18.0% Vesting period 2.8 years 2.8 years 2.8 years |
Compensation cost recognized for share-based compensation arrangements | The amounts of compensation cost recognized for share-based compensation arrangements are presented below: 2016 2015 2014 Total equity compensation cost $ 6.7 $ 6.7 $ 5.8 Compensation cost capitalized (2.2 ) (1.8 ) (1.8 ) Compensation cost recognized in net income $ 4.5 $ 4.9 $ 4.0 Income tax benefit recognized in net income (1.7 ) (1.9 ) (1.5 ) Compensation cost recognized in net income, net of income tax $ 2.8 $ 3.0 $ 2.5 |
EARNINGS PER COMMON SHARE (Tabl
EARNINGS PER COMMON SHARE (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Earnings Per Share [Abstract] | |
Earnings Per Common Share | 2016 2015 2014 Basic EPS: Net Income $ 144.2 $ 136.9 $ 84.6 Less: Income allocated to participating securities 0.5 0.5 0.3 Net Income Available to Common Shareholders $ 143.7 $ 136.4 $ 84.3 Weighted Average Shares Outstanding (millions) 44.1 43.2 35.8 Earnings Per Share of Common Stock $ 3.26 $ 3.16 $ 2.36 Diluted EPS: Net Income $ 144.2 $ 136.9 $ 84.6 Less: Income allocated to participating securities 0.5 0.5 0.3 Net Income Available to Common Shareholders $ 143.7 $ 136.4 $ 84.3 Weighted Average Shares Outstanding (millions) 44.1 43.2 35.8 Dilutive Effect of Stock Options, Restricted Stock, and Restricted Stock Units (millions) 0.2 0.1 0.1 Weighted Average Diluted Shares (millions) 44.3 43.3 35.9 Earnings Per Share of Common Stock $ 3.24 $ 3.16 $ 2.35 Outstanding Shares (in millions) Excluded from the Calculation of Diluted EPS Attributable to: Restricted stock and stock units subject to performance and/or market conditions 0.3 0.3 0.3 |
STOCKHOLDERS' EQUITY (Tables)
STOCKHOLDERS' EQUITY (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Stockholders' Equity Note [Abstract] | |
Schedule of stock purchase obligation | The purchase price to be paid under the stock purchase contracts is fifty dollars per Corporate Unit and the number of shares to be purchased will be determined as follows: If the applicable market value per share of Spire common stock is: Number of shares to be purchased per purchase contract is: Equal to or greater than $57.8125 0.8649 Less than $57.8125, but greater than $46.25 $50 ÷ applicable market value Less than or equal to $46.25 1.0811 |
Schedule of Company's equity units | Selected information about the Company’s equity units is presented below: Issuance Date Units Issued (Millions) Total Net Proceeds Total Long-term Debt RSN Annual Interest Rate Stock Purchase Contract Annual Rate Stock Purchase Contract Liability 6/11/2014 2.875 $139.4 $143.8 2.00% 4.75% $19.7 |
Schedule of accumulated other comprehensive income (loss) | The components of accumulated other comprehensive income (loss), net of income taxes, recognized in the balance sheets at September 30 were as follows: Net Unrealized Gains (Losses) on Cash Flow Hedges Defined Benefit Pension and Other Postretirement Benefit Plans Net Unrealized Losses on Available for Sale Securities Total Spire Balance at September 30, 2014 $ 0.2 $ (1.9 ) $ — $ (1.7 ) Other comprehensive (loss) income (0.6 ) 0.4 (0.1 ) (0.3 ) Balance at September 30, 2015 (0.4 ) (1.5 ) (0.1 ) (2.0 ) Other comprehensive (loss) income (1.9 ) (0.3 ) — (2.2 ) Balance at September 30, 2016 $ (2.3 ) $ (1.8 ) $ (0.1 ) $ (4.2 ) Laclede Gas Balance at September 30, 2014 $ — $ (1.9 ) $ — $ (1.9 ) Other comprehensive (loss) income (0.2 ) 0.4 — 0.2 Balance at September 30, 2015 (0.2 ) (1.5 ) — (1.7 ) Other comprehensive income (loss) 0.3 (0.3 ) (0.1 ) (0.1 ) Balance at September 30, 2016 $ 0.1 $ (1.8 ) $ (0.1 ) $ (1.8 ) |
LONG-TERM DEBT (Tables)
LONG-TERM DEBT (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Debt Disclosure [Abstract] | |
Schedule of maturities of long-term debt by fiscal year | Maturities of long-term debt for Spire, Laclede Gas and Alagasco for the five fiscal years subsequent to September 30, 2016 are as follows: Spire Laclede Gas Alagasco 2017 $ 250.0 $ — $ — 2018 100.0 100.0 — 2019 180.0 50.0 — 2020 40.0 — 40.0 2021 55.0 — — |
NOTES PAYABLE AND CREDIT AGRE36
NOTES PAYABLE AND CREDIT AGREEMENTS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Short-term Debt [Line Items] | |
Short-term borrowings | Information about Spire’s short-term borrowings (excluding intercompany borrowings) during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Laclede Gas Commercial Paper Borrowings Spire Bank Line Borrowings* Alagasco Bank Line Borrowings Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $201.0 $42.7 $30.2 $273.9 Weighted average interest rate 0.7% 1.6% 1.4% 0.9% Range of borrowings outstanding $43.0 - $307.2 $0.0 - $82.0 $0.0 - $82.0 $73.1 - $427.2 As of September 30, 2016 Borrowings outstanding at end of period $243.7 $73.0 $82.0 $398.7 Weighted average interest rate 0.8% 1.8% 1.5% 1.1% Year Ended September 30, 2015 Weighted average borrowings outstanding $212.7 $65.6 $22.3 $300.6 Weighted average interest rate 0.4% 1.4% 1.1% 0.7% Range of borrowings outstanding $ 102.1 - $341.0 $32.5 - $80.0 $0.0 - $69.5 $180.1 - $488.5 As of September 30, 2015 Borrowings outstanding at end of period $233.0 $74.0 $31.0 $338.0 Weighted average interest rate 0.5% 1.5% 1.2% 0.8% * Spire Inc., excluding its wholly owned subsidiaries. |
Laclede Gas | |
Short-term Debt [Line Items] | |
Short-term borrowings | Information about Laclede Gas’ short-term borrowings during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Commercial Paper Borrowings Borrowings from Spire Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $201.0 $14.7 $215.7 Weighted average interest rate 0.7% 0.8% 0.7% Range of borrowings outstanding $43.0 - $307.2 $0.0 - $114.2 $127.8 - $ 307.2 As of September 30, 2016 Borrowings outstanding at end of period $243.7 $— $243.7 Weighted average interest rate 0.8% —% 0.8% Year Ended September 30, 2015 Weighted average borrowings outstanding $212.7 $0.3 $213.0 Weighted average interest rate 0.4% 0.5% 0.4% Range of borrowings outstanding $102.1 - $341.0 $0.0 - $10.4 $104.2 - $ 341.0 As of September 30, 2015 Borrowings outstanding at end of period $233.0 $— $233.0 Weighted average interest rate 0.5% —% 0.5% |
Alagasco | |
Short-term Debt [Line Items] | |
Short-term borrowings | Information about Alagasco’s short-term borrowings during the twelve months ended September 30, and as of September 30, is presented below for 2016 and 2015 : Bank Line Borrowings Borrowings from Spire Total Short-Term Borrowings Year Ended September 30, 2016 Weighted average borrowings outstanding $30.2 $12.4 $42.6 Weighted average interest rate 1.4% 1.4% 1.4% Range of borrowings outstanding $0.0 - $82 $0.0 - $61.9 $19.0 - $82.0 As of September 30, 2016 Borrowings outstanding at end of period $82.0 $— $82.0 Weighted average interest rate 1.5% —% 1.5% Year Ended September 30, 2015 Weighted average borrowings outstanding $22.3 $— $22.3 Weighted average interest rate 1.1% —% 1.1% Range of borrowings outstanding $0.0 - $69.5 0 $0.0- $69.5 As of September 30, 2015 Borrowings outstanding at end of period $31.0 $— $31.0 Weighted average interest rate 1.2% —% 1.2% |
FAIR VALUE OF FINANCIAL INSTR37
FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |
Fair value of financial instruments | The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for the Company are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ 5.2 $ 5.2 $ 5.2 $ — $ — Short-term debt 398.7 398.7 — 398.7 — Long-term debt, including current portion 2,083.7 2,257.1 — 2,257.1 — As of September 30, 2015 Cash and cash equivalents $ 13.8 $ 13.8 $ 13.8 $ — $ — Short-term debt 338.0 338.0 — 338.0 — Long-term debt, including current portion 1,851.5 1,944.2 — 1,944.2 — |
Laclede Gas | |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |
Fair value of financial instruments | The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for Laclede Gas are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ 2.1 $ 2.1 $ 2.1 $ — $ — Short-term debt 243.7 243.7 — 243.7 — Long-term debt 808.3 900.4 — 900.4 — As of September 30, 2015 Cash and cash equivalents $ 1.7 $ 1.7 $ 1.7 $ — $ — Short-term debt 233.0 233.0 — 233.0 — Long-term debt 808.1 880.2 — 880.2 — |
Alagasco | |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |
Fair value of financial instruments | The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis for Alagasco are as follows: Classification of Estimated Fair Value Carrying Amount Fair Value Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) As of September 30, 2016 Cash and cash equivalents $ — $ — $ — $ — $ — Short-term debt 82.0 82.0 — 82.0 — Long-term debt 250.0 275.5 — 275.5 — As of September 30, 2015 Cash and cash equivalents $ 7.2 $ 7.2 $ 7.2 $ — $ — Short-term debt 31.0 31.0 — 31.0 — Long-term debt, including current portion 250.0 263.2 — 263.2 — |
FAIR VALUE MEASUREMENTS (Tables
FAIR VALUE MEASUREMENTS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value Measurements, Measured on Recurring Basis | The information presented below categorizes the assets and liabilities in the balance sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition. The mutual funds included in Level 1 are valued based on exchange-quoted market prices of individual securities. The mutual funds included in Level 2 are valued based on the closing net asset value per unit. Derivative instruments included in Level 1 are valued using quoted market prices on the NYMEX. Derivative instruments classified as Level 2 include physical commodity derivatives that are valued using Over-the-Counter Bulletin Board (OTCBB), broker, or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. There were no material Level 3 balances as of September 30, 2016 or 2015 . The Company’s and the Utilities’ policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer. The mutual funds are included in the “Other investments” line of the balance sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the balance sheets when a legally enforceable netting agreement exist between the Company or Laclede Gas and the counterparty to the derivative contract. For additional information on derivative instruments, see Note 10 , Derivative Instruments and Hedging Activities. Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Effects of Netting and Cash Margin Receivables /Payables Total As of September 30, 2016 ASSETS Gas Utility US stock/bond mutual funds $ 16.8 $ 4.1 $ — $ — $ 20.9 NYMEX/ICE natural gas contracts 5.3 — — (0.4 ) 4.9 Gasoline and heating oil contracts 0.4 — — (0.3 ) 0.1 Subtotal 22.5 4.1 — (0.7 ) 25.9 Gas Marketing NYMEX/ICE natural gas contracts 0.4 3.4 — (3.4 ) 0.4 Natural gas commodity contracts — 8.7 0.2 (0.9 ) 8.0 Total $ 22.9 $ 16.2 $ 0.2 $ (5.0 ) $ 34.3 LIABILITIES Gas Utility NYMEX/ICE natural gas contracts $ 1.6 $ — $ — $ (1.6 ) $ — OTCBB natural gas contracts — 0.2 — — 0.2 Subtotal 1.6 0.2 — (1.6 ) 0.2 Gas Marketing NYMEX/ICE natural gas contracts 3.5 1.6 — (5.1 ) — Natural gas commodity contracts — 2.6 — (0.9 ) 1.7 Other Interest rate swaps — 3.0 — — 3.0 Total $ 5.1 $ 7.4 $ — $ (7.6 ) $ 4.9 As of September 30, 2015 ASSETS Gas Utility US stock/bond mutual funds $ 15.5 $ 4.0 $ — $ — $ 19.5 NYMEX/ICE natural gas contracts 1.3 — — (1.3 ) — Subtotal 16.8 4.0 — (1.3 ) 19.5 Gas Marketing NYMEX natural gas contracts 6.3 4.3 — (6.6 ) 4.0 Natural gas commodity contracts — 1.5 0.2 (0.5 ) 1.2 Total $ 23.1 $ 9.8 $ 0.2 $ (8.4 ) $ 24.7 LIABILITIES Gas Utility NYMEX/ICE natural gas contracts $ 16.4 $ — $ — $ (16.4 ) $ — OTCBB natural gas contracts — 5.9 — — 5.9 NYMEX gasoline and heating oil contracts 0.3 — — (0.3 ) — Subtotal 16.7 5.9 — (16.7 ) 5.9 Gas Marketing NYMEX/ICE natural gas contracts 1.2 3.9 — (5.1 ) — Natural gas commodity contracts — 2.2 — (0.5 ) 1.7 Total $ 17.9 $ 12.0 $ — $ (22.3 ) $ 7.6 |
Laclede Gas | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value Measurements, Measured on Recurring Basis | Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Effects of Netting and Cash Margin Receivables /Payables Total As of September 30, 2016 ASSETS US stock/bond mutual funds $ 16.8 $ 4.1 $ — $ — $ 20.9 NYMEX/ICE natural gas contracts 5.3 — — (0.4 ) 4.9 Gasoline and heating oil contracts 0.3 — — (0.3 ) — Total $ 22.4 $ 4.1 $ — $ (0.7 ) $ 25.8 LIABILITIES NYMEX/ICE natural gas contracts $ 1.6 $ — $ — $ (1.6 ) $ — OTCBB natural gas contracts — 0.2 — — 0.2 Total $ 1.6 $ 0.2 $ — $ (1.6 ) $ 0.2 As of September 30, 2015 ASSETS US stock/bond mutual funds $ 15.5 $ 4.0 $ — $ — $ 19.5 NYMEX/ICE natural gas contracts 1.3 — — (1.3 ) — Total $ 16.8 $ 4.0 $ — $ (1.3 ) $ 19.5 LIABILITIES NYMEX/ICE natural gas contracts $ 16.4 $ — $ — $ (16.4 ) $ — OTCBB natural gas contracts — 5.9 — — 5.9 NYMEX gasoline and heating oil contracts 0.3 — — (0.3 ) — Total $ 16.7 $ 5.9 $ — $ (16.7 ) $ 5.9 |
DERIVATIVE INSTRUMENTS AND HE39
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Derivative [Line Items] | |
Derivative Instruments and Hedging Activities | Open NYMEX/ICE and OTCBB natural gas futures and swap positions at September 30, 2016 were as follows: Gas Utility Gas Marketing MMBtu (millions) Avg. Price Per MMBtu MMBtu (millions) Avg. Price Per MMBtu NYMEX/ICE Open short futures positions Fiscal 2017 — $ — 12.20 $ 2.86 Fiscal 2018 — — 1.27 2.95 NYMEX/ICE Open long futures/swap positions Fiscal 2017 18.43 2.95 4.62 3.12 Fiscal 2018 0.33 2.83 0.45 3.02 Fiscal 2019 — — 0.04 2.89 ICE Open long basis swap positions Fiscal 2017 — — 16.62 0.34 Fiscal 2018 — — 2.01 0.43 Fiscal 2019 — — 0.08 0.40 ICE Open short basis swap positions Fiscal 2017 — — 11.88 0.19 Fiscal 2018 — — 0.93 0.27 Fiscal 2019 — — 2.27 0.13 OTC Open long futures/swap positions Fiscal 2017 0.32 3.64 — — |
The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income | Effect of Derivative Instruments on the Consolidated Statements of Income and Consolidated Statements of Comprehensive Income Location of Gain (Loss) Recorded in Income 2016 2015 2014 Derivatives in Cash Flow Hedging Relationships Effective portion of gain (loss) recognized in OCI on derivatives: Gas Marketing natural gas contracts $ (0.6 ) $ (4.3 ) $ (4.6 ) Gas Utility gasoline and heating oil contracts — (1.2 ) 0.1 Interest Rate Swaps (3.4 ) — — Total $ (4.0 ) $ (5.5 ) $ (4.5 ) Effective portion of gain (loss) reclassified from AOCI to income: Natural gas contracts Gas Marketing Operating Revenues $ 4.3 $ 1.7 $ 4.2 Gas Marketing Operating Expenses (4.9 ) (5.2 ) (1.5 ) Subtotal (0.6 ) (3.5 ) 2.7 Gasoline and heating oil contracts Gas Utility Other Operating Expenses (0.5 ) (0.9 ) (0.2 ) Total $ (1.1 ) $ (4.4 ) $ 2.5 Ineffective portion of gain (loss) on derivatives recognized in income: Natural gas contracts Gas Marketing Operating Revenues $ 0.1 $ — $ (0.1 ) Gas Marketing Operating Expenses 0.1 (0.5 ) 0.1 Subtotal 0.2 (0.5 ) — Gasoline and heating oil contracts Gas Utility Other Operating Expenses 0.1 0.1 (0.2 ) Total $ 0.3 $ (0.4 ) $ (0.2 ) Derivatives Not Designated as Hedging Instruments* Gain (loss) recognized in income on derivatives: Natural gas commodity contracts Gas Marketing Operating Revenues $ 12.3 $ (1.3 ) $ (8.7 ) NYMEX / ICE natural gas contracts Gas Marketing Operating Revenues (1.7 ) (9.6 ) 3.0 Gasoline and heating oil contracts Other Income and (Income Deductions) - Net — (0.2 ) — Total $ 10.6 $ (11.1 ) $ (5.7 ) * Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Missouri Utilities’ PGA clauses and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the statements of income. Such amounts are recognized in the statements of income as a component of Regulated Gas Distribution Natural and Propane Gas operating expenses when they are recovered through the PGA clause and reflected in customer billings. |
Fair Value of Derivative Instruments in the Consolidated Balance Sheet | Fair Value of Derivative Instruments in the Consolidated Balance Sheet Asset Derivatives* Liability Derivatives* September 30, 2016 Balance Sheet Location Fair Value Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gas Utility: Gasoline and heating oil contracts Derivative Instrument Assets $ 0.3 Derivative Instrument Assets $ — Gas Marketing: Natural gas contracts Derivative Instrument Assets 2.5 Derivative Instrument Assets 0.8 Deferred Charges – Other 0.4 Deferred Charges – Other 0.1 Other: Interest swaps Derivative Instrument Assets — Derivative Instrument Assets 3.0 Subtotal 3.2 3.9 Derivatives not designated as hedging instruments Gas Utility: Natural gas contracts Accounts Receivable – Other 5.4 Accounts Receivable – Other 1.6 Derivative Instrument Assets — Derivative Instrument Assets 0.2 Gas Marketing: NYMEX / ICE natural gas contracts Derivative Instrument Assets 0.8 Derivative Instrument Assets 4.1 Deferred Charges – Other — Deferred Charges – Other 0.1 Natural gas commodity Derivative Instrument Assets 6.5 Derivative Instrument Assets 0.2 Other Deferred Charges 2.1 Other Deferred Charges 0.3 Current Liabilities – Other 0.2 Current Liabilities – Other 2.0 Deferred Credits – Other 0.2 Deferred Credits – Other 0.1 Subtotal 15.2 8.6 Total derivatives $ 18.4 $ 12.5 September 30, 2015 Derivatives designated as hedging instruments Gas Utility: Gasoline and heating oil contracts Accounts Receivable – Other $ — Accounts Receivable – Other $ 0.3 Gas Marketing: Natural gas contracts Derivative Instrument Assets 4.1 Derivative Instrument Assets 3.2 Deferred Charges – Other 1.1 Deferred Charges – Other 0.5 Subtotal 5.2 4.0 Derivatives not designated as hedging instruments Gas Utility: Natural gas contracts Accounts Receivable – Other 1.2 Accounts Receivable – Other 16.4 Derivative Instrument Assets — Derivative Instrument Assets 5.7 Deferred Charges – Other — Deferred Charges – Other 0.2 Gas Marketing: NYMEX / ICE natural gas contracts Derivative Instrument Assets 4.7 Derivative Instrument Assets 0.6 Deferred Charges – Other 0.7 Deferred Charges – Other 0.7 Natural gas commodity Derivative Instrument Assets 1.4 Derivative Instrument Assets 0.1 Current Liabilities – Other 0.2 Current Liabilities – Other 1.4 Deferred Credits – Other 0.1 Deferred Credits – Other 0.7 Subtotal 8.3 25.8 Total derivatives $ 13.5 $ 29.8 * The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the balance sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 9 , Fair Value Measurements, for information on the valuation of derivative instruments. |
Derivative instrument Reconciliation | Following is a reconciliation of the amounts in the tables above to the amounts presented in the Consolidated Balance Sheets: 2016 2015 Fair value of asset derivatives presented above $ 18.4 $ 13.5 Fair value of cash margin receivables offset with derivatives 2.5 13.9 Netting of assets and liabilities with the same counterparty (7.6 ) (22.2 ) Total $ 13.3 $ 5.2 Derivative Instrument Assets, per Consolidated Balance Sheets: Derivative instrument assets $ 11.4 $ 4.6 Deferred Charges – Other 1.9 0.6 Total $ 13.3 $ 5.2 Fair value of liability derivatives presented above $ 12.5 $ 29.8 Netting of assets and liabilities with the same counterparty (7.6 ) (22.2 ) Total $ 4.9 $ 7.6 Derivative Instrument Liabilities, per Consolidated Balance Sheets: Current Liabilities – Other $ 4.8 $ 6.8 Deferred Credits – Other 0.1 0.8 Total $ 4.9 $ 7.6 |
Laclede Gas | |
Derivative [Line Items] | |
Derivative Instruments and Hedging Activities | Laclede Gas’ derivative instruments consist primarily of NYMEX and OTCBB positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX and OTCBB natural gas futures positions at September 30, 2016 were as follows: MMBtu (millions) Avg. Price Per MMBtu NYMEX/ICE Open long futures/swap positions Fiscal 2017 18.43 $ 2.95 Fiscal 2018 0.33 2.83 OTC Open long futures/swap positions Fiscal 2017 0.32 $ 3.64 |
The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income | Effect of Derivative Instruments on the Statements of Income and Statements of Comprehensive Income Location of Gain (Loss) Recorded in Income 2016 2015 2014 Derivatives in Cash Flow Hedging Relationships Effective portion of gain (loss) recognized in OCI on derivatives: Gasoline and heating oil contracts $ — $ (1.2 ) $ 0.1 Effective portion of gain (loss) reclassified from AOCI to income: Gasoline and heating oil contracts Gas Utility Other Operating Expenses $ (0.5 ) $ (0.9 ) $ (0.2 ) Ineffective portion of gain (loss) on derivatives recognized in income: Gasoline and heating oil contracts Gas Utility Other Operating Expenses $ 0.1 $ 0.1 $ (0.2 ) Derivatives Not Designated as Hedging Instruments* Gain (loss) recognized in income on derivatives: Gasoline and heating oil contracts Other Income and (Income Deductions) - Net $ — $ (0.2 ) $ — * Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Laclede Gas’ PGA clauses and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Income. Such amounts are recognized in the Statements of Income as a component of Regulated Gas Distribution Natural and Propane Gas operating expenses when they are recovered through the PGA clause and reflected in customer billings. |
Fair Value of Derivative Instruments in the Consolidated Balance Sheet | Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2016 Asset Derivatives* Liability Derivatives* Balance Sheet Location Fair Value Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gasoline and heating oil contracts Derivative Instrument Assets $ 0.3 Derivative Instrument Assets $ — Subtotal 0.3 — Derivatives not designated as hedging instruments Natural gas contracts Accounts Receivable – Other 5.4 Accounts Receivable – Other 1.6 OTCBB natural gas contracts Derivative Instrument Assets — Derivative Instrument Assets 0.2 Subtotal 5.4 1.8 Total derivatives $ 5.7 $ 1.8 Fair Value of Derivative Instruments in the Balance Sheet at September 30, 2015 Asset Derivatives Liability Derivatives* Balance Sheet Location Fair Value * Balance Sheet Location Fair Value Derivatives designated as hedging instruments Gasoline and heating oil contracts Accounts Receivable – Other $ — Accounts Receivable – Other $ 0.3 Subtotal — 0.3 Derivatives not designated as hedging instruments Natural gas contracts Accounts Receivable – Other 1.2 Accounts Receivable – Other 16.4 Derivative Instrument Assets — Derivative Instrument Assets 5.7 Deferred Charges - Other — Deferred Charges - Other 0.2 Subtotal 1.2 22.3 Total derivatives $ 1.2 $ 22.6 * The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Balance Sheets. As such, the gross balances presented in the table above are not indicative of Laclede Gas’ net economic exposure. Refer to Note 9 , Fair Value Measurements, for information on the valuation of derivative instruments. |
Derivative instrument Reconciliation | Following is a reconciliation of the amounts in the tables above to the amounts presented in Laclede Gas’ Balance Sheets: 2016 2015 Fair value of asset derivatives presented above $ 5.7 $ 1.2 Fair value of cash margin receivables offset with derivatives 0.8 15.5 Netting of assets and liabilities with the same counterparty (1.6 ) (16.7 ) Total $ 4.9 $ — Derivative Instrument Assets, per Balance Sheets: Derivative instrument assets $ 4.9 $ — Total $ 4.9 $ — Fair value of liability derivatives presented above $ 1.8 $ 22.6 Netting of assets and liabilities with the same counterparty (1.6 ) (16.7 ) Total $ 0.2 $ 5.9 Derivative Instrument Liabilities, per Balance Sheets: Current Liabilities – Other $ 0.2 $ 5.7 Deferred Credits – Other — 0.2 Total $ 0.2 $ 5.9 |
INCOME TAXES (Tables)
INCOME TAXES (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Income Tax Contingency [Line Items] | |
Net Provision For Income Tax | The Company’s provision for income taxes charged during the fiscal years ended September 30, 2016 , 2015 , and 2014 are as follows: 2016 2015 2014 Federal Current $ 0.1 $ (3.3 ) $ 0.3 Deferred 62.0 58.8 30.6 Investment tax credits (0.2 ) (0.2 ) (0.2 ) State and local Current 0.6 — 0.6 Deferred 7.0 6.9 1.0 Total income tax expense $ 69.5 $ 62.2 $ 32.3 |
Effective income tax rate variation from stated tax rate | The Company’s effective income tax rate varied from the federal statutory income tax rate for each year due to the following: 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 3.0 1.8 Certain expenses capitalized on books and deducted on tax return (3.4 ) (3.7 ) (4.9 ) Taxes related to prior years (0.2 ) (0.6 ) (0.7 ) Other items – net * (1.7 ) (2.5 ) (3.6 ) Effective income tax rate 32.5 % 31.2 % 27.6 % * Other consists primarily of property adjustments. |
Significant Items in Net Deferred Tax Liability | The Company’s significant items comprising the net deferred tax liability recorded in the Consolidated Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 21.3 $ 14.8 Pension and other postretirement benefits 68.3 62.5 Operating losses 102.3 47.3 Other — 1.5 Deferred tax assets 191.9 126.1 Less: valuation allowance 0.9 — Total deferred tax assets 191.0 126.1 Deferred tax liabilities: Relating to property 623.1 472.1 Regulatory pension and other postretirement benefits 106.8 110.6 Deferred gas costs 20.0 8.1 Other 48.4 11.6 Total deferred tax liabilities 798.3 602.4 Net deferred tax liability 607.3 476.3 Net deferred tax asset – current — 5.8 Net deferred tax liability – noncurrent $ 607.3 $ 482.1 |
Unrecognized Tax Benefit Reconciliation | The following table presents a reconciliation of the beginning and ending balances of the Company’s unrecognized tax benefits: 2016 2015 2014 Unrecognized tax benefits, beginning of year $ 7.1 $ 4.6 $ 2.4 Increases related to tax positions taken in current year 3.4 2.9 2.6 Reductions due to lapse of applicable statute of limitations (0.5 ) (0.4 ) (0.4 ) Unrecognized tax benefits, end of year $ 10.0 $ 7.1 $ 4.6 |
Laclede Gas | |
Income Tax Contingency [Line Items] | |
Net Provision For Income Tax | Laclede Gas’ provision for income taxes charged during the fiscal years ended September 30, 2016 , 2015 , and 2014 are as follows: 2016 2015 2014 Federal Current $ — $ (2.1 ) $ (0.1 ) Deferred 37.5 40.9 34.3 Investment tax credits (0.2 ) (0.2 ) (0.2 ) State and local Current 0.1 (0.1 ) — Deferred 8.0 4.7 1.5 Total income tax expense $ 45.4 $ 43.2 $ 35.5 |
Effective income tax rate variation from stated tax rate | Laclede Gas’ effective income tax rate varied from the federal statutory income tax rate for each year due to the following: 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 2.8 1.8 Certain expenses capitalized on books and deducted on tax return (4.8 ) (4.9 ) (4.5 ) Taxes related to prior years (0.2 ) (0.8 ) (0.7 ) Other items – net * (2.8 ) (3.0 ) (3.3 ) Effective income tax rate 30.0 % 29.1 % 28.3 % * Other consists primarily of property adjustments. |
Significant Items in Net Deferred Tax Liability | Laclede Gas’ significant items comprising the net deferred tax liability reported in the Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 14.9 $ 15.4 Pension and other postretirement benefits 56.9 62.5 Operating losses 29.9 3.7 Other — 1.5 Deferred tax assets 101.7 83.1 Less: valuation allowance 0.9 — Total deferred tax assets 100.8 83.1 Deferred tax liabilities: Relating to utility property 497.0 425.0 Regulatory pension and other postretirement benefits 106.8 120.2 Deferred gas costs 20.0 8.2 Other 33.9 14.5 Total deferred tax liabilities 657.7 567.9 Net deferred tax liability 556.9 484.8 Net deferred tax asset – current — 0.4 Net deferred tax liability – noncurrent $ 556.9 $ 485.2 |
Unrecognized Tax Benefit Reconciliation | The following table presents a reconciliation of the beginning and ending balances of Laclede Gas unrecognized tax benefits: 2016 2015 2014 Unrecognized tax benefits, beginning of year $ 6.9 $ 4.2 $ 2.0 Increases related to tax positions taken in current year 3.3 2.9 2.5 Reductions due to lapse of applicable statute of limitations (0.5 ) (0.2 ) (0.3 ) Unrecognized tax benefits, end of year $ 9.7 $ 6.9 $ 4.2 |
Alagasco | |
Income Tax Contingency [Line Items] | |
Net Provision For Income Tax | Alagasco’s provision for income taxes charged during the fiscal years ended September 30, 2016 and 2015 , and the nine months ended September 30, 2014 , are as follows: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Federal Current $ (0.8 ) $ — $ 14.1 Deferred 29.4 25.9 3.5 State and local Current — 0.1 1.8 Deferred 3.8 3.3 0.5 Total income tax expense $ 32.4 $ 29.3 $ 19.9 |
Effective income tax rate variation from stated tax rate | Alagasco’s effective income tax rate varied from the federal statutory income tax rate for each year due to the following: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Federal income tax statutory rate 35.0 % 35.0 % 35.0 % State and local income taxes, net of federal income tax benefits 2.8 2.8 2.8 Other items – net 0.1 0.1 (0.2 ) Effective income tax rate 37.9 % 37.9 % 37.6 % |
Significant Items in Net Deferred Tax Liability | Alagasco’s significant items comprising the net deferred tax asset reported in the Balance Sheets as of September 30 are as follows: 2016 2015 Deferred tax assets: Reserves not currently deductible $ 6.3 $ 7.0 Pension and other postretirement benefits 11.4 9.6 Goodwill 233.4 251.5 Operating losses 60.2 32.4 Other — 1.4 Total deferred tax assets 311.3 301.9 Deferred tax liabilities: Relating to utility property 87.6 45.1 Other 2.3 2.2 Total deferred tax liabilities 89.9 47.3 Net deferred tax asset 221.4 254.6 Net deferred tax asset – current — 6.2 Net deferred tax asset – noncurrent $ 221.4 $ 248.4 |
Unrecognized Tax Benefit Reconciliation | The following table presents a reconciliation of the beginning and ending balances of Alagasco’s unrecognized tax benefits: Year Ended September 30, Year Ended September 30, Nine Months Ended September 30, 2016 2015 2014 Unrecognized tax benefits, beginning of period $ — $ — $ 0.3 Reduction for transfer of balance to Energen — — (0.3 ) Unrecognized tax benefits, end of period $ — $ — $ — |
PENSION PLANS AND OTHER POSTR41
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Fair value measurements of plan assets | The table below categorizes the fair value measurements of the Spire pension plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 51.2 $ — $ — $ 51.2 Stock/bond mutual fund 99.3 26.7 0.1 126.1 Debt Securities US bond mutual funds 23.0 126.0 — 149.0 US government 42.1 3.0 — 45.1 US corporate 137.4 — — 137.4 US municipal 6.3 — — 6.3 International 25.3 — — 25.3 Derivatives and margin (payable) (1.0 ) 1.1 — 0.1 Total $ 383.6 $ 156.8 $ 0.1 $ 540.5 As of September 30, 2015 Cash and cash equivalents $ 43.4 $ 0.2 $ — $ 43.6 Stock/bond mutual fund 46.4 74.6 9.6 130.6 Debt Securities US bond mutual funds — 9.3 — 9.3 US government 58.7 — — 58.7 US corporate 123.7 42.9 — 166.6 US municipal — 5.9 — 5.9 International — 31.3 — 31.3 Derivative instruments — 2.9 — 2.9 Total $ 272.2 $ 167.1 $ 9.6 $ 448.9 The table below categorizes the fair value measurements of Spire’s postretirement plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 4.8 $ — $ — $ 4.8 US stock/bond mutual fund 157.9 68.5 — 226.4 International fund 0.9 14.3 — 15.2 Total $ 163.6 $ 82.8 $ — $ 246.4 As of September 30, 2015 Cash and cash equivalents $ 1.6 $ — $ — $ 1.6 US stock/bond mutual fund 115.5 92.8 — 208.3 International fund — 13.4 — 13.4 Total $ 117.1 $ 106.2 $ — $ 223.3 |
Pension Plans | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Net periodic cost | The net periodic pension costs include the following components: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Service cost – benefits earned during the period $ 15.3 $ 17.3 $ 10.2 $ 10.0 $ 11.5 $ 9.7 $ 5.3 $ 5.8 $ 5.1 Interest cost on projected benefit obligation 28.0 29.5 24.5 21.7 23.3 24.0 6.3 6.2 4.1 Expected return on plan assets (34.9 ) (37.4 ) (27.2 ) (26.7 ) (29.2 ) (26.5 ) (8.2 ) (8.2 ) (5.2 ) Amortization of other comprehensive income — — 0.4 — — — — — — Amortization of prior service cost 0.4 0.5 0.5 0.4 0.5 0.5 — — 0.1 Amortization of actuarial loss 8.0 7.5 7.1 7.9 7.5 7.1 0.1 — 2.2 Loss on lump-sum settlements 3.3 19.6 1.5 — 18.0 1.5 3.3 1.6 10.1 Special termination benefits 1.6 — — 1.6 — — — — — Subtotal 21.7 37.0 17.0 14.9 31.6 16.3 6.8 5.4 16.4 Regulatory adjustment 17.8 (2.1 ) 10.4 11.7 (5.2 ) 10.4 6.1 3.1 0.4 Net pension cost $ 39.5 $ 34.9 $ 27.4 $ 26.6 $ 26.4 $ 26.7 $ 12.9 $ 8.5 $ 16.8 * Nine months ended September 30 |
Other changes in plan assets and benefit obligations recognized in other comprehensive income | Other changes in plan assets and pension benefit obligations recognized in other comprehensive income or loss (OCI) include the following: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Current year actuarial loss $ 46.8 $ 48.3 $ 15.7 $ 21.6 $ 26.0 $ 14.2 $ 25.2 $ 22.3 $ 1.5 Amortization of actuarial loss (8.0 ) (7.5 ) (7.1 ) (7.9 ) (7.5 ) (7.1 ) (0.1 ) — — Acceleration of loss recognized due to settlement (3.3 ) (19.6 ) (1.5 ) — (18.0 ) (1.5 ) (3.3 ) (1.6 ) — Amortization of current year service cost 5.0 — — 5.0 — — — — — Amortization of prior service cost (0.4 ) (0.5 ) (0.5 ) (0.4 ) (0.5 ) (0.5 ) — — — Subtotal 40.1 20.7 6.6 18.3 — 5.1 21.8 20.7 1.5 Regulatory adjustment (39.8 ) (21.2 ) (6.1 ) (18.0 ) (0.5 ) (4.7 ) (21.8 ) (20.7 ) (1.5 ) Total recognized in OCI $ 0.3 $ (0.5 ) $ 0.5 $ 0.3 $ (0.5 ) $ 0.4 $ — $ — $ — * Nine months ended September 30 |
Reconciliation of the beginning and ending balances of benefit obligation | The following table shows the reconciliation of the beginning and ending balances of the pension benefit obligation at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Benefit obligation, beginning of year $ 652.3 $ 692.4 $ 497.6 $ 543.6 $ 154.7 $ 148.8 Service cost 15.3 17.3 10.0 11.5 5.3 5.8 Interest cost 28.0 29.5 21.7 23.3 6.3 6.2 Actuarial loss (gain) 85.8 (12.8 ) 59.2 (20.7 ) 26.6 7.9 Plan amendments 5.1 — 5.1 — — — EnergySouth acquisition 60.4 — — — — — Settlement loss 1.1 16.5 — 14.5 1.1 2.0 Special termination benefits 1.6 — 1.6 — — — Settlement benefits paid (16.6 ) (71.1 ) — (58.2 ) (16.6 ) (12.9 ) Regular benefits paid (38.3 ) (19.5 ) (35.2 ) (16.4 ) (3.1 ) (3.1 ) Benefit obligation, end of year $ 794.7 $ 652.3 $ 560.0 $ 497.6 $ 174.3 $ 154.7 Accumulated benefit obligation, end of year 724.5 $ 591.4 517.7 $ 456.9 149.8 $ 134.5 |
Fair value of plan assets | The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Fair value of plan assets, beginning of year $ 448.9 $ 506.6 $ 339.9 $ 387.4 $ 109.0 $ 119.2 Actual return on plan assets 75.1 (7.2 ) 64.4 (3.0 ) 10.7 (4.2 ) Employer contributions 26.6 40.1 26.6 30.1 — 10.0 EnergySouth acquisition 44.8 — — — — — Settlement benefits paid (16.6 ) (71.1 ) — (58.2 ) (16.6 ) (12.9 ) Regular benefits paid (38.3 ) (19.5 ) (35.2 ) (16.4 ) (3.1 ) (3.1 ) Fair value of plan assets, end of year $ 540.5 $ 448.9 $ 395.7 $ 339.9 $ 100.0 $ 109.0 Funded status of plans, end of year $ (254.2 ) $ (203.4 ) $ (164.3 ) $ (157.7 ) $ (74.3 ) $ (45.7 ) |
Amounts recognized in consolidated balance sheets | The following table sets forth the amounts recognized in the balance sheets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Current liabilities $ (0.6 ) $ (0.5 ) $ (0.6 ) $ (0.5 ) $ — $ — Noncurrent liabilities (253.6 ) (202.9 ) (163.7 ) (157.2 ) (74.3 ) (45.7 ) Total $ (254.2 ) $ (203.4 ) $ (164.3 ) $ (157.7 ) $ (74.3 ) $ (45.7 ) Pre-tax amounts recognized in accumulated other comprehensive loss not yet recognized as components of net periodic pension cost consist of: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Net actuarial loss $ 179.4 $ 143.9 $ 135.5 $ 121.9 $ 43.9 $ 22.0 Prior service costs 8.2 3.5 8.2 3.5 — — Subtotal 187.6 147.4 143.7 125.4 43.9 22.0 Adjustments for amounts included in regulatory assets (184.8 ) (144.9 ) (140.9 ) (122.9 ) (43.9 ) (22.0 ) Total $ 2.8 $ 2.5 $ 2.8 $ 2.5 $ — $ — |
Pre-tax amounts amortized from accumulated other comprehensive income into net periodic cost | At September 30, 2016 , the following pre-tax amounts are expected to be amortized from accumulated other comprehensive loss into net periodic pension cost during fiscal year 2017 : Spire Laclede Gas Alagasco Amortization of net actuarial loss $ 13.5 $ 11.6 $ 1.9 Amortization of prior service cost 1.0 1.0 — Subtotal 14.5 12.6 1.9 Regulatory adjustment (14.2 ) (12.3 ) (1.9 ) Total $ 0.3 $ 0.3 $ — |
Assumptions used to calculate net periodic cost and benefit obligations. | The assumptions used to calculate the benefit obligations are as follows: 2016 2015 Weighted average discount rate - Laclede Gas division 3.50% 4.40% Weighted average discount rate - MGE division 3.50% 4.50% Weighted average discount rate - Alagasco 3.45%/3.50% 4.25%/4.30% Weighted average rate of future compensation increase - Laclede Gas, Alagasco and MGE 3.00% 3.00% The assumptions used to calculate net periodic pension costs for Laclede Gas are as follows: 2016 2015 2014 Weighted average discount rate - Laclede Gas division plans 4.40% 4.30% 4.70% Weighted average discount rate - MGE division plans 4.50% 4.45% 5.00% Weighted average rate of future compensation increase * 3.00% 3.00% 3.00% Expected long-term rate of return on plan assets * 7.75% 7.75% 7.75% * Assumptions for weighted average rate of future compensation increase and expected long-term rate of return on plan assets are the same for both Laclede Gas and MGE plans. The assumptions used to calculate net periodic pension costs for Alagasco are as follows: 2016 2015 2014* Weighted average discount rate 4.25% /4.30% 4.15% /4.25% 4.00% / 4.05% Weighted average rate of future compensation increase 3.00% 2.92% 2.92% Expected long-term rate of return on plan assets 7.50% 7.00% / 7.25% 7.00% / 7.25% * Nine-month transition period ended September 30 |
Projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have projected benefit obligation and accumulated benefit obligation in excess of plan assets | Following are the projected benefit obligation, accumulated benefit obligation, and fair value of plan assets for plans that have a projected benefit obligation and an accumulated benefit obligation in excess of plan assets: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Projected benefit obligation $ 794.8 $ 652.3 $ 560.0 $ 497.6 $ 174.3 $ 154.7 Accumulated benefit obligation 724.5 591.4 517.7 456.9 149.8 134.5 Fair value of plan assets 540.5 448.9 395.7 339.9 100.0 109.0 |
Targeted and actual plan assets by category | Following are the targeted and actual plan assets by category as of September 30 of each year for Laclede Gas and Alagasco: Laclede Gas 2016 Target 2016 Actual 2015 Target 2015 Actual Equity markets 56.2 % 56.9 % 52.0 % 48.4 % Debt securities 43.8 % 43.1 % 48.0 % 50.1 % Other* — % — % — % 1.5 % Total 100.0 % 100.0 % 100.0 % 100.0 % * Other investments in 2016 and 2015 consisted of cash equivalents. Alagasco 2016 Target 2016 Actual 2015 Target 2015 Actual Equity markets 60.0 % 59.2 % 60.0 % 52.9 % Debt securities 29.0 % 28.8 % 29.0 % 27.9 % Other* 11.0 % 12.0 % 11.0 % 19.2 % Total 100.0 % 100.0 % 100.0 % 100.0 % * Other investments in 2016 included cash, real estate, commodities, natural resources and TIPS. In 2015, this included cash and cash equivalents, hedge funds, real estate, and all asset funds, which can invest in equities or fixed income. |
Expected benefit payments for the succeeding five fiscal years | Following are expected pension benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter, for Spire, Laclede Gas, and Alagasco: 2017 2018 2019 2020 2021 2022- 2026 Spire $ 61.3 $ 56.2 $ 57.1 $ 56.6 $ 56.8 $ 286.3 Laclede Gas 48.2 43.3 43.5 42.2 40.4 196.6 Alagasco 10.9 10.6 11.2 11.9 13.7 74.5 |
Postretirement Plans | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Net periodic cost | Net periodic postretirement benefit costs consist of the following components: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Service cost – benefits earned during the period $ 10.9 $ 12.8 $ 11.3 $ 10.6 $ 12.3 $ 11.2 $ 0.3 $ 0.5 $ 0.4 Interest cost on accumulated postretirement benefit obligation 10.2 11.2 8.9 8.1 8.6 8.7 2.1 2.6 1.9 Expected return on plan assets (13.5 ) (13.2 ) (7.3 ) (8.5 ) (8.1 ) (6.8 ) (5.0 ) (5.1 ) (3.6 ) Amortization of prior other comprehensive loss — — (0.2 ) — — — — — — Amortization of prior service cost 0.3 0.8 — 0.3 0.8 — — — — Amortization of actuarial loss (gain) 3.6 5.1 6.0 3.8 5.1 6.0 (0.2 ) — (1.0 ) Special termination benefits 2.6 — — 2.6 — — — — — Subtotal 14.1 16.7 18.7 16.9 18.7 19.1 (2.8 ) (2.0 ) (2.3 ) Regulatory adjustment (6.6 ) (11.0 ) (9.6 ) (4.8 ) (9.2 ) (9.6 ) (1.8 ) (1.8 ) (0.2 ) Net postretirement benefit cost $ 7.5 $ 5.7 $ 9.1 $ 12.1 $ 9.5 $ 9.5 $ (4.6 ) $ (3.8 ) $ (2.5 ) * Nine months ended September 30 |
Other changes in plan assets and benefit obligations recognized in other comprehensive income | Other changes in plan assets and postretirement benefit obligations recognized in OCI include the following: Spire Laclede Gas Alagasco 2016 2015 2014 2016 2015 2014 2016 2015 2014* Current year actuarial loss (gain) $ 0.8 $ (8.5 ) $ (3.1 ) $ 1.4 $ (2.4 ) $ (4.2 ) $ (0.6 ) $ (6.1 ) $ 1.1 Amortization of actuarial (loss) gain (3.6 ) (5.1 ) (6.0 ) (3.8 ) (5.1 ) (6.0 ) 0.2 — — Amortization of prior service (cost) credit (0.3 ) (0.8 ) 2.5 (0.3 ) (0.8 ) 2.5 — — — Current year prior service credit (1.8 ) (4.9 ) — — (4.9 ) — (1.8 ) — — Subtotal (4.9 ) (19.3 ) (6.6 ) (2.7 ) (13.2 ) (7.7 ) (2.2 ) (6.1 ) 1.1 Regulatory adjustment 4.9 19.3 6.6 2.7 13.2 7.7 2.2 6.1 (1.1 ) Total recognized in OCI $ — $ — $ — $ — $ — $ — $ — $ — $ — * Nine months ended September 30 |
Reconciliation of the beginning and ending balances of benefit obligation | The following table sets forth the reconciliation of the beginning and ending balances of the postretirement benefit obligation at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Benefit obligation, beginning of year $ 239.2 $ 258.5 $ 191.9 $ 197.9 $ 47.3 $ 60.6 Service cost 10.9 12.8 10.6 12.3 0.3 0.5 Interest cost 10.2 11.2 8.1 8.6 2.1 2.6 Actuarial loss (gain) 7.1 (23.7 ) 6.7 (10.9 ) 0.4 (12.8 ) Plan amendments (1.8 ) (4.9 ) — (4.9 ) (1.8 ) — EnergySouth acquisition 5.9 — — — — — Special termination benefits 2.6 — 2.6 — — — Retiree drug subsidy program 0.2 0.4 — — 0.2 0.4 Gross benefits paid (15.1 ) (15.1 ) (12.0 ) (11.1 ) (3.1 ) (4.0 ) Benefit obligation, end of year $ 259.2 $ 239.2 $ 207.9 $ 191.9 $ 45.4 $ 47.3 |
Fair value of plan assets | The following table sets forth the reconciliation of the beginning and ending balances of the fair value of plan assets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Fair value of plan assets at beginning of year $ 223.3 $ 222.5 $ 143.6 $ 137.2 $ 79.7 $ 85.3 Actual return on plan assets 19.9 (2.0 ) 13.8 (0.4 ) 6.2 (1.6 ) Employer contributions 14.3 17.9 14.3 17.9 — — EnergySouth acquisition 4.0 — — — — — Gross benefits paid (15.1 ) (15.1 ) (12.0 ) (11.1 ) (3.1 ) (4.0 ) Fair value of plan assets, end of year $ 246.4 $ 223.3 $ 159.7 $ 143.6 $ 82.8 $ 79.7 Funded status of plans, end of year $ (12.8 ) $ (15.9 ) $ (48.2 ) $ (48.3 ) $ 37.4 $ 32.4 |
Amounts recognized in consolidated balance sheets | The following table sets forth the amounts recognized in the balance sheets at September 30: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Current assets $ 0.3 $ — $ 0.3 $ — $ — $ — Noncurrent assets 37.4 35.5 — 3.1 37.4 32.4 Current liabilities (0.4 ) (0.3 ) (0.4 ) (0.3 ) — — Noncurrent liabilities (50.1 ) (51.1 ) (48.1 ) (51.1 ) — — Total $ (12.8 ) $ (15.9 ) $ (48.2 ) $ (48.3 ) $ 37.4 $ 32.4 Pre-tax amounts recognized in accumulated other comprehensive loss not yet recognized as components of net periodic postretirement benefit cost consist of: Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Net actuarial loss $ 38.0 $ 40.8 $ 43.4 $ 45.8 $ (5.4 ) $ (5.0 ) Prior service credit (5.2 ) (3.1 ) (3.4 ) (3.1 ) (1.8 ) — Subtotal 32.8 37.7 40.0 42.7 (7.2 ) (5.0 ) Adjustments for amounts included in regulatory assets (32.8 ) (37.7 ) (40.0 ) (42.7 ) 7.2 5.0 Total $ — $ — $ — $ — $ — $ — |
Pre-tax amounts amortized from accumulated other comprehensive income into net periodic cost | At September 30, 2016 , the following pre-tax amounts are expected to be amortized from accumulated other comprehensive loss into net periodic postretirement benefit cost during fiscal year 2017: Spire Laclede Gas Alagasco Amortization of net actuarial loss (gain) $ 2.4 $ 2.5 $ (0.1 ) Amortization of prior service cost 0.1 0.3 (0.2 ) Subtotal 2.5 2.8 (0.3 ) Regulatory adjustment (2.5 ) (2.8 ) 0.3 Total $ — $ — $ — |
Assumptions used to calculate net periodic cost and benefit obligations. | The assumptions used to calculate the accumulated postretirement benefit obligations for Laclede Gas are as follows: 2016 2015 Weighted average discount rate - Laclede Gas division plans 3.15 % 4.00 % Weighted average discount rate - MGE division plans 3.45 % 4.30 % Weighted average rate of future compensation increase 3.00 % 3.00 % The assumptions used to calculate the accumulated postretirement benefit obligations for Alagasco are as follows: 2016 2015 Weighted average discount rate 3.60 % 4.50 % Weighted average rate of future compensation increase n/a n/a The assumptions used to calculate net periodic postretirement benefit costs for Laclede Gas are as follows: 2016 2015 2014 Weighted average discount rate Laclede Gas division plans 4.00 % 4.15 % 4.60 % Weighted average discount rate MGE division plans 4.30 % 4.40 % 4.95 % Weighted average rate of future compensation increase - Laclede Gas plans 3.00 % 3.00 % 3.00 % Expected long-term rate of return on plan assets - Laclede Gas division plans 6.00% / 7.75% 6.25% / 7.75% 6.25% / 7.75% Expected long-term rate of return on plan assets - MGE division plans 4.75 % 5.00 % 3.75% / 5.75% The assumptions used to calculate net periodic postretirement benefit costs for Alagasco are as follows: 2016 2015 2014 Weighted average discount rate 4.50 % 4.40 % 4.25 % Weighted average rate of future compensation increase n/a n/a 2.92 % Expected long-term rate of return on plan assets 4.50% / 7.25% 4.75% / 7.50% 4.75% / 7.25% |
Targeted and actual plan assets by category | Following are the targeted and actual plan assets by category as of September 30 of each year for Laclede Gas and Alagasco: Laclede Gas Target 2016 Actual 2015 Actual Equity securities 60.0 % 59.1 % 59.6 % Debt securities 40.0 % 39.4 % 39.7 % Other (cash and cash equivalents) — % 1.5 % 0.7 % Total 100.0 % 100.0 % 100.0 % Alagasco Target 2016 Actual 2015 Actual Equity securities 60.0 % 60.5 % 59.7 % Debt securities 40.0 % 39.5 % 40.3 % Total 100.0 % 100.0 % 100.0 % |
Expected benefit payments for the succeeding five fiscal years | Following are expected postretirement benefit payments for the succeeding five fiscal years, and in aggregate for the five years thereafter for Spire, Laclede Gas, and Alagasco: 2017 2018 2019 2020 2021 2022- 2026 Spire $ 15.4 $ 16.7 $ 17.9 $ 19.1 $ 20.1 $ 108.6 Laclede Gas 12.3 13.7 14.8 15.8 16.8 92.5 Alagasco 2.9 2.8 2.8 2.9 2.9 14.1 |
Assumed medical cost trend rates and effect of an assumed 1% changed in assumed medical cost trend. | The assumed medical cost trend rates at September 30 are as follows: 2016 2015 Medical cost trend assumed for next year - Laclede Gas 7.50 % 7.00 % Medical cost trend assumed for next year - Alagasco 7.50 % 7.00 % Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate) 5.00 % 5.00 % Year the rate reaches the ultimate trend 2023 2020 The following table presents the effects of an assumed 1% change in the assumed medical cost trend rate: Spire Laclede Gas Alagasco 1% Increase 1% Decrease 1% Increase 1% Decrease 1% Increase 1% Decrease Net periodic postretirement benefit cost $ 1.5 $ (1.4 ) $ 1.5 $ (1.4 ) $ — $ — Accumulated postretirement benefit obligation 11.0 (10.2 ) 9.0 (8.4 ) 1.3 (1.2 ) |
Laclede Gas | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
Fair value measurements of plan assets | The table below categorizes the fair value measurements of Laclede Gas’ pension plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 46.5 $ — $ — $ 46.5 Stock/bond mutual fund — 14.8 0.1 14.9 Debt Securities US bond mutual funds — 120.2 — 120.2 US government 42.1 3.0 — 45.1 US corporate 137.4 — — 137.4 US municipal 6.3 — — 6.3 International 25.2 — — 25.2 Derivatives and margin (payable) (1.0 ) 1.1 — 0.1 Total $ 256.5 $ 139.1 $ 0.1 $ 395.7 As of September 30, 2015 Cash and cash equivalents $ 31.8 $ — $ — $ 31.8 Stock/bond mutual funds — 67.6 0.1 67.7 Debt Securities US government 37.7 — — 37.7 US corporate 123.7 42.9 — 166.6 US municipal — 5.9 — 5.9 International — 27.3 — 27.3 Derivative instruments — 2.9 — 2.9 Total $ 193.2 $ 146.6 $ 0.1 $ 339.9 The table below categorizes the fair value measurements of Laclede Gas’ postretirement plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 4.6 $ — $ — $ 4.6 US stock/bond mutual funds 155.1 — — 155.1 Total $ 159.7 $ — $ — $ 159.7 As of September 30, 2015 Cash and cash equivalents $ 1.6 $ — $ — $ 1.6 US stock/bond mutual funds 115.5 26.5 — 142.0 Total $ 117.1 $ 26.5 $ — $ 143.6 Alagasco The table below categorizes the fair value measurements of Alagasco’s pension plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 Cash and cash equivalents $ 0.4 $ — $ — $ 0.4 Stock/bond mutual funds 59.0 11.9 — 70.9 Debt Securities US bond mutual funds 23.0 5.7 — 28.7 Total $ 82.4 $ 17.6 $ — $ 100.0 As of September 30, 2015 Cash and cash equivalents $ 11.6 $ 0.2 $ — $ 11.8 Stock/bond mutual fund 46.4 7.0 9.5 62.9 Debt Securities US bond mutual funds — 9.3 — 9.3 US government — 21.0 — 21.0 International — 4.0 — 4.0 Derivative instruments (b) — — — — Total $ 58.0 $ 41.5 $ 9.5 $ 109.0 The table below categorizes the fair value measurements of Alagasco’s postretirement plan assets: Quoted Prices in Active Markets (Level 1) Significant Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total As of September 30, 2016 US stock/bond mutual fund $ — $ 68.5 $ — $ 68.5 International fund — 14.3 — 14.3 Total $ — $ 82.8 $ — $ 82.8 As of September 30, 2015 US stock/bond mutual fund — 66.3 — 66.3 International fund — 13.4 — 13.4 Total $ — $ 79.7 $ — $ 79.7 |
INFORMATION BY OPERATING SEGM42
INFORMATION BY OPERATING SEGMENT (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Segment Reporting [Abstract] | |
Schedule of operating segment information | Gas Utility Gas Marketing Other Eliminations Consolidated 2016 Revenues from external customers $ 1,457.2 $ 78.5 $ 1.6 $ — $ 1,537.3 Intersegment revenues 2.2 — 3.2 (5.4 ) — Total Operating Revenues 1,459.4 78.5 4.8 (5.4 ) 1,537.3 Operating Expenses Gas Utility Natural and propane gas 539.7 — — (47.5 ) 492.2 Other operation and maintenance 379.3 — — (1.8 ) 377.5 Depreciation and amortization 136.9 — — — 136.9 Taxes, other than income taxes 125.2 — — — 125.2 Total Gas Utility Operating Expenses 1,181.1 — — (49.3 ) 1,131.8 Gas Marketing and Other — 66.7 (a) 12.6 (b) 43.9 123.2 Total Operating Expenses 1,181.1 66.7 12.6 (5.4 ) 1,255.0 Operating Income (Loss) 278.3 11.8 (7.8 ) — 282.3 Net Economic Earnings (Loss) 160.3 6.4 (17.6 ) — 149.1 Capital Expenditures 291.7 — 1.6 — 293.3 Gas Utility Gas Marketing Other Eliminations Consolidated 2015 Revenues from external customers $ 1,891.8 $ 82.9 $ 1.7 $ — $ 1,976.4 Intersegment revenues 4.0 70.5 2.0 (76.5 ) — Total Operating Revenues 1,895.8 153.4 3.7 (76.5 ) 1,976.4 Operating Expenses Gas Utility Natural and propane gas 957.6 — — (75.2 ) 882.4 Other operation and maintenance 391.6 — — (1.0 ) 390.6 Depreciation and amortization 129.9 — — — 129.9 Taxes, other than income taxes 142.1 — — — 142.1 Total Gas Utility Operating Expenses 1,621.2 — — (76.2 ) 1,545.0 Gas Marketing and Other — 146.6 (a) 12.6 (b) (0.3 ) 158.9 Total Operating Expenses 1,621.2 146.6 12.6 (76.5 ) 1,703.9 Operating Income (Loss) 274.6 6.8 (8.9 ) — 272.5 Net Economic Earnings (Loss) 150.4 4.2 (16.3 ) — 138.3 Capital Expenditures 284.4 — 5.4 — 289.8 Gas Utility Gas Marketing Other Eliminations Consolidated 2014 Revenues from external customers $ 1,462.6 $ 162.6 $ 2.0 $ — $ 1,627.2 Intersegment revenues 5.2 84.0 1.8 (91.0 ) — Total Operating Revenues 1,467.8 246.6 3.8 (91.0 ) 1,627.2 Operating Expenses Gas Utility Natural and propane gas 821.8 — — (90.1 ) 731.7 Other operation and maintenance 288.7 — — (0.9 ) 287.8 Depreciation and amortization 82.4 — — — 82.4 Taxes, other than income taxes 112.0 — — — 112.0 Total Gas Utility Operating Expenses 1,304.9 — — (91.0 ) 1,213.9 Gas Marketing and Other — 226.4 (a) 20.5 (b) — 246.9 Total Operating Expenses 1,304.9 226.4 20.5 (91.0 ) 1,460.8 Operating Income (Loss) 162.9 20.2 (16.7 ) — 166.4 Net Economic Earnings (Loss) 92.8 10.2 (2.9 ) — 100.1 Capital Expenditures 168.6 — 2.4 — 171.0 (a) Depreciation and amortization for Gas Marketing are included in Gas Marketing Expenses on the Consolidated Statements of Income ( $0.1 for 2016 , $0.3 for 2015 , and $0.4 for 2014 ). (b) Depreciation, amortization, and accretion for Other are included in the Other Operating Expenses on the Consolidated Statements of Income ( $0.5 for 2016 , $0.6 for 2015 , and $0.5 for 2014 ). Total Assets at End of Year 2016 2015 2014 Gas Utility $ 5,191.9 $ 4,686.2 $ 4,520.0 Gas Marketing 205.0 160.6 156.7 Other 1,842.4 1,560.2 1,575.7 Eliminations (1,161.9 ) (1,116.8 ) (1,178.4 ) Total Assets $ 6,077.4 $ 5,290.2 $ 5,074.0 |
Schedule of the reconciliation of consolidated net economic earnings to consolidated net income | Reconciliation of Consolidated Net Income to Consolidated Net Economic Earnings 2016 2015 2014 Net Income (GAAP) $ 144.2 $ 136.9 $ 84.6 Unrealized gain on energy-related derivatives (0.1 ) (2.8 ) (1.6 ) Lower of cost or market inventory adjustments 0.2 0.4 (1.1 ) Realized (gain) loss on economic hedges prior to the sale of the physical commodity (1.6 ) 2.4 (0.4 ) Acquisition, divestiture and restructuring activities 9.2 9.8 29.5 Gain on sale of property — (7.6 ) — Income tax effect of adjustments (2.8 ) (0.8 ) (10.9 ) Net Economic Earnings $ 149.1 $ 138.3 $ 100.1 |
REGULATORY MATTERS (Tables)
REGULATORY MATTERS (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Regulated Operations [Abstract] | |
Schedule of regulatory assets | The following regulatory assets and regulatory liabilities were reflected in the Balance Sheets as of September 30, 2016 and 2015 . Unamortized Purchased Gas Adjustments are also included below, which are reported separately in the current assets and liabilities sections of each balance sheet. Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Regulatory Assets: Current: Pension and postretirement benefit costs $ 27.0 $ 22.0 $ 20.2 $ 15.5 $ 6.8 $ 6.5 Unamortized purchased gas adjustments 49.7 12.9 43.1 12.9 5.6 — Other 17.2 5.6 3.7 0.7 8.1 4.9 Total Current Regulatory Assets 93.9 40.5 67.0 29.1 20.5 11.4 Noncurrent: Future income taxes due from customers 151.3 134.5 151.3 134.5 — — Pension and postretirement benefit costs 487.9 448.7 375.7 368.0 98.9 80.7 Cost of removal 130.6 78.9 — — 130.6 78.9 Purchased gas costs 12.6 24.1 12.6 24.1 — — Energy efficiency 25.5 22.3 25.5 22.3 — — Other 30.1 29.1 24.7 24.7 1.2 4.0 Total Noncurrent Regulatory Assets 838.0 737.6 589.8 573.6 230.7 163.6 Total Regulatory Assets $ 931.9 $ 778.1 $ 656.8 $ 602.7 $ 251.2 $ 175.0 Regulatory Liabilities: Current: RSE adjustment $ 7.5 $ 12.2 $ — $ — $ 5.0 $ 12.2 Unbilled service margin 5.9 6.4 — — 5.9 6.4 Refundable negative salvage 9.3 10.8 — — 9.3 10.8 Unamortized purchased gas adjustments 1.7 28.2 — — — 28.2 Other 6.2 3.0 1.3 0.6 2.5 2.4 Total Current Regulatory Liabilities 30.6 60.6 1.3 0.6 22.7 60.0 Noncurrent: Postretirement liabilities 28.9 28.9 — — 28.9 28.9 Refundable negative salvage 9.4 16.2 — — 9.4 16.2 Accrued cost of removal 74.8 58.7 55.1 58.7 — — Other 17.6 15.5 12.2 11.9 3.4 3.6 Total Noncurrent Regulatory Liabilities 130.7 119.3 67.3 70.6 41.7 48.7 Total Regulatory Liabilities $ 161.3 $ 179.9 $ 68.6 $ 71.2 $ 64.4 $ 108.7 A portion of the Company’s regulatory assets are not earning a return and are shown in the schedule below: Spire Laclede Gas 2016 2015 2016 2015 Future income taxes due from customers $ 151.3 $ 134.5 $ 151.3 $ 134.5 Pension and postretirement benefit costs 240.6 223.7 240.6 223.7 Compensated absences — — — — Other 12.9 14.2 12.9 14.2 Total Regulatory Assets Not Earning a Return $ 404.8 $ 372.4 $ 404.8 $ 372.4 |
Schedule of regulatory liabilities | The following regulatory assets and regulatory liabilities were reflected in the Balance Sheets as of September 30, 2016 and 2015 . Unamortized Purchased Gas Adjustments are also included below, which are reported separately in the current assets and liabilities sections of each balance sheet. Spire Laclede Gas Alagasco 2016 2015 2016 2015 2016 2015 Regulatory Assets: Current: Pension and postretirement benefit costs $ 27.0 $ 22.0 $ 20.2 $ 15.5 $ 6.8 $ 6.5 Unamortized purchased gas adjustments 49.7 12.9 43.1 12.9 5.6 — Other 17.2 5.6 3.7 0.7 8.1 4.9 Total Current Regulatory Assets 93.9 40.5 67.0 29.1 20.5 11.4 Noncurrent: Future income taxes due from customers 151.3 134.5 151.3 134.5 — — Pension and postretirement benefit costs 487.9 448.7 375.7 368.0 98.9 80.7 Cost of removal 130.6 78.9 — — 130.6 78.9 Purchased gas costs 12.6 24.1 12.6 24.1 — — Energy efficiency 25.5 22.3 25.5 22.3 — — Other 30.1 29.1 24.7 24.7 1.2 4.0 Total Noncurrent Regulatory Assets 838.0 737.6 589.8 573.6 230.7 163.6 Total Regulatory Assets $ 931.9 $ 778.1 $ 656.8 $ 602.7 $ 251.2 $ 175.0 Regulatory Liabilities: Current: RSE adjustment $ 7.5 $ 12.2 $ — $ — $ 5.0 $ 12.2 Unbilled service margin 5.9 6.4 — — 5.9 6.4 Refundable negative salvage 9.3 10.8 — — 9.3 10.8 Unamortized purchased gas adjustments 1.7 28.2 — — — 28.2 Other 6.2 3.0 1.3 0.6 2.5 2.4 Total Current Regulatory Liabilities 30.6 60.6 1.3 0.6 22.7 60.0 Noncurrent: Postretirement liabilities 28.9 28.9 — — 28.9 28.9 Refundable negative salvage 9.4 16.2 — — 9.4 16.2 Accrued cost of removal 74.8 58.7 55.1 58.7 — — Other 17.6 15.5 12.2 11.9 3.4 3.6 Total Noncurrent Regulatory Liabilities 130.7 119.3 67.3 70.6 41.7 48.7 Total Regulatory Liabilities $ 161.3 $ 179.9 $ 68.6 $ 71.2 $ 64.4 $ 108.7 |
COMMITMENTS AND CONTINGENCIES (
COMMITMENTS AND CONTINGENCIES (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Aggregate Rental Expense and Annual Minimum Rental Commitments | Aggregate rental expense and annual minimum rental commitments under all leases having an initial or remaining non-cancelable term of more than one year are shown below: Aggregate Rental Expense Minimum Rental Commitments 2016 2015 2014 2017 2018 2019 2020 2021 Later Total Spire $ 11.9 $ 14.1 $ 6.7 $ 10.5 $ 7.5 $ 7.3 $ 6.2 $ 6.0 $ 53.4 $ 90.9 Laclede Gas 4.3 7.6 6.3 2.5 0.9 0.9 0.3 0.1 — 4.7 Alagasco 3.7 4.0 2.0 3.9 2.5 2.5 2.1 2.1 4.9 18.0 |
INTERIM FINANCIAL INFORMATION45
INTERIM FINANCIAL INFORMATION (UNAUDITED) (Tables) | 12 Months Ended |
Sep. 30, 2016 | |
Quarterly Financial Information [Line Items] | |
Schedule of Quarterly Financial Information | Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 399.4 $ 609.3 $ 249.3 $ 279.3 Operating Income (Loss) 87.0 167.7 35.3 (7.7 ) Net Income (Loss) 46.9 100.8 10.7 (14.2 ) Basic Earnings (Loss) Per Share of Common Stock $ 1.08 $ 2.32 $ 0.24 $ (0.31 ) Diluted Earnings (Loss) Per Share of Common Stock $ 1.08 $ 2.31 $ 0.24 $ (0.31 ) Fiscal Year 2015 Total Operating Revenues $ 619.6 $ 877.4 $ 275.2 $ 204.2 Operating Income (Loss) 87.3 157.7 36.0 (8.5 ) Net Income (Loss) 47.1 94.4 14.1 (18.7 ) Basic Earnings (Loss) Per Share of Common Stock $ 1.09 $ 2.18 $ 0.32 $ (0.43 ) Diluted Earnings (Loss) Per Share of Common Stock $ 1.09 $ 2.18 $ 0.32 $ (0.43 ) |
Laclede Gas | |
Quarterly Financial Information [Line Items] | |
Schedule of Quarterly Financial Information | Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 317.2 $ 446.7 $ 179.3 $ 144.3 Operating Income 65.1 87.0 29.4 5.4 Net Income (Loss) 39.4 54.3 13.9 (1.7 ) Fiscal Year 2015 Total Operating Revenues $ 462.4 $ 615.7 $ 187.5 $ 151.0 Operating Income 64.8 80.6 34.5 5.5 Net Income (Loss) 39.0 49.9 20.0 (3.6 ) |
Alagasco | |
Quarterly Financial Information [Line Items] | |
Schedule of Quarterly Financial Information | Three Months Ended Dec. 31 March 31 June 30 Sept. 30 Fiscal Year 2016 Total Operating Revenues $ 82.3 $ 166.0 $ 74.0 $ 46.2 Operating Income (Loss) 18.9 80.4 9.3 (17.1 ) Net Income (Loss) 9.9 48.1 4.0 (8.8 ) Fiscal Year 2015 Total Operating Revenues $ 120.0 $ 233.3 $ 73.7 $ 52.2 Operating Income (Loss) 20.4 77.4 3.9 (12.5 ) Net Income (Loss) 10.6 46.3 0.7 (9.6 ) |
SUMMARY OF SIGNIFICANT ACCOUN46
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Narrative (Details) | Jun. 01, 2010 | Sep. 30, 2014USD ($) | Sep. 30, 2016USD ($)operating_segmentchange | Sep. 30, 2015USD ($) | Sep. 30, 2014USD ($) |
Related Party Transaction [Line Items] | |||||
Number of operating segments | operating_segment | 2 | ||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Capital expenditures | $ 293,300,000 | $ 289,800,000 | $ 171,000,000 | ||
Amount by which the replacement cost exceeds (less than) the cost basis value of stored gas inventories | $ 11,400,000 | 20,400,000 | |||
Number of months of the original maturity of debt instruments purchased | 3 months | ||||
Finance receivable, net | $ 11,800,000 | 11,200,000 | |||
Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Other Deferred Charges | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | (13,200,000) | (13,000,000) | |||
Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Long-Term Debt | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | $ 13,200,000 | $ 13,000,000 | |||
Laclede Gas | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Average annual depreciation and amortization expense percentage | 3.00% | 3.00% | 3.00% | 3.00% | |
Capital expenditures | $ 197,800,000 | $ 198,600,000 | $ 163,000,000 | ||
Accruals for capital expenditures | $ 14,800,000 | 9,600,000 | 3,000,000 | ||
Number of PGA discretionary changes | change | 3 | ||||
Months between PGA discretionary changes | 2 months | ||||
Cost savings retention percentage | 10.00% | ||||
Maximum amount of cost savings allowable | $ 3,000,000 | ||||
Accrued unbilled revenues | 26,100,000 | 27,600,000 | |||
Laclede Gas | Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Other Deferred Charges | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | (4,200,000) | (4,800,000) | |||
Laclede Gas | Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Long-Term Debt | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | 4,200,000 | 4,800,000 | |||
Alagasco | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Capital expenditures | $ 46,200,000 | 93,400,000 | 85,800,000 | $ 46,200,000 | |
Accruals for capital expenditures | $ 5,000,000 | $ 6,800,000 | 3,100,000 | ||
Composite depreciation rate | 3.10% | 3.10% | |||
Current refundable negative salvage costs to customers | $ 9,300,000 | ||||
Noncurrent refundable negative salvage costs to customers | $ 18,700,000 | ||||
Noncurrent refundable negative salvage costs period | 3 years | ||||
Accrued unbilled revenues | $ 5,900,000 | 6,400,000 | |||
Threshold period past due for collection | 90 days | ||||
Threshold period past due for write-off of financing receivable | 12 months | ||||
Write off on an allowance for credit losses | $ 400,000 | 400,000 | |||
Alagasco | Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Other Deferred Charges | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | (2,600,000) | (2,400,000) | |||
Alagasco | Retrospective Effect is ASU had been Adopted | ASU 2015-03 | New Accounting Pronouncement, Early Adoption, Effect | Long-Term Debt | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Deferred finance costs | 2,600,000 | 2,400,000 | |||
Alagasco | Financing Receivables, Equal to Greater than 90 Days Past Due | |||||
Utility Plant, Depreciation and Amortization [Abstract] | |||||
Finance receivable 90 days past due | $ 400,000 | $ 400,000 |
SUMMARY OF SIGNIFICANT ACCOUN47
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Asset Retirement Obligations (Details) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2015 | |
Asset retirement obligations [Roll forward] | ||
Asset retirement obligations, beginning of year | $ 159.2 | $ 99.2 |
Liabilities incurred during the period | 4.1 | 2.3 |
Liabilities settled during the period | (9.5) | (2) |
Accretion | 13.2 | 4.5 |
Revisions in estimated cash flows | 27.5 | 55.2 |
Asset retirement obligations, end of year | 206.4 | 159.2 |
Laclede Gas | ||
Asset retirement obligations [Roll forward] | ||
Asset retirement obligations, beginning of year | 72.4 | 71.2 |
Liabilities incurred during the period | 1.2 | 0.6 |
Liabilities settled during the period | (1.9) | (1.9) |
Accretion | 3.5 | 3.4 |
Revisions in estimated cash flows | 0 | (0.9) |
Asset retirement obligations, end of year | 75.2 | 72.4 |
Alagasco | ||
Asset retirement obligations [Roll forward] | ||
Asset retirement obligations, beginning of year | 86.6 | 27.7 |
Liabilities incurred during the period | 2.9 | 1.7 |
Liabilities settled during the period | (6.8) | (0.1) |
Accretion | 9.7 | 1.1 |
Revisions in estimated cash flows | 27.7 | 56.2 |
Asset retirement obligations, end of year | 120.1 | 86.6 |
EnergySouth | ||
Asset retirement obligations [Roll forward] | ||
Addition of EnergySouth asset retirement obligations | 11.9 | 0 |
EnergySouth | Laclede Gas | ||
Asset retirement obligations [Roll forward] | ||
Addition of EnergySouth asset retirement obligations | 0 | 0 |
EnergySouth | Alagasco | ||
Asset retirement obligations [Roll forward] | ||
Addition of EnergySouth asset retirement obligations | $ 0 | $ 0 |
SUMMARY OF SIGNIFICANT ACCOUN48
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Off System Sales (Details) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2017 | |
Eastern Missouri | First $2.0 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 2 | |
Customer Share | 100.00% | |
Company Share | 0.00% | |
Eastern Missouri | First $2.0 | Scenario, Forecast | ||
Off System Sales [Line Items] | ||
Customer Share | 85.00% | |
Company Share | 15.00% | |
Eastern Missouri | Next $2.0 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 2 | |
Customer Share | 80.00% | |
Company Share | 20.00% | |
Eastern Missouri | Next $2.0 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 2 | |
Customer Share | 75.00% | |
Company Share | 25.00% | |
Eastern Missouri | Amounts exceeding $6.0 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 6 | |
Customer Share | 70.00% | |
Company Share | 30.00% | |
Western Missouri | First $1.2 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 1.2 | |
Customer Share | 85.00% | |
Company Share | 15.00% | |
Western Missouri | Next $1.2 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 1.2 | |
Customer Share | 80.00% | |
Company Share | 20.00% | |
Western Missouri | Next $1.2 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 1.2 | |
Customer Share | 75.00% | |
Company Share | 25.00% | |
Western Missouri | Amounts exceeding $3.6 | ||
Off System Sales [Line Items] | ||
Pre-tax Income | $ 3.6 | |
Customer Share | 70.00% | |
Company Share | 30.00% |
SUMMARY OF SIGNIFICANT ACCOUN49
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Changes in Goodwill (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Goodwill [Roll Forward] | |||
Beginning balance | $ 946 | $ 937.8 | $ 247.1 |
Adjustments to finalize acquisition | 8.2 | (36.9) | |
Acquisition | 218.9 | 727.6 | |
Ending balance | 1,164.9 | 946 | 937.8 |
Operating Segments | Gas Utility | |||
Goodwill [Roll Forward] | |||
Beginning balance | 210.2 | 210.2 | 247.1 |
Adjustments to finalize acquisition | 0 | (36.9) | |
Acquisition | 0 | 0 | |
Ending balance | 210.2 | 210.2 | 210.2 |
Operating Segments | Gas Marketing | |||
Goodwill [Roll Forward] | |||
Beginning balance | 0 | 0 | 0 |
Adjustments to finalize acquisition | 0 | 0 | |
Acquisition | 0 | 0 | |
Ending balance | 0 | 0 | 0 |
Other | |||
Goodwill [Roll Forward] | |||
Beginning balance | 735.8 | 727.6 | 0 |
Adjustments to finalize acquisition | 8.2 | 0 | |
Acquisition | 218.9 | 727.6 | |
Ending balance | $ 954.7 | $ 735.8 | $ 727.6 |
SUMMARY OF SIGNIFICANT ACCOUN50
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Gross Receipts and Sales Taxes (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Schedule of Gross Receipts Taxes [Line Items] | |||
Gross Receipts taxes recorded in regulated gas distribution operating revenues | $ 75.5 | $ 97.3 | $ 77.5 |
Laclede Gas | |||
Schedule of Gross Receipts Taxes [Line Items] | |||
Gross Receipts taxes recorded in regulated gas distribution operating revenues | 57.4 | 74.5 | 76.3 |
Alagasco | |||
Schedule of Gross Receipts Taxes [Line Items] | |||
Gross Receipts taxes recorded in regulated gas distribution operating revenues | $ 17.9 | $ 22.6 | $ 20.6 |
SUMMARY OF SIGNIFICANT ACCOUN51
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Transactions with Affiliates (Details) - Affiliated Entity - Regulated Operation - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Laclede Gas | Laclede Energy Resources | |||
Related Party Transaction [Line Items] | |||
Revenue from related parties | $ 1.9 | $ 4 | $ 5.1 |
Laclede Energy Resources | Laclede Gas | |||
Related Party Transaction [Line Items] | |||
Revenue from related parties | 46.3 | 74.1 | 89.1 |
Laclede Risk Services | Laclede Gas | |||
Related Party Transaction [Line Items] | |||
Revenue from related parties | $ 1.8 | $ 1 | $ 0.6 |
ACQUISITIONS - Narrative (Detai
ACQUISITIONS - Narrative (Details) - USD ($) $ in Millions | Sep. 12, 2016 | Jan. 06, 2015 | Aug. 31, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2013 |
Business Acquisition [Line Items] | |||||||
Payments to acquire businesses, net of cash acquired | $ (317.7) | $ 0 | $ 0 | ||||
Goodwill | $ 1,164.9 | $ 946 | $ 937.8 | $ 247.1 | |||
Alagasco | |||||||
Business Acquisition [Line Items] | |||||||
Percentage of voting interest acquired | 100.00% | ||||||
Payments to acquire businesses, net of cash acquired | $ (1,313.4) | $ (1,305.2) | |||||
Payments for final reconciliation of acquisition | $ (8.2) | ||||||
Goodwill | 735.8 | ||||||
Goodwill, expected to be tax deductible | $ 717.6 | ||||||
EnergySouth | |||||||
Business Acquisition [Line Items] | |||||||
Percentage of voting interest acquired | 100.00% | ||||||
Payments to acquire businesses, net of cash acquired | $ (317.7) | ||||||
Goodwill | $ 218.9 |
ACQUISITIONS - Summary of Consi
ACQUISITIONS - Summary of Consideration Paid, Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 12, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | Aug. 31, 2014 | Sep. 30, 2013 |
Business Acquisition [Line Items] | ||||||
Goodwill | $ 1,164.9 | $ 946 | $ 937.8 | $ 247.1 | ||
Alagasco | ||||||
Business Acquisition [Line Items] | ||||||
Utility plant | $ 892.7 | |||||
Cash | 12.1 | |||||
Other current assets | 99.4 | |||||
Deferred tax assets | 282 | |||||
Other assets | 143.4 | |||||
Long-term debt | (249.8) | |||||
Current portion of long-term debt | (15) | |||||
Other current liabilities | (173.4) | |||||
Deferred tax liabilities | 0 | |||||
Other liabilities | (130.4) | |||||
Total identifiable net assets | 861 | |||||
Goodwill | 735.8 | |||||
Deferred tax elimination (Spire) | (271.3) | |||||
Consideration (cash) | $ 1,325.5 | |||||
EnergySouth | ||||||
Business Acquisition [Line Items] | ||||||
Utility plant | $ 199.5 | |||||
Cash | 2 | |||||
Other current assets | 17.5 | |||||
Deferred tax assets | 0 | |||||
Other assets | 79.8 | |||||
Long-term debt | (67) | |||||
Current portion of long-term debt | 0 | |||||
Other current liabilities | (42.7) | |||||
Deferred tax liabilities | (35.5) | |||||
Other liabilities | (52.8) | |||||
Total identifiable net assets | 100.8 | |||||
Goodwill | 218.9 | |||||
Deferred tax elimination (Spire) | 0 | |||||
Consideration (cash) | $ 319.7 |
ACQUISITIONS - Pro Forma Inform
ACQUISITIONS - Pro Forma Information, Revenues and Earnings (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Alagasco and EnergySouth | |||
Business Acquisition [Line Items] | |||
Total Operating Revenues | $ 1,632.4 | $ 2,081.6 | $ 2,187.1 |
Net Income | $ 153.9 | $ 143.6 | $ 133.5 |
Basic earnings (loss) per share (in dollars per share) | $ 3.48 | $ 3.32 | $ 3.11 |
Diluted earnings (loss) per share (in dollars per share) | $ 3.46 | $ 3.31 | $ 3.10 |
Alagasco | |||
Business Acquisition [Line Items] | |||
Pro forma, Total Operating Revenues | $ 368.5 | $ 479.2 | $ 19.7 |
Pro forma, Net Income (Loss) | $ 53.2 | $ 48 | $ (2.9) |
Pro forma, Earnings (Loss) Per Share (in dollars per share) | $ 1.20 | $ 1.11 | $ (0.08) |
EnergySouth | |||
Business Acquisition [Line Items] | |||
Pro forma, Total Operating Revenues | $ 3.3 | ||
Pro forma, Net Income (Loss) | $ (0.2) | ||
Pro forma, Earnings (Loss) Per Share (in dollars per share) | $ 0 |
STOCK-BASED COMPENSATION - Narr
STOCK-BASED COMPENSATION - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Vesting period, minimum | 3 years | ||
Number of shares of common stock that may be issued (in shares) | 1,000,000 | ||
Stock Option Awards [Abstract] | |||
Closing price of common stock (in dollars per share) | $ 63.74 | ||
Total unrecognized compensation costs | $ 9.2 | ||
Weighted average period for recognition of unrecognized compensation costs | 1 year 9 months 18 days | ||
Restricted Stock Awards | |||
Restricted Stock Awards [Abstract] | |||
Vested (in shares) | 107,238 | 128,135 | 88,533 |
Vested restricted stock withheld for tax withholding obligations (in shares) | 30,712 | 31,688 | 23,776 |
Vested restricted stock withheld for tax withholding obligations, weighted average price (in dollars per share) | $ 57.29 | $ 50.65 | $ 45.96 |
Fair value, restricted stock | $ 6.3 | $ 6.4 | $ 4.1 |
Actual tax benefit realized | $ 2.4 | $ 2.4 | $ 1.6 |
Restricted Stock Awards | Performance Vesting | |||
Restricted Stock Awards [Abstract] | |||
Granted (in shares) | 199,140 | ||
Granted, weighted average grant date fair value (in dollars per share) | $ 45.95 | ||
Vested (in shares) | 62,593 | ||
Restricted Stock Awards | Performance Vesting | Executive Officers and Key Employees | |||
Restricted Stock Awards [Abstract] | |||
Granted, weighted average grant date fair value (in dollars per share) | $ 36.69 | $ 37.21 | |
Restricted Stock Awards | Time Vesting | |||
Restricted Stock Awards [Abstract] | |||
Granted (in shares) | 48,730 | ||
Granted, weighted average grant date fair value (in dollars per share) | $ 60.65 | ||
Vested (in shares) | 44,645 | ||
Restricted Stock Awards | Time Vesting | Executive Officers and Key Employees | |||
Restricted Stock Awards [Abstract] | |||
Granted (in shares) | 35,210 | ||
Granted, weighted average grant date fair value (in dollars per share) | $ 59.40 | 50.90 | 45.66 |
Restricted Stock Awards | Time Vesting | Non Employee Directors | |||
Restricted Stock Awards [Abstract] | |||
Granted (in shares) | 13,520 | ||
Granted, weighted average grant date fair value (in dollars per share) | $ 63.93 | $ 54.66 | $ 46.02 |
Stock Option Awards | |||
Stock Option Awards [Abstract] | |||
Cash received from the exercise of stock options | $ 0.7 | $ 1.5 | $ 1.7 |
Intrinsic value of exercised | $ 0.7 | $ 0.9 | $ 0.9 |
STOCK-BASED COMPENSATION - Rest
STOCK-BASED COMPENSATION - Restricted Stock and Restricted Stock Unit Activity (Details) - Restricted Stock Awards - $ / shares | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Shares/ Units | |||
Vested (in shares) | (107,238) | (128,135) | (88,533) |
Performance Vesting | |||
Shares/ Units | |||
Nonvested at beginning of period (in shares) | 397,270 | ||
Granted (in shares) | 199,140 | ||
Vested (in shares) | (62,593) | ||
Forfeited (in shares) | (23,234) | ||
Nonvested at end of period (in shares) | 510,583 | 397,270 | |
Weighted Average Grant Date Fair Value Per Share | |||
Nonvested at beginning of period (in dollars per share) | $ 36.28 | ||
Granted (in dollars per share) | 45.95 | ||
Vested (in dollars per share) | 35.29 | ||
Forfeited (in dollars per share) | 30.96 | ||
Nonvested at end of period (in dollars per share) | $ 40.37 | $ 36.28 | |
Time Vesting | |||
Shares/ Units | |||
Nonvested at beginning of period (in shares) | 129,304 | ||
Granted (in shares) | 48,730 | ||
Vested (in shares) | (44,645) | ||
Forfeited (in shares) | (610) | ||
Nonvested at end of period (in shares) | 132,779 | 129,304 | |
Weighted Average Grant Date Fair Value Per Share | |||
Nonvested at beginning of period (in dollars per share) | $ 44.89 | ||
Granted (in dollars per share) | 60.65 | ||
Vested (in dollars per share) | 47.30 | ||
Forfeited (in dollars per share) | 53.12 | ||
Nonvested at end of period (in dollars per share) | $ 49.83 | $ 44.89 |
STOCK-BASED COMPENSATION - Stoc
STOCK-BASED COMPENSATION - Stock Option Awards Activity (Details) - Stock Option Awards | 12 Months Ended |
Sep. 30, 2016$ / sharesshares | |
Stock Options | |
Outstanding at beginning of period (in shares) | shares | 28,500 |
Exercised (in shares) | shares | (27,750) |
Forfeited (in shares) | shares | (750) |
Outstanding at end of period (in shares) | shares | 0 |
Weighted Average Exercise Price Per Share | |
Outstanding at beginning of period (in dollars per share) | $ / shares | $ 33.65 |
Exercised (in dollars per share) | $ / shares | 33.66 |
Forfeited (in dollars per share) | $ / shares | 33.45 |
Outstanding at end of period (in dollars per share) | $ / shares | $ 0 |
STOCK-BASED COMPENSATION - Fair
STOCK-BASED COMPENSATION - Fair Value Measurement Assumptions (Details) | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |||
Risk free interest rate | 1.14% | 0.83% | 0.53% |
Expected dividend yield of stock | 0.00% | 0.00% | 0.00% |
Expected volatility of stock | 15.00% | 14.00% | 18.00% |
Vesting period | 2 years 9 months 18 days | 2 years 9 months 18 days | 2 years 9 months 18 days |
STOCK-BASED COMPENSATION - Comp
STOCK-BASED COMPENSATION - Compensation Costs Recognized (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |||
Total equity compensation cost | $ 6.7 | $ 6.7 | $ 5.8 |
Compensation cost capitalized | (2.2) | (1.8) | (1.8) |
Compensation cost recognized in net income | 4.5 | 4.9 | 4 |
Income tax benefit recognized in net income | (1.7) | (1.9) | (1.5) |
Compensation cost recognized in net income, net of income tax | $ 2.8 | $ 3 | $ 2.5 |
EARNINGS PER COMMON SHARE (Deta
EARNINGS PER COMMON SHARE (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | Jun. 11, 2014 | Jun. 30, 2014 | Sep. 30, 2016 | Jun. 30, 2016 | Mar. 31, 2016 | Dec. 31, 2015 | Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 |
Basic EPS: | |||||||||||||
Net income | $ (14.2) | $ 10.7 | $ 100.8 | $ 46.9 | $ (18.7) | $ 14.1 | $ 94.4 | $ 47.1 | $ 144.2 | $ 136.9 | $ 84.6 | ||
Less: Income allocated to participating securities | 0.5 | 0.5 | 0.3 | ||||||||||
Net Income Available to Common Shareholders | $ 143.7 | $ 136.4 | $ 84.3 | ||||||||||
Weighted Average Shares Outstanding, Basic (in Shares) | 44.1 | 43.2 | 35.8 | ||||||||||
Earnings Per Share of Common Stock (in dollars per share) | $ (0.31) | $ 0.24 | $ 2.32 | $ 1.08 | $ (0.43) | $ 0.32 | $ 2.18 | $ 1.09 | $ 3.26 | $ 3.16 | $ 2.36 | ||
Diluted EPS: | |||||||||||||
Net income | $ (14.2) | $ 10.7 | $ 100.8 | $ 46.9 | $ (18.7) | $ 14.1 | $ 94.4 | $ 47.1 | $ 144.2 | $ 136.9 | $ 84.6 | ||
Less: Income allocated to participating securities | 0.5 | 0.5 | 0.3 | ||||||||||
Net Income Available to Common Shareholders | $ 143.7 | $ 136.4 | $ 84.3 | ||||||||||
Weighted Average Shares Outstanding, Basic (in Shares) | 44.1 | 43.2 | 35.8 | ||||||||||
Dilutive Effect of Stock Options, Restricted Stock, and Restricted Stock Units (in shares) | 0.2 | 0.1 | 0.1 | ||||||||||
Weighted Average Diluted Shares (in shares) | 44.3 | 43.3 | 35.9 | ||||||||||
Earnings Per Share of Common Stock (in dollars per share) | $ (0.31) | $ 0.24 | $ 2.31 | $ 1.08 | $ (0.43) | $ 0.32 | $ 2.18 | $ 1.09 | $ 3.24 | $ 3.16 | $ 2.35 | ||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||||||||||||
Equity units, contract annual rate | 4.75% | 2.00% | |||||||||||
Restricted stock and stock units subject to performance and/or market conditions | |||||||||||||
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items] | |||||||||||||
Outstanding shares excluded from calculation of diluted EPS (in shares) | 0.3 | 0.3 | 0.3 |
STOCKHOLDERS' EQUITY - Narrativ
STOCKHOLDERS' EQUITY - Narrative (Details) $ / shares in Units, Equity_Security in Thousands | May 17, 2016USD ($)shares | Jun. 11, 2014USD ($)Equity_Security | Apr. 30, 2017shares | Jun. 30, 2014USD ($)shares$ / shares | Sep. 30, 2016USD ($)$ / sharesshares | Sep. 30, 2015USD ($)$ / sharesshares | Sep. 30, 2014USD ($)shares | Nov. 11, 2016shares | Feb. 10, 2016USD ($) | Jun. 30, 2015USD ($) | Jun. 20, 2014shares |
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Number of equity units issued (in shares) | 2,875 | 2,875,000 | |||||||||
Proceeds from convertible debt | $ | $ 143,800,000 | ||||||||||
Stated value per Corporate Unit (in dollars per share) | $ / shares | $ 50 | ||||||||||
Common stock, par value (in dollars per share) | $ / shares | $ 1 | $ 1 | $ 1 | ||||||||
Percentage of beneficial ownership interest in Subordinated Notes | 5.00% | ||||||||||
Stated principal amount of Subordinated Notes | $ | $ 1,000 | ||||||||||
Interest rate on Subordinated borrowing | 2.00% | ||||||||||
Issuance of stock (in shares) | 2,185,000 | ||||||||||
Shares reserved for issuance under the stock purchase contracts (in shares) | 4,200,000 | ||||||||||
SEC effective shelf registration Form S-3 sale and issuance authorization under the dividend reinvestment and stock purchase program (in shares) | 168,698 | 168,698 | |||||||||
SEC effective shelf registration Form S-3 remaining and available for issuance under the dividend reinvestment and stock purchase program (in shares) | 106,535 | ||||||||||
Issuance of common stock | $ | $ 133,200,000 | $ 133,200,000 | $ 456,800,000 | ||||||||
Preferred stock shares authorized (in shares) | 5,000,000 | 5,000,000 | |||||||||
Preferred stock shares issued (in shares) | 0 | 0 | |||||||||
Preferred stock shares outstanding (in shares) | 0 | 0 | |||||||||
Dividend payment restriction formula component - fixed amount | $ | $ 8,000,000 | ||||||||||
Retained earnings available to pay dividends in period | $ | $ 916,800,000 | $ 891,700,000 | |||||||||
Laclede Gas | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Common stock, par value (in dollars per share) | $ / shares | $ 1 | $ 1 | |||||||||
Issuance of common stock | $ | $ 1,100,000 | ||||||||||
Preferred stock shares authorized (in shares) | 1,480,000 | 1,480,000 | |||||||||
Regulatory preferred stock and debt securities issuance, amount authorized | $ | $ 300,000,000 | $ 300,000,000 | $ 518,000,000 | ||||||||
Laclede Gas | Affiliated Entity | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Issuance of stock (in shares) | 0 | 0 | 28 | ||||||||
Issuance of common stock | $ | $ 1,100,000 | ||||||||||
Alagasco | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Common stock, par value (in dollars per share) | $ / shares | $ 0.01 | $ 0.01 | |||||||||
Preferred stock shares authorized (in shares) | 120,000 | 120,000 | |||||||||
Preferred stock shares issued (in shares) | 0 | 0 | |||||||||
Preferred stock shares outstanding (in shares) | 0 | 0 | |||||||||
Subsequent Event | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
SEC effective shelf registration Form S-3 remaining and available for issuance under the dividend reinvestment and stock purchase program (in shares) | 101,439 | ||||||||||
Scenario, Forecast | Minimum | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Issuance of stock (in shares) | 2,500,000 | ||||||||||
Scenario, Forecast | Maximum | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Issuance of stock (in shares) | 3,100,000 | ||||||||||
Junior Subordinated Debt | |||||||||||
Accumulated other comprehensive income (loss), net of income taxes [Line Items] | |||||||||||
Proceeds from convertible debt | $ | $ 143,800,000 |
STOCKHOLDERS' EQUITY - Stock Pu
STOCKHOLDERS' EQUITY - Stock Purchase Obligation (Details) | 12 Months Ended | |
Sep. 30, 2016shares / contract$ / shares | Jun. 30, 2014$ / shares | |
Stock Purchase Obligation [Line Items] | ||
Stated value per Corporate Unit (in dollars per share) | $ 50 | |
Equal to or greater than $57.8125 | ||
Stock Purchase Obligation [Line Items] | ||
Market value per share of common stock (in dollars per share) | $ 57.8125 | |
Number of shares to be purchased per purchase contract | shares / contract | 0.8649 | |
Less than $57.8125, but greater than $46.25 | Minimum | ||
Stock Purchase Obligation [Line Items] | ||
Market value per share of common stock (in dollars per share) | $ 46.25 | |
Less than $57.8125, but greater than $46.25 | Maximum | ||
Stock Purchase Obligation [Line Items] | ||
Market value per share of common stock (in dollars per share) | 57.8125 | |
Less than or equal to $46.25 | ||
Stock Purchase Obligation [Line Items] | ||
Market value per share of common stock (in dollars per share) | $ 46.25 | |
Number of shares to be purchased per purchase contract | shares / contract | 1.0811 |
STOCKHOLDERS' EQUITY - Schedule
STOCKHOLDERS' EQUITY - Schedule of Company's Equity Units (Details) shares in Thousands, Equity_Security in Thousands, $ in Millions | Jun. 11, 2014USD ($)Equity_Security | Jun. 30, 2014shares | Sep. 30, 2014USD ($) |
Stockholders' Equity Note [Abstract] | |||
Number of equity units issued (in shares) | 2,875 | 2,875 | |
Total Net Proceeds | $ 139.4 | ||
Total Long-term Debt | $ 143.8 | ||
RSN Annual Interest Rate | 2.00% | ||
Stock Purchase Contract Annual Rate | 4.75% | 2.00% | |
Stock Purchase Contract Liability | $ 19.7 | $ 19.7 |
STOCKHOLDERS' EQUITY - Schedu64
STOCKHOLDERS' EQUITY - Schedule of Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | $ 1,573.6 | $ 1,508.4 | $ 1,046.3 |
Other comprehensive (loss) income | (2.2) | (0.3) | (0.9) |
BALANCE | 1,768.2 | 1,573.6 | 1,508.4 |
Laclede Gas | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | 1,037.8 | 1,007.8 | 973.9 |
Other comprehensive (loss) income | (0.1) | 0.2 | 0.2 |
BALANCE | 1,068.5 | 1,037.8 | 1,007.8 |
Net Unrealized Gains (Losses) on Cash Flow Hedges | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (0.4) | 0.2 | |
Other comprehensive (loss) income | (1.9) | (0.6) | |
BALANCE | (2.3) | (0.4) | 0.2 |
Net Unrealized Gains (Losses) on Cash Flow Hedges | Laclede Gas | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (0.2) | 0 | |
Other comprehensive (loss) income | 0.3 | (0.2) | |
BALANCE | 0.1 | (0.2) | 0 |
Defined Benefit Pension and Other Postretirement Benefit Plans | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (1.5) | (1.9) | |
Other comprehensive (loss) income | (0.3) | 0.4 | |
BALANCE | (1.8) | (1.5) | (1.9) |
Defined Benefit Pension and Other Postretirement Benefit Plans | Laclede Gas | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (1.5) | (1.9) | |
Other comprehensive (loss) income | (0.3) | 0.4 | |
BALANCE | (1.8) | (1.5) | (1.9) |
Net Unrealized Losses on Available for Sale Securities | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (0.1) | 0 | |
Other comprehensive (loss) income | 0 | (0.1) | |
BALANCE | (0.1) | (0.1) | 0 |
Net Unrealized Losses on Available for Sale Securities | Laclede Gas | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | 0 | 0 | |
Other comprehensive (loss) income | (0.1) | 0 | |
BALANCE | (0.1) | 0 | 0 |
AOCI | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (2) | (1.7) | (0.8) |
Other comprehensive (loss) income | (2.2) | (0.3) | (0.9) |
BALANCE | (4.2) | (2) | (1.7) |
AOCI | Laclede Gas | |||
AOCI Attributable to Parent, Net of Tax [Roll Forward] | |||
BALANCE | (1.7) | (1.9) | (2.1) |
Other comprehensive (loss) income | (0.1) | 0.2 | 0.2 |
BALANCE | $ (1.8) | $ (1.7) | $ (1.9) |
LONG-TERM DEBT - Maturities of
LONG-TERM DEBT - Maturities of Long-term Debt (Details) $ in Millions | Sep. 30, 2016USD ($) |
Maturities on long-term debt [Abstract] | |
2,017 | $ 250 |
2,018 | 100 |
2,019 | 180 |
2,020 | 40 |
2,021 | 55 |
Laclede Gas | |
Maturities on long-term debt [Abstract] | |
2,017 | 0 |
2,018 | 100 |
2,019 | 50 |
2,020 | 0 |
2,021 | 0 |
Alagasco | |
Maturities on long-term debt [Abstract] | |
2,017 | 0 |
2,018 | 0 |
2,019 | 0 |
2,020 | 40 |
2,021 | $ 0 |
LONG-TERM DEBT - Narrative (Det
LONG-TERM DEBT - Narrative (Details) - USD ($) | Dec. 01, 2015 | Sep. 15, 2015 | Jan. 15, 2015 | Sep. 30, 2016 | Nov. 11, 2016 | Sep. 09, 2016 | Feb. 10, 2016 | Sep. 30, 2015 | Jun. 30, 2015 | Feb. 03, 2015 | Nov. 03, 2014 | Aug. 19, 2014 | Jun. 20, 2014 | Jun. 11, 2014 |
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 625,000,000 | |||||||||||||
Stated interest rate on debt issued | 2.00% | |||||||||||||
Long-term debt amount bearing variable interest rate | $ 250,000,000 | |||||||||||||
Long-term debt | $ 2,085,800,000 | |||||||||||||
SEC effective shelf registration Form S-3 sale and issuance authorization under the dividend reinvestment and stock purchase program (in shares) | 168,698 | 168,698 | ||||||||||||
SEC effective shelf registration Form S-3 remaining and available for issuance under the dividend reinvestment and stock purchase program (in shares) | 106,535 | |||||||||||||
Percent of common stock equity | 49.10% | 47.00% | ||||||||||||
Percent of long-term debt | 50.90% | 53.00% | ||||||||||||
Debt instrument, principal outstanding, excluding current portion | $ 1,833,700,000 | $ 1,771,500,000 | ||||||||||||
Subsequent Event | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
SEC effective shelf registration Form S-3 remaining and available for issuance under the dividend reinvestment and stock purchase program (in shares) | 101,439 | |||||||||||||
Senior Notes | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | 1,942,000,000 | |||||||||||||
Senior Notes | Unsecured Series 2016 Senior Notes | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 165,000,000 | |||||||||||||
Senior Notes | Unsecured Series 2016 Senior Notes, Tranche A | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 35,000,000 | |||||||||||||
Stated interest rate on debt issued | 2.52% | |||||||||||||
Senior Notes | Unsecured Series 2016 Senior Notes, Tranche B | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 130,000,000 | |||||||||||||
Stated interest rate on debt issued | 3.13% | |||||||||||||
Senior Notes | No Call Options | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | 25,000,000 | |||||||||||||
Senior Notes | Make Whole Call Options | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | 937,000,000 | |||||||||||||
Senior Notes | One to six months prior to maturity | Subject to Callable at Par | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 730,000,000 | |||||||||||||
Redemption period prior to maturity, minimum | 1 month | |||||||||||||
Redemption period prior to maturity, maximum | 6 months | |||||||||||||
Senior Notes | One year prior to maturity | Subject to Callable at Par | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 250,000,000 | |||||||||||||
Junior Subordinated Debt | 2.0% Series A Remarketable Subordinated Notes, due April 1, 2022 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Stated interest rate on debt issued | 2.00% | |||||||||||||
Long-term debt | $ 143,800,000 | |||||||||||||
Laclede Gas | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 810,000,000 | |||||||||||||
Percent of common stock equity | 56.90% | 56.20% | ||||||||||||
Percent of long-term debt | 43.10% | 43.80% | ||||||||||||
Regulatory preferred stock and debt securities issuance, amount authorized | $ 300,000,000 | $ 300,000,000 | $ 518,000,000 | |||||||||||
Debt instrument, principal outstanding, excluding current portion | 808,300,000 | $ 808,100,000 | ||||||||||||
Laclede Gas | No Call Options | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | 25,000,000 | |||||||||||||
Laclede Gas | Make Whole Call Options | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | 435,000,000 | |||||||||||||
Laclede Gas | Three to six months prior to maturity | Subject to Callable at Par | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 350,000,000 | |||||||||||||
Redemption period prior to maturity, minimum | 3 months | |||||||||||||
Redemption period prior to maturity, maximum | 6 months | |||||||||||||
Laclede Gas | Subsequent Event | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Regulatory preferred stock and debt securities issuance, authorized debt issuance - remaining available | $ 300,000,000 | |||||||||||||
Alagasco | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 250,000,000 | |||||||||||||
Percent of common stock equity | 77.60% | 83.70% | ||||||||||||
Percent of long-term debt | 22.40% | 16.30% | ||||||||||||
Long-term debt reclassified to current | $ 250,000,000 | |||||||||||||
Long-term debt amount authorized | $ 80,000,000 | $ 35,000,000 | ||||||||||||
Debt instrument, principal outstanding, excluding current portion | 250,000,000 | $ 170,000,000 | ||||||||||||
Debt instrument redeemed | $ 34,800,000 | |||||||||||||
Alagasco | Make Whole Call Options | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 250,000,000 | |||||||||||||
Alagasco | 5.7% Notes, due January 15, 2035 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Stated interest rate on debt issued | 5.70% | |||||||||||||
Debt instrument, principal outstanding, excluding current portion | $ 34,800,000 | |||||||||||||
Alagasco | 5.368% Notes, due December 1, 2015 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 80,000,000 | |||||||||||||
Alagasco | 3.21% Notes, due September 15, 2025 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Stated interest rate on debt issued | 3.21% | 3.21% | ||||||||||||
Alagasco | Notes 4.31%, Due December 1, 2045 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Stated interest rate on debt issued | 4.31% | 4.31% | ||||||||||||
Alagasco | Unsecured notes | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 115,000,000 | |||||||||||||
Alagasco | Unsecured notes | 3.21% Notes, due September 15, 2025 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 35,000,000 | |||||||||||||
Stated interest rate on debt issued | 3.21% | |||||||||||||
Debt issued, maturity term | 10 years | |||||||||||||
Alagasco | Unsecured notes | Notes 4.31%, Due December 1, 2045 | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt issued amount | $ 80,000,000 | |||||||||||||
Stated interest rate on debt issued | 4.31% | |||||||||||||
Debt issued, maturity term | 30 years | |||||||||||||
Other subsidiaries | ||||||||||||||
Debt Instrument [Line Items] | ||||||||||||||
Long-term debt | $ 67,000,000 |
NOTES PAYABLE AND CREDIT AGRE67
NOTES PAYABLE AND CREDIT AGREEMENTS - Narrative (Details) | Sep. 02, 2014USD ($)bank | Sep. 30, 2016USD ($)bank |
Line of Credit Facility [Line Items] | ||
Speculative interest rate increase percent | 1.00% | |
Decrease in cash flow with an impact of 100 basis point interest rate increase | $ 2,700,000 | |
Laclede Gas | ||
Line of Credit Facility [Line Items] | ||
Speculative interest rate increase percent | 1.00% | |
Decrease in cash flow with an impact of 100 basis point interest rate increase | $ 2,200,000 | |
Alagasco | ||
Line of Credit Facility [Line Items] | ||
Speculative interest rate increase percent | 1.00% | |
Decrease in cash flow with an impact of 100 basis point interest rate increase | $ 400,000 | |
Line of Credit | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility borrowing capacity | $ 150,000,000 | |
Banks in syndicated line of credit facility | bank | 9 | |
Minimum required ratio of earnings before interest, taxes, depreciation, and amortization (EBITDA) times interest expense as required by the line of credit covenant | 70.00% | |
Debt to total capitalization ratio | 0.585 | |
Line of Credit | Laclede Gas | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility borrowing capacity | $ 450,000,000 | |
Banks in syndicated line of credit facility | bank | 10 | |
Minimum required ratio of earnings before interest, taxes, depreciation, and amortization (EBITDA) times interest expense as required by the line of credit covenant | 70.00% | |
Debt to total capitalization ratio | 0.497 | |
Line of Credit | Alagasco | ||
Line of Credit Facility [Line Items] | ||
Line of credit facility borrowing capacity | $ 150,000,000 | |
Banks in syndicated line of credit facility | bank | 12 | |
Minimum required ratio of earnings before interest, taxes, depreciation, and amortization (EBITDA) times interest expense as required by the line of credit covenant | 70.00% | |
Debt to total capitalization ratio | 0.278 | |
Line of Credit | Liabilities | Lender Concentration Risk | ||
Line of Credit Facility [Line Items] | ||
Percent of debt by a singe bank | 15.60% | |
Line of Credit | Liabilities | Lender Concentration Risk | Laclede Gas | ||
Line of Credit Facility [Line Items] | ||
Percent of debt by a singe bank | 15.60% | |
Line of Credit | Liabilities | Lender Concentration Risk | Alagasco | ||
Line of Credit Facility [Line Items] | ||
Percent of debt by a singe bank | 10.00% |
NOTES PAYABLE AND CREDIT AGRE68
NOTES PAYABLE AND CREDIT AGREEMENTS - Spire Short-term Borrowings (Details) - USD ($) | 1 Months Ended | 12 Months Ended | |
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | |
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 273,900,000 | $ 300,600,000 | |
Weighted average interest rate | 0.90% | 0.70% | |
Minimum borrowing outstanding | $ 73,100,000 | $ 180,100,000 | |
Maximum borrowing outstanding | 427,200,000 | 488,500,000 | |
Short-term debt | $ 398,700,000 | $ 338,000,000 | |
Weighted average interest rate | 1.10% | 0.80% | |
Line of Credit | |||
Short-term Debt [Line Items] | |||
Minimum borrowing outstanding | $ 0 | $ 32,500,000 | |
Maximum borrowing outstanding | 82,000,000 | 80,000,000 | |
Laclede Gas | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 215,700,000 | $ 213,000,000 | |
Weighted average interest rate | 0.70% | 0.40% | |
Minimum borrowing outstanding | $ 127,800,000 | $ 104,200,000 | |
Maximum borrowing outstanding | 307,200,000 | 341,000,000 | |
Short-term debt | $ 243,700,000 | $ 233,000,000 | |
Weighted average interest rate | 0.80% | 0.50% | |
Laclede Gas | Commercial Paper | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 201,000,000 | $ 212,700,000 | |
Weighted average interest rate | 0.70% | 0.40% | |
Minimum borrowing outstanding | $ 43,000,000 | $ 102,100,000 | |
Maximum borrowing outstanding | 307,200,000 | 341,000,000 | |
Short-term debt | $ 243,700,000 | $ 233,000,000 | |
Weighted average interest rate | 0.80% | 0.50% | |
Spire | Line of Credit | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 42,700,000 | $ 65,600,000 | |
Weighted average interest rate | 1.60% | 1.40% | |
Short-term debt | $ 73,000,000 | $ 74,000,000 | |
Weighted average interest rate | 1.80% | 1.50% | |
Alagasco | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 42,600,000 | $ 22,300,000 | |
Weighted average interest rate | 1.40% | 1.10% | |
Minimum borrowing outstanding | $ 19,000,000 | $ 0 | |
Maximum borrowing outstanding | 82,000,000 | 69,500,000 | |
Short-term debt | $ 82,000,000 | $ 31,000,000 | |
Weighted average interest rate | 1.50% | 1.20% | |
Alagasco | Line of Credit | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 22,300,000 | $ 30,200,000 | $ 22,300,000 |
Weighted average interest rate | 1.10% | 1.40% | 1.10% |
Minimum borrowing outstanding | $ 0 | $ 0 | |
Maximum borrowing outstanding | 82,000,000 | 69,500,000 | |
Short-term debt | $ 82,000,000 | $ 31,000,000 | |
Weighted average interest rate | 1.50% | 1.20% |
NOTES PAYABLE AND CREDIT AGRE69
NOTES PAYABLE AND CREDIT AGREEMENTS - Laclede Gas' Short-term Borrowings (Details) - USD ($) | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2015 | |
Short-term Debt [Line Items] | ||
Weighted average borrowings outstanding | $ 273,900,000 | $ 300,600,000 |
Weighted average interest rate | 0.90% | 0.70% |
Minimum borrowing outstanding | $ 73,100,000 | $ 180,100,000 |
Maximum borrowing outstanding | 427,200,000 | 488,500,000 |
Short-term debt | $ 398,700,000 | $ 338,000,000 |
Weighted average interest rate | 1.10% | 0.80% |
Laclede Gas | ||
Short-term Debt [Line Items] | ||
Weighted average borrowings outstanding | $ 215,700,000 | $ 213,000,000 |
Weighted average interest rate | 0.70% | 0.40% |
Minimum borrowing outstanding | $ 127,800,000 | $ 104,200,000 |
Maximum borrowing outstanding | 307,200,000 | 341,000,000 |
Short-term debt | $ 243,700,000 | $ 233,000,000 |
Weighted average interest rate | 0.80% | 0.50% |
Laclede Gas | Commercial Paper | ||
Short-term Debt [Line Items] | ||
Weighted average borrowings outstanding | $ 201,000,000 | $ 212,700,000 |
Weighted average interest rate | 0.70% | 0.40% |
Minimum borrowing outstanding | $ 43,000,000 | $ 102,100,000 |
Maximum borrowing outstanding | 307,200,000 | 341,000,000 |
Short-term debt | $ 243,700,000 | $ 233,000,000 |
Weighted average interest rate | 0.80% | 0.50% |
Laclede Gas | Notes Payable to Related Party | ||
Short-term Debt [Line Items] | ||
Weighted average borrowings outstanding | $ 14,700,000 | $ 300,000 |
Weighted average interest rate | 0.80% | 0.50% |
Minimum borrowing outstanding | $ 0 | $ 0 |
Maximum borrowing outstanding | 114,200,000 | 10,400,000 |
Short-term debt | $ 0 | $ 0 |
Weighted average interest rate | 0.00% | 0.00% |
NOTES PAYABLE AND CREDIT AGRE70
NOTES PAYABLE AND CREDIT AGREEMENTS - Alagasco's Short-term Borrowings (Details) - USD ($) | 1 Months Ended | 12 Months Ended | |
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | |
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 273,900,000 | $ 300,600,000 | |
Weighted average interest rate | 0.90% | 0.70% | |
Minimum borrowing outstanding | $ 73,100,000 | $ 180,100,000 | |
Maximum borrowing outstanding | 427,200,000 | 488,500,000 | |
Short-term debt | $ 398,700,000 | $ 338,000,000 | |
Weighted average interest rate | 1.10% | 0.80% | |
Line of Credit | |||
Short-term Debt [Line Items] | |||
Minimum borrowing outstanding | $ 0 | $ 32,500,000 | |
Maximum borrowing outstanding | 82,000,000 | 80,000,000 | |
Alagasco | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 42,600,000 | $ 22,300,000 | |
Weighted average interest rate | 1.40% | 1.10% | |
Minimum borrowing outstanding | $ 19,000,000 | $ 0 | |
Maximum borrowing outstanding | 82,000,000 | 69,500,000 | |
Short-term debt | $ 82,000,000 | $ 31,000,000 | |
Weighted average interest rate | 1.50% | 1.20% | |
Alagasco | Line of Credit | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 22,300,000 | $ 30,200,000 | $ 22,300,000 |
Weighted average interest rate | 1.10% | 1.40% | 1.10% |
Minimum borrowing outstanding | $ 0 | $ 0 | |
Maximum borrowing outstanding | 82,000,000 | 69,500,000 | |
Short-term debt | $ 82,000,000 | $ 31,000,000 | |
Weighted average interest rate | 1.50% | 1.20% | |
Alagasco | Notes Payable to Related Party | |||
Short-term Debt [Line Items] | |||
Weighted average borrowings outstanding | $ 12,400,000 | $ 0 | |
Weighted average interest rate | 1.40% | 0.00% | |
Minimum borrowing outstanding | $ 0 | $ 0 | |
Maximum borrowing outstanding | 61,900,000 | 0 | |
Short-term debt | $ 0 | $ 0 | |
Weighted average interest rate | 0.00% | 0.00% |
FAIR VALUE OF FINANCIAL INSTR71
FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2013 | Sep. 30, 2013 |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | $ 5.2 | $ 13.8 | $ 16.1 | $ 53 | |
Carrying Amount | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 5.2 | 13.8 | |||
Short-term debt | 398.7 | 338 | |||
Long-term debt, including current portion | 2,083.7 | 1,851.5 | |||
Fair Value | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 5.2 | 13.8 | |||
Short-term debt | 398.7 | 338 | |||
Long-term debt, including current portion | 2,257.1 | 1,944.2 | |||
Laclede Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 2.1 | 1.7 | 3.7 | $ 23.9 | |
Laclede Gas | Carrying Amount | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 2.1 | 1.7 | |||
Short-term debt | 243.7 | 233 | |||
Long-term debt, including current portion | 808.3 | 808.1 | |||
Laclede Gas | Fair Value | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 2.1 | 1.7 | |||
Short-term debt | 243.7 | 233 | |||
Long-term debt, including current portion | 900.4 | 880.2 | |||
Alagasco | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 7.2 | $ 5.6 | $ 3 | |
Alagasco | Carrying Amount | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 7.2 | |||
Short-term debt | 82 | 31 | |||
Long-term debt, including current portion | 250 | 250 | |||
Alagasco | Fair Value | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 7.2 | |||
Short-term debt | 82 | 31 | |||
Long-term debt, including current portion | 275.5 | 263.2 | |||
Quoted Prices in Active Markets (Level 1) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 5.2 | 13.8 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | 0 | 0 | |||
Quoted Prices in Active Markets (Level 1) | Laclede Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 2.1 | 1.7 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | 0 | 0 | |||
Quoted Prices in Active Markets (Level 1) | Alagasco | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 7.2 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | 0 | 0 | |||
Significant Observable Inputs (Level 2) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 398.7 | 338 | |||
Long-term debt, including current portion | 2,257.1 | 1,944.2 | |||
Significant Observable Inputs (Level 2) | Laclede Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 243.7 | 233 | |||
Long-term debt, including current portion | 900.4 | 880.2 | |||
Significant Observable Inputs (Level 2) | Alagasco | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 82 | 31 | |||
Long-term debt, including current portion | 275.5 | 263.2 | |||
Significant Unobservable Inputs (Level 3) | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | 0 | 0 | |||
Significant Unobservable Inputs (Level 3) | Laclede Gas | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | 0 | 0 | |||
Significant Unobservable Inputs (Level 3) | Alagasco | |||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Short-term debt | 0 | 0 | |||
Long-term debt, including current portion | $ 0 | $ 0 |
FAIR VALUE MEASUREMENTS (Detail
FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
ASSETS | ||
Derivative asset after the effects of netting | $ 13.3 | $ 5.2 |
LIABILITIES | ||
Derivative liability after the effects of netting | 4.9 | 7.6 |
Laclede Gas | ||
ASSETS | ||
Derivative asset after the effects of netting | 4.9 | 0 |
LIABILITIES | ||
Derivative liability after the effects of netting | 0.2 | 5.9 |
Fair Value, Measurements, Recurring | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (5) | (8.4) |
Derivative asset after the effects of netting | 34.3 | 24.7 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (7.6) | |
Derivative liability after the effects of netting | 4.9 | |
Fair Value, Measurements, Recurring | Laclede Gas | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.7) | (1.3) |
Derivative asset after the effects of netting | 25.8 | 19.5 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (1.6) | (16.7) |
Derivative liability after the effects of netting | 0.2 | 5.9 |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 22.9 | 23.1 |
LIABILITIES | ||
Derivative liability before effects of netting | 5.1 | |
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 22.4 | 16.8 |
LIABILITIES | ||
Derivative liability before effects of netting | 1.6 | 16.7 |
Fair Value, Measurements, Recurring | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 16.2 | 9.8 |
LIABILITIES | ||
Derivative liability before effects of netting | 7.4 | |
Fair Value, Measurements, Recurring | Significant Observable Inputs (Level 2) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 4.1 | 4 |
LIABILITIES | ||
Derivative liability before effects of netting | 0.2 | 5.9 |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0.2 | 0.2 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | US stock/bond mutual funds | Laclede Gas | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | 0 | 0 |
Derivative asset after the effects of netting | 20.9 | 19.5 |
Fair Value, Measurements, Recurring | US stock/bond mutual funds | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 16.8 | 15.5 |
Fair Value, Measurements, Recurring | US stock/bond mutual funds | Significant Observable Inputs (Level 2) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 4.1 | 4 |
Fair Value, Measurements, Recurring | US stock/bond mutual funds | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | NYMEX/ICE natural gas contracts | Laclede Gas | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.4) | (1.3) |
Derivative asset after the effects of netting | 4.9 | 0 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (1.6) | (16.4) |
Derivative liability after the effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 5.3 | 1.3 |
LIABILITIES | ||
Derivative liability before effects of netting | 1.6 | 16.4 |
Fair Value, Measurements, Recurring | NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | OTCBB natural gas contracts | Laclede Gas | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | 0 | 0 |
Derivative liability after the effects of netting | 0.2 | 5.9 |
Fair Value, Measurements, Recurring | OTCBB natural gas contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | OTCBB natural gas contracts | Significant Observable Inputs (Level 2) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0.2 | 5.9 |
Fair Value, Measurements, Recurring | OTCBB natural gas contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Fair Value, Measurements, Recurring | Gasoline and heating oil contracts | Laclede Gas | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.3) | |
Derivative asset after the effects of netting | 0 | |
Fair Value, Measurements, Recurring | Gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0.3 | |
Fair Value, Measurements, Recurring | Gasoline and heating oil contracts | Significant Observable Inputs (Level 2) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
Fair Value, Measurements, Recurring | Gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
Fair Value, Measurements, Recurring | NYMEX gasoline and heating oil contracts | Laclede Gas | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (0.3) | |
Derivative liability after the effects of netting | 0 | |
Fair Value, Measurements, Recurring | NYMEX gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0.3 | |
Fair Value, Measurements, Recurring | NYMEX gasoline and heating oil contracts | Significant Observable Inputs (Level 2) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Fair Value, Measurements, Recurring | NYMEX gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3) | Laclede Gas | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Fair Value, Measurements, Recurring | Gas Marketing | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (22.3) | |
Derivative liability after the effects of netting | 7.6 | |
Fair Value, Measurements, Recurring | Gas Marketing | Quoted Prices in Active Markets (Level 1) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 17.9 | |
Fair Value, Measurements, Recurring | Gas Marketing | Significant Observable Inputs (Level 2) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 12 | |
Fair Value, Measurements, Recurring | Gas Marketing | Significant Unobservable Inputs (Level 3) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.7) | (1.3) |
Derivative asset after the effects of netting | 25.9 | 19.5 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (1.6) | (16.7) |
Derivative liability after the effects of netting | 0.2 | 5.9 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 22.5 | 16.8 |
LIABILITIES | ||
Derivative liability before effects of netting | 1.6 | 16.7 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 4.1 | 4 |
LIABILITIES | ||
Derivative liability before effects of netting | 0.2 | 5.9 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | US stock/bond mutual funds | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | 0 | 0 |
Derivative asset after the effects of netting | 20.9 | 19.5 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | US stock/bond mutual funds | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 16.8 | 15.5 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | US stock/bond mutual funds | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 4.1 | 4 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | US stock/bond mutual funds | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX/ICE natural gas contracts | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.4) | (1.3) |
Derivative asset after the effects of netting | 4.9 | 0 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (1.6) | (16.4) |
Derivative liability after the effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 5.3 | 1.3 |
LIABILITIES | ||
Derivative liability before effects of netting | 1.6 | 16.4 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | OTCBB natural gas contracts | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | 0 | 0 |
Derivative liability after the effects of netting | 0.2 | 5.9 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | OTCBB natural gas contracts | Quoted Prices in Active Markets (Level 1) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | OTCBB natural gas contracts | Significant Observable Inputs (Level 2) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0.2 | 5.9 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | OTCBB natural gas contracts | Significant Unobservable Inputs (Level 3) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Gasoline and heating oil contracts | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.3) | |
Derivative asset after the effects of netting | 0.1 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 0.4 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Gasoline and heating oil contracts | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | Gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX gasoline and heating oil contracts | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (0.3) | |
Derivative liability after the effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX gasoline and heating oil contracts | Quoted Prices in Active Markets (Level 1) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0.3 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX gasoline and heating oil contracts | Significant Observable Inputs (Level 2) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Utility | NYMEX gasoline and heating oil contracts | Significant Unobservable Inputs (Level 3) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX/ICE natural gas contracts | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (3.4) | |
Derivative asset after the effects of netting | 0.4 | |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (5.1) | (5.1) |
Derivative liability after the effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX/ICE natural gas contracts | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 0.4 | |
LIABILITIES | ||
Derivative liability before effects of netting | 3.5 | 1.2 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX/ICE natural gas contracts | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 3.4 | |
LIABILITIES | ||
Derivative liability before effects of netting | 1.6 | 3.9 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX/ICE natural gas contracts | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX natural gas contracts | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (6.6) | |
Derivative asset after the effects of netting | 4 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX natural gas contracts | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 6.3 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX natural gas contracts | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 4.3 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | NYMEX natural gas contracts | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | Natural gas commodity contracts | ||
ASSETS | ||
Effects of netting and cash margin receivables/payables | (0.9) | (0.5) |
Derivative asset after the effects of netting | 8 | 1.2 |
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | (0.9) | (0.5) |
Derivative liability after the effects of netting | 1.7 | 1.7 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | Natural gas commodity contracts | Quoted Prices in Active Markets (Level 1) | ||
ASSETS | ||
Derivative asset before effects of netting | 0 | 0 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | 0 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | Natural gas commodity contracts | Significant Observable Inputs (Level 2) | ||
ASSETS | ||
Derivative asset before effects of netting | 8.7 | 1.5 |
LIABILITIES | ||
Derivative liability before effects of netting | 2.6 | 2.2 |
Operating Segments | Fair Value, Measurements, Recurring | Gas Marketing | Natural gas commodity contracts | Significant Unobservable Inputs (Level 3) | ||
ASSETS | ||
Derivative asset before effects of netting | 0.2 | 0.2 |
LIABILITIES | ||
Derivative liability before effects of netting | 0 | $ 0 |
Other | Fair Value, Measurements, Recurring | Interest rate swaps | ||
LIABILITIES | ||
Effects of netting and cash margin receivables/payables | 0 | |
Derivative liability after the effects of netting | 3 | |
Other | Fair Value, Measurements, Recurring | Interest rate swaps | Quoted Prices in Active Markets (Level 1) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 0 | |
Other | Fair Value, Measurements, Recurring | Interest rate swaps | Significant Observable Inputs (Level 2) | ||
LIABILITIES | ||
Derivative liability before effects of netting | 3 | |
Other | Fair Value, Measurements, Recurring | Interest rate swaps | Significant Unobservable Inputs (Level 3) | ||
LIABILITIES | ||
Derivative liability before effects of netting | $ 0 |
DERIVATIVE INSTRUMENTS AND HE73
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES Narrative (Details) gal in Millions, MMBTU in Millions | Jun. 03, 2016USD ($) | May 21, 2015USD ($) | Aug. 06, 2014USD ($) | Sep. 30, 2016USD ($)MMBTU$ / galgal | Jun. 30, 2016USD ($) | Mar. 31, 2016USD ($) | Sep. 30, 2016USD ($)MMBTU$ / galgal | Sep. 30, 2015USD ($) | Sep. 30, 2014USD ($) | May 05, 2016USD ($) | Dec. 01, 2015USD ($) | Sep. 15, 2015USD ($) | Apr. 30, 2015USD ($) | Mar. 31, 2015USD ($) | Aug. 19, 2014USD ($) | Jul. 08, 2014USD ($) |
Derivative [Line Items] | ||||||||||||||||
Notional amount of non-exchange traded natural gas commodity contracts (in MMBtu) | MMBTU | 122.7 | 122.7 | ||||||||||||||
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2016 | MMBTU | 110.8 | 110.8 | ||||||||||||||
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2017 | MMBTU | 11.4 | 11.4 | ||||||||||||||
Notional amount of non-exchange traded natural gas commodity to be settled during fiscal 2018 | MMBTU | 0.2 | 0.2 | ||||||||||||||
Notional amount of non-exchange traded natural gas commodity to be settled during fiscal 2019 | MMBTU | 0.3 | 0.3 | ||||||||||||||
Notional amount | $ 120,000,000 | |||||||||||||||
Long-term debt issued amount | $ 625,000,000 | |||||||||||||||
Term of contract | 7 years | |||||||||||||||
Derivative average fixed interest rate | 1.501% | |||||||||||||||
Unrealized gain on energy-related derivatives | $ 100,000 | $ 2,800,000 | $ 1,600,000 | |||||||||||||
Gain (loss) to be reclassified within twelve months | 0 | |||||||||||||||
Cash margin receivables not offset with derivatives | $ 2,900,000 | $ 2,900,000 | 5,900,000 | |||||||||||||
Alagasco | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Unsecured debt | $ 115,000,000 | |||||||||||||||
Gasoline futures contracts notional amount (in gallons) | gal | 0.6 | 0.6 | ||||||||||||||
Average price of future contracts (dollars per gallon) | $ / gal | 1.53 | 1.53 | ||||||||||||||
Alagasco | 3.21% Notes, due September 15, 2025 | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Unsecured debt | $ 35,000,000 | |||||||||||||||
Alagasco | Notes 4.31%, Due December 1, 2045 | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Unsecured debt | $ 80,000,000 | |||||||||||||||
Laclede Gas | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
MMBtu (millions) | MMBTU | 19.8 | |||||||||||||||
Gain (loss) to be reclassified within twelve months | $ 0 | |||||||||||||||
Cash margin receivables not offset with derivatives | $ 500,000 | $ 500,000 | $ 5,900,000 | |||||||||||||
Gasoline futures contracts notional amount (in gallons) | gal | 1.8 | 1.8 | ||||||||||||||
Average price of future contracts (dollars per gallon) | $ / gal | 1.37 | 1.37 | ||||||||||||||
Interest rate swaps | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Notional amount | $ 105,000,000 | |||||||||||||||
Derivative fixed interest rate | 1.776% | |||||||||||||||
Term of contract | 5 years | |||||||||||||||
Unrealized gain on energy-related derivatives | $ 1,000,000 | $ (3,000,000) | ||||||||||||||
Designated as Hedging Instrument | Interest rate swaps | Alagasco | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Gain on settlement of derivative | $ 2,700,000 | |||||||||||||||
Cash Flow Hedging | Designated as Hedging Instrument | Interest rate swaps | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Notional amount | $ 85,000,000 | $ 24,000,000 | $ 375,000,000 | |||||||||||||
Loss on termination and settlement of interest rate swap | $ 19,000,000 | |||||||||||||||
Effective portion of gain (loss) recognized in OCI on derivatives | $ (400,000) | |||||||||||||||
Cash Flow Hedging | Designated as Hedging Instrument | Interest rate swaps | Alagasco | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Notional amount | $ 24,000,000 | $ 80,500,000 | ||||||||||||||
Cash Flow Hedging | Designated as Hedging Instrument | Interest rate swaps | Alagasco | Minimum | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Derivative fixed interest rate | 2.18% | |||||||||||||||
Cash Flow Hedging | Designated as Hedging Instrument | Interest rate swaps | Alagasco | Maximum | ||||||||||||||||
Derivative [Line Items] | ||||||||||||||||
Derivative fixed interest rate | 2.85% |
DERIVATIVE INSTRUMENTS AND HE74
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Exchange-Traded/Cleared Derivatives (Details) MMBTU in Thousands | 12 Months Ended |
Sep. 30, 2016MMBTU$ / gal$ / MMBTU | |
Laclede Gas | |
Derivative [Line Items] | |
MMBtu (millions) | 19,800 |
Avg. Price Per MMBtu | $ / gal | 1.37 |
Short | Gas Utility | Natural gas contracts | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Short | Gas Utility | Natural gas contracts | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Short | Gas Utility | ICE Open basis swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Short | Gas Utility | ICE Open basis swap positions | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Short | Gas Utility | ICE Open basis swap positions | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Short | Gas Marketing | Natural gas contracts | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 12,200 |
Avg. Price Per MMBtu | $ / MMBTU | 2.86 |
Short | Gas Marketing | Natural gas contracts | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 1,270 |
Avg. Price Per MMBtu | $ / MMBTU | 2.95 |
Short | Gas Marketing | ICE Open basis swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 11,880 |
Avg. Price Per MMBtu | $ / MMBTU | 0.19 |
Short | Gas Marketing | ICE Open basis swap positions | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 930 |
Avg. Price Per MMBtu | $ / MMBTU | 0.27 |
Short | Gas Marketing | ICE Open basis swap positions | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 2,270 |
Avg. Price Per MMBtu | $ / MMBTU | 0.13 |
Long | Gas Utility | Natural gas contracts | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 18,430 |
Avg. Price Per MMBtu | $ / MMBTU | 2.95 |
Long | Gas Utility | Natural gas contracts | Fiscal 2017 | Laclede Gas | |
Derivative [Line Items] | |
MMBtu (millions) | 18,430 |
Avg. Price Per MMBtu | $ / MMBTU | 2.95 |
Long | Gas Utility | Natural gas contracts | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 330 |
Avg. Price Per MMBtu | $ / MMBTU | 2.83 |
Long | Gas Utility | Natural gas contracts | Fiscal 2018 | Laclede Gas | |
Derivative [Line Items] | |
MMBtu (millions) | 330 |
Avg. Price Per MMBtu | $ / MMBTU | 2.83 |
Long | Gas Utility | Natural gas contracts | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Long | Gas Utility | ICE Open basis swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Long | Gas Utility | ICE Open basis swap positions | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Long | Gas Utility | ICE Open basis swap positions | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
Long | Gas Utility | OTC Open long futures/swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 320 |
Avg. Price Per MMBtu | $ / MMBTU | 3.64 |
Long | Gas Utility | OTC Open long futures/swap positions | Fiscal 2017 | Laclede Gas | |
Derivative [Line Items] | |
MMBtu (millions) | 320 |
Avg. Price Per MMBtu | $ / MMBTU | 3.64 |
Long | Gas Marketing | Natural gas contracts | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 4,620 |
Avg. Price Per MMBtu | $ / MMBTU | 3.12 |
Long | Gas Marketing | Natural gas contracts | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 450 |
Avg. Price Per MMBtu | $ / MMBTU | 3.02 |
Long | Gas Marketing | Natural gas contracts | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 40 |
Avg. Price Per MMBtu | $ / MMBTU | 2.89 |
Long | Gas Marketing | ICE Open basis swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 16,620 |
Avg. Price Per MMBtu | $ / MMBTU | 0.34 |
Long | Gas Marketing | ICE Open basis swap positions | Fiscal 2018 | |
Derivative [Line Items] | |
MMBtu (millions) | 2,010 |
Avg. Price Per MMBtu | $ / MMBTU | 0.43 |
Long | Gas Marketing | ICE Open basis swap positions | Fiscal 2019 | |
Derivative [Line Items] | |
MMBtu (millions) | 80 |
Avg. Price Per MMBtu | $ / MMBTU | 0.40 |
Long | Gas Marketing | OTC Open long futures/swap positions | Fiscal 2017 | |
Derivative [Line Items] | |
MMBtu (millions) | 0 |
Avg. Price Per MMBtu | $ / MMBTU | 0 |
DERIVATIVE INSTRUMENTS AND HE75
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Gains (Losses) on Derivative Instruments (Details) - USD ($) $ in Millions | Jun. 03, 2016 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 |
Designated as Hedging Instrument | Cash Flow Hedging | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | $ (1.1) | $ (4.4) | $ 2.5 | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.3 | (0.4) | (0.2) | |
Designated as Hedging Instrument | Cash Flow Hedging | Other Comprehensive Income (Loss) | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | (4) | (5.5) | (4.5) | |
Designated as Hedging Instrument | Cash Flow Hedging | Natural gas contracts | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | (0.6) | (3.5) | 2.7 | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.2 | (0.5) | 0 | |
Designated as Hedging Instrument | Cash Flow Hedging | Natural gas contracts | Other Comprehensive Income (Loss) | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | (0.6) | (4.3) | (4.6) | |
Designated as Hedging Instrument | Cash Flow Hedging | Natural gas contracts | Gas Marketing Operating Revenues | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | 4.3 | 1.7 | 4.2 | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.1 | 0 | (0.1) | |
Designated as Hedging Instrument | Cash Flow Hedging | Natural gas contracts | Gas Marketing Operating Expenses | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | (4.9) | (5.2) | (1.5) | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.1 | (0.5) | 0.1 | |
Designated as Hedging Instrument | Cash Flow Hedging | Gasoline and heating oil contracts | Other Comprehensive Income (Loss) | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | 0 | (1.2) | 0.1 | |
Designated as Hedging Instrument | Cash Flow Hedging | Gasoline and heating oil contracts | Gas Utility Other Operating Expenses | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | (0.5) | (0.9) | (0.2) | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.1 | 0.1 | (0.2) | |
Designated as Hedging Instrument | Cash Flow Hedging | Interest rate swaps | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | $ (0.4) | |||
Designated as Hedging Instrument | Cash Flow Hedging | Interest rate swaps | Other Comprehensive Income (Loss) | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | (3.4) | 0 | 0 | |
Not Designated as Hedging Instrument | ||||
Derivatives Not Designated as Hedging Instruments [Abstract] | ||||
Gain (loss) recognized in income on derivatives | 10.6 | (11.1) | (5.7) | |
Not Designated as Hedging Instrument | Gasoline and heating oil contracts | Other Income and (Income Deductions) - Net | ||||
Derivatives Not Designated as Hedging Instruments [Abstract] | ||||
Gain (loss) recognized in income on derivatives | 0 | (0.2) | 0 | |
Not Designated as Hedging Instrument | Natural gas commodity contracts | Gas Marketing Operating Revenues | ||||
Derivatives Not Designated as Hedging Instruments [Abstract] | ||||
Gain (loss) recognized in income on derivatives | 12.3 | (1.3) | (8.7) | |
Not Designated as Hedging Instrument | NYMEX / ICE natural gas contracts | Gas Marketing Operating Revenues | ||||
Derivatives Not Designated as Hedging Instruments [Abstract] | ||||
Gain (loss) recognized in income on derivatives | (1.7) | (9.6) | 3 | |
Laclede Gas | Designated as Hedging Instrument | Cash Flow Hedging | Gasoline and heating oil contracts | Other Comprehensive Income (Loss) | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) recognized in OCI on derivatives | 0 | (1.2) | 0.1 | |
Laclede Gas | Designated as Hedging Instrument | Cash Flow Hedging | Gasoline and heating oil contracts | Gas Utility Other Operating Expenses | ||||
Derivatives in Cash Flow Hedging Relationships [Abstract] | ||||
Effective portion of gain (loss) reclassified from AOCI to income | (0.5) | (0.9) | (0.2) | |
Ineffective portion of gain (loss) on derivatives recognized in income | 0.1 | 0.1 | (0.2) | |
Laclede Gas | Not Designated as Hedging Instrument | Gasoline and heating oil contracts | Other Income and (Income Deductions) - Net | ||||
Derivatives Not Designated as Hedging Instruments [Abstract] | ||||
Gain (loss) recognized in income on derivatives | $ 0 | $ (0.2) | $ 0 |
DERIVATIVE INSTRUMENTS AND HE76
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Fair Value of Derivative Instruments (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | $ 18.4 | $ 13.5 |
Fair value of liability derivatives presented above | 12.5 | 29.8 |
Designated as Hedging Instrument | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 3.2 | |
Fair value of liability derivatives presented above | 3.9 | |
Not Designated as Hedging Instrument | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 15.2 | 8.3 |
Fair value of liability derivatives presented above | 8.6 | 25.8 |
Other | Interest rate swaps | Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Gas Utility | Operating Segments | Gasoline and heating oil contracts | Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.3 | |
Fair value of liability derivatives presented above | 0 | |
Gas Utility | Operating Segments | Gasoline and heating oil contracts | Designated as Hedging Instrument | Accounts Receivable – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | 0.3 | |
Gas Utility | Operating Segments | Natural gas contracts | Not Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | 0 |
Fair value of liability derivatives presented above | 0.2 | 5.7 |
Gas Utility | Operating Segments | Natural gas contracts | Not Designated as Hedging Instrument | Accounts Receivable – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.4 | 1.2 |
Fair value of liability derivatives presented above | 1.6 | 16.4 |
Gas Utility | Operating Segments | Natural gas contracts | Not Designated as Hedging Instrument | Deferred Charges – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | 0.2 | |
Gas Marketing | Designated as Hedging Instrument | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.2 | |
Fair value of liability derivatives presented above | 4 | |
Gas Marketing | Operating Segments | Natural gas contracts | Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 2.5 | 4.1 |
Fair value of liability derivatives presented above | 0.8 | 3.2 |
Gas Marketing | Operating Segments | Natural gas contracts | Designated as Hedging Instrument | Deferred Charges – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.4 | 1.1 |
Fair value of liability derivatives presented above | 0.1 | 0.5 |
Gas Marketing | Operating Segments | NYMEX / ICE natural gas contracts | Not Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.8 | 4.7 |
Fair value of liability derivatives presented above | 4.1 | 0.6 |
Gas Marketing | Operating Segments | NYMEX / ICE natural gas contracts | Not Designated as Hedging Instrument | Deferred Charges – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | 0.7 |
Fair value of liability derivatives presented above | 0.1 | 0.7 |
Gas Marketing | Operating Segments | Natural gas commodity contracts | Not Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 6.5 | 1.4 |
Fair value of liability derivatives presented above | 0.2 | 0.1 |
Gas Marketing | Operating Segments | Natural gas commodity contracts | Not Designated as Hedging Instrument | Deferred Charges – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 2.1 | |
Fair value of liability derivatives presented above | 0.3 | |
Gas Marketing | Operating Segments | Natural gas commodity contracts | Not Designated as Hedging Instrument | Current Liabilities – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.2 | 0.2 |
Fair value of liability derivatives presented above | 2 | 1.4 |
Gas Marketing | Operating Segments | Natural gas commodity contracts | Not Designated as Hedging Instrument | Deferred Credits – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.2 | 0.1 |
Fair value of liability derivatives presented above | 0.1 | 0.7 |
Other Segments | Other | Interest rate swaps | Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of liability derivatives presented above | 3 | |
Laclede Gas | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.7 | 1.2 |
Fair value of liability derivatives presented above | 1.8 | 22.6 |
Laclede Gas | Gas Utility | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.7 | 1.2 |
Fair value of liability derivatives presented above | 1.8 | 22.6 |
Laclede Gas | Gas Utility | Designated as Hedging Instrument | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.3 | 0 |
Fair value of liability derivatives presented above | 0 | 0.3 |
Laclede Gas | Gas Utility | Not Designated as Hedging Instrument | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.4 | 1.2 |
Fair value of liability derivatives presented above | 1.8 | 22.3 |
Laclede Gas | Gas Utility | Gasoline and heating oil contracts | Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0.3 | |
Fair value of liability derivatives presented above | 0 | |
Laclede Gas | Gas Utility | Gasoline and heating oil contracts | Designated as Hedging Instrument | Accounts Receivable – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | 0.3 | |
Laclede Gas | Gas Utility | Natural gas contracts | Not Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | 5.7 | |
Laclede Gas | Gas Utility | Natural gas contracts | Not Designated as Hedging Instrument | Accounts Receivable – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 5.4 | 1.2 |
Fair value of liability derivatives presented above | 1.6 | 16.4 |
Laclede Gas | Gas Utility | Natural gas contracts | Not Designated as Hedging Instrument | Deferred Charges – Other | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | $ 0.2 | |
Laclede Gas | Gas Utility | OTCBB natural gas contracts | Not Designated as Hedging Instrument | Derivative Instrument Assets | ||
Derivatives, Fair Value [Line Items] | ||
Fair value of asset derivatives presented above | 0 | |
Fair value of liability derivatives presented above | $ 0.2 |
DERIVATIVE INSTRUMENTS AND HE77
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES - Derivative Instruments Reconciliation (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Offsetting Derivative Assets [Abstract] | ||
Fair value of asset derivatives presented above | $ 18.4 | $ 13.5 |
Fair value of cash margin receivables offset with derivatives | 2.5 | 13.9 |
Netting of assets and liabilities with the same counterparty | (7.6) | (22.2) |
Derivative asset after the effects of netting | 13.3 | 5.2 |
Derivative instrument assets | 11.4 | 4.6 |
Deferred Charges – Other | 1.9 | 0.6 |
Offsetting Derivative Liabilities [Abstract] | ||
Fair value of liability derivatives presented above | 12.5 | 29.8 |
Netting of assets and liabilities with the same counterparty | (7.6) | (22.2) |
Derivative liability after the effects of netting | 4.9 | 7.6 |
Current Liabilities – Other | 4.8 | 6.8 |
Deferred Credits – Other | 0.1 | 0.8 |
Laclede Gas | ||
Offsetting Derivative Assets [Abstract] | ||
Fair value of asset derivatives presented above | 5.7 | 1.2 |
Fair value of cash margin receivables offset with derivatives | 0.8 | 15.5 |
Netting of assets and liabilities with the same counterparty | (1.6) | (16.7) |
Derivative asset after the effects of netting | 4.9 | 0 |
Derivative instrument assets | 4.9 | 0 |
Offsetting Derivative Liabilities [Abstract] | ||
Fair value of liability derivatives presented above | 1.8 | 22.6 |
Netting of assets and liabilities with the same counterparty | (1.6) | (16.7) |
Derivative liability after the effects of netting | 0.2 | 5.9 |
Current Liabilities – Other | 0.2 | 5.7 |
Deferred Credits – Other | $ 0 | $ 0.2 |
CONCENTRATIONS OF CREDIT RISK (
CONCENTRATIONS OF CREDIT RISK (Details) $ in Millions | Sep. 30, 2016USD ($)counterparty |
Concentration Risk [Line Items] | |
Number of large counterparties for which credit risk is disclosed | counterparty | 5 |
Energy Producers And Their Affiliates | |
Concentration Risk [Line Items] | |
Accounts receivable | $ 15.8 |
Net receivable amount | 12.4 |
Utility Companies And Their Affiliates | |
Concentration Risk [Line Items] | |
Accounts receivable | 52.8 |
Net receivable amount | 50.5 |
Largest Counterparties | |
Concentration Risk [Line Items] | |
Accounts receivable | 31.2 |
Net receivable amount | $ 27.2 |
INCOME TAXES - Narrative (Detai
INCOME TAXES - Narrative (Details) - USD ($) | Sep. 30, 2016 | Sep. 30, 2015 |
Tax Credit Carryforward [Line Items] | ||
Federal and state loss carryforwards | $ 297,000,000 | |
Contribution carryforwards | 12,200,000 | |
Valuation allowance | 900,000 | $ 0 |
Tax credit carryforwards | 3,500,000 | |
Unrecognized tax benefits affect on the Company's effective tax rate | 3,300,000 | 3,100,000 |
Income taxes accrued | 0 | 0 |
income tax penalties accrued | 0 | |
Laclede Gas | ||
Tax Credit Carryforward [Line Items] | ||
Federal and state loss carryforwards | 105,000,000 | |
Contribution carryforwards | 12,000,000 | |
Valuation allowance | 900,000 | 0 |
Tax credit carryforwards | 2,000,000 | |
Unrecognized tax benefits affect on the Company's effective tax rate | 3,100,000 | 2,900,000 |
Income taxes accrued | 0 | 0 |
income tax penalties accrued | 0 | $ 0 |
Alagasco | ||
Tax Credit Carryforward [Line Items] | ||
Federal and state loss carryforwards | $ 159,000,000 |
INCOME TAXES - Net Provisions f
INCOME TAXES - Net Provisions for Income Taxes (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Federal | ||||
Current | $ 0.1 | $ (3.3) | $ 0.3 | |
Deferred | 62 | 58.8 | 30.6 | |
Investment tax credits | (0.2) | (0.2) | (0.2) | |
State and local | ||||
Current | 0.6 | 0 | 0.6 | |
Deferred | 7 | 6.9 | 1 | |
Total income tax expense | 69.5 | 62.2 | 32.3 | |
Laclede Gas | ||||
Federal | ||||
Current | 0 | (2.1) | (0.1) | |
Deferred | 37.5 | 40.9 | 34.3 | |
Investment tax credits | (0.2) | (0.2) | (0.2) | |
State and local | ||||
Current | 0.1 | (0.1) | 0 | |
Deferred | 8 | 4.7 | 1.5 | |
Total income tax expense | 45.4 | 43.2 | $ 35.5 | |
Alagasco | ||||
Federal | ||||
Current | $ 14.1 | (0.8) | 0 | |
Deferred | 3.5 | 29.4 | 25.9 | |
State and local | ||||
Current | 1.8 | 0 | 0.1 | |
Deferred | 0.5 | 3.8 | 3.3 | |
Total income tax expense | $ 19.9 | $ 32.4 | $ 29.3 |
INCOME TAXES - Effective Income
INCOME TAXES - Effective Income Tax Rate Variation from Stated Tax Rate (Details) | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Income Tax Contingency [Line Items] | ||||
Federal income tax statutory rate | 35.00% | 35.00% | 35.00% | |
State and local income taxes, net of federal income tax benefits | 2.80% | 3.00% | 1.80% | |
Certain expenses capitalized on books and deducted on tax return | (3.40%) | (3.70%) | (4.90%) | |
Taxes related to prior years | (0.20%) | (0.60%) | (0.70%) | |
Other items – net | (1.70%) | (2.50%) | (3.60%) | |
Effective income tax rate | 32.50% | 31.20% | 27.60% | |
Laclede Gas | ||||
Income Tax Contingency [Line Items] | ||||
Federal income tax statutory rate | 35.00% | 35.00% | 35.00% | |
State and local income taxes, net of federal income tax benefits | 2.80% | 2.80% | 1.80% | |
Certain expenses capitalized on books and deducted on tax return | (4.80%) | (4.90%) | (4.50%) | |
Taxes related to prior years | (0.20%) | (0.80%) | (0.70%) | |
Other items – net | (2.80%) | (3.00%) | (3.30%) | |
Effective income tax rate | 30.00% | 29.10% | 28.30% | |
Alagasco | ||||
Income Tax Contingency [Line Items] | ||||
Federal income tax statutory rate | 35.00% | 35.00% | 35.00% | |
State and local income taxes, net of federal income tax benefits | 2.80% | 2.80% | 2.80% | |
Other items – net | (0.20%) | 0.10% | 0.10% | |
Effective income tax rate | 37.60% | 37.90% | 37.90% |
INCOME TAXES - Significant Item
INCOME TAXES - Significant Items in Net Deferred Tax Liability (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Deferred tax assets: | ||
Reserves not currently deductible | $ 21.3 | $ 14.8 |
Pension and other postretirement benefits | 68.3 | 62.5 |
Operating losses | 102.3 | 47.3 |
Other | 0 | 1.5 |
Deferred tax assets | 191.9 | 126.1 |
Less: valuation allowance | 0.9 | 0 |
Total deferred tax assets | 191 | 126.1 |
Deferred tax liabilities: | ||
Relating to property | 623.1 | 472.1 |
Regulatory pension and other postretirement benefits | 106.8 | 110.6 |
Deferred gas costs | 20 | 8.1 |
Other | 48.4 | 11.6 |
Total deferred tax liabilities | 798.3 | 602.4 |
Net deferred tax liability | 607.3 | 476.3 |
Net deferred tax asset – current | 0 | 5.8 |
Net deferred tax liability | 607.3 | |
Det deferred tax asset (liability) - noncurrent | 482.1 | |
Laclede Gas | ||
Deferred tax assets: | ||
Reserves not currently deductible | 14.9 | 15.4 |
Pension and other postretirement benefits | 56.9 | 62.5 |
Operating losses | 29.9 | 3.7 |
Other | 0 | 1.5 |
Deferred tax assets | 101.7 | 83.1 |
Less: valuation allowance | 0.9 | 0 |
Total deferred tax assets | 100.8 | 83.1 |
Deferred tax liabilities: | ||
Relating to property | 497 | 425 |
Regulatory pension and other postretirement benefits | 106.8 | 120.2 |
Deferred gas costs | 20 | 8.2 |
Other | 33.9 | 14.5 |
Total deferred tax liabilities | 657.7 | 567.9 |
Net deferred tax liability | 556.9 | 484.8 |
Net deferred tax asset – current | 0 | 0.4 |
Net deferred tax liability | 556.9 | |
Det deferred tax asset (liability) - noncurrent | 485.2 | |
Alagasco | ||
Deferred tax assets: | ||
Reserves not currently deductible | 6.3 | 7 |
Pension and other postretirement benefits | 11.4 | 9.6 |
Goodwill | 233.4 | 251.5 |
Operating losses | 60.2 | 32.4 |
Other | 0 | 1.4 |
Deferred tax assets | 311.3 | 301.9 |
Deferred tax liabilities: | ||
Relating to property | 87.6 | 45.1 |
Other | 2.3 | 2.2 |
Total deferred tax liabilities | 89.9 | 47.3 |
Net deferred tax asset | 221.4 | 254.6 |
Net deferred tax asset – current | 0 | 6.2 |
Deferred income tax | $ 221.4 | |
Deferred income tax | $ 248.4 |
INCOME TAXES - Unrecognized Tax
INCOME TAXES - Unrecognized Tax Benefit Reconciliation (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Unrecognized tax benefits [Roll Forward] | ||||
Unrecognized tax benefits, beginning of year | $ 7.1 | $ 4.6 | $ 2.4 | |
Increases related to tax positions taken in current year | 3.4 | 2.9 | 2.6 | |
Reductions due to lapse of applicable statute of limitations | (0.5) | (0.4) | (0.4) | |
Unrecognized tax benefits, end of year | $ 4.6 | 10 | 7.1 | 4.6 |
Laclede Gas | ||||
Unrecognized tax benefits [Roll Forward] | ||||
Unrecognized tax benefits, beginning of year | 6.9 | 4.2 | 2 | |
Increases related to tax positions taken in current year | 3.3 | 2.9 | 2.5 | |
Reductions due to lapse of applicable statute of limitations | (0.5) | (0.2) | (0.3) | |
Unrecognized tax benefits, end of year | 4.2 | 9.7 | 6.9 | 4.2 |
Alagasco | ||||
Unrecognized tax benefits [Roll Forward] | ||||
Unrecognized tax benefits, beginning of year | 0.3 | 0 | 0 | |
Reductions due to lapse of applicable statute of limitations | (0.3) | 0 | 0 | |
Unrecognized tax benefits, end of year | $ 0 | $ 0 | $ 0 | $ 0 |
PENSION PLANS AND OTHER POSTR84
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | Jan. 01, 2011 | Feb. 20, 2010 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Extent of Lump-sum payments recognized, percentage | 100.00% | ||||
Implementation period used to calculate return on plan assets | 4 years | ||||
Gains or losses includible in cost amortized to extent exceeds benefit obligations or market-related value of plan assets, percentage | 10.00% | ||||
Anticipated Contributions to pension plans for qualified trust | $ 29 | ||||
Anticipated contributions to pension plans for non-qualified plans | $ 0.6 | ||||
Medical insurance available until age is reached after early retirement | 65 years | ||||
Recovery in rates for postretirement benefit | $ 9.5 | ||||
Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Recovery in rates for the qualified pension plans base allowance | $ 15.5 | ||||
Other Plans [Abstract] | |||||
401(K) plans, cost of defined contributions | $ 8.2 | $ 8 | $ 6.7 | ||
Alagasco | |||||
Other Plans [Abstract] | |||||
401(K) plans, cost of defined contributions | 2.3 | 3 | 4.7 | ||
Missouri Gas Energy (MGE) | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Recovery in rates for the qualified pension plans base allowance | $ 10 | ||||
Pension Plans | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Settlement benefits paid | $ 16.6 | $ 71.1 | $ 22.1 | ||
Pension Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 100.00% | 100.00% | |||
Settlement benefits paid | $ 0 | $ 58.2 | |||
Pension Plans | Alagasco | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 100.00% | 100.00% | |||
Settlement benefits paid | $ 16.6 | $ 12.9 | |||
Postretirement Plans | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Anticipated contributions to the postretirement plans for qualified trusts | 10.3 | ||||
Anticipated payment directly to participants in postretirement plan | $ 0.4 | ||||
Postretirement Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 100.00% | ||||
Postretirement Plans | Alagasco | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 100.00% | ||||
Equity markets | Pension Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 56.20% | 52.00% | |||
Equity markets | Pension Plans | Alagasco | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 60.00% | 60.00% | |||
Equity markets | Postretirement Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 60.00% | ||||
Equity markets | Postretirement Plans | Alagasco | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 60.00% | ||||
Debt securities | Pension Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 43.80% | 48.00% | |||
Debt securities | Postretirement Plans | Laclede Gas | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 40.00% | ||||
Debt securities | Postretirement Plans | Alagasco | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Targeted allocation of plan assets | 40.00% |
PENSION PLANS AND OTHER POSTR85
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Net Periodic Cost (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | $ 15.3 | $ 17.3 | $ 10.2 | |
Interest cost on projected benefit obligation | 28 | 29.5 | 24.5 | |
Expected return on plan assets | (34.9) | (37.4) | (27.2) | |
Amortization of other comprehensive income | 0 | 0 | 0.4 | |
Amortization of prior service cost | 0.4 | 0.5 | 0.5 | |
Amortization of actuarial loss | 8 | 7.5 | 7.1 | |
Loss on lump-sum settlements | 3.3 | 19.6 | 1.5 | |
Special termination benefits | 1.6 | 0 | 0 | |
Subtotal | 21.7 | 37 | 17 | |
Regulatory adjustment | 17.8 | (2.1) | 10.4 | |
Net benefit cost | 39.5 | 34.9 | 27.4 | |
Postretirement Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | 10.9 | 12.8 | 11.3 | |
Interest cost on projected benefit obligation | 10.2 | 11.2 | 8.9 | |
Expected return on plan assets | (13.5) | (13.2) | (7.3) | |
Amortization of other comprehensive income | 0 | 0 | (0.2) | |
Amortization of prior service cost | 0.3 | 0.8 | 0 | |
Amortization of actuarial loss | 3.6 | 5.1 | 6 | |
Special termination benefits | 2.6 | 0 | 0 | |
Subtotal | 14.1 | 16.7 | 18.7 | |
Regulatory adjustment | (6.6) | (11) | (9.6) | |
Net benefit cost | 7.5 | 5.7 | 9.1 | |
Laclede Gas | Pension Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | 10 | 11.5 | 9.7 | |
Interest cost on projected benefit obligation | 21.7 | 23.3 | 24 | |
Expected return on plan assets | (26.7) | (29.2) | (26.5) | |
Amortization of other comprehensive income | 0 | 0 | 0 | |
Amortization of prior service cost | 0.4 | 0.5 | 0.5 | |
Amortization of actuarial loss | 7.9 | 7.5 | 7.1 | |
Loss on lump-sum settlements | 0 | 18 | 1.5 | |
Special termination benefits | 1.6 | 0 | 0 | |
Subtotal | 14.9 | 31.6 | 16.3 | |
Regulatory adjustment | 11.7 | (5.2) | 10.4 | |
Net benefit cost | 26.6 | 26.4 | 26.7 | |
Laclede Gas | Postretirement Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | 10.6 | 12.3 | 11.2 | |
Interest cost on projected benefit obligation | 8.1 | 8.6 | 8.7 | |
Expected return on plan assets | (8.5) | (8.1) | (6.8) | |
Amortization of other comprehensive income | 0 | 0 | 0 | |
Amortization of prior service cost | 0.3 | 0.8 | 0 | |
Amortization of actuarial loss | 3.8 | 5.1 | 6 | |
Special termination benefits | 2.6 | 0 | 0 | |
Subtotal | 16.9 | 18.7 | 19.1 | |
Regulatory adjustment | (4.8) | (9.2) | (9.6) | |
Net benefit cost | 12.1 | 9.5 | $ 9.5 | |
Alagasco | Pension Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | $ 5.1 | 5.3 | 5.8 | |
Interest cost on projected benefit obligation | 4.1 | 6.3 | 6.2 | |
Expected return on plan assets | (5.2) | (8.2) | (8.2) | |
Amortization of other comprehensive income | 0 | 0 | 0 | |
Amortization of prior service cost | 0.1 | 0 | 0 | |
Amortization of actuarial loss | 2.2 | 0.1 | 0 | |
Loss on lump-sum settlements | 10.1 | 3.3 | 1.6 | |
Special termination benefits | 0 | 0 | 0 | |
Subtotal | 16.4 | 6.8 | 5.4 | |
Regulatory adjustment | 0.4 | 6.1 | 3.1 | |
Net benefit cost | 16.8 | 12.9 | 8.5 | |
Alagasco | Postretirement Plans | ||||
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract] | ||||
Service cost – benefits earned during the period | 0.4 | 0.3 | 0.5 | |
Interest cost on projected benefit obligation | 1.9 | 2.1 | 2.6 | |
Expected return on plan assets | (3.6) | (5) | (5.1) | |
Amortization of other comprehensive income | 0 | 0 | 0 | |
Amortization of prior service cost | 0 | 0 | 0 | |
Amortization of actuarial loss | (1) | (0.2) | 0 | |
Special termination benefits | 0 | 0 | 0 | |
Subtotal | (2.3) | (2.8) | (2) | |
Regulatory adjustment | (0.2) | (1.8) | (1.8) | |
Net benefit cost | $ (2.5) | $ (4.6) | $ (3.8) |
PENSION PLANS AND OTHER POSTR86
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Changes in Plan Assets and Benefit Obligations (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Amortization of actuarial loss | $ 0.3 | $ (0.4) | $ (0.5) | |
Pension Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | 46.8 | 48.3 | 15.7 | |
Amortization of actuarial loss | (8) | (7.5) | (7.1) | |
Acceleration of loss recognized due to settlement | (3.3) | (19.6) | (1.5) | |
Current year prior service credit | 5 | 0 | 0 | |
Amortization of prior service cost | (0.4) | (0.5) | (0.5) | |
Subtotal | 40.1 | 20.7 | 6.6 | |
Regulatory adjustment | (39.8) | (21.2) | (6.1) | |
Total recognized in OCI | 0.3 | (0.5) | 0.5 | |
Postretirement Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | 0.8 | (8.5) | (3.1) | |
Amortization of actuarial loss | (3.6) | (5.1) | (6) | |
Current year prior service credit | (1.8) | (4.9) | 0 | |
Amortization of prior service cost | (0.3) | (0.8) | 2.5 | |
Subtotal | (4.9) | (19.3) | (6.6) | |
Regulatory adjustment | 4.9 | 19.3 | 6.6 | |
Total recognized in OCI | 0 | 0 | 0 | |
Laclede Gas | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Amortization of actuarial loss | 0.3 | (0.4) | (0.4) | |
Laclede Gas | Pension Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | 21.6 | 26 | 14.2 | |
Amortization of actuarial loss | (7.9) | (7.5) | (7.1) | |
Acceleration of loss recognized due to settlement | 0 | (18) | (1.5) | |
Current year prior service credit | 5 | 0 | 0 | |
Amortization of prior service cost | (0.4) | (0.5) | (0.5) | |
Subtotal | 18.3 | 0 | 5.1 | |
Regulatory adjustment | (18) | (0.5) | (4.7) | |
Total recognized in OCI | 0.3 | (0.5) | 0.4 | |
Laclede Gas | Postretirement Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | 1.4 | (2.4) | (4.2) | |
Amortization of actuarial loss | (3.8) | (5.1) | (6) | |
Current year prior service credit | 0 | (4.9) | 0 | |
Amortization of prior service cost | (0.3) | (0.8) | 2.5 | |
Subtotal | (2.7) | (13.2) | (7.7) | |
Regulatory adjustment | 2.7 | 13.2 | 7.7 | |
Total recognized in OCI | 0 | 0 | $ 0 | |
Alagasco | Pension Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | $ 1.5 | 25.2 | 22.3 | |
Amortization of actuarial loss | 0 | (0.1) | 0 | |
Acceleration of loss recognized due to settlement | 0 | (3.3) | (1.6) | |
Current year prior service credit | 0 | 0 | 0 | |
Amortization of prior service cost | 0 | 0 | 0 | |
Subtotal | 1.5 | 21.8 | 20.7 | |
Regulatory adjustment | (1.5) | (21.8) | (20.7) | |
Total recognized in OCI | 0 | 0 | 0 | |
Alagasco | Postretirement Plans | ||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||
Current year actuarial loss | 1.1 | (0.6) | (6.1) | |
Amortization of actuarial loss | 0 | 0.2 | 0 | |
Current year prior service credit | 0 | (1.8) | 0 | |
Amortization of prior service cost | 0 | 0 | 0 | |
Subtotal | 1.1 | (2.2) | (6.1) | |
Regulatory adjustment | (1.1) | 2.2 | 6.1 | |
Total recognized in OCI | $ 0 | $ 0 | $ 0 |
PENSION PLANS AND OTHER POSTR87
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Benefit Obligation Rollforward (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | $ 652.3 | $ 692.4 | ||
Service cost | 15.3 | 17.3 | $ 10.2 | |
Interest cost | 28 | 29.5 | 24.5 | |
Actuarial loss (gain) | 85.8 | (12.8) | ||
Plan amendments | 5.1 | 0 | ||
EnergySouth acquisition | 60.4 | 0 | ||
Settlement loss | 1.1 | 16.5 | ||
Special termination benefits | 1.6 | 0 | ||
Settlement benefits paid | (16.6) | (71.1) | (22.1) | |
Regular benefits paid | (38.3) | (19.5) | ||
Benefit obligation, end of year | $ 692.4 | 794.7 | 652.3 | 692.4 |
Accumulated benefit obligation, end of year | 724.5 | 591.4 | ||
Postretirement Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | 239.2 | 258.5 | ||
Service cost | 10.9 | 12.8 | 11.3 | |
Interest cost | 10.2 | 11.2 | 8.9 | |
Actuarial loss (gain) | 7.1 | (23.7) | ||
Plan amendments | (1.8) | (4.9) | ||
EnergySouth acquisition | 5.9 | 0 | ||
Special termination benefits | 2.6 | 0 | ||
Retiree drug subsidy program | 0.2 | 0.4 | ||
Regular benefits paid | (15.1) | (15.1) | ||
Benefit obligation, end of year | 258.5 | 259.2 | 239.2 | 258.5 |
Laclede Gas | Pension Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | 497.6 | 543.6 | ||
Service cost | 10 | 11.5 | 9.7 | |
Interest cost | 21.7 | 23.3 | 24 | |
Actuarial loss (gain) | 59.2 | (20.7) | ||
Plan amendments | 5.1 | 0 | ||
EnergySouth acquisition | 0 | 0 | ||
Settlement loss | 0 | 14.5 | ||
Special termination benefits | 1.6 | |||
Settlement benefits paid | 0 | (58.2) | ||
Regular benefits paid | (35.2) | (16.4) | ||
Benefit obligation, end of year | 543.6 | 560 | 497.6 | 543.6 |
Accumulated benefit obligation, end of year | 517.7 | 456.9 | ||
Laclede Gas | Postretirement Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | 191.9 | 197.9 | ||
Service cost | 10.6 | 12.3 | 11.2 | |
Interest cost | 8.1 | 8.6 | 8.7 | |
Actuarial loss (gain) | 6.7 | (10.9) | ||
Plan amendments | 0 | (4.9) | ||
EnergySouth acquisition | 0 | 0 | ||
Special termination benefits | 2.6 | 0 | ||
Retiree drug subsidy program | 0 | 0 | ||
Regular benefits paid | (12) | (11.1) | ||
Benefit obligation, end of year | 197.9 | 207.9 | 191.9 | 197.9 |
Alagasco | Pension Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | 154.7 | 148.8 | ||
Service cost | 5.1 | 5.3 | 5.8 | |
Interest cost | 4.1 | 6.3 | 6.2 | |
Actuarial loss (gain) | 26.6 | 7.9 | ||
Plan amendments | 0 | 0 | ||
EnergySouth acquisition | 0 | 0 | ||
Settlement loss | 1.1 | 2 | ||
Special termination benefits | 0 | |||
Settlement benefits paid | (16.6) | (12.9) | ||
Regular benefits paid | (3.1) | (3.1) | ||
Benefit obligation, end of year | 148.8 | 174.3 | 154.7 | 148.8 |
Accumulated benefit obligation, end of year | 149.8 | 134.5 | ||
Alagasco | Postretirement Plans | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | ||||
Benefit obligation, beginning of year | 47.3 | 60.6 | ||
Service cost | 0.4 | 0.3 | 0.5 | |
Interest cost | 1.9 | 2.1 | 2.6 | |
Actuarial loss (gain) | 0.4 | (12.8) | ||
Plan amendments | (1.8) | 0 | ||
EnergySouth acquisition | 0 | 0 | ||
Special termination benefits | 0 | 0 | ||
Retiree drug subsidy program | 0.2 | 0.4 | ||
Regular benefits paid | (3.1) | (4) | ||
Benefit obligation, end of year | $ 60.6 | $ 45.4 | $ 47.3 | $ 60.6 |
PENSION PLANS AND OTHER POSTR88
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Fair Value of Plan Assets (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | $ 448.9 | $ 506.6 | |
Actual return on plan assets | 75.1 | (7.2) | |
Employer contributions | 26.6 | 40.1 | |
EnergySouth acquisition | 44.8 | 0 | |
Settlement benefits paid | (16.6) | (71.1) | $ (22.1) |
Regular benefits paid | (38.3) | (19.5) | |
Fair value of plan assets, end of year | 540.5 | 448.9 | 506.6 |
Funded status of plans, end of year | (254.2) | (203.4) | |
Postretirement Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | 223.3 | 222.5 | |
Actual return on plan assets | 19.9 | (2) | |
Employer contributions | 14.3 | 17.9 | |
EnergySouth acquisition | 4 | 0 | |
Regular benefits paid | (15.1) | (15.1) | |
Fair value of plan assets, end of year | 246.4 | 223.3 | 222.5 |
Funded status of plans, end of year | (12.8) | (15.9) | |
Laclede Gas | Pension Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | 339.9 | 387.4 | |
Actual return on plan assets | 64.4 | (3) | |
Employer contributions | 26.6 | 30.1 | |
EnergySouth acquisition | 0 | 0 | |
Settlement benefits paid | 0 | (58.2) | |
Regular benefits paid | (35.2) | (16.4) | |
Fair value of plan assets, end of year | 395.7 | 339.9 | 387.4 |
Funded status of plans, end of year | (164.3) | (157.7) | |
Laclede Gas | Postretirement Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | 143.6 | 137.2 | |
Actual return on plan assets | 13.8 | (0.4) | |
Employer contributions | 14.3 | 17.9 | |
EnergySouth acquisition | 0 | 0 | |
Regular benefits paid | (12) | (11.1) | |
Fair value of plan assets, end of year | 159.7 | 143.6 | 137.2 |
Funded status of plans, end of year | (48.2) | (48.3) | |
Alagasco | Pension Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | 109 | 119.2 | |
Actual return on plan assets | 10.7 | (4.2) | |
Employer contributions | 0 | 10 | |
EnergySouth acquisition | 0 | 0 | |
Settlement benefits paid | (16.6) | (12.9) | |
Regular benefits paid | (3.1) | (3.1) | |
Fair value of plan assets, end of year | 100 | 109 | 119.2 |
Funded status of plans, end of year | (74.3) | (45.7) | |
Alagasco | Postretirement Plans | |||
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward] | |||
Fair value of plan assets, beginning of year | 79.7 | 85.3 | |
Actual return on plan assets | 6.2 | (1.6) | |
Employer contributions | 0 | 0 | |
EnergySouth acquisition | 0 | 0 | |
Regular benefits paid | (3.1) | (4) | |
Fair value of plan assets, end of year | 82.8 | 79.7 | $ 85.3 |
Funded status of plans, end of year | $ 37.4 | $ 32.4 |
PENSION PLANS AND OTHER POSTR89
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Amounts Recognized in Consolidated Balance Sheets (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Noncurrent liabilities | $ (303.7) | $ (253.4) |
Pension Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current liabilities | (0.6) | (0.5) |
Noncurrent liabilities | (253.6) | (202.9) |
Total | (254.2) | (203.4) |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | 179.4 | 143.9 |
Prior service costs | 8.2 | 3.5 |
Subtotal | 187.6 | 147.4 |
Adjustments for amounts included in regulatory assets | (184.8) | (144.9) |
Total | 2.8 | 2.5 |
Postretirement Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current assets | 0.3 | 0 |
Noncurrent assets | 37.4 | 35.5 |
Current liabilities | (0.4) | (0.3) |
Noncurrent liabilities | (50.1) | (51.1) |
Total | (12.8) | (15.9) |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | 38 | 40.8 |
Prior service costs | (5.2) | (3.1) |
Subtotal | 32.8 | 37.7 |
Adjustments for amounts included in regulatory assets | (32.8) | (37.7) |
Total | 0 | 0 |
Laclede Gas | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Noncurrent liabilities | (211.8) | (207.8) |
Laclede Gas | Pension Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current liabilities | (0.6) | (0.5) |
Noncurrent liabilities | (163.7) | (157.2) |
Total | (164.3) | (157.7) |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | 135.5 | 121.9 |
Prior service costs | 8.2 | 3.5 |
Subtotal | 143.7 | 125.4 |
Adjustments for amounts included in regulatory assets | (140.9) | (122.9) |
Total | 2.8 | 2.5 |
Laclede Gas | Postretirement Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current assets | 0.3 | 0 |
Noncurrent assets | 0 | 3.1 |
Current liabilities | (0.4) | (0.3) |
Noncurrent liabilities | (48.1) | (51.1) |
Total | (48.2) | (48.3) |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | 43.4 | 45.8 |
Prior service costs | (3.4) | (3.1) |
Subtotal | 40 | 42.7 |
Adjustments for amounts included in regulatory assets | (40) | (42.7) |
Total | 0 | 0 |
Alagasco | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Noncurrent liabilities | (74.3) | (45.6) |
Alagasco | Pension Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current liabilities | 0 | 0 |
Noncurrent liabilities | (74.3) | (45.7) |
Total | (74.3) | (45.7) |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | 43.9 | 22 |
Prior service costs | 0 | 0 |
Subtotal | 43.9 | 22 |
Adjustments for amounts included in regulatory assets | (43.9) | (22) |
Total | 0 | 0 |
Alagasco | Postretirement Plans | ||
Defined Benefit Plan, Amounts Recognized in Balance Sheet [Abstract] | ||
Current assets | 0 | 0 |
Noncurrent assets | 37.4 | 32.4 |
Current liabilities | 0 | 0 |
Noncurrent liabilities | 0 | 0 |
Total | 37.4 | 32.4 |
Pre-tax amounts recognized in accumulated other comprehensive income not yet recognized as components of net periodic pension cost consist of: | ||
Net actuarial loss | (5.4) | (5) |
Prior service costs | (1.8) | 0 |
Subtotal | (7.2) | (5) |
Adjustments for amounts included in regulatory assets | 7.2 | 5 |
Total | $ 0 | $ 0 |
PENSION PLANS AND OTHER POSTR90
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Pre-tax Amortization from AOCI (Details) $ in Millions | 12 Months Ended |
Sep. 30, 2016USD ($) | |
Pension Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | $ 13.5 |
Amortization of prior service cost | 1 |
Subtotal | 14.5 |
Regulatory adjustment | (14.2) |
Total | 0.3 |
Postretirement Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | 2.4 |
Amortization of prior service cost | 0.1 |
Subtotal | 2.5 |
Regulatory adjustment | (2.5) |
Total | 0 |
Laclede Gas | Pension Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | 11.6 |
Amortization of prior service cost | 1 |
Subtotal | 12.6 |
Regulatory adjustment | (12.3) |
Total | 0.3 |
Laclede Gas | Postretirement Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | 2.5 |
Amortization of prior service cost | 0.3 |
Subtotal | 2.8 |
Regulatory adjustment | (2.8) |
Total | 0 |
Alagasco | Pension Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | 1.9 |
Amortization of prior service cost | 0 |
Subtotal | 1.9 |
Regulatory adjustment | (1.9) |
Total | 0 |
Alagasco | Postretirement Plans | |
Pre-tax amounts are expected to be amortized from accumulated other comprehensive income [Abstract] | |
Amortization of net actuarial loss (gain) | (0.1) |
Amortization of prior service cost | (0.2) |
Subtotal | (0.3) |
Regulatory adjustment | 0.3 |
Total | $ 0 |
PENSION PLANS AND OTHER POSTR91
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Assumptions Used to Calculate Net Periodic Cost and Benefit Obligations (Details) | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Alagasco | Pension Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average rate of future compensation increase | 2.92% | 3.00% | 2.92% | |
Expected long-term rate of return on plan assets | 7.50% | |||
Alagasco | Pension Plans | Minimum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.00% | 4.25% | 4.15% | |
Expected long-term rate of return on plan assets | 7.00% | 7.00% | ||
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.45% | 4.25% | ||
Alagasco | Pension Plans | Maximum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.05% | 4.30% | 4.25% | |
Expected long-term rate of return on plan assets | 7.25% | 7.25% | ||
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.50% | 4.30% | ||
Alagasco | Postretirement Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.50% | 4.40% | 4.25% | |
Weighted average rate of future compensation increase | 2.92% | |||
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.60% | 4.50% | ||
Alagasco | Postretirement Plans | Minimum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 4.75% | 4.50% | 4.75% | |
Alagasco | Postretirement Plans | Maximum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 7.25% | 7.25% | 7.50% | |
Laclede Gas | Pension Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.40% | 4.30% | 4.70% | |
Weighted average rate of future compensation increase | 3.00% | 3.00% | 3.00% | |
Expected long-term rate of return on plan assets | 7.75% | 7.75% | 7.75% | |
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.50% | 4.40% | ||
Laclede Gas | Postretirement Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.00% | 4.15% | 4.60% | |
Weighted average rate of future compensation increase | 3.00% | 3.00% | 3.00% | |
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.15% | 4.00% | ||
Weighted average rate of future compensation increase | 3.00% | 3.00% | ||
Laclede Gas | Postretirement Plans | Minimum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 6.00% | 6.25% | 6.25% | |
Laclede Gas | Postretirement Plans | Maximum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 7.75% | 7.75% | 7.75% | |
Missouri Gas Energy (MGE) | Pension Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.50% | 4.45% | 5.00% | |
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.50% | 4.50% | ||
Missouri Gas Energy (MGE) | Postretirement Plans | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Weighted average discount rate | 4.30% | 4.40% | 4.95% | |
Expected long-term rate of return on plan assets | 4.75% | 5.00% | ||
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average discount rate | 3.45% | 4.30% | ||
Missouri Gas Energy (MGE) | Postretirement Plans | Minimum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 3.75% | |||
Missouri Gas Energy (MGE) | Postretirement Plans | Maximum | ||||
Assumptions used to calculate net periodic cost [Abstract] | ||||
Expected long-term rate of return on plan assets | 5.75% | |||
Laclede Gas, Alabama Gas Company, And Missouri Gas Energy | Pension Plans | ||||
Assumptions used to calculate benefit obligations [Abstract] | ||||
Weighted average rate of future compensation increase | 3.00% | 3.00% |
PENSION PLANS AND OTHER POSTR92
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Projected Benefit Obligation (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Defined Benefit Plan Disclosure [Line Items] | ||
Projected benefit obligation | $ 794.8 | $ 652.3 |
Accumulated benefit obligation | 724.5 | 591.4 |
Fair value of plan assets | 540.5 | 448.9 |
Laclede Gas | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Projected benefit obligation | 560 | 497.6 |
Accumulated benefit obligation | 517.7 | 456.9 |
Fair value of plan assets | 395.7 | 339.9 |
Alagasco | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Projected benefit obligation | 174.3 | 154.7 |
Accumulated benefit obligation | 149.8 | 134.5 |
Fair value of plan assets | $ 100 | $ 109 |
PENSION PLANS AND OTHER POSTR93
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Targeted and Actual Plan Assets by Category (Details) | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2015 | |
Alagasco | Pension Plans | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 100.00% | 100.00% |
Actual allocation of plan assets | 100.00% | 100.00% |
Alagasco | Pension Plans | Equity markets | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 60.00% | 60.00% |
Actual allocation of plan assets | 59.20% | 52.90% |
Alagasco | Pension Plans | Commodity Contract [Member] | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 29.00% | 29.00% |
Actual allocation of plan assets | 28.80% | 27.90% |
Alagasco | Pension Plans | Real Estate [Member] | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 11.00% | 11.00% |
Actual allocation of plan assets | 12.00% | 19.20% |
Alagasco | Postretirement Plans | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 100.00% | |
Actual allocation of plan assets | 100.00% | 100.00% |
Alagasco | Postretirement Plans | Equity markets | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 60.00% | |
Actual allocation of plan assets | 60.50% | 59.70% |
Alagasco | Postretirement Plans | Debt securities | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 40.00% | |
Actual allocation of plan assets | 39.50% | 40.30% |
Laclede Gas | Pension Plans | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 100.00% | 100.00% |
Actual allocation of plan assets | 100.00% | 100.00% |
Laclede Gas | Pension Plans | Equity markets | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 56.20% | 52.00% |
Actual allocation of plan assets | 56.90% | 48.40% |
Laclede Gas | Pension Plans | Debt securities | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 43.80% | 48.00% |
Actual allocation of plan assets | 43.10% | 50.10% |
Laclede Gas | Pension Plans | Other | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 0.00% | 0.00% |
Actual allocation of plan assets | 0.00% | 1.50% |
Laclede Gas | Postretirement Plans | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 100.00% | |
Actual allocation of plan assets | 100.00% | 100.00% |
Laclede Gas | Postretirement Plans | Equity markets | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 60.00% | |
Actual allocation of plan assets | 59.10% | 59.60% |
Laclede Gas | Postretirement Plans | Debt securities | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 40.00% | |
Actual allocation of plan assets | 39.40% | 39.70% |
Laclede Gas | Postretirement Plans | Other | ||
Targeted and actual plan assets by category [Abstract] | ||
Targeted allocation of plan assets | 0.00% | |
Actual allocation of plan assets | 1.50% | 0.70% |
PENSION PLANS AND OTHER POSTR94
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Expected Future Benefit Payments (Details) $ in Millions | Sep. 30, 2016USD ($) |
Pension Plans | |
Expected benefit payments [Abstract] | |
2,017 | $ 61.3 |
2,018 | 56.2 |
2,019 | 57.1 |
2,020 | 56.6 |
2,021 | 56.8 |
2022 - 2026 | 286.3 |
Postretirement Plans | |
Expected benefit payments [Abstract] | |
2,017 | 15.4 |
2,018 | 16.7 |
2,019 | 17.9 |
2,020 | 19.1 |
2,021 | 20.1 |
2022 - 2026 | 108.6 |
Laclede Gas | Pension Plans | |
Expected benefit payments [Abstract] | |
2,017 | 48.2 |
2,018 | 43.3 |
2,019 | 43.5 |
2,020 | 42.2 |
2,021 | 40.4 |
2022 - 2026 | 196.6 |
Laclede Gas | Postretirement Plans | |
Expected benefit payments [Abstract] | |
2,017 | 12.3 |
2,018 | 13.7 |
2,019 | 14.8 |
2,020 | 15.8 |
2,021 | 16.8 |
2022 - 2026 | 92.5 |
Alagasco | Pension Plans | |
Expected benefit payments [Abstract] | |
2,017 | 10.9 |
2,018 | 10.6 |
2,019 | 11.2 |
2,020 | 11.9 |
2,021 | 13.7 |
2022 - 2026 | 74.5 |
Alagasco | Postretirement Plans | |
Expected benefit payments [Abstract] | |
2,017 | 2.9 |
2,018 | 2.8 |
2,019 | 2.8 |
2,020 | 2.9 |
2,021 | 2.9 |
2022 - 2026 | $ 14.1 |
PENSION PLANS AND OTHER POSTR95
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Assumed Medical Cost Trend Rates and Effect of 1% Changed (Details) - USD ($) $ in Millions | 12 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2015 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||
Rate to which the medical cost trend rate is assumed to decline (the ultimate medical cost trend rate) | 5.00% | 5.00% |
Year the rate reaches the ultimate trend | 2,023 | 2,020 |
Assumed 1% change in the assumed medical cost trend rate [Abstract] | ||
Effect of 1% increase on net periodic postretirement benefit cost | $ 1.5 | |
Effect of 1% decrease on net periodic postretirement benefit cost | (1.4) | |
Effect of 1% increase on accumulated postretirement benefit obligation | 11 | |
Effect of 1% decrease on accumulated postretirement benefit obligation | $ (10.2) | |
Laclede Gas | ||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||
Medical cost trend assumed for next year | 7.50% | 7.00% |
Assumed 1% change in the assumed medical cost trend rate [Abstract] | ||
Effect of 1% increase on net periodic postretirement benefit cost | $ 1.5 | |
Effect of 1% decrease on net periodic postretirement benefit cost | (1.4) | |
Effect of 1% increase on accumulated postretirement benefit obligation | 9 | |
Effect of 1% decrease on accumulated postretirement benefit obligation | $ (8.4) | |
Alagasco | ||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||
Medical cost trend assumed for next year | 7.50% | 7.00% |
Assumed 1% change in the assumed medical cost trend rate [Abstract] | ||
Effect of 1% increase on net periodic postretirement benefit cost | $ 0 | |
Effect of 1% decrease on net periodic postretirement benefit cost | 0 | |
Effect of 1% increase on accumulated postretirement benefit obligation | 1.3 | |
Effect of 1% decrease on accumulated postretirement benefit obligation | $ (1.2) |
PENSION PLANS AND OTHER POSTR96
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS - Fair Value Measurements of Plan Assets (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 |
Pension Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | $ 540.5 | $ 448.9 | $ 506.6 |
Pension Plans | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 51.2 | 43.6 | |
Pension Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 126.1 | 130.6 | |
Pension Plans | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 149 | 9.3 | |
Pension Plans | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 45.1 | 58.7 | |
Pension Plans | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 137.4 | 166.6 | |
Pension Plans | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 6.3 | 5.9 | |
Pension Plans | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 25.3 | 31.3 | |
Pension Plans | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | 2.9 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 383.6 | 272.2 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 51.2 | 43.4 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 99.3 | 46.4 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 23 | 0 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 42.1 | 58.7 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 137.4 | 123.7 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 6.3 | 0 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 25.3 | 0 | |
Pension Plans | Quoted Prices in Active Markets (Level 1) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | (1) | 0 | |
Pension Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 156.8 | 167.1 | |
Pension Plans | Significant Observable Inputs (Level 2) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0.2 | |
Pension Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 26.7 | 74.6 | |
Pension Plans | Significant Observable Inputs (Level 2) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 126 | 9.3 | |
Pension Plans | Significant Observable Inputs (Level 2) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 3 | 0 | |
Pension Plans | Significant Observable Inputs (Level 2) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 42.9 | |
Pension Plans | Significant Observable Inputs (Level 2) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 5.9 | |
Pension Plans | Significant Observable Inputs (Level 2) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 31.3 | |
Pension Plans | Significant Observable Inputs (Level 2) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 1.1 | 2.9 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | 9.6 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | 9.6 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Pension Plans | Significant Unobservable Inputs (Level 3) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Postretirement Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 246.4 | 223.3 | 222.5 |
Postretirement Plans | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4.8 | 1.6 | |
Postretirement Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 226.4 | 208.3 | |
Postretirement Plans | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 15.2 | 13.4 | |
Postretirement Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 163.6 | 117.1 | |
Postretirement Plans | Quoted Prices in Active Markets (Level 1) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4.8 | 1.6 | |
Postretirement Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 157.9 | 115.5 | |
Postretirement Plans | Quoted Prices in Active Markets (Level 1) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.9 | 0 | |
Postretirement Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 82.8 | 106.2 | |
Postretirement Plans | Significant Observable Inputs (Level 2) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Postretirement Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 68.5 | 92.8 | |
Postretirement Plans | Significant Observable Inputs (Level 2) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 14.3 | 13.4 | |
Postretirement Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Postretirement Plans | Significant Unobservable Inputs (Level 3) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Postretirement Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Postretirement Plans | Significant Unobservable Inputs (Level 3) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 395.7 | 339.9 | 387.4 |
Laclede Gas | Pension Plans | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 46.5 | 31.8 | |
Laclede Gas | Pension Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 14.9 | 67.7 | |
Laclede Gas | Pension Plans | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 120.2 | ||
Laclede Gas | Pension Plans | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 45.1 | 37.7 | |
Laclede Gas | Pension Plans | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 137.4 | 166.6 | |
Laclede Gas | Pension Plans | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 6.3 | 5.9 | |
Laclede Gas | Pension Plans | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 25.2 | 27.3 | |
Laclede Gas | Pension Plans | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 2.9 | ||
Laclede Gas | Pension Plans | Other | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | ||
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 256.5 | 193.2 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 46.5 | 31.8 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 42.1 | 37.7 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 137.4 | 123.7 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 6.3 | 0 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 25.2 | 0 | |
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Laclede Gas | Pension Plans | Quoted Prices in Active Markets (Level 1) | Other | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | (1) | ||
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 139.1 | 146.6 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 14.8 | 67.6 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 120.2 | ||
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 3 | 0 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 42.9 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 5.9 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 27.3 | |
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 2.9 | ||
Laclede Gas | Pension Plans | Significant Observable Inputs (Level 2) | Other | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 1.1 | ||
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | 0.1 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.1 | 0.1 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | US corporate | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | US municipal | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Laclede Gas | Pension Plans | Significant Unobservable Inputs (Level 3) | Other | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Laclede Gas | Postretirement Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 159.7 | 143.6 | 137.2 |
Laclede Gas | Postretirement Plans | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4.6 | 1.6 | |
Laclede Gas | Postretirement Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 155.1 | 142 | |
Laclede Gas | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 159.7 | 117.1 | |
Laclede Gas | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4.6 | 1.6 | |
Laclede Gas | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 155.1 | 115.5 | |
Laclede Gas | Postretirement Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 26.5 | |
Laclede Gas | Postretirement Plans | Significant Observable Inputs (Level 2) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Postretirement Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 26.5 | |
Laclede Gas | Postretirement Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Postretirement Plans | Significant Unobservable Inputs (Level 3) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Laclede Gas | Postretirement Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Pension Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 100 | 109 | 119.2 |
Alagasco | Pension Plans | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.4 | 11.8 | |
Alagasco | Pension Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 70.9 | 62.9 | |
Alagasco | Pension Plans | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 28.7 | 9.3 | |
Alagasco | Pension Plans | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 21 | ||
Alagasco | Pension Plans | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4 | ||
Alagasco | Pension Plans | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 82.4 | 58 | |
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0.4 | 11.6 | |
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 59 | 46.4 | |
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 23 | 0 | |
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Quoted Prices in Active Markets (Level 1) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 17.6 | 41.5 | |
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0.2 | |
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 11.9 | 7 | |
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 5.7 | 9.3 | |
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 21 | ||
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 4 | ||
Alagasco | Pension Plans | Significant Observable Inputs (Level 2) | Derivative instruments | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 9.5 | |
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | Cash and cash equivalents | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 9.5 | |
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | US bond mutual funds | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | US government | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Pension Plans | Significant Unobservable Inputs (Level 3) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | ||
Alagasco | Postretirement Plans | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 82.8 | 79.7 | $ 85.3 |
Alagasco | Postretirement Plans | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 68.5 | 66.3 | |
Alagasco | Postretirement Plans | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 14.3 | 13.4 | |
Alagasco | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Postretirement Plans | Quoted Prices in Active Markets (Level 1) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Postretirement Plans | Significant Observable Inputs (Level 2) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 82.8 | 79.7 | |
Alagasco | Postretirement Plans | Significant Observable Inputs (Level 2) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 68.5 | 66.3 | |
Alagasco | Postretirement Plans | Significant Observable Inputs (Level 2) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 14.3 | 13.4 | |
Alagasco | Postretirement Plans | Significant Unobservable Inputs (Level 3) | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Postretirement Plans | Significant Unobservable Inputs (Level 3) | Stock/bond mutual fund | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | 0 | 0 | |
Alagasco | Postretirement Plans | Significant Unobservable Inputs (Level 3) | International | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Fair value measurements of plan assets | $ 0 | $ 0 |
INFORMATION BY OPERATING SEGM97
INFORMATION BY OPERATING SEGMENT - Schedule of Operating Segment Information (Details) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2016USD ($) | Jun. 30, 2016USD ($) | Mar. 31, 2016USD ($) | Dec. 31, 2015USD ($) | Sep. 30, 2015USD ($) | Jun. 30, 2015USD ($) | Mar. 31, 2015USD ($) | Dec. 31, 2014USD ($) | Sep. 30, 2016USD ($)operating_segment | Sep. 30, 2015USD ($) | Sep. 30, 2014USD ($) | |
Segment Reporting, Revenue Reconciling Item [Line Items] | |||||||||||
Number of operating segments | operating_segment | 2 | ||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | $ 279.3 | $ 249.3 | $ 609.3 | $ 399.4 | $ 204.2 | $ 275.2 | $ 877.4 | $ 619.6 | $ 1,537.3 | $ 1,976.4 | $ 1,627.2 |
Gas Utility | |||||||||||
Natural and propane gas | 492.2 | 882.4 | 731.7 | ||||||||
Other operation and maintenance expenses | 377.5 | 390.6 | 287.8 | ||||||||
Depreciation and amortization | 136.9 | 129.9 | 82.4 | ||||||||
Taxes, other than income taxes | 125.2 | 142.1 | 112 | ||||||||
Total Gas Utility Operating Expenses | 1,131.8 | 1,545 | 1,213.9 | ||||||||
Gas Marketing and other | 123.2 | 158.9 | 246.9 | ||||||||
Total Operating Expenses | 1,255 | 1,703.9 | 1,460.8 | ||||||||
Operating Income | (7.7) | $ 35.3 | $ 167.7 | $ 87 | (8.5) | $ 36 | $ 157.7 | $ 87.3 | 282.3 | 272.5 | 166.4 |
Net Economic Earnings | 149.1 | 138.3 | 100.1 | ||||||||
Capital Expenditures | 293.3 | 289.8 | 171 | ||||||||
ASSETS | |||||||||||
Total Assets | 6,077.4 | 5,290.2 | 6,077.4 | 5,290.2 | 5,074 | ||||||
Eliminations | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | (5.4) | (76.5) | (91) | ||||||||
Gas Utility | |||||||||||
Natural and propane gas | (47.5) | (75.2) | (90.1) | ||||||||
Other operation and maintenance expenses | (1.8) | (1) | (0.9) | ||||||||
Depreciation and amortization | 0 | 0 | 0 | ||||||||
Taxes, other than income taxes | 0 | 0 | 0 | ||||||||
Total Gas Utility Operating Expenses | (49.3) | (76.2) | (91) | ||||||||
Gas Marketing and other | 43.9 | (0.3) | 0 | ||||||||
Total Operating Expenses | (5.4) | (76.5) | (91) | ||||||||
Operating Income | 0 | 0 | 0 | ||||||||
Net Economic Earnings | 0 | 0 | 0 | ||||||||
Capital Expenditures | 0 | 0 | 0 | ||||||||
ASSETS | |||||||||||
Total Assets | (1,161.9) | (1,116.8) | (1,161.9) | (1,116.8) | (1,178.4) | ||||||
Other | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 1.6 | 1.7 | 2 | ||||||||
Gas Utility | |||||||||||
Depreciation and amortization expense | 0.5 | 0.6 | 0.5 | ||||||||
ASSETS | |||||||||||
Total Assets | 1,842.4 | 1,560.2 | 1,842.4 | 1,560.2 | 1,575.7 | ||||||
Corporate Eliminations | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 3.2 | 2 | 1.8 | ||||||||
Corporate And Eliminations | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 4.8 | 3.7 | 3.8 | ||||||||
Gas Utility | |||||||||||
Natural and propane gas | 0 | 0 | 0 | ||||||||
Other operation and maintenance expenses | 0 | 0 | 0 | ||||||||
Depreciation and amortization | 0 | 0 | 0 | ||||||||
Taxes, other than income taxes | 0 | 0 | 0 | ||||||||
Total Gas Utility Operating Expenses | 0 | 0 | 0 | ||||||||
Gas Marketing and other | 12.6 | 12.6 | 20.5 | ||||||||
Total Operating Expenses | 12.6 | 12.6 | 20.5 | ||||||||
Operating Income | (7.8) | (8.9) | (16.7) | ||||||||
Net Economic Earnings | (17.6) | (16.3) | (2.9) | ||||||||
Capital Expenditures | 1.6 | 5.4 | 2.4 | ||||||||
Gas Utility | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 1,457.2 | 1,891.8 | 1,462.6 | ||||||||
Gas Utility | Operating Segments | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 1,459.4 | 1,895.8 | 1,467.8 | ||||||||
Gas Utility | |||||||||||
Natural and propane gas | 539.7 | 957.6 | 821.8 | ||||||||
Other operation and maintenance expenses | 379.3 | 391.6 | 288.7 | ||||||||
Depreciation and amortization | 136.9 | 129.9 | 82.4 | ||||||||
Taxes, other than income taxes | 125.2 | 142.1 | 112 | ||||||||
Total Gas Utility Operating Expenses | 1,181.1 | 1,621.2 | 1,304.9 | ||||||||
Gas Marketing and other | 0 | 0 | 0 | ||||||||
Total Operating Expenses | 1,181.1 | 1,621.2 | 1,304.9 | ||||||||
Operating Income | 278.3 | 274.6 | 162.9 | ||||||||
Net Economic Earnings | 160.3 | 150.4 | 92.8 | ||||||||
Capital Expenditures | 291.7 | 284.4 | 168.6 | ||||||||
ASSETS | |||||||||||
Total Assets | 5,191.9 | 4,686.2 | 5,191.9 | 4,686.2 | 4,520 | ||||||
Gas Utility | Eliminations | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 2.2 | 4 | 5.2 | ||||||||
Gas Marketing | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 78.5 | 82.9 | 162.6 | ||||||||
Gas Marketing | Operating Segments | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | 78.5 | 153.4 | 246.6 | ||||||||
Gas Utility | |||||||||||
Natural and propane gas | 0 | 0 | 0 | ||||||||
Other operation and maintenance expenses | 0 | 0 | 0 | ||||||||
Depreciation and amortization | 0 | 0 | 0 | ||||||||
Taxes, other than income taxes | 0 | 0 | 0 | ||||||||
Total Gas Utility Operating Expenses | 0 | 0 | 0 | ||||||||
Gas Marketing and other | 66.7 | 146.6 | 226.4 | ||||||||
Total Operating Expenses | 66.7 | 146.6 | 226.4 | ||||||||
Operating Income | 11.8 | 6.8 | 20.2 | ||||||||
Net Economic Earnings | 6.4 | 4.2 | 10.2 | ||||||||
Capital Expenditures | 0 | 0 | 0 | ||||||||
Depreciation and amortization expense | 0.1 | 0.3 | 0.4 | ||||||||
ASSETS | |||||||||||
Total Assets | $ 205 | $ 160.6 | 205 | 160.6 | 156.7 | ||||||
Gas Marketing | Eliminations | |||||||||||
Operating Segment Information [Abstract] | |||||||||||
Total Operating Revenues | $ 0 | $ 70.5 | $ 84 |
INFORMATION BY OPERATING SEGM98
INFORMATION BY OPERATING SEGMENT - Reconciliation of Consolidated Net Income to Consolidated Net Economic Earnings (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2016 | Jun. 30, 2016 | Mar. 31, 2016 | Dec. 31, 2015 | Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Segment Reporting [Abstract] | |||||||||||
Net Income | $ (14.2) | $ 10.7 | $ 100.8 | $ 46.9 | $ (18.7) | $ 14.1 | $ 94.4 | $ 47.1 | $ 144.2 | $ 136.9 | $ 84.6 |
Unrealized gain on energy-related derivatives | (0.1) | (2.8) | (1.6) | ||||||||
Lower of cost or market inventory adjustments | 0.2 | 0.4 | (1.1) | ||||||||
Realized (gain) loss on economic hedges prior to the sale of the physical commodity | (1.6) | 2.4 | (0.4) | ||||||||
Acquisition, divestiture and restructuring activities | 9.2 | 9.8 | 29.5 | ||||||||
Gain on sale of property | 0 | (7.6) | 0 | ||||||||
Income tax effect of adjustments | (2.8) | (0.8) | (10.9) | ||||||||
Net Economic Earnings | $ 149.1 | $ 138.3 | $ 100.1 |
REGULATORY MATTERS - Schedule
REGULATORY MATTERS - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Regulatory Assets [Line Items] | ||
Regulatory assets, current | $ 93.9 | $ 40.5 |
Regulatory assets, non current | 838 | 737.6 |
Total Regulatory Assets | 931.9 | 778.1 |
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 30.6 | 60.6 |
Regulatory liabilities, noncurrent | 130.7 | 119.3 |
Total Regulatory Liabilities | 161.3 | 179.9 |
RSE adjustment | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 7.5 | 12.2 |
Unbilled service margin | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 5.9 | 6.4 |
Pension and postretirement costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 9.3 | 10.8 |
Regulatory liabilities, noncurrent | 9.4 | 16.2 |
Unamortized purchased gas adjustments | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 1.7 | 28.2 |
Postretirement liabilities | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 28.9 | 28.9 |
Accrued cost of removal | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 74.8 | 58.7 |
Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 6.2 | 3 |
Regulatory liabilities, noncurrent | 17.6 | 15.5 |
Pension and postretirement benefit costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 27 | 22 |
Regulatory assets, non current | 487.9 | 448.7 |
Unamortized purchased gas adjustments | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 49.7 | 12.9 |
Future income taxes due from customers | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 151.3 | 134.5 |
Accrued cost of removal | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 130.6 | 78.9 |
Purchased gas costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 12.6 | 24.1 |
Energy efficiency | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 25.5 | 22.3 |
Other | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 17.2 | 5.6 |
Regulatory assets, non current | 30.1 | 29.1 |
Laclede Gas | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 67 | 29.1 |
Regulatory assets, non current | 589.8 | 573.6 |
Total Regulatory Assets | 656.8 | 602.7 |
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 1.3 | 0.6 |
Regulatory liabilities, noncurrent | 67.3 | 70.6 |
Total Regulatory Liabilities | 68.6 | 71.2 |
Laclede Gas | RSE adjustment | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 0 | 0 |
Laclede Gas | Unbilled service margin | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 0 | 0 |
Laclede Gas | Pension and postretirement costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 0 | 0 |
Regulatory liabilities, noncurrent | 0 | 0 |
Laclede Gas | Unamortized purchased gas adjustments | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 0 | 0 |
Laclede Gas | Postretirement liabilities | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 0 | 0 |
Laclede Gas | Accrued cost of removal | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 55.1 | 58.7 |
Laclede Gas | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 1.3 | 0.6 |
Regulatory liabilities, noncurrent | 12.2 | 11.9 |
Laclede Gas | Pension and postretirement benefit costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 20.2 | 15.5 |
Regulatory assets, non current | 375.7 | 368 |
Laclede Gas | Unamortized purchased gas adjustments | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 43.1 | 12.9 |
Laclede Gas | Future income taxes due from customers | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 151.3 | 134.5 |
Laclede Gas | Accrued cost of removal | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 0 | 0 |
Laclede Gas | Purchased gas costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 12.6 | 24.1 |
Laclede Gas | Energy efficiency | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 25.5 | 22.3 |
Laclede Gas | Other | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 3.7 | 0.7 |
Regulatory assets, non current | 24.7 | 24.7 |
Alagasco | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 20.5 | 11.4 |
Regulatory assets, non current | 230.7 | 163.6 |
Total Regulatory Assets | 251.2 | 175 |
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 22.7 | 60 |
Regulatory liabilities, noncurrent | 41.7 | 48.7 |
Total Regulatory Liabilities | 64.4 | 108.7 |
Alagasco | RSE adjustment | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 5 | 12.2 |
Alagasco | Unbilled service margin | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 5.9 | 6.4 |
Alagasco | Pension and postretirement costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 9.3 | 10.8 |
Regulatory liabilities, noncurrent | 9.4 | 16.2 |
Alagasco | Unamortized purchased gas adjustments | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 0 | 28.2 |
Alagasco | Postretirement liabilities | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 28.9 | 28.9 |
Alagasco | Accrued cost of removal | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, noncurrent | 0 | 0 |
Alagasco | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory liabilities, current | 2.5 | 2.4 |
Regulatory liabilities, noncurrent | 3.4 | 3.6 |
Alagasco | Pension and postretirement benefit costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 6.8 | 6.5 |
Regulatory assets, non current | 98.9 | 80.7 |
Alagasco | Unamortized purchased gas adjustments | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 5.6 | 0 |
Alagasco | Future income taxes due from customers | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 0 | 0 |
Alagasco | Accrued cost of removal | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 130.6 | 78.9 |
Alagasco | Purchased gas costs | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 0 | 0 |
Alagasco | Energy efficiency | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, non current | 0 | 0 |
Alagasco | Other | ||
Regulatory Assets [Line Items] | ||
Regulatory assets, current | 8.1 | 4.9 |
Regulatory assets, non current | $ 1.2 | $ 4 |
REGULATORY MATTERS - Schedule o
REGULATORY MATTERS - Schedule of Regulatory Assets Not Earnings a Return (Details) - USD ($) $ in Millions | Sep. 30, 2016 | Sep. 30, 2015 |
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | $ 404.8 | $ 372.4 |
Future income taxes due from customers | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 151.3 | 134.5 |
Pension and postretirement benefit costs | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 240.6 | 223.7 |
Compensated absences | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 0 | 0 |
Other | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 12.9 | 14.2 |
Laclede Gas | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 404.8 | 372.4 |
Laclede Gas | Future income taxes due from customers | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 151.3 | 134.5 |
Laclede Gas | Pension and postretirement benefit costs | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 240.6 | 223.7 |
Laclede Gas | Compensated absences | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | 0 | 0 |
Laclede Gas | Other | ||
Regulatory Assets [Line Items] | ||
Total Regulatory Assets Not Earning a Return | $ 12.9 | $ 14.2 |
REGULATORY MATTERS - Narrative
REGULATORY MATTERS - Narrative (Details) - USD ($) | Oct. 01, 2017 | Dec. 01, 2016 | Oct. 26, 2016 | Sep. 30, 2016 | Jul. 31, 2016 | May 31, 2016 | May 19, 2016 | Apr. 30, 2016 | Jan. 31, 2016 | Dec. 01, 2015 | Nov. 12, 2015 | Jan. 01, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Nov. 11, 2016 | Apr. 15, 2016 | Feb. 10, 2016 | Jun. 30, 2015 |
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Regulatory assets for which no return on investment during recovery period is provided | $ 404,800,000 | $ 404,800,000 | $ 372,400,000 | |||||||||||||||
Remaining recovery period for regulatory assets for which no return on investment during recovery period is provided | 15 years | |||||||||||||||||
Laclede Gas | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Regulatory assets for which no return on investment during recovery period is provided | 404,800,000 | $ 404,800,000 | 372,400,000 | |||||||||||||||
Regulatory preferred stock and debt securities issuance, amount authorized | 300,000,000 | $ 300,000,000 | $ 300,000,000 | $ 518,000,000 | ||||||||||||||
Regulatory preferred stock and debt securities issuance, amount requested | $ 550,000,000 | |||||||||||||||||
Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Potential performance-based adjustment | 0.05% | |||||||||||||||||
APSC | Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved rate increase (decrease) amount | $ (2,700,000) | $ (4,800,000) | $ (5,800,000) | $ 0 | $ 7,800,000 | $ 4,700,000 | ||||||||||||
Approved return rate on equity | 10.80% | |||||||||||||||||
Maximum return on equity, percentage of prior year revenues | 4.00% | |||||||||||||||||
Rate increase (decrease), margin of index range | 1.75% | 1.75% | ||||||||||||||||
Infrastructure System Replacement Surcharge | MoPSC | Laclede Gas | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved rate increase (decrease) amount | $ 25,000,000 | $ 5,400,000 | $ 4,400,000 | |||||||||||||||
Approved rate increase, annualized revenue | $ 19,600,000 | |||||||||||||||||
Requested rate increase | $ 5,000,000 | |||||||||||||||||
Infrastructure System Replacement Surcharge | MoPSC | Missouri Gas Energy (MGE) | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved rate increase (decrease) amount | $ 10,300,000 | $ 3,600,000 | $ 1,900,000 | |||||||||||||||
Approved rate increase, annualized revenue | $ 6,700,000 | |||||||||||||||||
Requested rate increase | $ 3,400,000 | |||||||||||||||||
Subsequent Event | Laclede Gas | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Regulatory preferred stock and debt securities issuance, authorized debt issuance - remaining available | $ 300,000,000 | |||||||||||||||||
Subsequent Event | APSC | Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved rate increase (decrease) amount | $ (4,800,000) | $ (1,300,000) | ||||||||||||||||
Minimum | APSC | Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved return rate on equity | 10.50% | |||||||||||||||||
Maximum | APSC | Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved return rate on equity | 10.95% | |||||||||||||||||
Scenario, Forecast | APSC | Alagasco | ||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||
Approved rate increase (decrease) amount | $ (2,700,000) |
COMMITMENTS AND CONTINGENCIES -
COMMITMENTS AND CONTINGENCIES - Commitments (Details) MMcf in Thousands, $ in Millions | 12 Months Ended |
Sep. 30, 2016USD ($)MMcf | |
Long-term Purchase Commitment [Line Items] | |
Minimum total payments required for natural gas contracts | $ 1,647.8 |
Laclede Gas | |
Long-term Purchase Commitment [Line Items] | |
Minimum total payments required for natural gas contracts | 1,227.6 |
Laclede Gas | Purchase Commitment | Subsidiary of Common Parent | |
Long-term Purchase Commitment [Line Items] | |
Annual purchase commitment | $ 1 |
Commitment termination minimum required notification period | 6 months |
Alagasco | |
Long-term Purchase Commitment [Line Items] | |
Minimum total payments required for natural gas contracts | $ 352.7 |
Alagasco | Inventories | |
Long-term Purchase Commitment [Line Items] | |
Minimum volume purchase commitment required (in Mmcf) | MMcf | 93 |
COMMITMENTS AND CONTINGENCIE103
COMMITMENTS AND CONTINGENCIES - Leases and Guarantees (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Loss Contingencies [Line Items] | |||
Aggregate rental expense | $ 11.9 | $ 14.1 | $ 6.7 |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Minimum rental commitments - in fiscal year 2017 | 10.5 | ||
Minimum rental commitments - due in fiscal year 2018 | 7.5 | ||
Minimum rental commitments - due in fiscal year 2019 | 7.3 | ||
Minimum rental commitments - due in fiscal year 2020 | 6.2 | ||
Minimum rental commitments - due in fiscal year 2021 | 6 | ||
Minimum rental commitments - due later | 53.4 | ||
Minimum rental commitments - total | 90.9 | ||
Sublease rentals | 2.1 | 2.1 | 0.2 |
Minimum future sublease rentals to be received - fiscal year 2017 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2018 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2019 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2020 | 0.5 | ||
Outstanding mortgage loans incurred in connection with various real estate ventures with general partners | 1.4 | ||
Laclede Gas | |||
Loss Contingencies [Line Items] | |||
Aggregate rental expense | 4.3 | 7.6 | 6.3 |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Minimum rental commitments - in fiscal year 2017 | 2.5 | ||
Minimum rental commitments - due in fiscal year 2018 | 0.9 | ||
Minimum rental commitments - due in fiscal year 2019 | 0.9 | ||
Minimum rental commitments - due in fiscal year 2020 | 0.3 | ||
Minimum rental commitments - due in fiscal year 2021 | 0.1 | ||
Minimum rental commitments - due later | 0 | ||
Minimum rental commitments - total | 4.7 | ||
Alagasco | |||
Loss Contingencies [Line Items] | |||
Aggregate rental expense | 3.7 | 4 | 2 |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | |||
Minimum rental commitments - in fiscal year 2017 | 3.9 | ||
Minimum rental commitments - due in fiscal year 2018 | 2.5 | ||
Minimum rental commitments - due in fiscal year 2019 | 2.5 | ||
Minimum rental commitments - due in fiscal year 2020 | 2.1 | ||
Minimum rental commitments - due in fiscal year 2021 | 2.1 | ||
Minimum rental commitments - due later | 4.9 | ||
Minimum rental commitments - total | 18 | ||
Sublease rentals | 2.1 | $ 2.1 | $ 0.2 |
Minimum future sublease rentals to be received - fiscal year 2017 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2018 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2019 | 2.1 | ||
Minimum future sublease rentals to be received - fiscal year 2020 | $ 0.5 |
COMMITMENTS AND CONTINGENCIE104
COMMITMENTS AND CONTINGENCIES - Contingencies (Details) | Dec. 17, 2013fatality | Sep. 30, 2016plaintiffsitelawsuit | Sep. 30, 2016sitelawsuit | Sep. 30, 2014site |
Site Contingency [Line Items] | ||||
Number of incident fatalities | fatality | 1 | |||
Laclede Gas | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) sites in Missouri | 3 | 3 | ||
Number of former manufactured gas plant (MGP) sites in Shrewsbury, Missouri | 1 | 1 | ||
Number of former manufactured gas plant (MGP) sites in the City of St. Louis | 2 | 2 | ||
Laclede Gas | Previous Ownership | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) | 19 | |||
Missouri Gas Energy (MGE) | Previous Ownership | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) | 7 | 7 | ||
Alagasco | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) | 9 | 9 | ||
Number of former manufactured gas distribution | 5 | 5 | ||
Alagasco | Current Ownership | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) | 4 | 4 | ||
Number of former manufactured gas distribution | 1 | 1 | ||
Mobile Gas | ||||
Site Contingency [Line Items] | ||||
Number of lawsuits | lawsuit | 14 | |||
Number of lawsuits settled | lawsuit | 11 | |||
Number of lawsuits pending | lawsuit | 3 | 3 | ||
Mobile Gas | Pending Litigation | ||||
Site Contingency [Line Items] | ||||
Number of plaintiffs | plaintiff | 270 | |||
Mobile Gas | Previous Ownership | ||||
Site Contingency [Line Items] | ||||
Number of former manufactured gas plant (MGP) | 1 |
INTERIM FINANCIAL INFORMATIO105
INTERIM FINANCIAL INFORMATION (UNAUDITED) (Details) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||||
Sep. 30, 2016 | Jun. 30, 2016 | Mar. 31, 2016 | Dec. 31, 2015 | Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | Sep. 30, 2014 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2014 | |
Quarterly Financial Information [Line Items] | ||||||||||||
Total Operating Revenues | $ 279.3 | $ 249.3 | $ 609.3 | $ 399.4 | $ 204.2 | $ 275.2 | $ 877.4 | $ 619.6 | $ 1,537.3 | $ 1,976.4 | $ 1,627.2 | |
Operating Income (Loss) | (7.7) | 35.3 | 167.7 | 87 | (8.5) | 36 | 157.7 | 87.3 | 282.3 | 272.5 | 166.4 | |
Net Income (Loss) | $ (14.2) | $ 10.7 | $ 100.8 | $ 46.9 | $ (18.7) | $ 14.1 | $ 94.4 | $ 47.1 | $ 144.2 | $ 136.9 | $ 84.6 | |
Basic Earnings Per Share of Common Stock (in dollars per share) | $ (0.31) | $ 0.24 | $ 2.32 | $ 1.08 | $ (0.43) | $ 0.32 | $ 2.18 | $ 1.09 | $ 3.26 | $ 3.16 | $ 2.36 | |
Diluted Earnings Per Share of Common Stock (in dollars per share) | $ (0.31) | $ 0.24 | $ 2.31 | $ 1.08 | $ (0.43) | $ 0.32 | $ 2.18 | $ 1.09 | $ 3.24 | $ 3.16 | $ 2.35 | |
Laclede Gas | ||||||||||||
Quarterly Financial Information [Line Items] | ||||||||||||
Total Operating Revenues | $ 144.3 | $ 179.3 | $ 446.7 | $ 317.2 | $ 151 | $ 187.5 | $ 615.7 | $ 462.4 | $ 1,087.5 | $ 1,416.6 | $ 1,448.2 | |
Operating Income (Loss) | 5.4 | 29.4 | 87 | 65.1 | 5.5 | 34.5 | 80.6 | 64.8 | 186.9 | 185.4 | 166.4 | |
Net Income (Loss) | (1.7) | 13.9 | 54.3 | 39.4 | (3.6) | 20 | 49.9 | 39 | 105.9 | 105.3 | $ 90.1 | |
Alagasco | ||||||||||||
Quarterly Financial Information [Line Items] | ||||||||||||
Total Operating Revenues | 46.2 | 74 | 166 | 82.3 | 52.2 | 73.7 | 233.3 | 120 | $ 417.2 | 368.5 | 479.2 | |
Operating Income (Loss) | (17.1) | 9.3 | 80.4 | 18.9 | (12.5) | 3.9 | 77.4 | 20.4 | 62.2 | 91.5 | 89.2 | |
Net Income (Loss) | $ (8.8) | $ 4 | $ 48.1 | $ 9.9 | $ (9.6) | $ 0.7 | $ 46.3 | $ 10.6 | $ 33 | $ 53.2 | $ 48 |