Document_and_Entity_Informatio
Document and Entity Information (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Jan. 31, 2014 | Jun. 30, 2013 | |
Entity Information [Line Items] | ' | ' | ' |
Entity Registrant Name | 'QUESTAR CORP | ' | ' |
Entity Central Index Key | '0000751652 | ' | ' |
Current Fiscal Year End Date | '--12-31 | ' | ' |
Entity Well-known Seasoned Issuer | 'Yes | ' | ' |
Entity Voluntary Filers | 'No | ' | ' |
Entity Current Reporting Status | 'Yes | ' | ' |
Entity Filer Category | 'Large Accelerated Filer | ' | ' |
Entity Public Float | ' | ' | $4,200,000,000 |
Entity Common Stock, Shares Outstanding | ' | 175,114,937 | ' |
Document Fiscal Year Focus | '2013 | ' | ' |
Document Fiscal Period Focus | 'FY | ' | ' |
Document Type | '10-K | ' | ' |
Amendment Flag | 'false | ' | ' |
Document Period End Date | 31-Dec-13 | ' | ' |
Questar Gas [Member] | ' | ' | ' |
Entity Information [Line Items] | ' | ' | ' |
Entity Registrant Name | 'QUESTAR GAS CO | ' | ' |
Entity Central Index Key | '0000068589 | ' | ' |
Current Fiscal Year End Date | '--12-31 | ' | ' |
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 | ' | 9,189,626 | ' |
Document Fiscal Year Focus | '2013 | ' | ' |
Document Fiscal Period Focus | 'FY | ' | ' |
Document Type | '10-K | ' | ' |
Amendment Flag | 'false | ' | ' |
Document Period End Date | 31-Dec-13 | ' | ' |
Questar Pipeline [Member] | ' | ' | ' |
Entity Information [Line Items] | ' | ' | ' |
Entity Registrant Name | 'QUESTAR PIPELINE CO | ' | ' |
Entity Central Index Key | '0000764044 | ' | ' |
Current Fiscal Year End Date | '--12-31 | ' | ' |
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 | ' | 6,550,843 | ' |
Document Fiscal Year Focus | '2013 | ' | ' |
Document Fiscal Period Focus | 'FY | ' | ' |
Document Type | '10-K | ' | ' |
Amendment Flag | 'false | ' | ' |
Document Period End Date | 31-Dec-13 | ' | ' |
CONSOLIDATED_STATEMENTS_OF_INC
CONSOLIDATED STATEMENTS OF INCOME (USD $) | 12 Months Ended | ||
In Millions, except Per Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
REVENUES | ' | ' | ' |
Questar Gas / Revenues from unaffiliated customers | $985.20 | $859.70 | $965.50 |
Wexpro | 45.1 | 36.1 | 31.5 |
Questar Pipeline / Revenues from unaffiliated customers | 189.5 | 203.1 | 197.4 |
Other | 0.2 | 0 | 0 |
Total Revenues | 1,220 | 1,098.90 | 1,194.40 |
OPERATING EXPENSES | ' | ' | ' |
Cost of sales (excluding operating expenses shown separately) | 285.9 | 192.3 | 321.5 |
Cost of natural gas sold | ' | ' | ' |
Operating and maintenance | 174.3 | 180.8 | 175.9 |
General and administrative | 121 | 120.8 | 117.9 |
Retirement incentive | 0 | 4.9 | 0 |
Production and other taxes | 57.4 | 47.9 | 52.5 |
Depreciation, depletion and amortization | 194.8 | 181.6 | 159.9 |
Asset impairment | 80.6 | 0 | 0 |
Other taxes | 57.4 | 47.9 | 52.5 |
Total Operating Expenses | 914 | 728.3 | 827.7 |
Net gain (loss) from asset sales | -0.2 | 5.1 | 0.2 |
OPERATING INCOME | 305.8 | 375.7 | 366.9 |
Interest and other income | 9.9 | 7 | 10.4 |
Income from unconsolidated affiliate | 3.7 | 3.7 | 3.8 |
Interest expense | -56.9 | -57.9 | -56.8 |
INCOME BEFORE INCOME TAXES | 262.5 | 328.5 | 324.3 |
Income taxes | -101.3 | -116.5 | -116.4 |
NET INCOME | 161.2 | 212 | 207.9 |
Earnings Per Common Share | ' | ' | ' |
Basic | $0.92 | $1.20 | $1.17 |
Diluted | $0.92 | $1.19 | $1.16 |
Weighted-average common shares outstanding | ' | ' | ' |
Used in basic calculation | 175.4 | 176.5 | 177.4 |
Used in diluted calculation | 176 | 177.5 | 178.8 |
Questar Gas [Member] | ' | ' | ' |
REVENUES | ' | ' | ' |
Questar Gas / Revenues from unaffiliated customers | 985.2 | 859.7 | 965.5 |
Revenues from affiliated company | 0.6 | 2.5 | 3.3 |
Total Revenues | 985.8 | 862.2 | 968.8 |
Cost of natural gas sold | ' | ' | ' |
Cost of natural gas sold / Unaffiliated parties | 279.7 | 185.6 | 318.4 |
Cost of natural gas sold / Affiliated companies | 370.9 | 347.7 | 327.3 |
Total cost of natural gas sold (excluding operating expenses shown separately) | 650.6 | 533.3 | 645.7 |
Operating and maintenance | 113.1 | 119 | 118.5 |
General and administrative | 52.5 | 51.2 | 51 |
Retirement incentive | 0 | 2.4 | 0 |
Depreciation and amortization | 49.7 | 47.2 | 44.5 |
Other taxes | 18 | 16.2 | 15 |
Total Operating Expenses | 883.9 | 769.3 | 874.7 |
OPERATING INCOME | 101.9 | 92.9 | 94.1 |
Interest and other income | 5.1 | 5.5 | 5.4 |
Interest expense | -22.3 | -24.1 | -25.9 |
INCOME BEFORE INCOME TAXES | 84.7 | 74.3 | 73.6 |
Income taxes | -31.9 | -27.2 | -27.5 |
NET INCOME | 52.8 | 47.1 | 46.1 |
Questar Pipeline [Member] | ' | ' | ' |
REVENUES | ' | ' | ' |
Questar Pipeline / Revenues from unaffiliated customers | 189.5 | 203.1 | 197.4 |
Revenues from affiliated companies | 76.7 | 74.4 | 74.4 |
Total Revenues | 266.2 | 277.5 | 271.8 |
Cost of natural gas sold | ' | ' | ' |
Operating and maintenance | 32.5 | 35.2 | 35.3 |
General and administrative | 46.7 | 50 | 46.5 |
Retirement incentive | 0 | 0.9 | 0 |
Depreciation and amortization | 55.5 | 54.3 | 51.2 |
Asset impairment | 80.6 | 0 | 0 |
Other taxes | 9.3 | 9.1 | 10.1 |
Cost of sales (excluding operating expenses shown separately) | 6.1 | 6.7 | 3.1 |
Total Operating Expenses | 230.7 | 156.2 | 146.2 |
Net gain (loss) from asset sales | 0 | 2.7 | 0.3 |
OPERATING INCOME | 35.5 | 124 | 125.9 |
Interest and other income | 1.8 | 0.6 | 0.9 |
Income from unconsolidated affiliate | 3.7 | 3.7 | 3.8 |
Interest expense | -25.8 | -26.3 | -24.5 |
INCOME BEFORE INCOME TAXES | 15.2 | 102 | 106.1 |
Income taxes | -7 | -37.3 | -38.2 |
NET INCOME | $8.20 | $64.70 | $67.90 |
CONSOLIDATED_STATEMENTS_OF_COM
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Net income | $161.20 | $212 | $207.90 |
Pension and other postretirement benefits | ' | ' | ' |
Change in unrecognized actuarial loss | 167.7 | -35.7 | -162.9 |
Change in unrecognized prior service cost | 1.1 | 2.7 | 3 |
Interest rate cash flow hedges | 0.5 | 0.4 | -37.2 |
Change in fair value of long-term investment | -0.1 | 0.1 | 0 |
Income taxes | -64.7 | 12.3 | 75 |
Net other comprehensive income (loss) | 104.5 | -20.2 | -122.1 |
COMPREHENSIVE INCOME | 265.7 | 191.8 | 85.8 |
Questar Pipeline [Member] | ' | ' | ' |
Net income | 8.2 | 64.7 | 67.9 |
Pension and other postretirement benefits | ' | ' | ' |
Interest rate cash flow hedges | 0.5 | 0.4 | -37.2 |
Income taxes | -0.2 | -0.2 | 13.8 |
Net other comprehensive income (loss) | 0.3 | 0.2 | -23.4 |
COMPREHENSIVE INCOME | $8.50 | $64.90 | $44.50 |
CONSOLIDATED_BALANCE_SHEETS
CONSOLIDATED BALANCE SHEETS (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
Current Assets | ' | ' |
Cash and cash equivalents | $16,000,000 | $16,800,000 |
Federal income taxes receivable | 4,500,000 | 10,700,000 |
Accounts receivable, net | 119,300,000 | 103,600,000 |
Unbilled gas accounts receivable | 93,400,000 | 78,300,000 |
Inventories, at lower of average cost or market: | ' | ' |
Gas stored underground | 40,000,000 | 39,000,000 |
Materials and supplies | 23,700,000 | 24,500,000 |
Current regulatory assets | 35,800,000 | 46,700,000 |
Prepaid expenses and other | 9,500,000 | 13,100,000 |
Deferred income taxes - current | 9,700,000 | 13,000,000 |
Total Current Assets | 351,900,000 | 345,700,000 |
Property, Plant and Equipment | ' | ' |
Distribution property, plant and equipment | 2,203,000,000 | 2,040,900,000 |
Cost-of-service gas and oil property, plant and equipment, successful efforts method | 1,626,400,000 | 1,397,600,000 |
Transportation property, plant and equipment | 1,774,300,000 | 1,840,100,000 |
Other property, plant and equipment | 71,000,000 | 54,700,000 |
Total Property, Plant and Equipment | 5,674,700,000 | 5,333,300,000 |
Distribution accumulated depreciation and amortization | -745,200,000 | -716,600,000 |
Cost-of-service gas and oil accumulated depreciation, depletion and amortization | -689,800,000 | -617,200,000 |
Transportation accumulated depreciation and amortization | -627,200,000 | -629,300,000 |
Other accumulated depreciation and amortization | -9,500,000 | -7,000,000 |
Total accumulated depreciation, depletion and amortization | -2,071,700,000 | -1,970,100,000 |
Net Property, Plant and Equipment | 3,603,000,000 | 3,363,200,000 |
Investment in unconsolidated affiliate | 25,600,000 | 26,500,000 |
Other Assets | ' | ' |
Goodwill | 9,800,000 | 9,800,000 |
Noncurrent regulatory assets | 20,500,000 | 21,600,000 |
Other noncurrent assets | 43,500,000 | 36,500,000 |
Total Other Assets | 73,800,000 | 67,900,000 |
TOTAL ASSETS | 4,054,300,000 | 3,803,300,000 |
Current Liabilities | ' | ' |
Short-term debt | 276,000,000 | 263,000,000 |
Accounts payable and accrued expenses | 200,100,000 | 167,500,000 |
Production and other taxes | 34,700,000 | 28,000,000 |
Customer advances | 19,800,000 | 30,200,000 |
Current regulatory liabilities | 14,100,000 | 5,800,000 |
Interest payable | 10,200,000 | 9,500,000 |
Current portion of long-term debt | 0 | 42,000,000 |
Current portion of capital lease obligation | 900,000 | 700,000 |
Total Current Liabilities | 555,800,000 | 546,700,000 |
Long-term debt, less current portion | 1,247,100,000 | 1,098,900,000 |
Capital lease obligation, less current portion | 38,400,000 | 39,300,000 |
Deferred income taxes | 707,200,000 | 603,400,000 |
Asset retirement obligations | 67,700,000 | 67,200,000 |
Defined benefit pension plan | 70,700,000 | 246,900,000 |
Other postretirement benefits | 42,500,000 | 56,800,000 |
Noncurrent regulatory liabilities | 61,200,000 | 54,400,000 |
Customer contributions in aid of construction | 29,100,000 | 22,900,000 |
Other noncurrent liabilities | 35,800,000 | 31,200,000 |
Commitments and contingencies - Note 9 | ' | ' |
COMMON SHAREHOLDERS' EQUITY | ' | ' |
Common stock | 464,500,000 | 442,400,000 |
Retained earnings | 876,100,000 | 839,500,000 |
Accumulated other comprehensive loss | -141,800,000 | -246,300,000 |
Total Common Shareholders' Equity | 1,198,800,000 | 1,035,600,000 |
TOTAL LIABILITIES AND COMMON SHAREHOLDERS' EQUITY | 4,054,300,000 | 3,803,300,000 |
Questar Gas [Member] | ' | ' |
Current Assets | ' | ' |
Cash and cash equivalents | 8,800,000 | 1,400,000 |
Federal income taxes receivable | 2,800,000 | 0 |
Accounts receivable, net | 86,100,000 | 67,000,000 |
Unbilled gas accounts receivable | 93,400,000 | 78,200,000 |
Accounts receivable from affiliates | 30,400,000 | 31,800,000 |
Inventories, at lower of average cost or market: | ' | ' |
Gas stored underground | 39,200,000 | 38,300,000 |
Materials and supplies | 12,100,000 | 13,500,000 |
Current regulatory assets | 30,200,000 | 41,000,000 |
Prepaid expenses and other | 3,000,000 | 3,200,000 |
Deferred income taxes - current | 2,900,000 | 1,500,000 |
Total Current Assets | 308,900,000 | 275,900,000 |
Property, Plant and Equipment | ' | ' |
Distribution property, plant and equipment | 1,839,800,000 | 1,690,500,000 |
Other property, plant and equipment | 289,800,000 | 281,600,000 |
Construction work in progress | 73,400,000 | 68,800,000 |
Total Property, Plant and Equipment | 2,203,000,000 | 2,040,900,000 |
Total accumulated depreciation, depletion and amortization | -745,200,000 | -716,600,000 |
Net Property, Plant and Equipment | 1,457,800,000 | 1,324,300,000 |
Other Assets | ' | ' |
Goodwill | 5,600,000 | 5,600,000 |
Noncurrent regulatory assets | 16,100,000 | 16,400,000 |
Other noncurrent assets | 4,000,000 | 3,100,000 |
Total Other Assets | 25,700,000 | 25,100,000 |
TOTAL ASSETS | 1,792,400,000 | 1,625,300,000 |
Current Liabilities | ' | ' |
Notes payable to Questar | 17,700,000 | 166,100,000 |
Accounts payable and accrued expenses | 134,000,000 | 100,500,000 |
Accounts payable to affiliates | 67,800,000 | 50,900,000 |
Customer advances | 19,800,000 | 30,200,000 |
Current regulatory liabilities | 11,100,000 | 4,300,000 |
Interest payable | 5,200,000 | 4,500,000 |
Current portion of long-term debt | 0 | 42,000,000 |
Total Current Liabilities | 255,600,000 | 398,500,000 |
Long-term debt, less current portion | 534,500,000 | 384,500,000 |
Deferred income taxes | 340,700,000 | 301,600,000 |
Asset retirement obligations | 600,000 | 500,000 |
Noncurrent regulatory liabilities | 53,000,000 | 46,700,000 |
Customer contributions in aid of construction | 29,100,000 | 22,900,000 |
Other noncurrent liabilities | 3,200,000 | 3,500,000 |
Commitments and contingencies - Note 9 | ' | ' |
COMMON SHAREHOLDERS' EQUITY | ' | ' |
Common stock | 23,000,000 | 23,000,000 |
Additional paid-in capital | 263,900,000 | 172,500,000 |
Retained earnings | 289,400,000 | 272,100,000 |
Total Common Shareholders' Equity | 576,300,000 | 467,600,000 |
TOTAL LIABILITIES AND COMMON SHAREHOLDERS' EQUITY | 1,792,400,000 | 1,625,300,000 |
Questar Pipeline [Member] | ' | ' |
Current Assets | ' | ' |
Cash and cash equivalents | 2,700,000 | 7,100,000 |
Notes receivable from Questar | 29,400,000 | 38,700,000 |
Accounts receivable, net | 18,500,000 | 19,100,000 |
Accounts receivable from affiliates | 36,600,000 | 27,500,000 |
Inventories, at lower of average cost or market: | ' | ' |
Materials and supplies | 8,100,000 | 7,200,000 |
Current regulatory assets | 5,600,000 | 5,700,000 |
Prepaid expenses and other | 4,400,000 | 7,700,000 |
Deferred income taxes - current | 1,800,000 | 1,600,000 |
Total Current Assets | 107,100,000 | 114,600,000 |
Property, Plant and Equipment | ' | ' |
Transportation property, plant and equipment | 1,331,000,000 | 1,394,700,000 |
Storage | 296,200,000 | 288,900,000 |
Processing | 24,100,000 | 25,700,000 |
General and intangible | 82,100,000 | 81,500,000 |
Construction work in progress | 40,900,000 | 49,300,000 |
Total Property, Plant and Equipment | 1,774,300,000 | 1,840,100,000 |
Total accumulated depreciation, depletion and amortization | -627,200,000 | -629,300,000 |
Net Property, Plant and Equipment | 1,147,100,000 | 1,210,800,000 |
Investment in unconsolidated affiliate | 25,600,000 | 26,500,000 |
Other Assets | ' | ' |
Goodwill | 4,200,000 | 4,200,000 |
Noncurrent regulatory assets | 4,400,000 | 5,200,000 |
Noncurrent regulatory and other liabilities | 7,700,000 | 9,000,000 |
Total Other Assets | 11,900,000 | 13,200,000 |
TOTAL ASSETS | 1,291,700,000 | 1,365,100,000 |
Current Liabilities | ' | ' |
Accounts payable and accrued expenses | 20,600,000 | 23,600,000 |
Accounts payable to affiliates | 9,400,000 | 16,900,000 |
Federal income taxes payable | 2,900,000 | 0 |
Current regulatory liabilities | 3,000,000 | 1,500,000 |
Interest payable | 2,100,000 | 2,100,000 |
Total Current Liabilities | 38,000,000 | 44,100,000 |
Long-term debt, less current portion | 458,900,000 | 458,900,000 |
Deferred income taxes | 228,600,000 | 242,500,000 |
Asset retirement obligations | 2,200,000 | 2,100,000 |
Noncurrent regulatory liabilities | 8,200,000 | 7,700,000 |
Other noncurrent liabilities | 13,900,000 | 13,800,000 |
Commitments and contingencies - Note 9 | ' | ' |
COMMON SHAREHOLDERS' EQUITY | ' | ' |
Common stock | 6,600,000 | 6,600,000 |
Additional paid-in capital | 349,500,000 | 347,500,000 |
Retained earnings | 219,100,000 | 274,900,000 |
Accumulated other comprehensive loss | -22,900,000 | -23,200,000 |
Total Common Shareholders' Equity | 552,300,000 | 605,800,000 |
TOTAL LIABILITIES AND COMMON SHAREHOLDERS' EQUITY | $1,291,700,000 | $1,365,100,000 |
CONSOLIDATED_BALANCE_SHEETS_Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
Common Stock, No Par Value | $0 | ' |
Common Stock, Shares Authorized | 500,000,000 | ' |
Common Stock, Shares Outstanding | 175,100,000 | 175,000,000 |
Questar Gas [Member] | ' | ' |
Common Stock, Par or Stated Value Per Share | $2.50 | ' |
Common Stock, Shares Authorized | 50,000,000 | ' |
Common Stock, Shares Issued | 9,200,000 | 9,200,000 |
Common Stock, Shares Outstanding | 9,200,000 | 9,200,000 |
Questar Pipeline [Member] | ' | ' |
Common Stock, Par or Stated Value Per Share | $1 | ' |
Common Stock, Shares Authorized | 25,000,000 | ' |
Common Stock, Shares Issued | 6,600,000 | 6,600,000 |
Common Stock, Shares Outstanding | 6,600,000 | 6,600,000 |
CONSOLIDATED_STATEMENTS_OF_COM1
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (USD $) | Total | Common Stock Including Additional Paid in Capital [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive Loss [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] |
In Millions | Common Stock [Member] | Additional Paid-in Capital [Member] | Retained Earnings [Member] | Common Stock [Member] | Additional Paid-in Capital [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive Loss [Member] | ||||||
Beginning Balance at Dec. 31, 2010 | $1,036.10 | $493 | $647.10 | ($104) | $415.50 | $23 | $150.30 | $242.20 | $586.80 | $6.60 | $344 | $236.20 | $0 |
Beginning Balance (in shares) at Dec. 31, 2010 | ' | 176.5 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued | 7.6 | 7.6 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued (in shares) | ' | 1.6 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased | -4.9 | -4.9 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased (in shares) | ' | -0.2 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Dividends paid | -110.1 | 0 | -110.1 | 0 | -30.3 | 0 | 0 | -30.3 | -30.9 | 0 | 0 | -30.9 | 0 |
Share-based compensation | 9.8 | 9.8 | 0 | 0 | 1.1 | 0 | 1.1 | 0 | 1.7 | 0 | 1.7 | 0 | 0 |
Tax benefits from share-based compensation | 9.2 | 9.2 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Equity contribution from Questar | ' | ' | ' | ' | 20 | 0 | 20 | 0 | ' | ' | ' | ' | ' |
Net income | 207.9 | 0 | 207.9 | 0 | 46.1 | 0 | 0 | 46.1 | 67.9 | 0 | 0 | 67.9 | 0 |
Net other comprehensive income (loss) | -122.1 | 0 | 0 | -122.1 | ' | ' | ' | ' | -23.4 | 0 | 0 | 0 | -23.4 |
Ending Balance at Dec. 31, 2011 | 1,033.50 | 514.7 | 744.9 | -226.1 | 452.4 | 23 | 171.4 | 258 | 602.1 | 6.6 | 345.7 | 273.2 | -23.4 |
Ending Balance (in shares) at Dec. 31, 2011 | ' | 177.9 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued | 7.2 | 7.2 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued (in shares) | ' | 1.5 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased | -88.5 | -88.5 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased (in shares) | ' | -4.4 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Dividends paid | -117.4 | 0 | -117.4 | 0 | -33 | 0 | 0 | -33 | -63 | 0 | 0 | -63 | 0 |
Share-based compensation | 9 | 9 | 0 | 0 | 1.1 | 0 | 1.1 | 0 | 1.8 | 0 | 1.8 | 0 | 0 |
Net income | 212 | 0 | 212 | 0 | 47.1 | 0 | 0 | 47.1 | 64.7 | 0 | 0 | 64.7 | 0 |
Net other comprehensive income (loss) | -20.2 | 0 | 0 | -20.2 | ' | ' | ' | ' | 0.2 | 0 | 0 | 0 | 0.2 |
Ending Balance at Dec. 31, 2012 | 1,035.60 | 442.4 | 839.5 | -246.3 | 467.6 | 23 | 172.5 | 272.1 | 605.8 | 6.6 | 347.5 | 274.9 | -23.2 |
Ending Balance (in shares) at Dec. 31, 2012 | ' | 175 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued | 2.3 | 2.3 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock issued (in shares) | ' | 0.3 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased | -4.2 | -4.2 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Common stock repurchased (in shares) | ' | -0.2 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Dividends paid | -124.6 | 0 | -124.6 | 0 | -35.5 | 0 | 0 | -35.5 | -64 | 0 | 0 | -64 | 0 |
Share-based compensation | 10 | 10 | 0 | 0 | 1.4 | 0 | 1.4 | 0 | 2 | 0 | 2 | 0 | 0 |
Tax benefits from share-based compensation | 14 | 14 | 0 | 0 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Equity contribution from Questar | ' | ' | ' | ' | 90 | 0 | 90 | 0 | ' | ' | ' | ' | ' |
Net income | 161.2 | 0 | 161.2 | 0 | 52.8 | 0 | 0 | 52.8 | 8.2 | 0 | 0 | 8.2 | 0 |
Net other comprehensive income (loss) | 104.5 | 0 | 0 | 104.5 | ' | ' | ' | ' | 0.3 | 0 | 0 | 0 | 0.3 |
Ending Balance at Dec. 31, 2013 | $1,198.80 | $464.50 | $876.10 | ($141.80) | $576.30 | $23 | $263.90 | $289.40 | $552.30 | $6.60 | $349.50 | $219.10 | ($22.90) |
Ending Balance (in shares) at Dec. 31, 2013 | ' | 175.1 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
CONSOLIDATED_STATEMENTS_OF_COM2
CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY (Parenthetical) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Statement of Stockholders' Equity [Abstract] | ' | ' | ' |
Dividends paid per common share | $0.71 | $0.67 | $0.62 |
CONSOLIDATED_STATEMENTS_OF_CAS
CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
OPERATING ACTIVITIES | ' | ' | ' |
Net income | $161.20 | $212 | $207.90 |
Adjustments to reconcile net income to net cash provided by operating activities: | ' | ' | ' |
Depreciation, depletion and amortization | 201.8 | 189.2 | 169.4 |
Deferred income taxes | 42.4 | 118.6 | 96.2 |
Asset impairment | 80.6 | 0 | 0 |
Share-based compensation | 10.2 | 9.9 | 10.1 |
Net (gain) loss from asset sales | 0.2 | -5.1 | -0.2 |
(Income) from unconsolidated affiliate | -3.7 | -3.7 | -3.8 |
Distributions from unconsolidated affiliate | 4.6 | 4.5 | 4.4 |
Other operating | 0.9 | 0.4 | 0.1 |
Changes in operating assets and liabilities | ' | ' | ' |
Accounts receivable including unbilled gas sales | -41.5 | 23.7 | 7.7 |
Inventories | -0.2 | 2.5 | -3.3 |
Prepaid expenses and other | 3.6 | -2.8 | -2.1 |
Interest rate hedges - current | 0 | 7.6 | -37.3 |
Accounts payable and accrued expenses | 33.7 | -5.1 | 11.7 |
Federal income taxes | 6.2 | -10.7 | 37.1 |
Current regulatory assets and liabilities | 19.2 | -24.6 | 31.2 |
Noncurrent regulatory and other assets and liabilities | -17.1 | -48.7 | -40.1 |
NET CASH PROVIDED BY OPERATING ACTIVITIES | 502.1 | 467.7 | 489 |
INVESTING ACTIVITIES | ' | ' | ' |
Property, plant and equipment | -399.4 | -370.7 | -367.7 |
Wexpro acquisition of producing properties | -104.3 | 0 | 0 |
Cash used in disposition of assets | -4.9 | -3 | -3.5 |
Proceeds from disposition of assets | 0.6 | 8.4 | 0.3 |
NET CASH USED IN INVESTING ACTIVITIES | -508 | -365.3 | -370.9 |
FINANCING ACTIVITIES | ' | ' | ' |
Common stock issued | 2.3 | 7.2 | 7.6 |
Common stock repurchased | -4.2 | -87.5 | -4.9 |
Long-term debt issued, net of issuance costs | 147.3 | 148.8 | 174.9 |
Long-term debt repaid | -42 | -91.5 | -182 |
Capital lease obligation repaid | -0.7 | -0.8 | 0 |
Change in short-term debt | 13 | 44 | -23 |
Dividends paid | -124.6 | -117.4 | -110.1 |
Tax benefits from share-based compensation | 14 | 0 | 9.2 |
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES | 5.1 | -97.2 | -128.3 |
Change in cash and cash equivalents | -0.8 | 5.2 | -10.2 |
Beginning cash and cash equivalents | 16.8 | 11.6 | 21.8 |
Ending cash and cash equivalents | 16 | 16.8 | 11.6 |
Supplemental Disclosure of Cash Paid (Received) During the Year for: | ' | ' | ' |
Interest | 55.8 | 58.5 | 54.2 |
Income taxes | 33.6 | 9.1 | -29.2 |
Supplemental Disclosure of Noncash Investing and Financing Transaction: | ' | ' | ' |
Capital lease obligation incurred | ' | 40.8 | ' |
Questar Gas [Member] | ' | ' | ' |
OPERATING ACTIVITIES | ' | ' | ' |
Net income | 52.8 | 47.1 | 46.1 |
Adjustments to reconcile net income to net cash provided by operating activities: | ' | ' | ' |
Depreciation and amortization | 54.7 | 52.1 | 49.2 |
Deferred income taxes | 37.7 | 45.9 | 25.2 |
Share-based compensation | 1.4 | 1.2 | 1.1 |
Changes in operating assets and liabilities | ' | ' | ' |
Accounts receivable including unbilled gas sales | -43.7 | -12.7 | 5 |
Inventories | 0.5 | 0.7 | -1.3 |
Prepaid expenses and other | 0.2 | -0.1 | -0.2 |
Accounts payable and accrued expenses | 29.5 | 7.8 | -1.8 |
Federal income taxes | -2.8 | 1.5 | 6.2 |
Current regulatory assets and liabilities | 17.6 | -24.4 | 37.6 |
Noncurrent regulatory and other assets and liabilities | 5.4 | -6.4 | -20.2 |
NET CASH PROVIDED BY OPERATING ACTIVITIES | 153.3 | 112.7 | 146.9 |
INVESTING ACTIVITIES | ' | ' | ' |
Property, plant and equipment | -166.2 | -162.1 | -121.5 |
Cash used in disposition of assets | -3.9 | -2.3 | -2.2 |
Proceeds from disposition of assets | 0.3 | 0.4 | 0.2 |
Affiliated-company property, plant and equipment transfers | 10.8 | 0 | 0.1 |
NET CASH USED IN INVESTING ACTIVITIES | -159 | -164 | -123.4 |
FINANCING ACTIVITIES | ' | ' | ' |
Equity contribution from Questar | 0 | 0 | 20 |
Long-term debt issued, net of issuance costs | 149 | 148.8 | 0 |
Long-term debt repaid | -42 | -91.5 | -2 |
Change in notes payable to Questar | -58.4 | 23.4 | -10.9 |
Dividends paid | -35.5 | -33 | -30.3 |
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES | 13.1 | 47.7 | -23.2 |
Change in cash and cash equivalents | 7.4 | -3.6 | 0.3 |
Beginning cash and cash equivalents | 1.4 | 5 | 4.7 |
Ending cash and cash equivalents | 8.8 | 1.4 | 5 |
Supplemental Disclosure of Cash Paid (Received) During the Year for: | ' | ' | ' |
Interest | 21 | 24.7 | 25.1 |
Income taxes | -13.8 | -20.4 | -3.3 |
Supplemental Disclosure of Noncash Investing and Financing Transaction: | ' | ' | ' |
Noncash reduction in notes payable to Questar due to equity contribution | 90 | ' | ' |
Questar Pipeline [Member] | ' | ' | ' |
OPERATING ACTIVITIES | ' | ' | ' |
Net income | 8.2 | 64.7 | 67.9 |
Adjustments to reconcile net income to net cash provided by operating activities: | ' | ' | ' |
Depreciation and amortization | 58.1 | 56.8 | 53.9 |
Deferred income taxes | -14.3 | 41.1 | 34.5 |
Asset impairment | 80.6 | 0 | 0 |
Share-based compensation | 2 | 2 | 1.8 |
Net (gain) loss from asset sales | 0 | -2.7 | -0.3 |
(Income) from unconsolidated affiliate | -3.7 | -3.7 | -3.8 |
Distributions from unconsolidated affiliate | 4.6 | 4.5 | 4.4 |
Other operating | 0.5 | 0.4 | 0.1 |
Changes in operating assets and liabilities | ' | ' | ' |
Accounts receivable including unbilled gas sales | -8.5 | -2.1 | -0.8 |
Inventories | -0.9 | 0.2 | -0.2 |
Prepaid expenses and other | 3.3 | -3.3 | 0 |
Interest rate hedges - current | 0 | 0 | -37.3 |
Accounts payable and accrued expenses | 0.4 | -3.4 | 0.8 |
Federal income taxes | 2.9 | 0 | 1.1 |
Current regulatory assets and liabilities | 2.1 | -0.9 | -5 |
NET CASH PROVIDED BY OPERATING ACTIVITIES | 135.3 | 153.6 | 117.1 |
INVESTING ACTIVITIES | ' | ' | ' |
Property, plant and equipment | -73.4 | -60.6 | -104.5 |
Cash used in disposition of assets | -1 | -0.7 | -1.3 |
Proceeds from disposition of assets | 0.1 | 4.3 | 0.1 |
Affiliated-company property, plant and equipment transfers | -10.7 | 0 | -0.1 |
NET CASH USED IN INVESTING ACTIVITIES | -85 | -57 | -105.8 |
FINANCING ACTIVITIES | ' | ' | ' |
Long-term debt issued, net of issuance costs | 0 | 0 | 176.2 |
Long-term debt repaid | 0 | 0 | -180 |
Change in notes receivable from Questar | 9.3 | -29.9 | 21.5 |
Dividends paid | -64 | -63 | -30.9 |
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES | -54.7 | -92.9 | -13.2 |
Change in cash and cash equivalents | -4.4 | 3.7 | -1.9 |
Beginning cash and cash equivalents | 7.1 | 3.4 | 5.3 |
Ending cash and cash equivalents | 2.7 | 7.1 | 3.4 |
Supplemental Disclosure of Cash Paid (Received) During the Year for: | ' | ' | ' |
Interest | 25.2 | 25.2 | 24.7 |
Income taxes | $11 | ($3.80) | $2.90 |
Summary_of_Significant_Account
Summary of Significant Accounting Policies (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Accounting Policies [Abstract] | ' | |||||||||||
Summary of Significant Accounting Policies | ' | |||||||||||
Note 1 - Summary of Significant Accounting Policies | ||||||||||||
A. Nature of Business | ||||||||||||
Questar Corporation (Questar or the Company) is a Rockies-based integrated natural gas company with three principal complementary and wholly-owned lines of business: | ||||||||||||
• | Questar Gas Company (Questar Gas) provides retail natural gas distribution in Utah, Wyoming and Idaho. | |||||||||||
• | Wexpro Company (Wexpro) develops and produces natural gas from cost-of-service reserves for Questar Gas customers. | |||||||||||
• | Questar Pipeline Company (Questar Pipeline) operates interstate natural gas pipelines and storage facilities in the western United States and provides other energy services. | |||||||||||
Questar is headquartered in Salt Lake City, Utah. Shares of Questar common stock trade on the New York Stock Exchange (NYSE:STR). | ||||||||||||
B. Principles of Consolidation | ||||||||||||
The Questar and Questar Pipeline consolidated financial statements contain the accounts of the parent companies and their majority-owned or controlled subsidiaries. The consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles (GAAP) and with the instructions for Annual Reports on Form 10-K and SEC Regulations S-X and S-K. All significant intercompany accounts and transactions have been eliminated in consolidation. | ||||||||||||
C. Investment in Unconsolidated Affiliate | ||||||||||||
Questar uses the equity method to account for its investment in an unconsolidated affiliate where it does not have control, but has significant influence. The investment in the unconsolidated affiliate on the Company's Consolidated Balance Sheets equals the Company's proportionate share of equity reported by the unconsolidated affiliate. The investment is assessed for possible impairment when events indicate that the fair value of the investment may be below the Company's carrying value. When such a condition is deemed to be other-than-temporary, the carrying value of the investment is written down to its fair value, and the amount of the write-down is included in the determination of net income. | ||||||||||||
White River Hub, LLC, a limited liability company and FERC-regulated transporter of natural gas, is the sole unconsolidated affiliate. Questar Pipeline owns 50% of White River Hub, LLC, and is the operator. | ||||||||||||
D. Use of Estimates | ||||||||||||
The preparation of financial statements and notes in conformity with GAAP requires that management formulate estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. The Company also incorporates estimates of proved developed and total proved gas and oil reserves in the calculation of depreciation, depletion and amortization rates of its gas and oil properties. Changes in estimated quantities of the Company's reserves could impact its reported financial results as well as disclosures regarding the quantities of proved gas and oil reserves. Actual results could differ from these estimates. | ||||||||||||
E. Revenue Recognition | ||||||||||||
Questar Gas | ||||||||||||
Questar Gas records revenues in the period that gas is delivered, including gas delivered to residential and commercial customers but not billed as of the end of the accounting period. Unbilled gas deliveries are estimated for the period from the date meters are read to the end of the month. Approximately one-half month of revenue is estimated in any period. Gas costs and other variable costs are recorded on the same basis to ensure proper matching of revenues and expenses. Questar Gas's tariff allows for monthly adjustments to customer bills to approximate the effect of abnormal weather on non-gas revenues. The weather-normalization adjustment significantly reduces the impact of weather on gas-distribution earnings. The PSCU and PSCW approved a CET to promote energy conservation. Under the CET, Questar Gas non-gas revenues are decoupled from the volume of gas used by customers. The tariff specifies an allowed revenue per customer for each month with differences to be deferred and recovered from customers or refunded to customers through periodic rate adjustments. Rate adjustments occur every six months under the CET. The adjustments amortize deferred CET amounts over a 12-month period. These adjustments are limited to 5% of non-gas revenues. | ||||||||||||
Questar Gas allows customers the option of paying an estimated fixed monthly bill throughout the year on a budget-billing program. The estimated payments are adjusted to actual usage annually. Amounts collected from customers under this program in excess of gas deliveries are recorded on the Consolidated Balance Sheets as customer advances. The budget-billing option does not impact revenue recognition. Questar Gas may collect revenues subject to possible refunds and establish reserves pending final orders from regulatory agencies. | ||||||||||||
Wexpro | ||||||||||||
Wexpro recognizes revenues in the period that services are provided or products are delivered. Wexpro recovers its costs and receives an unlevered, after-tax return of approximately 20% on its investment base. In accordance with the Wexpro Agreement, production from the gas properties operated by Wexpro is delivered to Questar Gas at Wexpro's cost of providing this service including a return on Wexpro's investment. Wexpro sells crude oil and NGL production from certain producing properties at market prices with the revenues used to recover operating expenses and to provide Wexpro a return on its investment. Any operating income remaining after recovery of expenses and Wexpro's return on investment is divided between Questar Gas and Wexpro, with Wexpro retaining 46%. Amounts received by Questar Gas from the sharing of Wexpro's oil and NGL income are used to reduce natural gas costs to utility customers. | ||||||||||||
Wexpro's investment base consists of its investment in commercial wells and related facilities and is adjusted for working capital and reduced for deferred income taxes and accumulated depreciation, depletion and amortization. Revenue associated with the sale of gas, oil and NGL is accounted for using the sales method, whereby revenue is recognized as gas, oil and NGL are sold to purchasers. Wexpro may collect revenues subject to possible refunds and establish reserves pending final calculation of the after-tax return on investment, which is adjusted annually. | ||||||||||||
Questar Pipeline | ||||||||||||
Questar Pipeline and subsidiaries recognize revenues in the period that services are provided or products are delivered. The straight-fixed-variable rate design used by Questar Pipeline, which allows for recovery of substantially all fixed costs in the demand or reservation charge, reduces the earnings impact of volume changes on gas transportation and storage operations. Questar Pipeline may collect revenues subject to possible refunds and establish reserves pending final orders from regulatory agencies. | ||||||||||||
F. Cost of Sales | ||||||||||||
Questar Gas obtains the majority of its gas supply from Wexpro's cost-of-service production and pays Wexpro an operator service fee based on the terms of the Wexpro Agreement. Questar Gas also obtains transportation and storage services from Questar Pipeline. These intercompany revenues and expenses are eliminated in the Questar Consolidated Statements of Income by reducing revenues and cost of sales. The underlying costs of Wexpro's production and Questar Pipeline's transportation and storage services are disclosed in other categories in the Consolidated Statements of Income, including operating and maintenance expense and depreciation, depletion and amortization expense. During the second and third quarters of the year, a significant portion of the natural gas from Wexpro production is injected into underground storage. This gas is withdrawn from storage as needed during the heating season in the first and fourth quarters. The cost of natural gas sold is credited with the value of natural gas as it is injected into storage and debited as it is withdrawn from storage. The reported balance in consolidated cost of sales may be a negative amount during the second and third quarters because of the entries to record injection of gas into storage and the elimination of intercompany transactions. | ||||||||||||
The details of Questar's consolidated cost of sales are as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Questar Gas | ||||||||||||
Gas purchases | $ | 186.6 | $ | 104.2 | $ | 221.2 | ||||||
Operator service fee | 294.6 | 274 | 253.4 | |||||||||
Transportation and storage | 80.1 | 79.6 | 78.4 | |||||||||
Gathering | 18.8 | 20.5 | 25 | |||||||||
Royalties | 44.3 | 32 | 38.9 | |||||||||
Storage (injection) withdrawal, net | (0.8 | ) | 1.9 | 3 | ||||||||
Purchased-gas account adjustment | 22 | 16.1 | 20.6 | |||||||||
Other | 5 | 5 | 5.2 | |||||||||
Total Questar Gas cost of natural gas sold | 650.6 | 533.3 | 645.7 | |||||||||
Elimination of Questar Gas cost of natural gas sold - affiliated parties | (370.9 | ) | (347.7 | ) | (327.3 | ) | ||||||
Total Questar Gas cost of natural gas sold - unaffiliated parties | 279.7 | 185.6 | 318.4 | |||||||||
Questar Pipeline | ||||||||||||
Total Questar Pipeline cost of sales | 6.1 | 6.7 | 3.1 | |||||||||
Other cost of sales | 0.1 | — | — | |||||||||
Total cost of sales | $ | 285.9 | $ | 192.3 | $ | 321.5 | ||||||
G. Regulation | ||||||||||||
The Company applies the regulatory accounting principles to the rate-regulated businesses. Under these principles, the Company records regulatory assets and liabilities that would not be otherwise recorded under GAAP for non-rate-regulated entities. Regulatory assets and liabilities record probable future revenues or expenses associated with certain charges or credits that will be recovered from or refunded to customers through the rate-making process. | ||||||||||||
Questar Gas accounts for purchased-gas costs in accordance with procedures authorized by the PSCU and the PSCW. Purchased-gas costs that are different from those provided for in present rates are accumulated and recovered or credited through future rate changes. Questar Gas may hedge a portion of its natural gas supply to mitigate price fluctuations for gas-distribution customers. The regulatory commissions allow Questar Gas to record periodic mark-to-market adjustments for commodity-price derivatives in the purchased-gas adjustment account. Questar did not have any commodity-price derivatives at December 31, 2013 or 2012. See Note 11 for a description and comparison of regulatory assets and liabilities as of December 31, 2013 and 2012. | ||||||||||||
Wexpro manages and produces cost-of-service reserves for gas utility affiliate Questar Gas under the terms of the Wexpro Agreement, a long-standing comprehensive agreement with the states of Utah and Wyoming (see Note 10). | ||||||||||||
Questar Pipeline is regulated by the FERC. Questar Gas is regulated by the PSCU and the PSCW. The Idaho Public Utilities Commission has contracted with the PSCU for rate oversight of Questar Gas operations in a small area of southeastern Idaho. These regulatory agencies establish rates for the storage, transportation and sale of natural gas. The regulatory agencies also regulate, among other things, the extension and enlargement or abandonment of jurisdictional natural gas facilities. Regulation is intended to permit the recovery, through rates, of the cost of service, including a return on investment. | ||||||||||||
H. Cash and Cash Equivalents | ||||||||||||
Cash equivalents consist principally of repurchase agreements with maturities of three months or less. In almost all cases, the repurchase agreements are highly liquid investments in overnight securities made through commercial bank accounts that result in available funds the next business day. | ||||||||||||
I. Notes Receivable from and Notes Payable to Questar | ||||||||||||
Notes receivable from or payable to Questar appearing in the financial statements and disclosures of Questar Gas and Questar Pipeline represent interest bearing demand notes for cash loaned to or borrowed from Questar until needed in operations. The funds are centrally managed by Questar. Amounts loaned to Questar earn an interest rate that is identical to the interest rate paid by the companies for borrowings from Questar. | ||||||||||||
J. Property, Plant and Equipment | ||||||||||||
Property, plant and equipment balances are stated at historical cost. Maintenance and repair costs are expensed as incurred. | ||||||||||||
Cost-of-service gas and oil operations | ||||||||||||
The successful efforts method of accounting is used for cost-of-service reserves developed and produced by Wexpro for gas utility affiliate Questar Gas. Cost-of-service reserves are properties for which the operations and return on investment are subject to the Wexpro Agreement (see Note 10). Under the successful efforts method, Wexpro capitalizes the costs of acquiring leaseholds, drilling development wells, drilling successful exploratory wells, and purchasing related support equipment and facilities. Geological and geophysical studies and other exploratory activities are expensed as incurred. Costs of production and general corporate activities are expensed in the period incurred. A gain or loss is generally recognized on assets as they are retired from service. | ||||||||||||
Contributions in aid of construction | ||||||||||||
Customer contributions in aid of construction reduce plant unless the amounts are refundable to customers. Contributions for main-line extensions may be refundable to customers if additional customers connect to the main-line segment within five years. Refundable contributions are recorded as liabilities until refunded or the five-year period expires without additional customer connections. Amounts not refunded reduce plant. Capital expenditures in the Consolidated Statements of Cash Flows are reported net of non-refundable contributions. | ||||||||||||
Depreciation, depletion and amortization | ||||||||||||
Major categories of fixed assets in gas distribution, transportation and storage operations are grouped together and depreciated using a straight-line method. Gains and losses on asset disposals are recorded as adjustments in accumulated depreciation. The Company has not capitalized future abandonment costs on a majority of its long-lived gas distribution and transportation assets due to a lack of a legal obligation to restore the area surrounding abandoned assets. In these cases, the regulatory agencies have opted to leave retired facilities in the ground undisturbed rather than excavate and dispose of the assets. Depreciation rates for Questar Gas and Questar Pipeline are established through rate proceedings. | ||||||||||||
Capitalized costs of development wells and leaseholds are amortized on a field-by-field basis using the unit-of-production method and the estimated proved developed or total proved gas and oil reserves. Oil and NGL volumes are converted to natural gas equivalents using the ratio of one barrel of crude oil, condensate or NGL to 6,000 cubic feet of natural gas. The Company capitalizes an estimate of the fair value of future abandonment costs associated with cost-of-service reserves and depreciates these costs using a unit-of-production method. | ||||||||||||
The following represent average depreciation, depletion and amortization rates of the Company's capitalized costs: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Questar Gas distribution plant | 2.7 | % | 2.8 | % | 2.8 | % | ||||||
Cost-of-service gas and oil properties, per Mcfe | $ | 1.56 | $ | 1.49 | $ | 1.49 | ||||||
Questar Pipeline transportation, storage and other energy services | 3.4 | % | 3.4 | % | 3.5 | % | ||||||
Questar Gas's depreciation rates include a component for the cost of plant removal. Accordingly, Questar Gas recognizes cost of plant removal as depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of plant removal accrual. | ||||||||||||
K. Impairment of Long-Lived Assets | ||||||||||||
Proved gas and oil properties are evaluated on a field-by-field basis for potential impairment. Other properties are evaluated on a specific-asset basis or in groups of similar assets, as applicable. Impairment is indicated when a triggering event occurs and the sum of the estimated undiscounted future net cash flows of an evaluated asset is less than the asset's carrying value. Triggering events could include, but are not limited to, an impairment of gas and oil reserves caused by mechanical problems, faster-than-expected decline of reserves, lease-ownership issues, other-than-temporary decline in gas and oil prices, and changes in the utilization of pipeline assets. If impairment is indicated, fair value is estimated using a discounted cash flow approach using market interest rates or, if available, other market data. Cash flow estimates require forecasts and assumptions for many years into the future for a variety of factors, including commodity prices, commodity transportation rates and operating costs. Questar Pipeline recorded an $80.6 million pre-tax impairment of the eastern segment of its Southern Trails Pipeline in the third quarter of 2013. See Note 16 for additional details. There were no impairments in 2012 or 2011. | ||||||||||||
L. Goodwill and Other Intangible Assets | ||||||||||||
Goodwill represents the excess of the amount paid over the fair value of net assets acquired in a business combination and is not subject to amortization. Goodwill and indefinite-lived intangible assets are tested for impairment at a minimum of once a year or when a triggering event occurs. The Company evaluates whether it is more likely than not that the carrying value of a reporting unit is greater than its fair value using events and circumstances such as economic conditions, industry changes, financial performance, etc. Fair value is measured using actively traded market values of other comparable companies in the same businesses. If the fair value of the reporting unit exceeds its carrying value then goodwill is considered not to be impaired. If the carrying value of the business unit is greater than the fair value, an impairment of goodwill is recognized equal to the excess of carrying amount of goodwill over its fair value. | ||||||||||||
M. Capitalized Interest and Allowance for Funds Used During Construction | ||||||||||||
The Company capitalizes interest costs when applicable. The FERC, PSCU and PSCW require the capitalization of an allowance for funds used during construction (AFUDC) for rate-regulated plant and equipment. The Wexpro Agreement requires capitalization of AFUDC on cost-of-service gas and oil development projects. Amounts recorded in the Consolidated Statements of Income for the capitalization of AFUDC and interest costs are disclosed in the table below: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
AFUDC (recorded as an increase in interest and other income) | ||||||||||||
Wexpro | $ | 4.6 | $ | 2.1 | $ | 3.3 | ||||||
Questar Pipeline | 1.7 | 0.2 | 1.1 | |||||||||
Total AFUDC | $ | 6.3 | $ | 2.3 | $ | 4.4 | ||||||
Capitalized interest costs (recorded as a reduction of interest expense) | ||||||||||||
Questar Gas | $ | 0.2 | $ | 0.1 | $ | 0.1 | ||||||
Questar Pipeline | 0.6 | 0.1 | 0.5 | |||||||||
Total capitalized interest costs | $ | 0.8 | $ | 0.2 | $ | 0.6 | ||||||
N. Derivative Instruments and Hedging Activities | ||||||||||||
The Company may elect to designate a derivative instrument as a hedge of exposure to changes in fair value or cash flows. A derivative instrument qualifies as a hedge if all of the following tests are met: | ||||||||||||
• | The item to be hedged exposes the Company to market risk. | |||||||||||
• | The derivative reduces the risk exposure and is designated as a hedge at the inception of the hedging relationship. | |||||||||||
• | At the inception of the hedge and throughout the hedge period, there is a high correlation between changes in the fair value of the derivative instrument and the fair value of the underlying hedged item. | |||||||||||
If the hedged exposure is a fair value exposure, the gain or loss on the derivative instrument is recognized in earnings in the period of the change together with the offsetting gain or loss from the change in fair value of the hedged item. If the hedged exposure is a cash flow exposure, the effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) (AOCI) and subsequently reclassified into earnings when the forecasted transaction affects earnings. Any amount excluded from the assessment of hedge effectiveness, as well as the ineffective portion of the gain or loss, is reported currently in earnings. When a derivative instrument is designated as a cash flow hedge of a forecasted transaction that becomes probable of not occurring, the gain or loss on the derivative is immediately reclassified into earnings from AOCI. See Note 6 for further discussion on derivatives and hedging. | ||||||||||||
O. Credit Risk | ||||||||||||
The Rocky Mountain region is the Company's primary market area. Exposure to credit risk may be affected by the concentration of customers in this region due to changes in economic or other conditions. Customers include individuals and numerous commercial and industrial enterprises that may react differently to changing conditions. Management believes that its credit-review procedures, loss reserves, customer deposits and collection procedures have adequately provided for usual and customary credit-related losses. Loss reserves are periodically reviewed for adequacy and may be established on a specific-case basis. | ||||||||||||
Bad debt expense associated with accounts receivable amounted to $0.2 million in 2013, $1.2 million in 2012 and $2.4 million in 2011. The allowance for bad debts was $1.7 million at December 31, 2013 and $3.1 million at December 31, 2012. Questar Gas's retail gas operations account for a majority of the bad debt expense. Questar Gas estimates bad debt expense as a percentage of general-service revenues with periodic adjustments. Uncollected accounts are generally written off six months after gas is delivered and interest is no longer accrued. Questar Gas recovers bad debt costs related to the gas-cost portion of rates in its Utah operations through a purchased-gas adjustment to rates. | ||||||||||||
P. Asset Retirement Obligations | ||||||||||||
Questar records an asset retirement obligation (ARO) when there is a legal obligation associated with the retirement of a tangible long-lived asset. Questar's AROs apply primarily to abandonment costs associated with gas and oil wells, production facilities and certain other properties. The Company has not capitalized future abandonment costs on a majority of its long-lived transportation and distribution assets because the Company does not have a legal obligation to restore the area surrounding abandoned assets. In these cases, the regulatory agencies have opted to leave retired facilities in the ground undisturbed rather than requiring the Company to excavate and dispose of the assets. Cost-of-service gas and oil AROs apply primarily to abandonment costs associated with gas and oil wells and certain other properties. The fair value of retirement costs is estimated by Company personnel based on abandonment costs of similar properties available to field operations and depreciated over the life of the related assets. Revisions to estimates result from material changes in the expected timing or amount of cash flows associated with AROs. Income or expense resulting from the settlement of ARO liabilities is included in net gain (loss) from asset sales on the Consolidated Statements of Income. The ARO liability is adjusted to present value each period through an accretion calculation using a credit-adjusted risk-free interest rate. See Note 4 for further discussion on AROs. | ||||||||||||
Q. Income Taxes | ||||||||||||
Questar and its subsidiaries file a consolidated federal income tax return. Questar Gas and Questar Pipeline account for income taxes on a separate return basis and record tax expenses and benefits as they are generated. Questar Gas and Questar Pipeline make payments to Questar or receive payments from Questar for such tax expenses or benefits as they are generated on the consolidated income tax return. Deferred income taxes are recorded for the temporary differences arising between the book and tax carrying amounts of assets and liabilities. These differences create taxable or tax-deductible amounts for future periods. Questar Gas and Questar Pipeline use the deferral method to account for investment tax credits as required by regulatory commissions. The Company records interest earned on income tax refunds in interest and other income and records penalties and interest charged on tax deficiencies in interest expense. | ||||||||||||
Accounting standards for income taxes specify the accounting for uncertainty in income taxes by prescribing a minimum recognition threshold for a tax position to be reflected in the financial statements. If recognized, the tax benefit is measured as the largest amount of tax benefit that is more-likely-than-not to be realized upon ultimate settlement. Management has considered the amounts and the probabilities of the outcomes that could be realized upon ultimate settlement and believes that it is more-likely-than-not that the Company's recorded income tax benefits will be fully realized. There were no unrecognized tax benefits at the beginning or at the end of the years ended December 31, 2013, 2012 or 2011. The federal income tax return for 2012 is under examination by the Internal Revenue Service (IRS). The 2013 federal income tax return has not been filed. | ||||||||||||
For tax year 2012, Questar was in the IRS's Compliance Assurance Process (CAP). For the 2013 and 2014 tax years, Questar was accepted into the CAP Maintenance program. The CAP employs real-time resolution to improve federal tax compliance by resolving all or most tax positions prior to filing the related tax return. Successful conclusion of the CAP allows the IRS to achieve an acceptable level of assurance regarding the accuracy of the taxpayer's filed tax return and to eliminate or substantially reduce the need for a traditional examination. The CAP Maintenance program is administered by the IRS and indicates that the Company is a compliant taxpayer. | ||||||||||||
Current federal tax statutes allow taxpayers a deduction of bonus depreciation related to capital expenditures of 100% in 2011 and 50% in 2012 and 2013. The effects of bonus depreciation and other significant book/tax timing differences resulted in a net operating loss (NOL) carryforward for federal income tax purposes in 2012 of $30.0 million. Questar's estimated taxable income for 2013 is $153.8 million. The NOL carryforward from 2012 of $30.0 million is expected to be utilized on the 2013 federal income tax return. See Note 8 for further discussion on income taxes. | ||||||||||||
R. Earnings Per Share | ||||||||||||
Basic earnings per share (EPS) is computed by dividing net income by the weighted-average number of common shares outstanding during the reporting period, which includes vested undistributed restricted stock units (RSUs). Diluted EPS includes the potential increase in the number of outstanding shares that could result from the exercise of in-the-money stock options, the vesting of RSUs with forfeitable dividends and the distribution of performance shares that are part of the Company's Long-term Stock Incentive Plan (LTSIP), less shares repurchased under the treasury stock method. See Note 2 for further discussion on EPS. | ||||||||||||
S. Share-Based Compensation | ||||||||||||
Questar may issue stock options, restricted shares, RSUs and performance shares to certain officers, employees and non-employee directors under its LTSIP. The Company uses the Black-Scholes-Merton mathematical model in estimating the fair value of stock options and the Monte Carlo simulation method in estimating the fair value of performance shares for accounting purposes. The granting of restricted shares and RSUs results in recognition of compensation cost measured at the grant-date market price. Questar uses an accelerated method in recognizing share-based compensation costs with graded vesting periods. See Note 12 for further discussion on share-based compensation. | ||||||||||||
T. Comprehensive Income | ||||||||||||
Beginning in 2012, the Company and its subsidiaries adopted accounting guidance issued in June 2011 that resulted in the addition of statements of comprehensive income to the primary financial statements. Beginning in 2013, the Company and its subsidiaries adopted accounting guidance issued in February 2013 that requires additional disclosures about reclassifications out of AOCI. | ||||||||||||
Comprehensive income, as reported on Questar's Consolidated Statements of Comprehensive Income, is the sum of net income as reported on the Questar Consolidated Statements of Income and net other comprehensive income (loss) (OCI) as reported on the Questar Consolidated Statements of Common Shareholders' Equity. OCI includes recognition of the under-funded position of pension and other postretirement benefit plans, interest rate cash flow hedges, changes in the fair value of long-term investment, and the related income taxes. Income or loss is recognized when the pension or other postretirement benefit (OPRB) costs are accrued, as the Company records interest expense for hedged interest payments and when the long-term investment is sold or otherwise realized. | ||||||||||||
Comprehensive income, as reported on Questar Pipeline's Consolidated Statements of Comprehensive Income, is the sum of net income as reported on the Questar Pipeline Consolidated Statements of Income and net OCI as reported on the Questar Pipeline Consolidated Statements of Common Shareholder's Equity. OCI includes interest rate cash flow hedges and the related income taxes. Income or loss is recognized as the company records interest expense for hedged interest payments. See Note 3 for additional information related to OCI and AOCI. | ||||||||||||
U. Business Segments | ||||||||||||
Line of business information is presented according to senior management's basis for evaluating performance considering differences in the nature of products, services and regulation, among other factors. Certain intersegment sales include intercompany profit. | ||||||||||||
V. Reclassifications | ||||||||||||
Certain reclassifications were made to prior year financial statements and notes to conform to the 2013 presentation. Questar and Questar Gas reclassified amounts received from customers for the cost of plant removal from accumulated depreciation to a regulatory liability for prior years. This reclassification did not impact net income or cash flows. The Company does not believe this change is material to prior year financial statements. | ||||||||||||
All dollar amounts in this Annual Report on Form 10-K are in millions, except per-share information and where otherwise noted. |
Earnings_Per_Share_Notes
Earnings Per Share (Notes) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Earnings Per Share [Abstract] | ' | ||||||||
Earnings Per Share | ' | ||||||||
Note 2 - Earnings Per Share | |||||||||
Earnings Per Share | |||||||||
Basic EPS is computed by dividing net income by the weighted-average number of common shares outstanding during the reporting period, which includes vested undistributed RSUs. Diluted EPS includes the potential increase in the number of outstanding shares that could result from the exercise of in-the-money stock options, the vesting of RSUs with forfeitable dividends and the distribution of performance shares that are part of the Company's LTSIP, less shares repurchased under the treasury stock method. Restricted shares and RSUs with nonforfeitable dividends are participating securities for the computation of basic earnings per share. The application of the two-class method had an insignificant impact on the calculation of both basic and diluted EPS. | |||||||||
A reconciliation of the components of basic and diluted shares used in the EPS calculation follows: | |||||||||
Year Ended December 31, | |||||||||
2013 | 2012 | 2011 | |||||||
(in millions) | |||||||||
Weighted-average basic common shares outstanding | 175.4 | 176.5 | 177.4 | ||||||
Potential number of shares issuable under the Company's LTSIP | 0.6 | 1 | 1.4 | ||||||
Weighted-average diluted common shares outstanding | 176 | 177.5 | 178.8 | ||||||
In the past three years, Questar had the ability to issue shares under the terms of the Dividend Reinvestment and Stock Purchase Plan, Employee Investment Plan (see Note 13) and LTSIP. | |||||||||
Dividend Reinvestment and Stock Purchase Plan | |||||||||
The Dividend Reinvestment and Stock Purchase Plan allows shareholders to reinvest dividends or invest additional funds in Questar common stock. The Company can issue new shares or buy shares in the open market to meet shareholders' purchase requests. The Company bought shares in the open market to satisfy shareholders' purchases in 2013 and 2012 and no shares were issued. The Company issued 4,400 shares in 2011 and relied on open market purchases to supplement Company-issued shares. At December 31, 2013, there were 20,210,415 shares reserved and authorized for future issuance. | |||||||||
Long-Term Stock Incentive Plan | |||||||||
Questar may issue stock options, restricted shares and RSUs to certain officers, directors and employees under its LTSIP. Stock options for participants have terms ranging from five to ten years with a majority issued with a seven- to ten-year term. Options generally vest in three or four equal, annual installments. Restricted shares and RSUs vest in equal installments over a specified number of years after the grant date with the majority vesting in three years. Unvested restricted shares have voting and dividend rights; however, sale or transfer is restricted. RSUs do not have voting rights until shares are distributed, but they do have dividend equivalent rights. Most RSU dividend equivalents are paid in cash quarterly and vest immediately. Dividend equivalents on certain RSUs with deferred share distributions accrue quarterly and are subject to the same vesting, distribution and voting conditions of the underlying award. | |||||||||
Questar grants performance shares to Company officers under the terms of the LTSIP. The awards are designed to motivate and reward these officers for long-term Company performance and provide an incentive for them to remain with the Company. The target number of performance shares for each officer is subject to adjustment upward or downward based on the Company's total shareholder return relative to a specified peer group of companies over a three-year performance period. Each three-year performance period commences at the beginning of the year of grant. Distributions of performance shares, if any, take place in the quarter following the conclusion of the performance period so long as such officer was employed by the Company or its affiliates as of the last day of the performance period. For a summary of LTSIP transactions, see Note 12. |
Other_Comprehensive_Income_Not
Other Comprehensive Income (Notes) | 12 Months Ended | |||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||
Other Comprehensive Income [Abstract] | ' | |||||||||||||||||||||||||||
Other Comprehensive Income | ' | |||||||||||||||||||||||||||
Note 3 - Other Comprehensive Income | ||||||||||||||||||||||||||||
Details of the changes in the components of AOCI, net of income taxes, as reported in Questar's Consolidated Balance Sheets, are shown in the table below. The table also discloses details of income taxes related to each component of OCI: | ||||||||||||||||||||||||||||
Pension | OPRB | Interest rate cash flow hedges | Long-term invest. | Total | ||||||||||||||||||||||||
Actuarial loss | Prior service cost | Total | Actuarial loss | |||||||||||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||||||
AOCI at beginning of year | $ | (202.4 | ) | $ | (1.1 | ) | $ | (203.5 | ) | $ | (19.7 | ) | $ | (23.2 | ) | $ | 0.1 | $ | (246.3 | ) | ||||||||
OCI before reclassifications | 123.4 | — | 123.4 | 12.4 | — | (0.1 | ) | 135.7 | ||||||||||||||||||||
Reclassified from AOCI(1) | 28.9 | 1.1 | 30 | 3 | 0.5 | — | 33.5 | |||||||||||||||||||||
Income taxes | ||||||||||||||||||||||||||||
OCI before reclassifications | (47.2 | ) | — | (47.2 | ) | (4.7 | ) | — | 0.1 | (51.8 | ) | |||||||||||||||||
Reclassified from AOCI(2) | (11.1 | ) | (0.4 | ) | (11.5 | ) | (1.2 | ) | (0.2 | ) | — | (12.9 | ) | |||||||||||||||
Total income taxes | (58.3 | ) | (0.4 | ) | (58.7 | ) | (5.9 | ) | (0.2 | ) | 0.1 | (64.7 | ) | |||||||||||||||
Net other comprehensive income | 94 | 0.7 | 94.7 | 9.5 | 0.3 | — | 104.5 | |||||||||||||||||||||
AOCI at end of year | $ | (108.4 | ) | $ | (0.4 | ) | $ | (108.8 | ) | $ | (10.2 | ) | $ | (22.9 | ) | $ | 0.1 | $ | (141.8 | ) | ||||||||
(1) Interest rate cash flow hedge amounts are included in their entirety as charges to interest expense on the Consolidated Statements of Income. | ||||||||||||||||||||||||||||
(2) Interest rate cash flow hedge amounts are included in their entirety as credits to income taxes on the Consolidated Statements of Income. | ||||||||||||||||||||||||||||
Pension and other postretirement benefit AOCI reclassifications are included in the computation of net periodic pension and postretirement benefit costs. See Note 13 for additional details. | ||||||||||||||||||||||||||||
For years not disclosed in the above table, income taxes allocated to each component of Questar's consolidated OCI are shown below. Expenses are in parentheses. | ||||||||||||||||||||||||||||
Year Ended December 31, | ||||||||||||||||||||||||||||
2012 | 2011 | |||||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||||||
Change in unrecognized actuarial loss | $ | 13.6 | $ | 62.3 | ||||||||||||||||||||||||
Change in unrecognized prior service cost | (1.0 | ) | (1.1 | ) | ||||||||||||||||||||||||
Interest rate cash flow hedges | (0.2 | ) | 13.8 | |||||||||||||||||||||||||
Change in fair value of long-term investment | (0.1 | ) | — | |||||||||||||||||||||||||
Income taxes | $ | 12.3 | $ | 75 | ||||||||||||||||||||||||
Disclosures regarding interest rate cash flow hedges, including income taxes and income statement reclassification effects, apply to Questar Pipeline. There were no significant changes in Questar Pipeline AOCI during 2012. |
Asset_Retirement_Obligations_N
Asset Retirement Obligations (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Asset Retirement Obligation [Abstract] | ' | |||||||
Asset Retirement Obligation Disclosure | ' | |||||||
Note 4 - Asset Retirement Obligations | ||||||||
Changes in Questar's AROs from the Consolidated Balance Sheets were as follows: | ||||||||
Year Ended December 31, | ||||||||
2013 | 2012 | |||||||
(in millions) | ||||||||
AROs at beginning of year | $ | 67.2 | $ | 63.8 | ||||
Accretion | 3.3 | 3.4 | ||||||
Liabilities incurred | 6 | 3.1 | ||||||
Revisions in estimated cash flows | (6.9 | ) | (1.7 | ) | ||||
Liabilities settled | (1.9 | ) | (1.4 | ) | ||||
AROs at end of year | $ | 67.7 | $ | 67.2 | ||||
Questar's consolidated AROs by line of business are summarized in the table below: | ||||||||
December 31, | ||||||||
2013 | 2012 | |||||||
(in millions) | ||||||||
Questar Gas | $ | 0.6 | $ | 0.5 | ||||
Wexpro | 64.9 | 64.6 | ||||||
Questar Pipeline | 2.2 | 2.1 | ||||||
Total | $ | 67.7 | $ | 67.2 | ||||
Wexpro collects from Questar Gas and deposits in trust certain funds related to estimated ARO costs. The funds are recorded as other noncurrent assets on the Consolidated Balance Sheets and are used to satisfy retirement obligations as the properties are abandoned. The accounting treatment of reclamation activities associated with AROs for properties administered under the Wexpro Agreement is defined in a guideline letter between Wexpro and the Utah Division of Public Utilities and the staff of the PSCW. |
Fair_Value_Measurements_Notes
Fair Value Measurements (Notes) | 12 Months Ended | ||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||
Fair Value Disclosures [Abstract] | ' | ||||||||||||||||
Fair Value Measurements | ' | ||||||||||||||||
Note 5 - Fair Value Measurements | |||||||||||||||||
Questar complies with the accounting standards for fair value measurements and disclosures. These standards define fair value in applying GAAP, establish a framework for measuring fair value and expand disclosures about fair value measurements. The standards establish a fair value hierarchy. Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Company has the ability to access at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. The Company had no assets or liabilities measured using Level 3 inputs at December 31, 2013 or 2012. Fair value accounting standards also apply to certain nonfinancial assets and liabilities that are measured at fair value on a nonrecurring basis. | |||||||||||||||||
Beginning in 2012, Questar adopted fair value accounting guidance issued in May 2011. The guidance did not result in any changes to the reported amounts of assets or liabilities, but did result in disclosure of the fair value hierarchy levels associated with fair value estimates for financial assets and liabilities not carried at fair value. | |||||||||||||||||
Questar primarily applies the market approach for recurring fair value measurements and maximizes its use of observable inputs and minimizes its use of unobservable inputs. Questar considers bid and ask prices for valuing the majority of its assets and liabilities measured and reported at fair value. In addition to using market data, Questar makes assumptions in valuing its assets and liabilities, including assumptions about risk and the risks inherent in the inputs to the valuation technique. | |||||||||||||||||
Questar | |||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar's financial statements in this Annual Report on Form 10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 16 | $ | 16 | $ | 16.8 | $ | 16.8 | ||||||||
Long-term investment | 1 | 17.3 | 17.3 | 15.5 | 15.5 | ||||||||||||
Financial liabilities | |||||||||||||||||
Short-term debt | 1 | 276 | 276 | 263 | 263 | ||||||||||||
Long-term debt, including current portion | 2 | 1,247.10 | 1,310.80 | 1,140.90 | 1,303.10 | ||||||||||||
The carrying amounts of cash and cash equivalents and short-term debt approximate fair value. The long-term investment is recorded at fair value and consists of money market and short-term bond index mutual funds representing funds held in Wexpro's trust (see Note 4). The fair value of the long-term investment is based on quoted prices for the underlying funds. The fair value of fixed-rate long-term debt is based on the discounted present value of cash flows using the Company's current credit risk-adjusted borrowing rates. | |||||||||||||||||
Questar Gas | |||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar Gas's financial statements in this Annual Report on Form 10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 8.8 | $ | 8.8 | $ | 1.4 | $ | 1.4 | ||||||||
Financial liabilities | |||||||||||||||||
Notes payable to Questar | 1 | 17.7 | 17.7 | 166.1 | 166.1 | ||||||||||||
Long-term debt, including current portion | 2 | 534.5 | 568 | 426.5 | 503.7 | ||||||||||||
The carrying amounts of cash and cash equivalents and notes payable to Questar approximate fair value. The fair value of fixed-rate long-term debt is based on the discounted present value of cash flows using Questar Gas's current credit risk-adjusted borrowing rates. | |||||||||||||||||
Questar Pipeline | |||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar Pipeline's financial statements in this Annual Report on Form | |||||||||||||||||
10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 2.7 | $ | 2.7 | $ | 7.1 | $ | 7.1 | ||||||||
Notes receivable from Questar | 1 | 29.4 | 29.4 | 38.7 | 38.7 | ||||||||||||
Financial liabilities | |||||||||||||||||
Long-term debt | 2 | 458.9 | 486 | 458.9 | 536.6 | ||||||||||||
The carrying amounts of cash and cash equivalents and notes receivable from Questar approximate fair value. The fair value of fixed-rate long-term debt is based on the discounted present value of cash flows using Questar Pipeline's current credit risk-adjusted borrowing rates. | |||||||||||||||||
The Questar and Questar Pipeline Condensed Consolidated Balance Sheets included a nonrecurring fair value measurement at September 30, 2013 related to the impairment of the eastern segment of Questar Southern Trails Pipeline. The asset's fair value of zero was based on inputs that indicated overall negative future net cash flows. Questar Pipeline used a probability-weighted discounted cash flow analysis that included significant inputs such as Questar Pipeline's cost of capital and assumptions regarding future transportation rates and operating costs. This was a Level 3 fair value measurement because the inputs were unobservable. Based on this analysis, Questar Pipeline determined that the asset was impaired. See Note 16 for additional information. Questar did not have any assets or liabilities measured at fair value on a nonrecurring basis at December 31, 2013 or 2012. |
Derivative_Instruments_and_Hed
Derivative Instruments and Hedging Activities (Notes) | 12 Months Ended | ||||||||||||
Dec. 31, 2013 | |||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ' | ||||||||||||
Derivative Instruments and Hedging Activities | ' | ||||||||||||
Note 6 - Derivative Instruments and Hedging Activities | |||||||||||||
Questar and its subsidiaries may enter into derivative instruments to manage exposure to changes in current and future market interest rates. In order to mitigate its exposure to changes in the fair value of its fixed-rate corporate debt resulting from changes in benchmark interest rates, in the second quarter of 2011 Questar executed a fixed-to-floating interest rate swap transaction with a counterparty and converted $125.0 million of its 2.75% fixed-rate long-term debt to floating-rate debt. The 2.75% rate was swapped for a London Interbank Offered Rate (LIBOR)-based floating rate. Questar terminated and settled this hedge transaction in March 2012, for a deferred gain of $7.2 million, which is being amortized to interest expense through the maturity of the notes in 2016. Prior to its termination, this swap was accounted for as a fair value hedge under the accounting standards for derivatives and hedging. | |||||||||||||
Questar Pipeline entered into forward starting swaps totaling $150.0 million in the second and third quarters of 2011 in anticipation of issuing $180.0 million of notes in December 2011. Settlement of these swaps required payments of $37.3 million because of declines in interest rates. These swaps qualified as cash flow hedges and the settlement payments are being amortized to interest expense over the 30-year life of the debt. | |||||||||||||
Interest rate swaps and forward starting interest rate swaps are settled in cash on periodic payment dates with one party paying the other for the net difference between the fixed and floating interest rate for the payment period as specified in the swap agreement, multiplied by the notional amount. Forward starting interest rate swaps used as cash flow hedges of forecasted fixed-rate debt issuances are terminated and settled in cash when the forecasted debt is issued or as the swaps expire, with one party paying the other for the swap's net fair value at the time of settlement. Questar reports cash flows related to derivative instruments qualifying and designated as hedges in the Consolidated Statements of Cash Flows based upon the nature of the hedged items. | |||||||||||||
The table below presents the pre-tax effects of the derivative instruments designated as a fair value hedge (including the hedged item) and cash flow hedges on the Consolidated Statements of Income. The table also shows the pre-tax effects of the derivative instruments designated as cash flow hedges on OCI: | |||||||||||||
Financial Statement Location of Gain (Loss) | Year Ended December 31, | ||||||||||||
Instrument and Activity | 2013 | 2012 | 2011 | ||||||||||
(in millions) | |||||||||||||
Fair Value Hedge | |||||||||||||
Questar Corporation | |||||||||||||
Interest rate derivative instrument | |||||||||||||
Realized and unrealized gain | Interest expense | $ | — | $ | — | $ | 9.8 | ||||||
2.75% Notes due 2016 | |||||||||||||
Unrealized loss | Interest expense | — | — | (9.8 | ) | ||||||||
Cash Flow Hedges | |||||||||||||
Questar Pipeline | |||||||||||||
Interest rate derivative instruments | |||||||||||||
Deferrals of effective portions | OCI | $ | — | $ | — | $ | (37.3 | ) | |||||
Losses reclassified from AOCI into earnings for effective portions | Interest expense | (0.5 | ) | (0.4 | ) | (0.1 | ) | ||||||
There was no ineffectiveness recognized on the fair value hedge in 2013, 2012 or 2011. There was no ineffectiveness recognized on the cash flow hedges in 2013 or 2012. Ineffectiveness recognized on the cash flow hedges was de minimis in 2011. Reclassifications into earnings of amounts reported in AOCI will continue as interest expense is recorded for the hedged interest payments through maturity in 2041. Pre-tax net losses of $0.5 million are expected to be reclassified from AOCI to the Consolidated Statements of Income in the next 12 months. As of December 31, 2013, the Company was not hedging any exposure to variability in future cash flows of forecasted transactions. |
Debt_Notes
Debt (Notes) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Debt Disclosure [Abstract] | ' | |||||||||||||||
Debt | ' | |||||||||||||||
Note 7 - Debt | ||||||||||||||||
The Company has a revolving credit facility with various banks to provide back-up credit liquidity support for its commercial paper program. Credit commitments under this revolving credit facility totaled $750.0 million at December 31, 2013, with no amounts borrowed. This revolving credit facility has interest-rate options generally below the prime interest rate and carries commitment fees on the unused balance. In April 2013, Questar amended and restated its revolving credit facility to increase its size from $500.0 million to $750.0 million and extend its maturity from August 31, 2016 to April 19, 2018. On October 29, 2012, the Company amended its revolving credit facility to enable Questar Gas to issue $150.0 million in the private placement market in December 2012. Under both amendments, consolidated funded debt cannot exceed 70% of consolidated capitalization. The Company was in compliance with this covenant at December 31, 2013. | ||||||||||||||||
The details of short-term debt are as follows: | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Commercial paper with various interest rates | $ | 276 | $ | 263 | ||||||||||||
Weighted-average interest rate at end of year | 0.27 | % | 0.31 | % | ||||||||||||
Questar centrally manages cash. Questar makes loans to Questar Gas and Questar Pipeline under a short-term borrowing arrangement. Amounts loaned earn an interest rate that is identical to the interest rate paid on amounts borrowed. The rate is adjusted monthly based on prevailing short-term market interest rates. | ||||||||||||||||
The following table details the notes payable to Questar from Questar Gas and the associated interest rates. There were no notes payable to Questar from Questar Pipeline at December 31, 2013 or 2012. | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Questar Gas | ||||||||||||||||
Notes payable to Questar | $ | 17.7 | $ | 166.1 | ||||||||||||
Interest rate at end of year | 0.3 | % | 0.39 | % | ||||||||||||
All short- and long-term debt and the revolving credit facility are unsecured obligations and rank equally with all other unsecured liabilities. The terms of the Questar Corporation, Questar Gas and Questar Pipeline long-term debt obligations do not have dividend-payment restrictions. | ||||||||||||||||
In December 2013, Questar Gas issued $90.0 million of 30-year Senior Notes at 4.78% and $60.0 million of 35-year Senior Notes at 4.83% in the private placement market. The proceeds of approximately $149.0 million, after deducting estimated issuance costs, were used to repay existing indebtedness and for general corporate purposes. | ||||||||||||||||
In December 2012, Questar Gas issued $110.0 million of 15-year Senior Notes at 3.28% and $40.0 million of 12-year Senior Notes at 2.98% in the private placement market. The proceeds of approximately $148.8 million, after deducting estimated issuance costs, were used to refinance $91.5 million of long-term debt that matured in 2012, $40.0 million that matured in January 2013 and $2.0 million that matured in September 2013, and for general corporate purposes. These maturities had a weighted-average interest rate of 6.06%. The details of long-term debt are as follows: | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Questar Corporation | ||||||||||||||||
2.75% Notes due 2016 | $ | 250 | $ | 250 | ||||||||||||
Questar Gas | ||||||||||||||||
5.00% and 6.89% Medium-term Notes due 2013 | — | 42 | ||||||||||||||
5.31% and 6.85% Medium-term Notes due 2017 and 2018 | 84.5 | 84.5 | ||||||||||||||
6.30% Notes due 2018 | 50 | 50 | ||||||||||||||
2.98% Notes due 2024 | 40 | 40 | ||||||||||||||
3.28% Notes due 2027 | 110 | 110 | ||||||||||||||
7.20% Notes due 2038 | 100 | 100 | ||||||||||||||
4.78% Notes due 2043 | 90 | — | ||||||||||||||
4.83% Notes due 2048 | 60 | — | ||||||||||||||
Total Questar Gas long-term debt | 534.5 | 426.5 | ||||||||||||||
Questar Pipeline | ||||||||||||||||
6.45% and 6.48% Medium-term Notes due 2015 and 2018 | 30.1 | 30.1 | ||||||||||||||
5.83% Notes due 2018 | 250 | 250 | ||||||||||||||
4.875% Notes due 2041 | 180 | 180 | ||||||||||||||
Total Questar Pipeline long-term debt | 460.1 | 460.1 | ||||||||||||||
Total long-term debt outstanding | 1,244.60 | 1,136.60 | ||||||||||||||
Less current portion | — | (42.0 | ) | |||||||||||||
Less unamortized debt discount | (2.1 | ) | (2.3 | ) | ||||||||||||
Plus unamortized debt premium | 0.7 | 0.8 | ||||||||||||||
Plus fair value hedge adjustment | 3.9 | 5.8 | ||||||||||||||
Total long-term debt, less current portion | $ | 1,247.10 | $ | 1,098.90 | ||||||||||||
The aggregate maturities of Questar Corporation, Questar Gas and Questar Pipeline long-term debt for the next five years are as follows: | ||||||||||||||||
Questar Corporation | Questar | Questar Pipeline | Total | |||||||||||||
Gas | ||||||||||||||||
Years Ending December 31, | ||||||||||||||||
(in millions) | ||||||||||||||||
2014 | $ | — | $ | — | $ | — | $ | — | ||||||||
2015 | — | — | 25.1 | 25.1 | ||||||||||||
2016 | 250 | — | — | 250 | ||||||||||||
2017 | — | 14.5 | — | 14.5 | ||||||||||||
2018 | — | 120 | 255 | 375 | ||||||||||||
Income_Taxes_Notes
Income Taxes (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Income Tax Disclosure [Abstract] | ' | |||||||||||
Income Taxes | ' | |||||||||||
Note 8 - Income Taxes | ||||||||||||
Questar | ||||||||||||
Details of Questar's income tax expense and deferred income taxes are provided in the following tables. The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 66.5 | $ | 1.3 | $ | — | ||||||
Deferred | 18.4 | 112 | 110.8 | |||||||||
State | ||||||||||||
Current | 10.7 | — | (1.3 | ) | ||||||||
Deferred | 5.9 | 3.6 | 7.3 | |||||||||
Deferred investment tax credits recognized | (0.2 | ) | (0.4 | ) | (0.4 | ) | ||||||
Total income tax expense | $ | 101.3 | $ | 116.5 | $ | 116.4 | ||||||
The difference between the statutory federal income tax rate and the Company's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase (decrease) in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 4 | 1 | 1.3 | |||||||||
Tax benefits from dividends paid to employee stock plan | (1.0 | ) | (0.5 | ) | (0.5 | ) | ||||||
Other | 0.6 | — | 0.1 | |||||||||
Effective income tax rate | 38.6 | % | 35.5 | % | 35.9 | % | ||||||
The 2013 combined effective federal and state income tax rate increased due to the impairment of Southern Trails Pipeline. There was no state tax benefit recorded in association with the impairment charge because the Company has limited state operations for Southern Trails Pipeline. The effective combined federal and state income tax rate also increased in 2013 due to adjustments to estimated state income taxes for the consolidated Questar return that were in excess of state income taxes calculated on a separate return basis for the operating companies. | ||||||||||||
Significant components of Questar's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 797.5 | $ | 767 | ||||||||
Employee benefits | 30.2 | 33.9 | ||||||||||
Other | 4.9 | 3.2 | ||||||||||
Deferred tax liabilities - noncurrent | 832.6 | 804.1 | ||||||||||
Deferred tax assets | ||||||||||||
Asset retirement obligations | 22.7 | 23.2 | ||||||||||
Pension and other postretirement benefits | 73.7 | 138.3 | ||||||||||
Deferred compensation | 14.5 | 8.6 | ||||||||||
Hedging activities | 13.4 | 13.6 | ||||||||||
State tax credits | 3.4 | 3.4 | ||||||||||
Net operating loss carryforward | — | 15.8 | ||||||||||
Valuation allowance | (2.3 | ) | (2.2 | ) | ||||||||
Deferred tax assets, net of allowance - noncurrent | 125.4 | 200.7 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 707.2 | $ | 603.4 | ||||||||
Deferred income taxes - current | ||||||||||||
Deferred tax assets - current | $ | 10.1 | $ | 17.6 | ||||||||
Deferred tax liabilities - current | 0.4 | 4.6 | ||||||||||
Net deferred income tax asset - current | $ | 9.7 | $ | 13 | ||||||||
Questar Gas | ||||||||||||
Details of Questar Gas's income tax expense and deferred income taxes are provided in the following tables. The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 6 | $ | (18.7 | ) | $ | — | |||||
Deferred | 23.5 | 45.1 | 26.3 | |||||||||
State | ||||||||||||
Current | 0.6 | — | (1.6 | ) | ||||||||
Deferred | 2 | 1.2 | 3.2 | |||||||||
Deferred investment tax credit recognized | (0.2 | ) | (0.4 | ) | (0.4 | ) | ||||||
Total income tax expense | $ | 31.9 | $ | 27.2 | $ | 27.5 | ||||||
The difference between the statutory federal income tax rate and Questar Gas's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase (decrease) in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 2.1 | 1 | 1.4 | |||||||||
Amortization of investment tax credits related to rate-regulated assets | (0.3 | ) | (0.4 | ) | (0.5 | ) | ||||||
Other | 0.9 | 1 | 1.5 | |||||||||
Effective income tax rate | 37.7 | % | 36.6 | % | 37.4 | % | ||||||
Significant components of Questar Gas's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 322.6 | $ | 293 | ||||||||
Employee benefits | 14 | 17.2 | ||||||||||
Other | 4.9 | 3.4 | ||||||||||
Deferred tax liabilities - noncurrent | 341.5 | 313.6 | ||||||||||
Deferred tax assets | ||||||||||||
Deferred compensation | 0.8 | 0.9 | ||||||||||
Net operating loss carryforward | — | 11.1 | ||||||||||
Deferred tax assets - noncurrent | 0.8 | 12 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 340.7 | $ | 301.6 | ||||||||
Deferred income taxes - current | ||||||||||||
Deferred tax assets - current | $ | 3.3 | $ | 6.1 | ||||||||
Deferred tax liabilities - current | 0.4 | 4.6 | ||||||||||
Net deferred income tax asset - current | $ | 2.9 | $ | 1.5 | ||||||||
Questar Pipeline | ||||||||||||
Details of Questar Pipeline's income tax expense and deferred income taxes are provided in the following tables. The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 20.2 | $ | (5.4 | ) | $ | — | |||||
Deferred | (15.2 | ) | 40.4 | 37 | ||||||||
State | ||||||||||||
Current | 1.3 | 1.6 | (0.7 | ) | ||||||||
Deferred | 0.7 | 0.7 | 1.9 | |||||||||
Total income tax expense | $ | 7 | $ | 37.3 | $ | 38.2 | ||||||
The difference between the statutory federal income tax rate and Questar Pipeline's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 8.5 | 1.6 | 1 | |||||||||
Other | 2.6 | — | — | |||||||||
Effective income tax rate | 46.1 | % | 36.6 | % | 36 | % | ||||||
The 2013 combined effective federal and state income tax rate increased due to the impairment of Southern Trails Pipeline. There was no state tax benefit recorded in association with the impairment charge because the company has limited state operations for Southern Trails Pipeline. | ||||||||||||
Significant components of Questar Pipeline's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 237.1 | $ | 250.8 | ||||||||
Employee benefits | 7.4 | 8.4 | ||||||||||
Deferred tax liabilities - noncurrent | 244.5 | 259.2 | ||||||||||
Deferred tax assets | ||||||||||||
Deferred compensation | 1.8 | 1.5 | ||||||||||
Hedging activities | 13.4 | 13.6 | ||||||||||
State tax credits | 0.7 | 0.7 | ||||||||||
Net operating loss carryforward | — | 1 | ||||||||||
Other | — | (0.1 | ) | |||||||||
Deferred tax assets - noncurrent | 15.9 | 16.7 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 228.6 | $ | 242.5 | ||||||||
Net deferred income tax asset - current | $ | 1.8 | $ | 1.6 | ||||||||
Commitments_Contingencies_and_
Commitments, Contingencies and Leases (Notes) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Commitments and Contingencies Disclosure [Abstract] | ' | |||
Commitments, Contingencies and Leases | ' | |||
Note 9 - Commitments, Contingencies and Leases | ||||
On May 1, 2012, Questar Gas Company filed a legal action against QEP Field Services Company, a subsidiary of QEP Resources, Inc. The case, entitled Questar Gas Company v. QEP Field Services Company, was filed in the Third District Court in Salt Lake County, Utah. Questar Gas believes certain charges of QEP Field Services Company for gathering services exceed the amounts contemplated under a Gas Gathering Agreement, effective September 1, 1993, pertaining to certain gas produced by Wexpro Company under the Wexpro Agreement. Questar Gas is alleging breach of contract by QEP Field Services Company and is seeking an accounting, damages and a declaratory judgment relating to the services and charges under the Gas Gathering Agreement. The charges under the Gas Gathering Agreement are included in Questar Gas's rates as part of its purchased-gas costs. QEP Field Services Company filed an answer and counterclaim alleging that Questar Gas breached the Agreement by failing to allow QEP Field Services to gather and process gas from certain wells located in two fields in the state of Wyoming. While Questar Gas intends to vigorously pursue its legal rights, the claims and counterclaims involve complex legal issues and uncertainties that make it difficult to predict the outcome of the case and therefore management cannot determine at this time whether this litigation may have an adverse material effect on its financial position, results of operations or cash flows. | ||||
Questar incurs environmental remediation costs related to both owned and previously-owned facilities, including transmission and production facilities, manufactured gas plant sites and a previously-owned chemical business. | ||||
Questar and each of its subsidiaries are involved in various commercial, environmental, and regulatory claims. Litigation and other legal proceedings arise in the ordinary course of business. Except as stated above concerning the QEP lawsuit, management does not believe any of them individually or in the aggregate will have a material adverse effect on Questar's, Questar Gas's or Questar Pipeline's financial position, results of operations or cash flows. | ||||
A liability is recorded for a loss contingency when its occurrence is probable and its amount can be reasonably estimated. If some amount within a range of possible outcomes appears to be a better estimate than any other amount within the range, that amount is recorded. Otherwise, the minimum amount in the range is recorded. Disclosures are provided for contingencies reasonably likely to occur, which would have a material adverse effect on Questar's, Questar Gas's or Questar Pipeline's financial position, results of operations or cash flows. Some of the claims involve highly complex issues relating to liability, damages and other matters subject to substantial uncertainties and, therefore, the probability of liability or an estimate of loss cannot be reasonably determined. | ||||
Commitments | ||||
Questar Gas | ||||
Currently, more than half of Questar Gas's natural gas supply is provided by cost-of-service reserves developed and produced by Wexpro. In 2013, Questar Gas purchased the remainder of its gas supply from multiple third parties under index-based or fixed-price contracts. Questar Gas has commitments to purchase gas for $27.4 million in 2014, $21.0 million in 2015, $21.1 million in 2016, $25.3 million in 2017, and $29.4 million in 2018 based on current prices. Generally, at the conclusion of the heating season and after a bid process, new agreements for the next heating season are put in place. Questar Gas bought natural gas under third-party purchase agreements amounting to $186.5 million in 2013, $104.1 million in 2012 and $221.0 million in 2011. | ||||
In addition, Questar Gas stores gas during off-peak periods (typically during the summer) and withdraws gas from storage to meet peak gas demand (typically in the winter). The company has contracted for transportation and underground storage services with Questar Pipeline. Annual payments for these services amount to $74.4 million in 2014, $73.3 million in 2015 and 2016, $46.6 million in 2017, and $13.4 million in 2018. Questar Gas has third-party transportation and gathering commitments requiring yearly payments of $27.2 million in 2014 through 2017 and $24.2 million in 2018. | ||||
Leases | ||||
The lease on the Company's former headquarters building ended on April 30, 2012. Rental expense on this long-term operating lease amounted to $1.5 million in 2012 and $3.2 million in 2011. | ||||
In June 2010, Questar entered into a lease agreement for a new headquarters building. The lease term is 17 years and commenced on May 1, 2012. Rental payments under the lease escalate at a rate of 3% per year during the lease term. The lease agreement does not include bargain renewal periods or material rent holidays and is not subject to contingent rent or other unusual provisions. Questar accounts for this lease as a capital lease. Other property, plant and equipment on the Consolidated Balance Sheets includes $40.8 million under the capital lease as of December 31, 2013 and 2012. Other accumulated depreciation and amortization on the Consolidated Balance Sheets includes $4.3 million and $1.9 million under the capital lease as of December 31, 2013 and 2012, respectively. Amortization of the asset under the capital lease is included with depreciation, depletion and amortization on the Consolidated Statements of Income. | ||||
Future minimum lease payments for the five years following 2013 and the years thereafter are shown in the table below. Also shown is the present value of minimum lease payments at December 31, 2013, which is reflected in the Consolidated Balance Sheets as current and noncurrent capital lease obligations of $0.9 million and $38.4 million, respectively. | ||||
Years Ending December 31, | ||||
(in millions) | ||||
2014 | $ | 3 | ||
2015 | 3.4 | |||
2016 | 3.5 | |||
2017 | 3.6 | |||
2018 | 3.7 | |||
After 2018 | 44.8 | |||
Total minimum lease payments | 62 | |||
Less: amount representing interest | (22.7 | ) | ||
Present value of minimum lease payments at December 31, 2013 | $ | 39.3 | ||
Wexpro_and_Wexpro_II_Agreement
Wexpro and Wexpro II Agreements (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Wexpro Agreement [Abstract] | ' | |||||||||||
Wexpro Agreement | ' | |||||||||||
Note 10 - Wexpro and Wexpro II Agreements | ||||||||||||
Wexpro's operations are subject to the terms of the Wexpro Agreement. The agreement was effective August 1, 1981, and sets forth the rights of Questar Gas to receive certain benefits from Wexpro's operations. The agreement was approved by the PSCU and PSCW in 1981 and affirmed by the Supreme Court of Utah in 1983. The Utah Division of Public Utilities and the staff of the PSCW are entitled to review the performance of Questar Gas and Wexpro under the Wexpro Agreement and have retained an independent certified public accountant and an independent petroleum engineer to monitor the performance of the agreement. Major provisions of the agreement are as follows: | ||||||||||||
a. Wexpro conducts gas-development drilling on a finite group of productive gas properties, as defined in the agreement, and bears any costs of dry holes. Natural gas produced from successful drilling on these properties is delivered to Questar Gas. Wexpro is reimbursed for the costs of producing the natural gas plus a return on its investment in successful wells. The after-tax return allowed Wexpro is adjusted annually and is approximately 20.2%. | ||||||||||||
b. Wexpro operates certain natural gas properties for Questar Gas. Wexpro is reimbursed for its costs of operating these properties, including a rate of return on any investment it makes. This after-tax rate of return is adjusted annually and is approximately 12.2%. | ||||||||||||
c. Wexpro conducts developmental-oil drilling on productive oil properties and bears any costs of dry holes. Oil and NGL discovered from these properties is sold at market prices with the revenues used to recover operating expenses and to give Wexpro a return on its investment in successful wells. The after-tax rate of return is adjusted annually and is approximately 17.2%. Any operating income remaining after recovery of expenses and Wexpro's return on investment is divided between Wexpro and Questar Gas, with Wexpro retaining 46% and Questar Gas retaining 54%. | ||||||||||||
d. Crude oil and NGL production from certain oil-producing properties is sold at market prices with the revenues used to recover operating expenses and to provide Wexpro a return on its investment. The after-tax rate of return on investments in these properties is adjusted annually and is approximately 12.2%. Any operating income remaining after recovery of expenses and Wexpro's return on investment is divided between Wexpro and Questar Gas, with Wexpro retaining 46%. | ||||||||||||
e. Amounts received by Questar Gas from the sharing of Wexpro's oil and NGL income are used to reduce natural gas costs to utility customers. | ||||||||||||
f. Wexpro's return on investment base is determined based on authorized returns from a group of rate-regulated companies plus an 8% risk premium for natural gas development drilling and a 5% risk premium for oil development drilling. The authorized returns for this group of companies have declined in recent years, resulting in lower returns on investment base for Wexpro. | ||||||||||||
Wexpro's net investment base, yearly average rate of return, and oil and NGL income shared with Questar Gas are shown in the table below: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Wexpro net investment base at December 31, (in millions) | $ | 589.7 | $ | 531.1 | $ | 474.4 | ||||||
Average annual rate of return (after tax) | 19.7 | % | 19.9 | % | 20 | % | ||||||
Oil and NGL income sharing (in millions) | $ | 0.6 | $ | 2.5 | $ | 3.3 | ||||||
Wexpro II Agreement | ||||||||||||
Wexpro and Questar Gas have received approval of the PSCU and PSCW (the Commissions) for a Wexpro II Agreement to add properties under the cost-of-service pricing methodology for the benefit of Questar Gas customers. The agreement is modeled after the terms of the original Wexpro Agreement. Under the Wexpro II Agreement, Wexpro may acquire gas development properties and Questar Gas may submit an application to the Commissions to treat these properties similar to the original Wexpro properties. If the Commissions approve the applications, the gas will be developed for the benefit of Questar Gas customers. Wexpro will be entitled to a return on the acquisition costs based on Questar Gas's approved cost of capital. Future development costs will earn returns consistent with the original Wexpro Agreement. | ||||||||||||
In September 2013, Wexpro completed a transaction to acquire an additional interest in natural gas-producing properties in the Trail Unit of southwestern Wyoming's Vermillion Basin for $104.3 million, after post-closing adjustments (Trail acquisition). In January 2014, the Commissions approved a stipulation for inclusion of these properties in the Wexpro II Agreement. As part of this stipulation, Wexpro agreed to a provision to manage the combined production from the original Wexpro properties and the Trail acquisition to 65% of Questar Gas's annual forecasted demand. Beginning in June 2015 through May 2016 and for each subsequent 12-month period, if the combined annual production exceeds 65% of the forecasted demand and the cost-of-service price is greater than the Questar Gas purchased-gas price, an amount equal to the excess production times the excess price will be credited back to Questar Gas customers. Wexpro may also sell production to manage the 65% level and credit back to Questar Gas customers the higher of market price or the cost-of-service price times the sales volumes. |
Rate_Regulation_Notes
Rate Regulation (Notes) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Regulated Operations [Abstract] | ' | |||||||||||||||
Rate Regulation | ' | |||||||||||||||
Note 11 - Rate Regulation | ||||||||||||||||
The following table details regulatory assets and liabilities: | ||||||||||||||||
December 31, 2013 | December 31, 2012 | |||||||||||||||
Current | Noncurrent | Current | Noncurrent | |||||||||||||
(in millions) | ||||||||||||||||
Regulatory assets: | ||||||||||||||||
Questar Gas | ||||||||||||||||
Purchased-gas adjustment | $ | — | $ | — | $ | 15.2 | $ | — | ||||||||
DSM | 11.2 | — | 11 | — | ||||||||||||
Deferred production taxes | 5.7 | — | 5 | — | ||||||||||||
Deferred royalties | 5.2 | — | 6.3 | — | ||||||||||||
Contract withholding | 8.1 | — | 3.5 | — | ||||||||||||
Cost of reacquired debt | — | 4.8 | — | 5.3 | ||||||||||||
Pipeline integrity costs | — | 9.3 | — | 8.7 | ||||||||||||
ARO cost-of-service gas wells | — | 2 | — | 2.4 | ||||||||||||
Total Questar Gas regulatory assets | 30.2 | 16.1 | 41 | 16.4 | ||||||||||||
Questar Pipeline | ||||||||||||||||
Gas imbalance | 5.3 | — | 4.4 | — | ||||||||||||
Revenue sharing | 0.3 | — | 1.3 | — | ||||||||||||
Cost of reacquired debt | — | 2.6 | — | 3 | ||||||||||||
Income taxes recoverable from customers | — | 0.6 | — | 0.9 | ||||||||||||
Other | — | 1.2 | — | 1.3 | ||||||||||||
Total Questar Pipeline regulatory assets | 5.6 | 4.4 | 5.7 | 5.2 | ||||||||||||
Total regulatory assets | $ | 35.8 | $ | 20.5 | $ | 46.7 | $ | 21.6 | ||||||||
Regulatory liabilities: | ||||||||||||||||
Questar Gas | ||||||||||||||||
Purchased-gas adjustment | $ | 7.4 | $ | — | $ | — | $ | — | ||||||||
CET | 3.3 | — | 4.2 | — | ||||||||||||
Cost of plant removal | — | 52.7 | — | 46.2 | ||||||||||||
Income taxes refundable to customers | — | 0.3 | — | 0.5 | ||||||||||||
Other | 0.4 | — | 0.1 | — | ||||||||||||
Total Questar Gas regulatory liabilities | 11.1 | 53 | 4.3 | 46.7 | ||||||||||||
Questar Pipeline | ||||||||||||||||
Gas imbalance | 3 | — | 1.4 | — | ||||||||||||
Revenue sharing | — | — | 0.1 | — | ||||||||||||
Postretirement medical | — | 8.2 | — | 7.7 | ||||||||||||
Total Questar Pipeline regulatory liabilities | 3 | 8.2 | 1.5 | 7.7 | ||||||||||||
Total regulatory liabilities | $ | 14.1 | $ | 61.2 | $ | 5.8 | $ | 54.4 | ||||||||
Questar Gas and Questar Pipeline record regulatory assets and liabilities. They recover the costs of assets but do not generally receive a return on these assets. | ||||||||||||||||
Following is a description of Questar Gas's regulatory assets and liabilities: | ||||||||||||||||
- | Purchased-gas costs that are different from those provided for in present rates are accumulated and recovered or credited through future rate changes. | |||||||||||||||
- | The DSM program asset represents funds expended for promoting the conservation of natural gas through advertising, rebates for efficient homes and appliances, and home energy audits. These costs are deferred and recovered from customers through periodic rate adjustments. | |||||||||||||||
- | Production taxes and royalties on cost-of-service gas production are recorded when the gas is produced and recovered from customers when taxes and royalties are paid, generally within 12 months. | |||||||||||||||
- Questar Gas recorded a regulatory asset for a disputed amount withheld from a supplier of gathering services. The amount withheld will be recovered from customers if it is determined that Questar Gas is required to pay the supplier. | ||||||||||||||||
- | Gains and losses on the reacquisition of debt by rate-regulated companies are deferred and amortized as interest expense over the would-be remaining life of the reacquired debt. The reacquired debt costs had a weighted-average life of approximately 9 years as of December 31, 2013. | |||||||||||||||
- | The costs of complying with pipeline-integrity regulations are recovered in rates subject to a PSCU order. Questar Gas is allowed to recover $4.4 million per year. Costs incurred in excess of this amount will be recovered in future rate changes. | |||||||||||||||
- | A regulatory asset that represents future expenses related to abandonment of Wexpro-operated gas and oil wells. The regulatory asset will be reduced over an 18-year period following an amortization schedule that commenced January 1, 2003, or as cash is paid to plug and abandon wells. | |||||||||||||||
- | The CET liability represents actual revenues received that are in excess of the allowed revenues. These amounts are refunded through periodic rate adjustments. | |||||||||||||||
- Cost of plant removal represents asset retirement costs recovered from customers for other than legal obligations. | ||||||||||||||||
- | Income taxes refundable to customers arise from adjustments to deferred taxes, refunded over the life of the related property, plant and equipment. | |||||||||||||||
Following is a description of Questar Pipeline's regulatory assets and liabilities: | ||||||||||||||||
- | Regulatory assets and liabilities for gas imbalances, fuel over- or under-recovered and sharing interruptible revenues with customers. | |||||||||||||||
- | Gains and losses on the reacquisition of debt are deferred and amortized as interest expense over the would-be remaining life of the reacquired debt. The reacquired debt costs had a weighted-average life of approximately 7 years as of December 31, 2013. | |||||||||||||||
- | Income taxes recoverable from customers arise from adjustments to deferred taxes, recovered over the life of the related property, plant and equipment. | |||||||||||||||
- | A regulatory liability for the collection of postretirement medical costs allowed in rates in excess of actual charges. | |||||||||||||||
Rate Changes | ||||||||||||||||
Questar Gas has an allowed return on equity of 10.35% in Utah. Questar Gas filed a general rate case in Utah in July 2013, requesting a $19 million increase in revenues and a continuation of its 10.35% authorized return on equity. Hearings were held in January 2014 and a decision in the case was received on February 21, 2014, which authorized an allowed return on equity of 9.85% and an annual increase in revenues of $7.6 million effective March 1, 2014. Questar Gas filed a general rate case in Wyoming in December 2011 and received an order in 2012, which increased rates by $0.6 million per year and authorized a return on equity of 9.16%. |
ShareBased_Compensation_Notes
Share-Based Compensation (Notes) | 12 Months Ended | ||||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||||
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | ' | ||||||||||||||||||||||
Share-Based Compensation | ' | ||||||||||||||||||||||
Note 12 - Share-Based Compensation | |||||||||||||||||||||||
Questar may issue stock options, restricted shares, RSUs and performance shares to certain officers, employees and non-employee directors under its LTSIP. Questar recognizes expense over time as the stock options, restricted shares, RSUs and performance shares vest. Total share-based compensation expense amounted to $10.2 million in 2013 compared to $9.9 million in 2012 and $10.1 million in 2011. Deferred share-based compensation, representing the unvested value of restricted share awards and RSU awards, amounted to $4.8 million at December 31, 2013, and $5.1 million at December 31, 2012. Cash flow from income tax benefits in excess of recognized compensation expense amounted to $14.0 million in 2013 and $9.2 million in 2011. There were no cash flows from income tax benefits in excess of recognized compensation expense in 2012. At December 31, 2013, there were 5,568,160 shares available for future grant. | |||||||||||||||||||||||
There were no unvested stock options at December 31, 2013, reflecting a decrease of 29,398 since December 31, 2012. No stock options have been granted since 2010 and no stock options were forfeited in 2013. | |||||||||||||||||||||||
Stock option transactions under the terms of the LTSIP are summarized for the year ended December 31, 2013, below: | |||||||||||||||||||||||
Options | Exercise | Weighted-Average Exercise Price | |||||||||||||||||||||
Outstanding | Price Range | ||||||||||||||||||||||
Balance at December 31, 2012 | 770,923 | $ | 4.37 | - | $ | 17.35 | $ | 11.35 | |||||||||||||||
Exercised | (53,083 | ) | 4.37 | - | 13.1 | 4.75 | |||||||||||||||||
Balance at December 31, 2013 | 717,840 | $ | 7.84 | - | $ | 17.35 | $ | 11.84 | |||||||||||||||
Options Outstanding | Options Exercisable | ||||||||||||||||||||||
Range of | Number outstanding at Dec. 31, 2013 | Weighted-average remaining term in years | Weighted-average exercise price | Number exercisable at Dec. 31, 2013 | Weighted-average exercise price | ||||||||||||||||||
exercise | |||||||||||||||||||||||
prices | |||||||||||||||||||||||
$ | 7.84 | - | $ | 11.4 | 404,174 | 1.9 | $ | 10.52 | 404,174 | $ | 10.52 | ||||||||||||
13.1 | - | 17.35 | 313,666 | 2.5 | 13.54 | 313,666 | 13.54 | ||||||||||||||||
717,840 | 2.2 | $ | 11.84 | 717,840 | $ | 11.84 | |||||||||||||||||
As of December 31, 2013, the aggregate intrinsic value of outstanding and exercisable options was $8.0 million. | |||||||||||||||||||||||
Restricted shares are valued at the grant-date market price and amortized to expense over the vesting period. Most restricted share grants vest in equal installments over a three-year period from the grant date. The weighted-average remaining vesting period of unvested restricted shares at December 31, 2013, was 7 months. Transactions involving restricted shares under the terms of the LTSIP for the year ended December 31, 2013, are summarized below: | |||||||||||||||||||||||
Restricted Shares Outstanding | Price Range | Weighted- Average Price | |||||||||||||||||||||
Balance at December 31, 2012 | 810,342 | $ | 13.1 | - | $ | 20.9 | $ | 17.74 | |||||||||||||||
Granted | 658 | 21.53 | - | 21.53 | 21.53 | ||||||||||||||||||
Vested | (417,882 | ) | 13.1 | - | 20.9 | 17.24 | |||||||||||||||||
Forfeited | (791 | ) | 19.39 | - | 19.39 | 19.39 | |||||||||||||||||
Balance at December 31, 2013 | 392,327 | $ | 13.1 | - | $ | 21.53 | $ | 18.28 | |||||||||||||||
Starting in the first quarter of 2013, Questar granted RSUs to certain officers, employees and non-employee directors under its LTSIP. One share of Questar common stock will be distributed for each RSU at the time of vesting. RSUs are valued at the grant-date market price and amortized to expense over the vesting period. RSU grants typically vest in equal installments over a three-year period from the grant date. Several grants vest in a single installment after a specified period. The weighted-average remaining vesting period of unvested RSUs at December 31, 2013, was 14 months. Transactions involving RSUs under the terms of the LTSIP are summarized below: | |||||||||||||||||||||||
RSUs | Price Range | Weighted-Average Price | |||||||||||||||||||||
Outstanding | |||||||||||||||||||||||
Granted | 330,061 | $ | 22.17 | - | $ | 25.44 | $ | 23.62 | |||||||||||||||
Vested | (12,522 | ) | 23.62 | - | 23.62 | 23.62 | |||||||||||||||||
Forfeited | (1,271 | ) | 23.62 | - | 23.62 | 23.62 | |||||||||||||||||
Balance at December 31, 2013 | 316,268 | $ | 22.17 | - | $ | 25.44 | $ | 23.62 | |||||||||||||||
Grants of RSUs with deferred share distributions (deferred RSUs) typically vest in equal installments over a three-year period from the grant date. At December 31, 2013, Questar's outstanding deferred RSUs totaled 73,646 with a weighted-average price of $15.73 per share. The deferred RSUs were fully vested as of July 1, 2013. One share of Questar common stock will be distributed for each vested deferred RSU (including accrued reinvested dividend equivalents) at the time of the grantee's separation from service. | |||||||||||||||||||||||
Questar grants performance shares to Company officers under the terms of the LTSIP. The awards are designed to motivate and reward these officers for long-term Company performance and provide an incentive for them to remain with the Company. The target number of performance shares for each officer is subject to adjustment upward or downward based on the Company's total shareholder return relative to a specified peer group of companies over a three-year performance period. Each three-year performance period commences at the beginning of the year of grant. Distributions of performance shares, if any, take place in the quarter following the conclusion of the performance period so long as such officer was employed by the Company or its affiliates as of the last day of the performance period. | |||||||||||||||||||||||
The Company uses the Monte Carlo simulation method in estimating the fair value of performance shares. Fair value estimates rely upon subjective assumptions used in the mathematical model and may not be representative of future results. The estimated fair value of performance shares granted and major assumptions used in the simulation at the date of grant are listed below: | |||||||||||||||||||||||
2013 | 2012 | 2011 | |||||||||||||||||||||
Performance Share | |||||||||||||||||||||||
Input Variables | |||||||||||||||||||||||
Fair value of performance shares at grant date | $ | 39.62 | $ | 25.42 | $ | 18.23 | |||||||||||||||||
Risk-free interest rate | 0.4 | % | 0.35 | % | 1.32 | % | |||||||||||||||||
Expected price volatility | 19 | % | 22 | % | 31.3 | % | |||||||||||||||||
Expected dividend yield | 2.88 | % | 3.35 | % | 3.39 | % | |||||||||||||||||
Expected life in years | 2.9 | 2.9 | 2.9 | ||||||||||||||||||||
The grant-date fair value of performance shares is amortized to expense over the vesting period. Half of any award will be distributed in shares of Questar common stock and half in cash. Equity- and liability-based performance share compensation expense amounted to $2.0 million in 2013, $1.8 million in 2012 and $0.6 million in 2011. The weighted-average remaining vesting period of unvested performance shares at December 31, 2013, was 18 months. Transactions involving performance shares under the terms of the LTSIP for the year ended December 31, 2013, are summarized below: | |||||||||||||||||||||||
Target Number of Performance Shares Outstanding | Grant-Date | Weighted- Average Grant-Date Fair Value | |||||||||||||||||||||
Fair Value Range | |||||||||||||||||||||||
Balance at December 31, 2012 | 264,867 | $ | 18.23 | - | $ | 25.42 | $ | 21.94 | |||||||||||||||
Granted | 126,606 | 39.62 | 39.62 | 39.62 | |||||||||||||||||||
Forfeited | (3,594 | ) | 18.23 | - | 39.62 | 33.09 | |||||||||||||||||
Balance at December 31, 2013 | 387,879 | $ | 18.23 | - | $ | 39.62 | $ | 27.61 | |||||||||||||||
The above December 31, 2013 balance includes 130,221 vested target performance shares with a weighted-average grant-date fair value of $18.44. The substantial majority of these shares represent the 2011 grant, whose performance and vesting periods ended on December 31, 2013. Distribution of the 2011 award, adjusted based on Questar's relative total shareholder return, will take place in the first quarter of 2014. | |||||||||||||||||||||||
As of December 31, 2013, the total unrecognized compensation cost related to outstanding stock options, restricted shares, RSUs and performance shares was $7.9 million, which the Company expects to recognize over a weighted-average period of 12 months. | |||||||||||||||||||||||
Certain officers, employees and non-employee directors of former subsidiary QEP Resources held 298,098 Questar stock options with a weighted-average exercise price of $11.41 per share and a weighted-average remaining life of 2.4 years at December 31, 2013. | |||||||||||||||||||||||
Questar may issue stock options, restricted shares, RSUs and performance shares to certain officers and employees of Questar Gas and Questar Pipeline under its LTSIP and recognizes expense over time as the stock options, restricted shares, RSUs and performance shares vest. Questar Gas share-based compensation expense amounted to $1.4 million in 2013 compared with $1.2 million in 2012 and $1.1 million in 2011. Questar Pipeline share-based compensation expense amounted to $2.0 million in 2013 compared with $2.0 million in 2012 and $1.8 million in 2011. | |||||||||||||||||||||||
The following table summarizes the stock options held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013: | |||||||||||||||||||||||
Options Outstanding | Options Exercisable | ||||||||||||||||||||||
Range of | Number outstanding at Dec. 31, 2013 | Weighted-average remaining term in years | Weighted-average exercise price | Number exercisable at Dec. 31, 2013 | Weighted-average exercise price | ||||||||||||||||||
exercise | |||||||||||||||||||||||
prices | |||||||||||||||||||||||
Questar Gas | |||||||||||||||||||||||
$ | 11.4 | - | $ | 13.1 | 17,000 | 2.6 | $ | 12.1 | 17,000 | $ | 12.1 | ||||||||||||
Questar Pipeline | |||||||||||||||||||||||
$ | 7.84 | - | $ | 13.1 | 158,933 | 1.6 | $ | 9.36 | 158,933 | $ | 9.36 | ||||||||||||
The following table summarizes the restricted shares held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013. The weighted-average remaining vesting periods of unvested restricted shares at December 31, 2013, for Questar Gas and Questar Pipeline were 6 months and 7 months, respectively. | |||||||||||||||||||||||
Restricted | Price Range | Weighted-Average Price | |||||||||||||||||||||
Shares Outstanding | |||||||||||||||||||||||
Questar Gas | 58,837 | $ | 13.1 | - | $ | 19.39 | $ | 18.6 | |||||||||||||||
Questar Pipeline | 70,758 | $ | 13.1 | - | $ | 19.56 | $ | 18.78 | |||||||||||||||
The following table summarizes the RSUs held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013. The weighted-average remaining vesting period of unvested RSUs at December 31, 2013, for Questar Gas and Questar Pipeline was 14 months. | |||||||||||||||||||||||
RSUs Outstanding | Price Range | Weighted-Average Price | |||||||||||||||||||||
Questar Gas | 55,631 | $ | 22.17 | - | $ | 23.62 | $ | 23.54 | |||||||||||||||
Questar Pipeline | 50,230 | $ | 23.62 | - | $ | 23.62 | $ | 23.62 | |||||||||||||||
The following table summarizes the target number of performance shares held under the LTSIP by Questar Gas and Questar Pipeline officers at December 31, 2013. The weighted-average remaining vesting period of unvested performance shares at December 31, 2013, for Questar Gas and Questar Pipeline was 18 months. | |||||||||||||||||||||||
Target Number of Performance Shares Outstanding | Grant-Date | Weighted- Average Grant-Date Fair Value | |||||||||||||||||||||
Fair Value Range | |||||||||||||||||||||||
Questar Gas | 34,326 | $ | 18.23 | - | $ | 39.62 | $ | 27.91 | |||||||||||||||
Questar Pipeline | 65,283 | $ | 18.23 | - | $ | 39.62 | $ | 26.85 | |||||||||||||||
Employee_Benefits_Notes
Employee Benefits (Notes) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Compensation and Retirement Disclosure [Abstract] | ' | |||||||||||||||||||||||
Employee Benefits | ' | |||||||||||||||||||||||
Note 13 - Employee Benefits | ||||||||||||||||||||||||
Defined Benefit Pension Plans and Other Postretirement Benefits | ||||||||||||||||||||||||
The Company has a noncontributory defined benefit pension plan covering a majority of its employees and postretirement medical and life insurance plans providing coverage to less than half of its employees. Employees hired or rehired after June 30, 2010 are not eligible for the noncontributory defined benefit pension plan and employees hired or rehired after December 31, 1996, are not eligible for the postretirement medical plan and are not eligible to receive basic life coverage once they retire. | ||||||||||||||||||||||||
Questar funds a trust for Employee Retirement Income Security Act (ERISA)-qualified pension and other postretirement benefit obligations to pay benefits currently due and to build asset balances over a reasonable time period to pay future obligations. Questar is subject to and complies with minimum-required and maximum-allowed annual contribution levels mandated by ERISA and by the Internal Revenue Code. Subject to these limitations, the Company seeks to fund the qualified pension plan in amounts that are at a minimum equal to the yearly net cost. The Company also has a nonqualified pension plan that covers a group of management employees in addition to the qualified pension plan. The nonqualified pension plan provides for defined benefit payments upon retirement of the management employee, or to the spouse upon death of the management employee, above the benefit limit defined by the IRS for the qualified plan. The nonqualified pension plan is unfunded; claims are paid from the Company's general funds. The Company commingles postretirement medical plan assets with those of the ERISA-qualified pension plan as permitted by section 401(h) of the Internal Revenue Code. | ||||||||||||||||||||||||
The Company's Employee Benefits Committee (EBC) has oversight over investment of qualified pension and other postretirement benefit plan assets. The EBC uses a third-party consultant to assist in setting targeted policy ranges for the allocation of assets among various investment categories. The EBC allocates qualified pension, postretirement medical and postretirement life plan assets among broad asset categories and reviews the asset allocation at least annually. Asset allocation decisions consider risk and return, future benefit requirements, participant growth and other expected cash flows. The EBC seeks investment returns consistent with reasonable and prudent levels of liquidity and risk. | ||||||||||||||||||||||||
The EBC uses asset-mix guidelines that include permissible ranges for each asset category, return objectives for each asset group and the desired level of diversification and liquidity. These guidelines change from time to time based on the EBC's ongoing evaluation of each plan's risk tolerance. The EBC estimates an expected overall long-term rate of return on assets by weighting expected returns of each asset class by its targeted asset allocation percentage. Expected return estimates are developed from analysis of past performance and forecasts of long-term return expectations by third-parties. Qualified pension and other postretirement benefit plan assets were invested as follows: | ||||||||||||||||||||||||
Actual Allocation | Policy Range | |||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2013 | 2012 | 2013 | 2012 | |||||||||||||||||||||
Total domestic equity securities | 38 | % | 34 | % | 35 | % | - | 45 | % | 35 | % | - | 45 | % | ||||||||||
Foreign equity securities | ||||||||||||||||||||||||
Developed market foreign equity securities | 20 | % | 20 | % | ||||||||||||||||||||
Emerging market foreign equity securities | 5 | % | 5 | % | ||||||||||||||||||||
Total foreign securities | 25 | % | 25 | % | 25 | % | - | 35 | % | 25 | % | - | 35 | % | ||||||||||
Debt securities | ||||||||||||||||||||||||
Investment-grade intermediate-term debt | 7 | % | 4 | % | ||||||||||||||||||||
Investment-grade long-term debt | 11 | % | 14 | % | ||||||||||||||||||||
Below-investment-grade debt | 9 | % | 10 | % | ||||||||||||||||||||
Total debt securities | 27 | % | 28 | % | 25 | % | - | 35 | % | 25 | % | - | 35 | % | ||||||||||
Inflation protection securities | 9 | % | 9 | % | — | % | - | 10 | % | — | % | - | 10 | % | ||||||||||
Cash and short-term investments | 1 | % | 4 | % | — | % | - | 3 | % | — | % | - | 3 | % | ||||||||||
At December 31, 2013, domestic equity assets were invested in a passive total stock market index fund that invests in a diversified portfolio of stocks representative of the whole U.S. stock market and an S&P 500 index fund. Developed market foreign equity assets were invested in funds that hold a diversified portfolio of common stocks of corporations in developed countries outside the United States. These investments are benchmarked against the Morgan Stanley Capital International Europe Australasia and Far East (MSCI EAFE) index. Emerging market foreign equity assets are invested in funds that hold a diversified portfolio of common stocks of corporations in emerging countries outside the United States and are benchmarked against the MSCI Emerging Markets index. | ||||||||||||||||||||||||
Investment-grade intermediate-term debt assets are invested in funds holding a diversified portfolio of debt of governments, corporations and mortgage borrowers with average maturities of 5 to 10 years and investment-grade credit ratings. The investments are benchmarked against the Barclays Capital Aggregate Bond index. Investment-grade long-term debt assets are invested in a diversified portfolio of debt of governments, corporations and mortgage borrowers with an average maturity of more than 10 years and investment-grade credit ratings. These assets are benchmarked against the Barclays Capital Government/Credit Bond index. Below-investment-grade debt assets are invested in a fund holding a diversified portfolio of debt securities of corporations with an average maturity up to 10 years and below-investment-grade credit ratings. This investment is benchmarked against the Merrill Lynch High Yield II Total Return Bond index. | ||||||||||||||||||||||||
To mitigate the impact of inflation, assets are allocated to inflation protection funds. These funds invest in indices that comprise the Dow Jones U.S. Select REIT, Dow Jones-UBS Commodity Total Return, S&P Global LargeMidCap Commodity and Resources, and Barclays Capital U.S. Treasury Inflation Protected Securities. Cash and short-term investments are held in a fund that purchases investment-grade short-term debt issued by governments and corporations. | ||||||||||||||||||||||||
Responsibility for individual security selection rests with each investment manager, who is subject to guidelines specified by the EBC. These guidelines are designed to ensure consistency with overall plan objectives. The EBC sets performance objectives for each investment manager that are expected to be met over a three-year period or a complete market cycle, whichever is shorter. Performance and risk levels are regularly monitored to confirm policy compliance and that results are within expectations. | ||||||||||||||||||||||||
Pension plan guidelines prohibit transactions between a fiduciary and parties-in-interest unless specifically provided for in ERISA. No restricted securities, such as letter stock or private placements, may be purchased for any investment fund. Questar securities may be considered for purchase at an investment manager's discretion, but within limitations prescribed by ERISA and other laws. There was no direct investment in Questar shares for the periods disclosed. Use of derivative securities by any investment manager is prohibited except where the EBC has given specific approval or where commingled funds are utilized that have previously adopted permitting guidelines. | ||||||||||||||||||||||||
Fair value accounting standards define fair value in applying GAAP as well as establish a framework for measuring fair value and for making disclosures about fair value measurements. The standards establish a fair value hierarchy with Levels 1, 2 and 3 ranging from the most observable to the least observable valuation inputs. Level 1 inputs are unadjusted quoted prices in active markets that the Company has the ability to access for identical assets or liabilities at the measurement date. Level 2 inputs are inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. Level 3 inputs are unobservable inputs for the asset or liability. The following is a description of the valuation methodologies used at December 31, 2013 and 2012, to value pension and other postretirement benefit plan assets. The Company's pension and other postretirement benefit plan assets did not include any investments measured using Level 3 inputs at December 31, 2013 or 2012. | ||||||||||||||||||||||||
Corporate bonds and U.S. government securities: Corporate bonds and United States government corporation and agency securities are valued at the closing price reported on the markets on which the individual securities are traded, which in general are less active than the markets for common stocks and registered investment companies. | ||||||||||||||||||||||||
Registered investment companies: Registered investment companies, also known as mutual funds, are valued at the closing price reported on the active market on which the individual funds are traded. | ||||||||||||||||||||||||
Commingled funds and 103-12 investment entity: These investments are investment vehicles generally restricted to institutional investors and are valued using the net asset value (NAV) of the fund. The NAV is based on the value of the underlying assets owned by the fund excluding transaction costs, and minus liabilities. The underlying assets are valued at the closing prices reported on the markets on which they are traded. No assets that were valued using a NAV methodology were subject to significant redemption restrictions or unfunded commitments on their valuation dates. | ||||||||||||||||||||||||
The following tables set forth, by level within the fair value hierarchy, qualified pension and other postretirement benefit plan assets at fair value as of December 31, 2013 and 2012: | ||||||||||||||||||||||||
Investments at Fair Value | ||||||||||||||||||||||||
December 31, 2013 | ||||||||||||||||||||||||
Level 1 | Level 2 | Total | ||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Corporate bonds | $ | — | $ | 1.7 | $ | 1.7 | ||||||||||||||||||
U.S. government securities | — | 1.6 | 1.6 | |||||||||||||||||||||
Registered investment companies: | ||||||||||||||||||||||||
Fixed income funds | 110.7 | — | 110.7 | |||||||||||||||||||||
Inflation protection fund | 29.4 | — | 29.4 | |||||||||||||||||||||
Domestic equity fund | 2 | — | 2 | |||||||||||||||||||||
Commingled funds: | ||||||||||||||||||||||||
Cash equivalent funds | — | 3.5 | 3.5 | |||||||||||||||||||||
Domestic equity index fund | — | 256.2 | 256.2 | |||||||||||||||||||||
Foreign equity growth fund | — | 42.9 | 42.9 | |||||||||||||||||||||
Foreign equity index funds | — | 76 | 76 | |||||||||||||||||||||
Corporate debt funds | — | 72.1 | 72.1 | |||||||||||||||||||||
Inflation protection fund | — | 28.8 | 28.8 | |||||||||||||||||||||
Foreign equity growth 103-12 investment entity | — | 47.1 | 47.1 | |||||||||||||||||||||
Total | $ | 142.1 | $ | 529.9 | $ | 672 | ||||||||||||||||||
Investments at Fair Value | ||||||||||||||||||||||||
December 31, 2012 | ||||||||||||||||||||||||
Level 1 | Level 2 | Total | ||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Corporate bonds | $ | — | $ | 1.9 | $ | 1.9 | ||||||||||||||||||
U.S. government securities | — | 2 | 2 | |||||||||||||||||||||
Registered investment companies: | ||||||||||||||||||||||||
Fixed income funds | 79.2 | — | 79.2 | |||||||||||||||||||||
Inflation protection fund | 25.5 | — | 25.5 | |||||||||||||||||||||
Domestic equity fund | 1.9 | — | 1.9 | |||||||||||||||||||||
Commingled funds: | ||||||||||||||||||||||||
Cash equivalent funds | — | 20.8 | 20.8 | |||||||||||||||||||||
Domestic equity index fund | — | 185.9 | 185.9 | |||||||||||||||||||||
Foreign equity growth fund | — | 37.3 | 37.3 | |||||||||||||||||||||
Foreign equity index funds | — | 60.1 | 60.1 | |||||||||||||||||||||
Corporate debt funds | — | 72.8 | 72.8 | |||||||||||||||||||||
Inflation protection fund | — | 24.5 | 24.5 | |||||||||||||||||||||
Foreign equity growth 103-12 investment entity | — | 36.5 | 36.5 | |||||||||||||||||||||
Total | $ | 106.6 | $ | 441.8 | $ | 548.4 | ||||||||||||||||||
Pension plan benefits are based on the employee's age at retirement, years of service and highest earnings during 72 consecutive semimonthly pay periods in the last 10 years of employment. Postretirement health-care and life insurance benefits are provided only to employees hired before January 1, 1997. The Company pays a portion of the costs of health-care benefits determined by an employee's years of service and generally limited to 170% of the 1992 contribution for employees who retired after January 1, 1993. The Company amortized its transition obligation over a 20-year period that began in 1992 and ended in 2012. | ||||||||||||||||||||||||
The qualified pension projected benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 4.9 | % | 4.2 | % | ||||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | ||||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | ||||||||||||||||||||||
The nonqualified pension projected benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 3.3 | % | 2.4 | % | ||||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | ||||||||||||||||||||||
The postretirement accumulated benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 4.7 | % | 4 | % | ||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | ||||||||||||||||||||||
Health-care inflation rate | 8 | 8.5 | ||||||||||||||||||||||
decreasing to | decreasing to | |||||||||||||||||||||||
4.5 | % | by | 2021 | 4.5 | % | by | 2021 | |||||||||||||||||
Questar does not expect any plan assets to be returned during 2014. The qualified and nonqualified pension plan accumulated benefit obligation totaled $597.8 million at December 31, 2013. Plan obligations and fair value of all plan assets are shown in the following table: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2013 | 2012 | |||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Change in benefit obligation | ||||||||||||||||||||||||
Benefit obligation at beginning of year | $ | 760.3 | $ | 646.9 | $ | 94.4 | $ | 88.7 | ||||||||||||||||
Service cost | 13.9 | 13.2 | 0.7 | 0.7 | ||||||||||||||||||||
Interest cost | 30.6 | 31.1 | 3.7 | 3.8 | ||||||||||||||||||||
Change in plan assumptions | (73.6 | ) | 69 | (8.6 | ) | 7.3 | ||||||||||||||||||
Actuarial (gain) loss | (7.7 | ) | 18.2 | (0.5 | ) | (1.0 | ) | |||||||||||||||||
Benefits paid | (20.8 | ) | (18.1 | ) | (3.4 | ) | (5.1 | ) | ||||||||||||||||
Benefit obligation at end of year | 702.7 | 760.3 | 86.3 | 94.4 | ||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||
Fair value of plan assets at beginning of year | 510.8 | 390 | 37.6 | 34 | ||||||||||||||||||||
Actual gain on plan assets | 80.2 | 59.3 | 5.8 | 4.6 | ||||||||||||||||||||
Company contributions to the plan | 58 | 79.6 | 3.8 | 4.1 | ||||||||||||||||||||
Benefits paid | (20.8 | ) | (18.1 | ) | (3.4 | ) | (5.1 | ) | ||||||||||||||||
Fair value of plan assets at end of year | 628.2 | 510.8 | 43.8 | 37.6 | ||||||||||||||||||||
Underfunded status (current and long-term) | $ | (74.5 | ) | $ | (249.5 | ) | $ | (42.5 | ) | $ | (56.8 | ) | ||||||||||||
The projected 2014 qualified pension plan funding is $18.0 million. Estimated benefit plan payments for the five years following 2013 and the subsequent five years aggregated are as follows: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Years Ending December 31, | ||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
2014 | $ | 26.7 | $ | 4.6 | ||||||||||||||||||||
2015 | 35.9 | 4.8 | ||||||||||||||||||||||
2016 | 27.9 | 4.9 | ||||||||||||||||||||||
2017 | 28.7 | 5.1 | ||||||||||||||||||||||
2018 | 31.1 | 5.2 | ||||||||||||||||||||||
2019 through 2023 | 195.7 | 27.4 | ||||||||||||||||||||||
The components of the net pension and other postretirement benefit costs are as follows. The net pension cost includes both the qualified and nonqualified pension plans. | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2011 | 2013 | 2012 | 2011 | |||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Service cost | $ | 13.9 | $ | 13.2 | $ | 9.3 | $ | 0.7 | $ | 0.7 | $ | 0.5 | ||||||||||||
Interest cost | 30.6 | 31.1 | 28.5 | 3.7 | 3.8 | 4.2 | ||||||||||||||||||
Expected return on plan assets | (38.1 | ) | (31.8 | ) | (26.0 | ) | (2.6 | ) | (2.3 | ) | (2.6 | ) | ||||||||||||
Prior service and other costs | 1.1 | 1.1 | 1.1 | — | 1.6 | 1.9 | ||||||||||||||||||
Recognized net actuarial loss | 28.9 | 24.9 | 12.1 | 3 | 2.5 | 0.3 | ||||||||||||||||||
Curtailment charges | — | — | 0.8 | — | — | — | ||||||||||||||||||
Accretion of regulatory liability | — | — | — | 0.5 | 0.3 | 0.5 | ||||||||||||||||||
Net periodic cost | $ | 36.4 | $ | 38.5 | $ | 25.8 | $ | 5.3 | $ | 6.6 | $ | 4.8 | ||||||||||||
Assumptions at January 1, used to calculate the qualified net pension cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 4.2 | % | 4.8 | % | 5.75 | % | ||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | 4 | |||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | 7.25 | |||||||||||||||||||||
Assumptions at January 1, used to calculate the nonqualified net pension cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 2.4 | % | 3.3 | % | 5.75 | % | ||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | 4 | |||||||||||||||||||||
Assumptions at January 1, used to calculate the net postretirement benefit cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 4 | % | 4.4 | % | 5.75 | % | ||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | 7.25 | |||||||||||||||||||||
Health-care inflation rate | 8.5 | 7 | 8 | |||||||||||||||||||||
decreasing to | decreasing to | decreasing to | ||||||||||||||||||||||
4.5 | % | by | 2021 | 5 | % | by | 2014 | 5 | % | by | 2014 | |||||||||||||
The 2014 estimated qualified and nonqualified net pension cost is $19.1 million. In 2014, $15.7 million of estimated net actuarial loss and $0.6 million of prior service cost for the pension plans will be amortized from AOCI. The 2014 estimated net postretirement benefit cost is $2.8 million, excluding amortization of a regulatory liability. In 2014, $1.2 million of estimated net actuarial loss for the postretirement benefit plans will be amortized from AOCI. | ||||||||||||||||||||||||
Service costs and interest costs are sensitive to changes in the health-care inflation rate. A 1% increase in the health-care inflation rate would cause a minimal increase in the yearly service and interest costs and would increase the postretirement accumulated benefit obligation by $0.8 million. A 1% decrease in the health-care inflation rate would cause a minimal decrease in the yearly service and interest costs and would decrease the postretirement accumulated benefit obligation by $0.7 million. | ||||||||||||||||||||||||
Questar Gas and Questar Pipeline participate in Questar's qualified and nonqualified pension plans as well as its postretirement medical and life plans. Questar Gas's and Questar Pipeline's pension plan and postretirement medical and life insurance assets and benefit obligations cannot be separately determined because plan assets are not segregated or restricted to meet the companies' pension and postretirement medical and life obligations. If the companies were to withdraw from the plans, the pension and other postretirement obligations for Questar Gas and Questar Pipeline employees would be retained by the Questar plans. Pension and other postretirement benefit net cost and plan contribution information for Questar Gas and Questar Pipeline are shown below: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2011 | 2013 | 2012 | 2011 | |||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Questar Gas | ||||||||||||||||||||||||
Net periodic cost | $ | 18.1 | $ | 19.7 | $ | 13.4 | $ | 2.4 | $ | 3.3 | $ | 2.3 | ||||||||||||
Share of total plan contributions | 29.6 | 39.4 | 27.1 | 2 | 1.9 | 2.2 | ||||||||||||||||||
Questar Pipeline | ||||||||||||||||||||||||
Net periodic cost | $ | 6.7 | $ | 7.4 | $ | 5 | $ | 0.2 | $ | 1.2 | $ | 1 | ||||||||||||
Share of total plan contributions | 11.2 | 15.1 | 8.7 | 0.7 | 0.6 | 0.2 | ||||||||||||||||||
Employee Investment Plan | ||||||||||||||||||||||||
The Employee Investment Plan (EIP) is a defined contribution pension plan that allows eligible employees to purchase shares of Questar common stock or other investments through payroll deduction at the fair market value on the transaction date. The Company currently contributes an overall match of 100% of employees' purchases up to a maximum of 6% of their qualifying earnings. To satisfy employee purchases of Questar stock, the EIP trustee may purchase Questar shares on the open market with cash received or Questar may issue new shares. The Company recognizes expense equal to its yearly matching contributions. Questar's expense amounted to $7.2 million in 2013, $7.3 million in 2012, and $7.0 million in 2011. | ||||||||||||||||||||||||
Questar Gas's EIP expense equaled its matching contribution of $3.4 million in 2013, $3.6 million in 2012 and $3.4 million in 2011. Questar Pipeline's EIP expense equaled its matching contribution of $1.4 million in 2013, 2012 and 2011. |
Operations_by_Line_of_Business
Operations by Line of Business (Notes) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Segment Reporting [Abstract] | ' | |||||||||||||||||||||||
Operations by Line of Business | ' | |||||||||||||||||||||||
Note 14 - Operations by Line of Business | ||||||||||||||||||||||||
Questar's three principal complementary lines of business include Questar Gas, which provides retail natural gas distribution in Utah, Wyoming and Idaho; Wexpro, which develops and produces natural gas for Questar Gas customers; and Questar Pipeline, which operates interstate natural gas pipelines and storage facilities and provides other energy services. Line-of-business information is presented according to senior management's basis for evaluating performance and considering differences in the nature of products, services and regulation, among other factors. The following is a summary of operations by line of business for the three years ended December 31, 2013: | ||||||||||||||||||||||||
Questar | Interco. | Questar | Wexpro | Questar | Corp and Other | |||||||||||||||||||
Consol. | Trans. | Gas | Pipeline | |||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
2013 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,220.00 | $ | — | $ | 985.2 | $ | 45.1 | $ | 189.5 | $ | 0.2 | ||||||||||||
From affiliated companies | — | (372.1 | ) | 0.6 | 294.8 | 76.7 | — | |||||||||||||||||
Total Revenues | 1,220.00 | (372.1 | ) | 985.8 | 339.9 | 266.2 | 0.2 | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 285.9 | (370.9 | ) | 650.6 | — | 6.1 | 0.1 | |||||||||||||||||
Operating and maintenance | 174.3 | — | 113.1 | 28.6 | 32.5 | 0.1 | ||||||||||||||||||
General and administrative | 121 | (0.6 | ) | 52.5 | 28.7 | 46.7 | (6.3 | ) | ||||||||||||||||
Production and other taxes | 57.4 | — | 18 | 28.3 | 9.3 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 194.8 | — | 49.7 | 85.8 | 55.5 | 3.8 | ||||||||||||||||||
Asset impairment | 80.6 | — | — | — | 80.6 | — | ||||||||||||||||||
Other operating expenses | — | (0.6 | ) | — | 0.6 | — | — | |||||||||||||||||
Total Operating Expenses | 914 | (372.1 | ) | 883.9 | 172 | 230.7 | (0.5 | ) | ||||||||||||||||
Net loss from asset sales | (0.2 | ) | — | — | (0.2 | ) | — | — | ||||||||||||||||
Operating Income | 305.8 | — | 101.9 | 167.7 | 35.5 | 0.7 | ||||||||||||||||||
Interest and other income (expense) | 9.9 | (0.7 | ) | 5.1 | 5 | 1.8 | (1.3 | ) | ||||||||||||||||
Income from unconsolidated affiliate | 3.7 | — | — | — | 3.7 | — | ||||||||||||||||||
Interest expense | (56.9 | ) | 0.7 | (22.3 | ) | (0.1 | ) | (25.8 | ) | (9.4 | ) | |||||||||||||
Income taxes | (101.3 | ) | — | (31.9 | ) | (62.0 | ) | (7.0 | ) | (0.4 | ) | |||||||||||||
Net Income (Loss) | $ | 161.2 | $ | — | $ | 52.8 | $ | 110.6 | $ | 8.2 | $ | (10.4 | ) | |||||||||||
Identifiable assets | $ | 4,054.30 | $ | — | $ | 1,762.00 | $ | 993.8 | $ | 1,222.80 | $ | 75.7 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 25.6 | — | — | — | 25.6 | — | ||||||||||||||||||
Cash capital expenditures including acquisitions | 503.7 | — | 166.2 | 249.5 | 73.4 | 14.6 | ||||||||||||||||||
Accrued capital expenditures including acquisitions | 505.6 | — | 177.3 | 240.7 | 70 | 17.6 | ||||||||||||||||||
2012 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,098.90 | $ | — | $ | 859.7 | $ | 36.1 | $ | 203.1 | $ | — | ||||||||||||
From affiliated companies | — | (351.0 | ) | 2.5 | 274.1 | 74.4 | — | |||||||||||||||||
Total Revenues | 1,098.90 | (351.0 | ) | 862.2 | 310.2 | 277.5 | — | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 192.3 | (347.7 | ) | 533.3 | — | 6.7 | — | |||||||||||||||||
Operating and maintenance | 180.8 | (0.2 | ) | 119 | 26.8 | 35.2 | — | |||||||||||||||||
General and administrative | 120.8 | (0.6 | ) | 51.2 | 26.8 | 50 | (6.6 | ) | ||||||||||||||||
Retirement incentive | 4.9 | — | 2.4 | 0.2 | 0.9 | 1.4 | ||||||||||||||||||
Production and other taxes | 47.9 | — | 16.2 | 20.8 | 9.1 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 181.6 | — | 47.2 | 77.4 | 54.3 | 2.7 | ||||||||||||||||||
Other operating expenses | — | (2.5 | ) | — | 2.5 | — | — | |||||||||||||||||
Total Operating Expenses | 728.3 | (351.0 | ) | 769.3 | 154.5 | 156.2 | (0.7 | ) | ||||||||||||||||
Net gain from asset sales | 5.1 | — | — | 2.4 | 2.7 | — | ||||||||||||||||||
Operating Income | 375.7 | — | 92.9 | 158.1 | 124 | 0.7 | ||||||||||||||||||
Interest and other income (expense) | 7 | (0.7 | ) | 5.5 | 2.8 | 0.6 | (1.2 | ) | ||||||||||||||||
Income from unconsolidated affiliate | 3.7 | — | — | — | 3.7 | — | ||||||||||||||||||
Interest expense | (57.9 | ) | 0.7 | (24.1 | ) | — | (26.3 | ) | (8.2 | ) | ||||||||||||||
Income taxes | (116.5 | ) | — | (27.2 | ) | (57.0 | ) | (37.3 | ) | 5 | ||||||||||||||
Net Income (Loss) | $ | 212 | $ | — | $ | 47.1 | $ | 103.9 | $ | 64.7 | $ | (3.7 | ) | |||||||||||
Identifiable assets | $ | 3,803.30 | $ | — | $ | 1,593.50 | $ | 836.1 | $ | 1,298.90 | $ | 74.8 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 26.5 | — | — | — | 26.5 | — | ||||||||||||||||||
Cash capital expenditures | 370.7 | — | 162.1 | 144.5 | 60.6 | 3.5 | ||||||||||||||||||
Accrued capital expenditures | 366.3 | — | 161.2 | 145.5 | 58.6 | 1 | ||||||||||||||||||
2011 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,194.40 | $ | — | $ | 965.5 | $ | 31.5 | $ | 197.4 | $ | — | ||||||||||||
From affiliated companies | — | (331.3 | ) | 3.3 | 253.6 | 74.4 | — | |||||||||||||||||
Total Revenues | 1,194.40 | (331.3 | ) | 968.8 | 285.1 | 271.8 | — | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 321.5 | (327.3 | ) | 645.7 | — | 3.1 | — | |||||||||||||||||
Operating and maintenance | 175.9 | (0.2 | ) | 118.5 | 22.3 | 35.3 | — | |||||||||||||||||
General and administrative | 117.9 | (0.5 | ) | 51 | 24.2 | 46.5 | (3.3 | ) | ||||||||||||||||
Production and other taxes | 52.5 | — | 15 | 25.6 | 10.1 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 159.9 | — | 44.5 | 63.9 | 51.2 | 0.3 | ||||||||||||||||||
Other operating expenses | — | (3.3 | ) | — | 3.3 | — | — | |||||||||||||||||
Total Operating Expenses | 827.7 | (331.3 | ) | 874.7 | 139.3 | 146.2 | (1.2 | ) | ||||||||||||||||
Net gain (loss) from asset sales | 0.2 | — | — | (0.1 | ) | 0.3 | — | |||||||||||||||||
Operating Income | 366.9 | — | 94.1 | 145.7 | 125.9 | 1.2 | ||||||||||||||||||
Interest and other income | 10.4 | (0.6 | ) | 5.4 | 4.2 | 0.9 | 0.5 | |||||||||||||||||
Income from unconsolidated affiliate | 3.8 | — | — | — | 3.8 | — | ||||||||||||||||||
Interest expense | (56.8 | ) | 0.6 | (25.9 | ) | — | (24.5 | ) | (7.0 | ) | ||||||||||||||
Income taxes | (116.4 | ) | — | (27.5 | ) | (54.7 | ) | (38.2 | ) | 4 | ||||||||||||||
Net Income (Loss) | $ | 207.9 | $ | — | $ | 46.1 | $ | 95.2 | $ | 67.9 | $ | (1.3 | ) | |||||||||||
Identifiable assets | $ | 3,572.20 | $ | — | $ | 1,483.80 | $ | 768.2 | $ | 1,286.60 | $ | 33.6 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 27.3 | — | — | — | 27.3 | — | ||||||||||||||||||
Cash capital expenditures | 367.7 | — | 121.5 | 136.2 | 104.5 | 5.5 | ||||||||||||||||||
Accrued capital expenditures | 373.9 | — | 127.7 | 144.3 | 93.8 | 8.1 | ||||||||||||||||||
RelatedParty_Transaction_Notes
Related-Party Transaction (Notes) | 12 Months Ended |
Dec. 31, 2013 | |
Related Party Transactions [Abstract] | ' |
Related-Party Transactions | ' |
Note 15 - Related-Party Transactions | |
Questar Gas | |
In 2013 Questar Gas provided technical services to affiliates. In 2012 and 2011 Questar Gas also provided communication services to affiliates. Questar Gas provided these services at its cost and charged $6.7 million in 2013, $13.6 million in 2012 and $14.0 million in 2011. The majority of these costs are allocated. The allocation methods are based on the specific nature of the charges. Management believes that the allocation methods are reasonable. | |
Questar Gas has reserved transportation capacity on Questar Pipeline's system for 916 Mdth per day during the heating season and 841 Mdth per day during off-peak months. Questar Gas periodically releases excess capacity and receives a credit from Questar Pipeline for the released capacity revenues and a portion of Questar Pipeline's interruptible transportation revenues. Questar Gas paid for transportation, storage and processing services provided by Questar Pipeline and a subsidiary amounting to $73.0 million in 2013, $73.6 million in 2012 and $73.7 million in 2011, which included demand charges. The costs of these services were included in the cost of natural gas sold. | |
Under the terms of the Wexpro Agreement, Questar Gas receives a portion of Wexpro's income from oil and NGL operations after recovery of Wexpro's operating expenses and a return on investment. This amount, which is included in revenues and reduces amounts billed to gas distribution customers, was $0.6 million in 2013, $2.5 million in 2012 and $3.3 million in 2011. The amounts that Questar Gas paid Wexpro for the operation of cost-of-service gas properties were $294.6 million in 2013, $274.0 million in 2012 and $253.4 million in 2011. Questar Gas reports these amounts in the cost of natural gas sold. | |
Questar Gas had a lease with an affiliate for space in an office building located in Salt Lake City, Utah, which expired on April 30, 2012. Rent expense was $0.4 million in 2012 and $1.1 million in 2011. | |
Questar charged Questar Gas for certain administrative functions amounting to $48.4 million in 2013, $49.3 million in 2012 and $47.4 million in 2011. These costs are included in operating expenses and are generally allocated based on each affiliated company's proportional share of revenues less product costs; property, plant and equipment; and labor costs. Management believes that the allocation method is reasonable. | |
Questar Pipeline charged Questar Gas for communication services amounting to $3.7 million in 2013. These costs are included in operating expenses and are allocated based on usage. | |
Questar Gas borrowed cash from Questar and incurred interest expense of $0.5 million in 2013, $0.6 million in 2012 and $0.3 million in 2011. | |
Questar Pipeline | |
Questar Pipeline receives a substantial portion of its revenues from Questar Gas. Total revenues received from Questar Gas were $76.3 million in 2013, $74.0 million in 2012 and $74.1 million in 2011. | |
Beginning in 2013, Questar Pipeline provided communication services to affiliates. Questar Pipeline provided these services at its cost and charged $4.9 million in 2013. The majority of these costs are allocated based on usage. | |
In 2013 Questar Gas provided technical services to Questar Pipeline. In 2012 and 2011, Questar Gas also provided communication services to Questar Pipeline. Questar Gas provided these services at its cost of $3.5 million in 2013, $8.8 million in 2012 and $9.6 million in 2011. The majority of these costs are allocated and included in operating expenses. The allocation methods are based on the specific nature of the charges. Management believes that the allocation methods are reasonable. | |
Questar charged Questar Pipeline for certain administrative functions amounting to $28.2 million in 2013, $24.5 million in 2012 and $22.6 million in 2011. These costs are included in operating expenses and are generally allocated based on each affiliate's proportional share of revenues less product costs; property, plant and equipment; and labor costs. Management believes that the allocation method is reasonable. | |
Questar Pipeline had a lease with an affiliate for space in an office building located in Salt Lake City, Utah, which expired on April 30, 2012. Rent expense was $0.3 million in 2012 and $0.9 million in 2011. | |
Questar Pipeline loaned excess funds to Questar and earned interest income of $0.2 million in 2013 and $0.1 million in 2012 and 2011. Questar Pipeline borrowed cash from Questar and incurred interest expense of $0.1 million in 2011. |
Strategic_Review_of_Questar_So
Strategic Review of Questar Southern Trails Pipeline and Impairment of Eastern Segment (Notes) | 12 Months Ended |
Dec. 31, 2013 | |
Strategic Review of Southern Trails Pipeline and Impairment of Eastern Segment [Abstract] | ' |
Strategic Review of Questar Southern Trails Pipeline [Text Block] | ' |
Note 16 - Strategic Review of Questar Southern Trails Pipeline and Impairment of Eastern Segment | |
In the fourth quarter of 2012, Questar Pipeline initiated a strategic review of the noncore Questar Southern Trails Pipeline. All strategic options were analyzed, including joint ventures, asset sales and other alternatives. The eastern segment of Southern Trails Pipeline is in natural gas service and extends 487 miles from the San Juan Basin in New Mexico to connections with other pipelines in the eastern portion of Southern California. The western segment of Southern Trails Pipeline extends 96 miles from Whitewater to Long Beach, California. This segment has not been placed in service. | |
As a result of that review, Questar Pipeline entered into an agreement with an affiliate of Spectra Energy Corp to evaluate and potentially recommission the western portion of its Southern Trails Pipeline to its original purpose as a crude oil transport pipeline and to develop a rail terminal to offload crude into the pipeline for transportation to refineries in Southern California. Questar Pipeline's net book value of the western segment of Southern Trails Pipeline is approximately $22 million. This project is in the marketing and engineering phase and a decision whether or not to proceed with the development is expected in 2014. Questar Pipeline evaluated this asset for impairment in 2013 and does not believe that it is impaired. | |
During the third quarter of 2013, Questar Pipeline updated its five-year forecast for the eastern segment of Southern Trails Pipeline, which resulted in revised projections of higher operating expenses including right-of-way and pipeline safety costs. Current and projected market rates for natural gas transportation between the San Juan Basin and California markets did not cover these increasing operating expenses over the forecast period. Because of changes in expected cash flows in the third quarter of 2013 and the lack of progress in selling or recontracting this pipeline, Questar Pipeline recorded a noncash impairment of its entire investment in the eastern segment of Southern Trails Pipeline of $80.6 million, or $52.4 million after income taxes. Questar Pipeline used a probability-weighted discounted cash flow analysis that included significant inputs such as Questar Pipeline's cost of capital and assumptions regarding future transportation rates and operating costs. |
Wexpro_Acquisition_of_Producin
Wexpro Acquisition of Producing Properties (Notes) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Wexpro Acquisition of Producing Properties [Abstract] | ' | |||
Wexpro Acquisition of Producing Properties | ' | |||
Note 17 - Wexpro Acquisition of Producing Properties | ||||
On September 4, 2013, Wexpro completed the transaction announced in July 2013 to acquire an additional interest in natural gas-producing properties in the Trail Unit of southwestern Wyoming's Vermillion Basin. This is a “bolt-on” acquisition to the company’s current Trail assets, which are governed by the 1981 Wexpro Agreement. In January 2014, the PSCU and PSCW approved the inclusion of these properties in the Wexpro II Agreement. | ||||
Because it contains producing properties, the Trail acquisition is accounted for under the accounting guidance for business combinations. Summary information related to the Trail acquisition is shown in the table below. Amounts reflect routine post-closing adjustments to the purchase price recorded in the fourth quarter of 2013. | ||||
(in millions) | ||||
Fair value of consideration transferred: | ||||
Net cash paid, after post-closing adjustments | $ | 104.3 | ||
Recognized amounts of identifiable assets acquired and liabilities assumed, at fair value: | ||||
Proved properties | $ | 106.4 | ||
Asset retirement obligations | (2.1 | ) | ||
Total fair value of identifiable net assets acquired | $ | 104.3 | ||
Revenues of $6.0 million and net income of $1.3 million attributable to the Trail acquisition are included in Questar's Consolidated Statements of Income for the period between the September 4, 2013 closing date and December 31, 2013. Trail acquisition-related transaction costs of $0.3 million for 2013 are included in general and administrative expense on Questar's Consolidated Statement of Income. Supplemental pro forma income information related to the Trail acquisition is not presented because it is immaterial to Questar's consolidated revenues, expenses and income in all periods presented. | ||||
Quarterly_Financial_Informatio
Quarterly Financial Information - Unaudited (Notes) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Selected Quarterly Financial Information [Abstract] | ' | |||||||||||||||||||
Quarterly Financial Information (Unaudited) | ' | |||||||||||||||||||
Note 18 - Quarterly Financial Information (Unaudited) | ||||||||||||||||||||
Following is a summary of unaudited quarterly financial information: | ||||||||||||||||||||
First | Second | Third | Fourth | Year | ||||||||||||||||
Quarter | Quarter | Quarter | Quarter | |||||||||||||||||
(in millions, except per-share amounts) | ||||||||||||||||||||
2013 | ||||||||||||||||||||
Revenues | $ | 476.9 | $ | 195.6 | $ | 149.6 | $ | 397.9 | $ | 1,220.00 | ||||||||||
Operating income (loss) | 131.4 | 71.2 | (19.4 | ) | 122.6 | 305.8 | ||||||||||||||
Net income (loss) | 72.9 | 39.4 | (19.2 | ) | 68.1 | 161.2 | ||||||||||||||
Asset impairment charge, before income taxes | — | — | 80.6 | — | 80.6 | |||||||||||||||
Basic earnings (loss) per common share | $ | 0.42 | $ | 0.22 | $ | (0.11 | ) | $ | 0.39 | $ | 0.92 | |||||||||
Diluted earnings (loss) per common share | 0.41 | 0.22 | (0.11 | ) | 0.39 | 0.92 | ||||||||||||||
2012 | ||||||||||||||||||||
Revenues | $ | 425.7 | $ | 188.4 | $ | 141.8 | $ | 343 | $ | 1,098.90 | ||||||||||
Operating income | 130.9 | 72.6 | 63.6 | 108.6 | 375.7 | |||||||||||||||
Net income | 75.2 | 39.2 | 33.8 | 63.8 | 212 | |||||||||||||||
Basic earnings per common share | $ | 0.42 | $ | 0.22 | $ | 0.2 | $ | 0.36 | $ | 1.2 | ||||||||||
Diluted earnings per common share | 0.42 | 0.22 | 0.19 | 0.36 | 1.19 | |||||||||||||||
Supplemental_Gas_and_Oil_Infor
Supplemental Gas and Oil Information - Unaudited (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Extractive Industries [Abstract] | ' | |||||||||||
Supplemental Gas and Oil Information (Unaudited) | ' | |||||||||||
Note 19 - Supplemental Gas and Oil Information (Unaudited) | ||||||||||||
The Company is making the following supplemental disclosures of gas and oil producing activities, in accordance with accounting standards for extractive activities - oil and gas and SEC Regulation S-X. | ||||||||||||
The Company uses the successful efforts accounting method for its cost-of-service gas and oil properties. | ||||||||||||
Cost-of-Service Activities | ||||||||||||
The following information is provided with respect to cost-of-service gas and oil properties managed and developed by Wexpro and governed by the Wexpro Agreement. Information on the standardized measure of future net cash flows has not been included for cost-of-service activities because the operations of and return on investment for such properties are regulated by the Wexpro Agreement. | ||||||||||||
In September 2013, Wexpro completed the Trail acquisition. In January 2014, the PSCU and PSCW approved the inclusion of the Trail acquisition properties in the Wexpro II Agreement. The 2013 supplemental gas and oil information for cost-of-service activities includes this acquisition because the properties are regulated by the Wexpro II Agreement. | ||||||||||||
Capitalized Costs of Cost-of-Service Activities | ||||||||||||
Capitalized costs of cost-of-service gas and oil properties net of the related accumulated depreciation, depletion and amortization are shown below: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Wexpro | $ | 936.6 | $ | 780.4 | ||||||||
Questar Gas | 7.2 | 7.8 | ||||||||||
Total capitalized costs of cost-of-service activities | $ | 943.8 | $ | 788.2 | ||||||||
Costs Incurred for Cost-of-Service Activities | ||||||||||||
The costs incurred for cost-of-service gas and oil development activities are displayed in the table below. The costs incurred to develop proved undeveloped reserves were $106.3 million in 2013, $50.4 million in 2012 and $69.7 million in 2011. | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Property acquisition | ||||||||||||
Unproved | $ | 0.3 | $ | 0.6 | $ | — | ||||||
Proved | 106.4 | — | — | |||||||||
Development | 133.1 | 146.9 | 149.1 | |||||||||
Total costs incurred for cost-of-service activities | $ | 239.8 | $ | 147.5 | $ | 149.1 | ||||||
Results of Operations for Cost-of-Service Activities | ||||||||||||
Following are the results of operations for cost-of-service gas- and oil-producing activities, before corporate overhead and interest expenses: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Revenues | ||||||||||||
From unaffiliated customers | $ | 45.1 | $ | 36.1 | $ | 31.5 | ||||||
From affiliated company(1) | 294.8 | 274.1 | 253.6 | |||||||||
Total revenues | 339.9 | 310.2 | 285.1 | |||||||||
Production costs | 57.5 | 50.1 | 51.2 | |||||||||
Depreciation, depletion and amortization | 85.8 | 77.4 | 63.9 | |||||||||
Total expenses | 143.3 | 127.5 | 115.1 | |||||||||
Revenues less expenses | 196.6 | 182.7 | 170 | |||||||||
Income taxes | (70.5 | ) | (64.8 | ) | (62.0 | ) | ||||||
Results of operations for cost-of-service gas- and oil-producing activities excluding corporate overhead and interest expenses | $ | 126.1 | $ | 117.9 | $ | 108 | ||||||
(1) Primarily represents revenues received from Questar Gas pursuant to the Wexpro Agreement. Revenues include reimbursement of general and administrative expenses amounting to $27.5 million in 2013, $26.5 million in 2012 and $23.5 million in 2011. | ||||||||||||
Estimated Quantities of Cost-of-Service Proved Gas and Oil Reserves | ||||||||||||
Estimates of cost-of-service proved gas and oil reserves have been prepared in accordance with professional engineering standards and the Company's established internal controls. The estimates were prepared by Wexpro's reservoir engineers, individuals who possess professional qualifications and demonstrated competency in reserves estimation and evaluation. Because gas reserves managed, developed and produced by Wexpro are delivered to Questar Gas at cost of service, SEC guidelines with respect to standard economic assumptions are not applicable. The SEC acknowledges this potential circumstance and provides that companies may give appropriate recognition to differences arising because of the effect of the rate-making process. Accordingly, in cases where differences arise because of the effect of the rate-making process, Wexpro uses a minimum-producing rate or maximum well-life limit to determine the ultimate quantity of reserves attributable to each well. | ||||||||||||
The Company annually reviews all proved undeveloped reserves to ensure an appropriate plan for development exists. All proved undeveloped reserves are converted to proved developed reserves within five years of the proved undeveloped reserve booking. At December, 2013, all of the Company's proved undeveloped reserves were scheduled to be developed within five years from the date such locations were initially disclosed as proved undeveloped reserves. Wexpro converted 42% of prior year-end proved undeveloped reserves to developed status in 2013, 15% in 2012 and 19% in 2011. | ||||||||||||
Revisions of prior estimates reflect the addition of new proved undeveloped reserves associated with current five-year development plans, revisions to prior proved undeveloped reserves, revisions to infill drilling development plans, as well as the transfer of proved undeveloped reserves to unproved reserve categories due to changes in development plans. The negative revisions reflected in the 2013 cost-of-service reserve estimates are due in part to an increase in well spacing in the Pinedale field based on 2013 drilling results. | ||||||||||||
In establishing reserves, the SEC allows the use of techniques that have been field tested and demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. In general, the Company uses numerous data elements and analysis techniques in the estimation of proved reserves. These data elements and techniques include, but are not limited to, production tests, well performance data, decline curve analysis, wireline logs, core data, pressure transient analysis, seismic data and interpretation, and material balance calculations. The Company utilizes these reliable technologies to book proved reserves, however, no reserves were recorded from increasing recovery factor estimates or from extending down-dip reservoir limits associated with the use of reliable technology. | ||||||||||||
Wexpro's estimates of proved reserves were made by the Company's engineers and are the responsibility of management. The Company requires that reserve estimates be made by qualified reserves estimators (QREs), as defined by the Society of Petroleum Engineers' standards. The QREs interact with engineering, land, and geoscience personnel to obtain the necessary data for projecting future production, costs, net revenues and ultimate recoverable reserves. Management approves the QREs' reserve estimates annually. All QREs receive ongoing education on the fundamentals of SEC reserves reporting through internal and external training over the policies for estimating and recording reserves in compliance with applicable SEC definitions and guidance. | ||||||||||||
Estimated quantities of cost-of-service proved gas and oil reserves are set forth below: | ||||||||||||
Natural Gas | Oil and NGL | Natural Gas | ||||||||||
Equivalents | ||||||||||||
(Bcf) | (Mbbl) | (Bcfe) | ||||||||||
Proved Reserves | ||||||||||||
Balances at December 31, 2010 | 738.4 | 4,856 | 767.5 | |||||||||
Revisions - previous estimates | (153.9 | ) | (259 | ) | (155.5 | ) | ||||||
Extensions and discoveries | 224.7 | 1,214 | 232 | |||||||||
Production | (50.5 | ) | (467 | ) | (53.3 | ) | ||||||
Balances at December 31, 2011 | 758.7 | 5,344 | 790.7 | |||||||||
Revisions - previous estimates | (158.4 | ) | (122 | ) | (159.0 | ) | ||||||
Extensions and discoveries | 154.4 | 1,612 | 164 | |||||||||
Production | (57.5 | ) | (665 | ) | (61.5 | ) | ||||||
Balances at December 31, 2012 | 697.2 | 6,169 | 734.2 | |||||||||
Revisions - previous estimates | (112.8 | ) | (1,348 | ) | (120.8 | ) | ||||||
Extensions and discoveries | 153.5 | 857 | 158.6 | |||||||||
Purchase of reserves in place | 133.9 | 556 | 137.2 | |||||||||
Production | (60.6 | ) | (617 | ) | (64.3 | ) | ||||||
Balances at December 31, 2013 | 811.2 | 5,617 | 844.9 | |||||||||
Proved Developed Reserves | ||||||||||||
Balances at December 31, 2010 | 463.8 | 3,138 | 482.6 | |||||||||
Balances at December 31, 2011 | 491.2 | 4,420 | 517.7 | |||||||||
Balances at December 31, 2012 | 523.9 | 4,967 | 553.7 | |||||||||
Balances at December 31, 2013 | 560 | 4,384 | 586.3 | |||||||||
Proved Undeveloped Reserves | ||||||||||||
Balances at December 31, 2010 | 274.6 | 1,718 | 284.9 | |||||||||
Balances at December 31, 2011 | 267.5 | 924 | 273 | |||||||||
Balances at December 31, 2012 | 173.3 | 1,202 | 180.5 | |||||||||
Balances at December 31, 2013 | 251.2 | 1,233 | 258.6 | |||||||||
Schedule_of_Valuation_and_Qual
Schedule of Valuation and Qualifying Accounts (Notes) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Valuation and Qualifying Accounts [Abstract] | ' | |||||||||||||||
Schedule of Valuation and Qualifying Accounts | ' | |||||||||||||||
Financial Statement Schedules: | ||||||||||||||||
QUESTAR CORPORATION | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 3.1 | $ | 0.2 | $ | (1.6 | ) | $ | 1.7 | |||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 3.2 | 1.2 | (1.3 | ) | 3.1 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 3.2 | 2.4 | (2.4 | ) | 3.2 | |||||||||||
QUESTAR GAS COMPANY | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 2.8 | $ | 0.2 | $ | (1.6 | ) | $ | 1.4 | |||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 2.9 | 1.1 | (1.2 | ) | 2.8 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 2.9 | 2.4 | (2.4 | ) | 2.9 | |||||||||||
QUESTAR PIPELINE COMPANY | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 0.3 | $ | — | $ | — | $ | 0.3 | ||||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 0.3 | 0.1 | (0.1 | ) | 0.3 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 0.3 | — | — | 0.3 | ||||||||||||
Summary_of_Significant_Account1
Summary of Significant Accounting Policies (Policies) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Accounting Policies [Line Items] | ' | |||||||||||
Nature of Business | ' | |||||||||||
A. Nature of Business | ||||||||||||
Questar Corporation (Questar or the Company) is a Rockies-based integrated natural gas company with three principal complementary and wholly-owned lines of business: | ||||||||||||
• | Questar Gas Company (Questar Gas) provides retail natural gas distribution in Utah, Wyoming and Idaho. | |||||||||||
• | Wexpro Company (Wexpro) develops and produces natural gas from cost-of-service reserves for Questar Gas customers. | |||||||||||
• | Questar Pipeline Company (Questar Pipeline) operates interstate natural gas pipelines and storage facilities in the western United States and provides other energy services. | |||||||||||
Questar is headquartered in Salt Lake City, Utah. Shares of Questar common stock trade on the New York Stock Exchange (NYSE:STR). | ||||||||||||
Principles of Consolidation | ' | |||||||||||
B. Principles of Consolidation | ||||||||||||
The Questar and Questar Pipeline consolidated financial statements contain the accounts of the parent companies and their majority-owned or controlled subsidiaries. The consolidated financial statements were prepared in accordance with U.S. generally accepted accounting principles (GAAP) and with the instructions for Annual Reports on Form 10-K and SEC Regulations S-X and S-K. All significant intercompany accounts and transactions have been eliminated in consolidation. | ||||||||||||
Investment in Unconsolidated Affiliate | ' | |||||||||||
C. Investment in Unconsolidated Affiliate | ||||||||||||
Questar uses the equity method to account for its investment in an unconsolidated affiliate where it does not have control, but has significant influence. The investment in the unconsolidated affiliate on the Company's Consolidated Balance Sheets equals the Company's proportionate share of equity reported by the unconsolidated affiliate. The investment is assessed for possible impairment when events indicate that the fair value of the investment may be below the Company's carrying value. When such a condition is deemed to be other-than-temporary, the carrying value of the investment is written down to its fair value, and the amount of the write-down is included in the determination of net income. | ||||||||||||
White River Hub, LLC, a limited liability company and FERC-regulated transporter of natural gas, is the sole unconsolidated affiliate. Questar Pipeline owns 50% of White River Hub, LLC, and is the operator. | ||||||||||||
Use of Estimates | ' | |||||||||||
D. Use of Estimates | ||||||||||||
The preparation of financial statements and notes in conformity with GAAP requires that management formulate estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities. The Company also incorporates estimates of proved developed and total proved gas and oil reserves in the calculation of depreciation, depletion and amortization rates of its gas and oil properties. Changes in estimated quantities of the Company's reserves could impact its reported financial results as well as disclosures regarding the quantities of proved gas and oil reserves. Actual results could differ from these estimates. | ||||||||||||
Revenue Recognition | ' | |||||||||||
E. Revenue Recognition | ||||||||||||
Questar Gas | ||||||||||||
Questar Gas records revenues in the period that gas is delivered, including gas delivered to residential and commercial customers but not billed as of the end of the accounting period. Unbilled gas deliveries are estimated for the period from the date meters are read to the end of the month. Approximately one-half month of revenue is estimated in any period. Gas costs and other variable costs are recorded on the same basis to ensure proper matching of revenues and expenses. Questar Gas's tariff allows for monthly adjustments to customer bills to approximate the effect of abnormal weather on non-gas revenues. The weather-normalization adjustment significantly reduces the impact of weather on gas-distribution earnings. The PSCU and PSCW approved a CET to promote energy conservation. Under the CET, Questar Gas non-gas revenues are decoupled from the volume of gas used by customers. The tariff specifies an allowed revenue per customer for each month with differences to be deferred and recovered from customers or refunded to customers through periodic rate adjustments. Rate adjustments occur every six months under the CET. The adjustments amortize deferred CET amounts over a 12-month period. These adjustments are limited to 5% of non-gas revenues. | ||||||||||||
Questar Gas allows customers the option of paying an estimated fixed monthly bill throughout the year on a budget-billing program. The estimated payments are adjusted to actual usage annually. Amounts collected from customers under this program in excess of gas deliveries are recorded on the Consolidated Balance Sheets as customer advances. The budget-billing option does not impact revenue recognition. Questar Gas may collect revenues subject to possible refunds and establish reserves pending final orders from regulatory agencies. | ||||||||||||
Wexpro | ||||||||||||
Wexpro recognizes revenues in the period that services are provided or products are delivered. Wexpro recovers its costs and receives an unlevered, after-tax return of approximately 20% on its investment base. In accordance with the Wexpro Agreement, production from the gas properties operated by Wexpro is delivered to Questar Gas at Wexpro's cost of providing this service including a return on Wexpro's investment. Wexpro sells crude oil and NGL production from certain producing properties at market prices with the revenues used to recover operating expenses and to provide Wexpro a return on its investment. Any operating income remaining after recovery of expenses and Wexpro's return on investment is divided between Questar Gas and Wexpro, with Wexpro retaining 46%. Amounts received by Questar Gas from the sharing of Wexpro's oil and NGL income are used to reduce natural gas costs to utility customers. | ||||||||||||
Wexpro's investment base consists of its investment in commercial wells and related facilities and is adjusted for working capital and reduced for deferred income taxes and accumulated depreciation, depletion and amortization. Revenue associated with the sale of gas, oil and NGL is accounted for using the sales method, whereby revenue is recognized as gas, oil and NGL are sold to purchasers. Wexpro may collect revenues subject to possible refunds and establish reserves pending final calculation of the after-tax return on investment, which is adjusted annually. | ||||||||||||
Questar Pipeline | ||||||||||||
Questar Pipeline and subsidiaries recognize revenues in the period that services are provided or products are delivered. The straight-fixed-variable rate design used by Questar Pipeline, which allows for recovery of substantially all fixed costs in the demand or reservation charge, reduces the earnings impact of volume changes on gas transportation and storage operations. Questar Pipeline may collect revenues subject to possible refunds and establish reserves pending final orders from regulatory agencies. | ||||||||||||
Cost of Sales | ' | |||||||||||
F. Cost of Sales | ||||||||||||
Questar Gas obtains the majority of its gas supply from Wexpro's cost-of-service production and pays Wexpro an operator service fee based on the terms of the Wexpro Agreement. Questar Gas also obtains transportation and storage services from Questar Pipeline. These intercompany revenues and expenses are eliminated in the Questar Consolidated Statements of Income by reducing revenues and cost of sales. The underlying costs of Wexpro's production and Questar Pipeline's transportation and storage services are disclosed in other categories in the Consolidated Statements of Income, including operating and maintenance expense and depreciation, depletion and amortization expense. During the second and third quarters of the year, a significant portion of the natural gas from Wexpro production is injected into underground storage. This gas is withdrawn from storage as needed during the heating season in the first and fourth quarters. The cost of natural gas sold is credited with the value of natural gas as it is injected into storage and debited as it is withdrawn from storage. The reported balance in consolidated cost of sales may be a negative amount during the second and third quarters because of the entries to record injection of gas into storage and the elimination of intercompany transactions. | ||||||||||||
Regulation | ' | |||||||||||
G. Regulation | ||||||||||||
The Company applies the regulatory accounting principles to the rate-regulated businesses. Under these principles, the Company records regulatory assets and liabilities that would not be otherwise recorded under GAAP for non-rate-regulated entities. Regulatory assets and liabilities record probable future revenues or expenses associated with certain charges or credits that will be recovered from or refunded to customers through the rate-making process. | ||||||||||||
Questar Gas accounts for purchased-gas costs in accordance with procedures authorized by the PSCU and the PSCW. Purchased-gas costs that are different from those provided for in present rates are accumulated and recovered or credited through future rate changes. Questar Gas may hedge a portion of its natural gas supply to mitigate price fluctuations for gas-distribution customers. The regulatory commissions allow Questar Gas to record periodic mark-to-market adjustments for commodity-price derivatives in the purchased-gas adjustment account. Questar did not have any commodity-price derivatives at December 31, 2013 or 2012. See Note 11 for a description and comparison of regulatory assets and liabilities as of December 31, 2013 and 2012. | ||||||||||||
Wexpro manages and produces cost-of-service reserves for gas utility affiliate Questar Gas under the terms of the Wexpro Agreement, a long-standing comprehensive agreement with the states of Utah and Wyoming (see Note 10). | ||||||||||||
Questar Pipeline is regulated by the FERC. Questar Gas is regulated by the PSCU and the PSCW. The Idaho Public Utilities Commission has contracted with the PSCU for rate oversight of Questar Gas operations in a small area of southeastern Idaho. These regulatory agencies establish rates for the storage, transportation and sale of natural gas. The regulatory agencies also regulate, among other things, the extension and enlargement or abandonment of jurisdictional natural gas facilities. Regulation is intended to permit the recovery, through rates, of the cost of service, including a return on investment. | ||||||||||||
Cash and Cash Equivalents | ' | |||||||||||
H. Cash and Cash Equivalents | ||||||||||||
Cash equivalents consist principally of repurchase agreements with maturities of three months or less. In almost all cases, the repurchase agreements are highly liquid investments in overnight securities made through commercial bank accounts that result in available funds the next business day. | ||||||||||||
Notes Receivable and Notes Payable | ' | |||||||||||
I. Notes Receivable from and Notes Payable to Questar | ||||||||||||
Notes receivable from or payable to Questar appearing in the financial statements and disclosures of Questar Gas and Questar Pipeline represent interest bearing demand notes for cash loaned to or borrowed from Questar until needed in operations. The funds are centrally managed by Questar. Amounts loaned to Questar earn an interest rate that is identical to the interest rate paid by the companies for borrowings from Questar. | ||||||||||||
Property, Plant and Equipment | ' | |||||||||||
J. Property, Plant and Equipment | ||||||||||||
Property, plant and equipment balances are stated at historical cost. Maintenance and repair costs are expensed as incurred. | ||||||||||||
Cost-of-service gas and oil operations | ' | |||||||||||
Cost-of-service gas and oil operations | ||||||||||||
The successful efforts method of accounting is used for cost-of-service reserves developed and produced by Wexpro for gas utility affiliate Questar Gas. Cost-of-service reserves are properties for which the operations and return on investment are subject to the Wexpro Agreement (see Note 10). Under the successful efforts method, Wexpro capitalizes the costs of acquiring leaseholds, drilling development wells, drilling successful exploratory wells, and purchasing related support equipment and facilities. Geological and geophysical studies and other exploratory activities are expensed as incurred. Costs of production and general corporate activities are expensed in the period incurred. A gain or loss is generally recognized on assets as they are retired from service. | ||||||||||||
Contributions-in-aid-of construction | ' | |||||||||||
Contributions in aid of construction | ||||||||||||
Customer contributions in aid of construction reduce plant unless the amounts are refundable to customers. Contributions for main-line extensions may be refundable to customers if additional customers connect to the main-line segment within five years. Refundable contributions are recorded as liabilities until refunded or the five-year period expires without additional customer connections. Amounts not refunded reduce plant. Capital expenditures in the Consolidated Statements of Cash Flows are reported net of non-refundable contributions. | ||||||||||||
Depreciation, depletion and amortization | ' | |||||||||||
Depreciation, depletion and amortization | ||||||||||||
Major categories of fixed assets in gas distribution, transportation and storage operations are grouped together and depreciated using a straight-line method. Gains and losses on asset disposals are recorded as adjustments in accumulated depreciation. The Company has not capitalized future abandonment costs on a majority of its long-lived gas distribution and transportation assets due to a lack of a legal obligation to restore the area surrounding abandoned assets. In these cases, the regulatory agencies have opted to leave retired facilities in the ground undisturbed rather than excavate and dispose of the assets. Depreciation rates for Questar Gas and Questar Pipeline are established through rate proceedings. | ||||||||||||
Capitalized costs of development wells and leaseholds are amortized on a field-by-field basis using the unit-of-production method and the estimated proved developed or total proved gas and oil reserves. Oil and NGL volumes are converted to natural gas equivalents using the ratio of one barrel of crude oil, condensate or NGL to 6,000 cubic feet of natural gas. The Company capitalizes an estimate of the fair value of future abandonment costs associated with cost-of-service reserves and depreciates these costs using a unit-of-production method. | ||||||||||||
The following represent average depreciation, depletion and amortization rates of the Company's capitalized costs: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Questar Gas distribution plant | 2.7 | % | 2.8 | % | 2.8 | % | ||||||
Cost-of-service gas and oil properties, per Mcfe | $ | 1.56 | $ | 1.49 | $ | 1.49 | ||||||
Questar Pipeline transportation, storage and other energy services | 3.4 | % | 3.4 | % | 3.5 | % | ||||||
Questar Gas's depreciation rates include a component for the cost of plant removal. Accordingly, Questar Gas recognizes cost of plant removal as depreciation expense. The related cost of removal accrual is reflected as a regulatory liability on the balance sheet. At the time property, plant and equipment is retired, removal expenses less salvage, are charged to the regulatory cost of plant removal accrual. | ||||||||||||
Impairment of Long-Lived Assets | ' | |||||||||||
K. Impairment of Long-Lived Assets | ||||||||||||
Proved gas and oil properties are evaluated on a field-by-field basis for potential impairment. Other properties are evaluated on a specific-asset basis or in groups of similar assets, as applicable. Impairment is indicated when a triggering event occurs and the sum of the estimated undiscounted future net cash flows of an evaluated asset is less than the asset's carrying value. Triggering events could include, but are not limited to, an impairment of gas and oil reserves caused by mechanical problems, faster-than-expected decline of reserves, lease-ownership issues, other-than-temporary decline in gas and oil prices, and changes in the utilization of pipeline assets. If impairment is indicated, fair value is estimated using a discounted cash flow approach using market interest rates or, if available, other market data. Cash flow estimates require forecasts and assumptions for many years into the future for a variety of factors, including commodity prices, commodity transportation rates and operating costs. Questar Pipeline recorded an $80.6 million pre-tax impairment of the eastern segment of its Southern Trails Pipeline in the third quarter of 2013. See Note 16 for additional details. There were no impairments in 2012 or 2011. | ||||||||||||
Goodwill and Other Intangible Assets | ' | |||||||||||
L. Goodwill and Other Intangible Assets | ||||||||||||
Goodwill represents the excess of the amount paid over the fair value of net assets acquired in a business combination and is not subject to amortization. Goodwill and indefinite-lived intangible assets are tested for impairment at a minimum of once a year or when a triggering event occurs. The Company evaluates whether it is more likely than not that the carrying value of a reporting unit is greater than its fair value using events and circumstances such as economic conditions, industry changes, financial performance, etc. Fair value is measured using actively traded market values of other comparable companies in the same businesses. If the fair value of the reporting unit exceeds its carrying value then goodwill is considered not to be impaired. If the carrying value of the business unit is greater than the fair value, an impairment of goodwill is recognized equal to the excess of carrying amount of goodwill over its fair value. | ||||||||||||
Capitalized Interest and Allowance for Funds Used During Construction | ' | |||||||||||
M. Capitalized Interest and Allowance for Funds Used During Construction | ||||||||||||
The Company capitalizes interest costs when applicable. The FERC, PSCU and PSCW require the capitalization of an allowance for funds used during construction (AFUDC) for rate-regulated plant and equipment. The Wexpro Agreement requires capitalization of AFUDC on cost-of-service gas and oil development projects. | ||||||||||||
Derivative Instruments and Hedging Activities | ' | |||||||||||
N. Derivative Instruments and Hedging Activities | ||||||||||||
The Company may elect to designate a derivative instrument as a hedge of exposure to changes in fair value or cash flows. A derivative instrument qualifies as a hedge if all of the following tests are met: | ||||||||||||
• | The item to be hedged exposes the Company to market risk. | |||||||||||
• | The derivative reduces the risk exposure and is designated as a hedge at the inception of the hedging relationship. | |||||||||||
• | At the inception of the hedge and throughout the hedge period, there is a high correlation between changes in the fair value of the derivative instrument and the fair value of the underlying hedged item. | |||||||||||
If the hedged exposure is a fair value exposure, the gain or loss on the derivative instrument is recognized in earnings in the period of the change together with the offsetting gain or loss from the change in fair value of the hedged item. If the hedged exposure is a cash flow exposure, the effective portion of the gain or loss on the derivative instrument is reported initially as a component of accumulated other comprehensive income (loss) (AOCI) and subsequently reclassified into earnings when the forecasted transaction affects earnings. Any amount excluded from the assessment of hedge effectiveness, as well as the ineffective portion of the gain or loss, is reported currently in earnings. When a derivative instrument is designated as a cash flow hedge of a forecasted transaction that becomes probable of not occurring, the gain or loss on the derivative is immediately reclassified into earnings from AOCI. See Note 6 for further discussion on derivatives and hedging. | ||||||||||||
Credit Risk | ' | |||||||||||
O. Credit Risk | ||||||||||||
The Rocky Mountain region is the Company's primary market area. Exposure to credit risk may be affected by the concentration of customers in this region due to changes in economic or other conditions. Customers include individuals and numerous commercial and industrial enterprises that may react differently to changing conditions. Management believes that its credit-review procedures, loss reserves, customer deposits and collection procedures have adequately provided for usual and customary credit-related losses. Loss reserves are periodically reviewed for adequacy and may be established on a specific-case basis. | ||||||||||||
Bad debt expense associated with accounts receivable amounted to $0.2 million in 2013, $1.2 million in 2012 and $2.4 million in 2011. The allowance for bad debts was $1.7 million at December 31, 2013 and $3.1 million at December 31, 2012. Questar Gas's retail gas operations account for a majority of the bad debt expense. Questar Gas estimates bad debt expense as a percentage of general-service revenues with periodic adjustments. Uncollected accounts are generally written off six months after gas is delivered and interest is no longer accrued. Questar Gas recovers bad debt costs related to the gas-cost portion of rates in its Utah operations through a purchased-gas adjustment to rates. | ||||||||||||
Asset Retirement Obligations | ' | |||||||||||
P. Asset Retirement Obligations | ||||||||||||
Questar records an asset retirement obligation (ARO) when there is a legal obligation associated with the retirement of a tangible long-lived asset. Questar's AROs apply primarily to abandonment costs associated with gas and oil wells, production facilities and certain other properties. The Company has not capitalized future abandonment costs on a majority of its long-lived transportation and distribution assets because the Company does not have a legal obligation to restore the area surrounding abandoned assets. In these cases, the regulatory agencies have opted to leave retired facilities in the ground undisturbed rather than requiring the Company to excavate and dispose of the assets. Cost-of-service gas and oil AROs apply primarily to abandonment costs associated with gas and oil wells and certain other properties. The fair value of retirement costs is estimated by Company personnel based on abandonment costs of similar properties available to field operations and depreciated over the life of the related assets. Revisions to estimates result from material changes in the expected timing or amount of cash flows associated with AROs. Income or expense resulting from the settlement of ARO liabilities is included in net gain (loss) from asset sales on the Consolidated Statements of Income. The ARO liability is adjusted to present value each period through an accretion calculation using a credit-adjusted risk-free interest rate. See Note 4 for further discussion on AROs. | ||||||||||||
Income Taxes | ' | |||||||||||
Q. Income Taxes | ||||||||||||
Questar and its subsidiaries file a consolidated federal income tax return. Questar Gas and Questar Pipeline account for income taxes on a separate return basis and record tax expenses and benefits as they are generated. Questar Gas and Questar Pipeline make payments to Questar or receive payments from Questar for such tax expenses or benefits as they are generated on the consolidated income tax return. Deferred income taxes are recorded for the temporary differences arising between the book and tax carrying amounts of assets and liabilities. These differences create taxable or tax-deductible amounts for future periods. Questar Gas and Questar Pipeline use the deferral method to account for investment tax credits as required by regulatory commissions. The Company records interest earned on income tax refunds in interest and other income and records penalties and interest charged on tax deficiencies in interest expense. | ||||||||||||
Accounting standards for income taxes specify the accounting for uncertainty in income taxes by prescribing a minimum recognition threshold for a tax position to be reflected in the financial statements. If recognized, the tax benefit is measured as the largest amount of tax benefit that is more-likely-than-not to be realized upon ultimate settlement. Management has considered the amounts and the probabilities of the outcomes that could be realized upon ultimate settlement and believes that it is more-likely-than-not that the Company's recorded income tax benefits will be fully realized. There were no unrecognized tax benefits at the beginning or at the end of the years ended December 31, 2013, 2012 or 2011. The federal income tax return for 2012 is under examination by the Internal Revenue Service (IRS). The 2013 federal income tax return has not been filed. | ||||||||||||
For tax year 2012, Questar was in the IRS's Compliance Assurance Process (CAP). For the 2013 and 2014 tax years, Questar was accepted into the CAP Maintenance program. The CAP employs real-time resolution to improve federal tax compliance by resolving all or most tax positions prior to filing the related tax return. Successful conclusion of the CAP allows the IRS to achieve an acceptable level of assurance regarding the accuracy of the taxpayer's filed tax return and to eliminate or substantially reduce the need for a traditional examination. The CAP Maintenance program is administered by the IRS and indicates that the Company is a compliant taxpayer. | ||||||||||||
Current federal tax statutes allow taxpayers a deduction of bonus depreciation related to capital expenditures of 100% in 2011 and 50% in 2012 and 2013. The effects of bonus depreciation and other significant book/tax timing differences resulted in a net operating loss (NOL) carryforward for federal income tax purposes in 2012 of $30.0 million. Questar's estimated taxable income for 2013 is $153.8 million. The NOL carryforward from 2012 of $30.0 million is expected to be utilized on the 2013 federal income tax return. See Note 8 for further discussion on income taxes. | ||||||||||||
Earnings Per Share | ' | |||||||||||
R. Earnings Per Share | ||||||||||||
Basic earnings per share (EPS) is computed by dividing net income by the weighted-average number of common shares outstanding during the reporting period, which includes vested undistributed restricted stock units (RSUs). Diluted EPS includes the potential increase in the number of outstanding shares that could result from the exercise of in-the-money stock options, the vesting of RSUs with forfeitable dividends and the distribution of performance shares that are part of the Company's Long-term Stock Incentive Plan (LTSIP), less shares repurchased under the treasury stock method. See Note 2 for further discussion on EPS. | ||||||||||||
Share-Based Compensation | ' | |||||||||||
S. Share-Based Compensation | ||||||||||||
Questar may issue stock options, restricted shares, RSUs and performance shares to certain officers, employees and non-employee directors under its LTSIP. The Company uses the Black-Scholes-Merton mathematical model in estimating the fair value of stock options and the Monte Carlo simulation method in estimating the fair value of performance shares for accounting purposes. The granting of restricted shares and RSUs results in recognition of compensation cost measured at the grant-date market price. Questar uses an accelerated method in recognizing share-based compensation costs with graded vesting periods. See Note 12 for further discussion on share-based compensation. | ||||||||||||
Comprehensive Income | ' | |||||||||||
T. Comprehensive Income | ||||||||||||
Beginning in 2012, the Company and its subsidiaries adopted accounting guidance issued in June 2011 that resulted in the addition of statements of comprehensive income to the primary financial statements. Beginning in 2013, the Company and its subsidiaries adopted accounting guidance issued in February 2013 that requires additional disclosures about reclassifications out of AOCI. | ||||||||||||
Comprehensive income, as reported on Questar's Consolidated Statements of Comprehensive Income, is the sum of net income as reported on the Questar Consolidated Statements of Income and net other comprehensive income (loss) (OCI) as reported on the Questar Consolidated Statements of Common Shareholders' Equity. OCI includes recognition of the under-funded position of pension and other postretirement benefit plans, interest rate cash flow hedges, changes in the fair value of long-term investment, and the related income taxes. Income or loss is recognized when the pension or other postretirement benefit (OPRB) costs are accrued, as the Company records interest expense for hedged interest payments and when the long-term investment is sold or otherwise realized. | ||||||||||||
Comprehensive income, as reported on Questar Pipeline's Consolidated Statements of Comprehensive Income, is the sum of net income as reported on the Questar Pipeline Consolidated Statements of Income and net OCI as reported on the Questar Pipeline Consolidated Statements of Common Shareholder's Equity. OCI includes interest rate cash flow hedges and the related income taxes. Income or loss is recognized as the company records interest expense for hedged interest payments. See Note 3 for additional information related to OCI and AOCI. | ||||||||||||
Business Segments | ' | |||||||||||
U. Business Segments | ||||||||||||
Line of business information is presented according to senior management's basis for evaluating performance considering differences in the nature of products, services and regulation, among other factors. Certain intersegment sales include intercompany profit. | ||||||||||||
Reclassifications | ' | |||||||||||
V. Reclassifications | ||||||||||||
Certain reclassifications were made to prior year financial statements and notes to conform to the 2013 presentation. |
Summary_of_Significant_Account2
Summary of Significant Accounting Policies (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Accounting Policies [Line Items] | ' | |||||||||||
Cost of sales detail | ' | |||||||||||
The details of Questar's consolidated cost of sales are as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Questar Gas | ||||||||||||
Gas purchases | $ | 186.6 | $ | 104.2 | $ | 221.2 | ||||||
Operator service fee | 294.6 | 274 | 253.4 | |||||||||
Transportation and storage | 80.1 | 79.6 | 78.4 | |||||||||
Gathering | 18.8 | 20.5 | 25 | |||||||||
Royalties | 44.3 | 32 | 38.9 | |||||||||
Storage (injection) withdrawal, net | (0.8 | ) | 1.9 | 3 | ||||||||
Purchased-gas account adjustment | 22 | 16.1 | 20.6 | |||||||||
Other | 5 | 5 | 5.2 | |||||||||
Total Questar Gas cost of natural gas sold | 650.6 | 533.3 | 645.7 | |||||||||
Elimination of Questar Gas cost of natural gas sold - affiliated parties | (370.9 | ) | (347.7 | ) | (327.3 | ) | ||||||
Total Questar Gas cost of natural gas sold - unaffiliated parties | 279.7 | 185.6 | 318.4 | |||||||||
Questar Pipeline | ||||||||||||
Total Questar Pipeline cost of sales | 6.1 | 6.7 | 3.1 | |||||||||
Other cost of sales | 0.1 | — | — | |||||||||
Total cost of sales | $ | 285.9 | $ | 192.3 | $ | 321.5 | ||||||
Average depreciation, depletion and amortization rates of the Company's capitalized costs | ' | |||||||||||
The following represent average depreciation, depletion and amortization rates of the Company's capitalized costs: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Questar Gas distribution plant | 2.7 | % | 2.8 | % | 2.8 | % | ||||||
Cost-of-service gas and oil properties, per Mcfe | $ | 1.56 | $ | 1.49 | $ | 1.49 | ||||||
Questar Pipeline transportation, storage and other energy services | 3.4 | % | 3.4 | % | 3.5 | % | ||||||
Amounts recorded in the income statement for the capitalization of funds used during construction and interest costs | ' | |||||||||||
Amounts recorded in the Consolidated Statements of Income for the capitalization of AFUDC and interest costs are disclosed in the table below: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
AFUDC (recorded as an increase in interest and other income) | ||||||||||||
Wexpro | $ | 4.6 | $ | 2.1 | $ | 3.3 | ||||||
Questar Pipeline | 1.7 | 0.2 | 1.1 | |||||||||
Total AFUDC | $ | 6.3 | $ | 2.3 | $ | 4.4 | ||||||
Capitalized interest costs (recorded as a reduction of interest expense) | ||||||||||||
Questar Gas | $ | 0.2 | $ | 0.1 | $ | 0.1 | ||||||
Questar Pipeline | 0.6 | 0.1 | 0.5 | |||||||||
Total capitalized interest costs | $ | 0.8 | $ | 0.2 | $ | 0.6 | ||||||
Earnings_Per_Share_Tables
Earnings Per Share (Tables) | 12 Months Ended | ||||||||
Dec. 31, 2013 | |||||||||
Earnings Per Share [Abstract] | ' | ||||||||
Schedule Of Weighted Average Number Of Shares Basic And Diluted | ' | ||||||||
A reconciliation of the components of basic and diluted shares used in the EPS calculation follows: | |||||||||
Year Ended December 31, | |||||||||
2013 | 2012 | 2011 | |||||||
(in millions) | |||||||||
Weighted-average basic common shares outstanding | 175.4 | 176.5 | 177.4 | ||||||
Potential number of shares issuable under the Company's LTSIP | 0.6 | 1 | 1.4 | ||||||
Weighted-average diluted common shares outstanding | 176 | 177.5 | 178.8 | ||||||
Other_Comprehensive_Income_Tab
Other Comprehensive Income (Tables) | 12 Months Ended | |||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||
Other Comprehensive Income [Abstract] | ' | |||||||||||||||||||||||||||
Schedule of Accumulated Other Comprehensive Income (Loss) | ' | |||||||||||||||||||||||||||
Details of the changes in the components of AOCI, net of income taxes, as reported in Questar's Consolidated Balance Sheets, are shown in the table below. The table also discloses details of income taxes related to each component of OCI: | ||||||||||||||||||||||||||||
Pension | OPRB | Interest rate cash flow hedges | Long-term invest. | Total | ||||||||||||||||||||||||
Actuarial loss | Prior service cost | Total | Actuarial loss | |||||||||||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||||||
AOCI at beginning of year | $ | (202.4 | ) | $ | (1.1 | ) | $ | (203.5 | ) | $ | (19.7 | ) | $ | (23.2 | ) | $ | 0.1 | $ | (246.3 | ) | ||||||||
OCI before reclassifications | 123.4 | — | 123.4 | 12.4 | — | (0.1 | ) | 135.7 | ||||||||||||||||||||
Reclassified from AOCI(1) | 28.9 | 1.1 | 30 | 3 | 0.5 | — | 33.5 | |||||||||||||||||||||
Income taxes | ||||||||||||||||||||||||||||
OCI before reclassifications | (47.2 | ) | — | (47.2 | ) | (4.7 | ) | — | 0.1 | (51.8 | ) | |||||||||||||||||
Reclassified from AOCI(2) | (11.1 | ) | (0.4 | ) | (11.5 | ) | (1.2 | ) | (0.2 | ) | — | (12.9 | ) | |||||||||||||||
Total income taxes | (58.3 | ) | (0.4 | ) | (58.7 | ) | (5.9 | ) | (0.2 | ) | 0.1 | (64.7 | ) | |||||||||||||||
Net other comprehensive income | 94 | 0.7 | 94.7 | 9.5 | 0.3 | — | 104.5 | |||||||||||||||||||||
AOCI at end of year | $ | (108.4 | ) | $ | (0.4 | ) | $ | (108.8 | ) | $ | (10.2 | ) | $ | (22.9 | ) | $ | 0.1 | $ | (141.8 | ) | ||||||||
(1) Interest rate cash flow hedge amounts are included in their entirety as charges to interest expense on the Consolidated Statements of Income. | ||||||||||||||||||||||||||||
(2) Interest rate cash flow hedge amounts are included in their entirety as credits to income taxes on the Consolidated Statements of Income. | ||||||||||||||||||||||||||||
Income taxes allocated to each component of consolidated OCI | ' | |||||||||||||||||||||||||||
For years not disclosed in the above table, income taxes allocated to each component of Questar's consolidated OCI are shown below. Expenses are in parentheses. | ||||||||||||||||||||||||||||
Year Ended December 31, | ||||||||||||||||||||||||||||
2012 | 2011 | |||||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||||||
Change in unrecognized actuarial loss | $ | 13.6 | $ | 62.3 | ||||||||||||||||||||||||
Change in unrecognized prior service cost | (1.0 | ) | (1.1 | ) | ||||||||||||||||||||||||
Interest rate cash flow hedges | (0.2 | ) | 13.8 | |||||||||||||||||||||||||
Change in fair value of long-term investment | (0.1 | ) | — | |||||||||||||||||||||||||
Income taxes | $ | 12.3 | $ | 75 | ||||||||||||||||||||||||
Asset_Retirement_Obligations_T
Asset Retirement Obligations (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Asset Retirement Obligation [Abstract] | ' | |||||||
Changes in AROs | ' | |||||||
Changes in Questar's AROs from the Consolidated Balance Sheets were as follows: | ||||||||
Year Ended December 31, | ||||||||
2013 | 2012 | |||||||
(in millions) | ||||||||
AROs at beginning of year | $ | 67.2 | $ | 63.8 | ||||
Accretion | 3.3 | 3.4 | ||||||
Liabilities incurred | 6 | 3.1 | ||||||
Revisions in estimated cash flows | (6.9 | ) | (1.7 | ) | ||||
Liabilities settled | (1.9 | ) | (1.4 | ) | ||||
AROs at end of year | $ | 67.7 | $ | 67.2 | ||||
Asset Retirement Obligations by line of business | ' | |||||||
Questar's consolidated AROs by line of business are summarized in the table below: | ||||||||
December 31, | ||||||||
2013 | 2012 | |||||||
(in millions) | ||||||||
Questar Gas | $ | 0.6 | $ | 0.5 | ||||
Wexpro | 64.9 | 64.6 | ||||||
Questar Pipeline | 2.2 | 2.1 | ||||||
Total | $ | 67.7 | $ | 67.2 | ||||
Fair_Value_Measurements_Tables
Fair Value Measurements (Tables) | 12 Months Ended | ||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ||||||||||||||||
Fair Value, by Balance Sheet Grouping | ' | ||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar's financial statements in this Annual Report on Form 10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 16 | $ | 16 | $ | 16.8 | $ | 16.8 | ||||||||
Long-term investment | 1 | 17.3 | 17.3 | 15.5 | 15.5 | ||||||||||||
Financial liabilities | |||||||||||||||||
Short-term debt | 1 | 276 | 276 | 263 | 263 | ||||||||||||
Long-term debt, including current portion | 2 | 1,247.10 | 1,310.80 | 1,140.90 | 1,303.10 | ||||||||||||
Questar Gas [Member] | ' | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ||||||||||||||||
Fair Value, by Balance Sheet Grouping | ' | ||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar Gas's financial statements in this Annual Report on Form 10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 8.8 | $ | 8.8 | $ | 1.4 | $ | 1.4 | ||||||||
Financial liabilities | |||||||||||||||||
Notes payable to Questar | 1 | 17.7 | 17.7 | 166.1 | 166.1 | ||||||||||||
Long-term debt, including current portion | 2 | 534.5 | 568 | 426.5 | 503.7 | ||||||||||||
Questar Pipeline [Member] | ' | ||||||||||||||||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ||||||||||||||||
Fair Value, by Balance Sheet Grouping | ' | ||||||||||||||||
The following table discloses the carrying amount, estimated fair value and level within the fair value hierarchy of certain financial instruments not disclosed in other notes to Questar Pipeline's financial statements in this Annual Report on Form | |||||||||||||||||
10-K: | |||||||||||||||||
Hierarchy Level of Fair Value Estimates | Carrying | Estimated | Carrying | Estimated | |||||||||||||
Amount | Fair Value | Amount | Fair Value | ||||||||||||||
December 31, 2013 | December 31, 2012 | ||||||||||||||||
(in millions) | |||||||||||||||||
Financial assets | |||||||||||||||||
Cash and cash equivalents | 1 | $ | 2.7 | $ | 2.7 | $ | 7.1 | $ | 7.1 | ||||||||
Notes receivable from Questar | 1 | 29.4 | 29.4 | 38.7 | 38.7 | ||||||||||||
Financial liabilities | |||||||||||||||||
Long-term debt | 2 | 458.9 | 486 | 458.9 | 536.6 | ||||||||||||
Derivative_Instruments_and_Hed1
Derivative Instruments and Hedging Activities (Tables) | 12 Months Ended | ||||||||||||
Dec. 31, 2013 | |||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ' | ||||||||||||
Derivative instruments on Consolidated Statements of Income and Accumulated Other Comprehensive Income | ' | ||||||||||||
The table below presents the pre-tax effects of the derivative instruments designated as a fair value hedge (including the hedged item) and cash flow hedges on the Consolidated Statements of Income. The table also shows the pre-tax effects of the derivative instruments designated as cash flow hedges on OCI: | |||||||||||||
Financial Statement Location of Gain (Loss) | Year Ended December 31, | ||||||||||||
Instrument and Activity | 2013 | 2012 | 2011 | ||||||||||
(in millions) | |||||||||||||
Fair Value Hedge | |||||||||||||
Questar Corporation | |||||||||||||
Interest rate derivative instrument | |||||||||||||
Realized and unrealized gain | Interest expense | $ | — | $ | — | $ | 9.8 | ||||||
2.75% Notes due 2016 | |||||||||||||
Unrealized loss | Interest expense | — | — | (9.8 | ) | ||||||||
Cash Flow Hedges | |||||||||||||
Questar Pipeline | |||||||||||||
Interest rate derivative instruments | |||||||||||||
Deferrals of effective portions | OCI | $ | — | $ | — | $ | (37.3 | ) | |||||
Losses reclassified from AOCI into earnings for effective portions | Interest expense | (0.5 | ) | (0.4 | ) | (0.1 | ) |
Debt_Tables
Debt (Tables) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Debt Disclosure [Abstract] | ' | |||||||||||||||
Schedule of Short-term Debt | ' | |||||||||||||||
The details of short-term debt are as follows: | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Commercial paper with various interest rates | $ | 276 | $ | 263 | ||||||||||||
Weighted-average interest rate at end of year | 0.27 | % | 0.31 | % | ||||||||||||
Schedule of Notes Payable | ' | |||||||||||||||
The following table details the notes payable to Questar from Questar Gas and the associated interest rates. There were no notes payable to Questar from Questar Pipeline at December 31, 2013 or 2012. | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Questar Gas | ||||||||||||||||
Notes payable to Questar | $ | 17.7 | $ | 166.1 | ||||||||||||
Interest rate at end of year | 0.3 | % | 0.39 | % | ||||||||||||
Schedule of Debt | ' | |||||||||||||||
The details of long-term debt are as follows: | ||||||||||||||||
December 31, | ||||||||||||||||
2013 | 2012 | |||||||||||||||
(in millions) | ||||||||||||||||
Questar Corporation | ||||||||||||||||
2.75% Notes due 2016 | $ | 250 | $ | 250 | ||||||||||||
Questar Gas | ||||||||||||||||
5.00% and 6.89% Medium-term Notes due 2013 | — | 42 | ||||||||||||||
5.31% and 6.85% Medium-term Notes due 2017 and 2018 | 84.5 | 84.5 | ||||||||||||||
6.30% Notes due 2018 | 50 | 50 | ||||||||||||||
2.98% Notes due 2024 | 40 | 40 | ||||||||||||||
3.28% Notes due 2027 | 110 | 110 | ||||||||||||||
7.20% Notes due 2038 | 100 | 100 | ||||||||||||||
4.78% Notes due 2043 | 90 | — | ||||||||||||||
4.83% Notes due 2048 | 60 | — | ||||||||||||||
Total Questar Gas long-term debt | 534.5 | 426.5 | ||||||||||||||
Questar Pipeline | ||||||||||||||||
6.45% and 6.48% Medium-term Notes due 2015 and 2018 | 30.1 | 30.1 | ||||||||||||||
5.83% Notes due 2018 | 250 | 250 | ||||||||||||||
4.875% Notes due 2041 | 180 | 180 | ||||||||||||||
Total Questar Pipeline long-term debt | 460.1 | 460.1 | ||||||||||||||
Total long-term debt outstanding | 1,244.60 | 1,136.60 | ||||||||||||||
Less current portion | — | (42.0 | ) | |||||||||||||
Less unamortized debt discount | (2.1 | ) | (2.3 | ) | ||||||||||||
Plus unamortized debt premium | 0.7 | 0.8 | ||||||||||||||
Plus fair value hedge adjustment | 3.9 | 5.8 | ||||||||||||||
Total long-term debt, less current portion | $ | 1,247.10 | $ | 1,098.90 | ||||||||||||
Schedule of Debt Maturities | ' | |||||||||||||||
The aggregate maturities of Questar Corporation, Questar Gas and Questar Pipeline long-term debt for the next five years are as follows: | ||||||||||||||||
Questar Corporation | Questar | Questar Pipeline | Total | |||||||||||||
Gas | ||||||||||||||||
Years Ending December 31, | ||||||||||||||||
(in millions) | ||||||||||||||||
2014 | $ | — | $ | — | $ | — | $ | — | ||||||||
2015 | — | — | 25.1 | 25.1 | ||||||||||||
2016 | 250 | — | — | 250 | ||||||||||||
2017 | — | 14.5 | — | 14.5 | ||||||||||||
2018 | — | 120 | 255 | 375 | ||||||||||||
Income_Taxes_Tables
Income Taxes (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Components of income tax expense | ' | |||||||||||
The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 66.5 | $ | 1.3 | $ | — | ||||||
Deferred | 18.4 | 112 | 110.8 | |||||||||
State | ||||||||||||
Current | 10.7 | — | (1.3 | ) | ||||||||
Deferred | 5.9 | 3.6 | 7.3 | |||||||||
Deferred investment tax credits recognized | (0.2 | ) | (0.4 | ) | (0.4 | ) | ||||||
Total income tax expense | $ | 101.3 | $ | 116.5 | $ | 116.4 | ||||||
Difference between statutory federal income tax rate and the Company's effective income tax rate | ' | |||||||||||
The difference between the statutory federal income tax rate and the Company's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase (decrease) in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 4 | 1 | 1.3 | |||||||||
Tax benefits from dividends paid to employee stock plan | (1.0 | ) | (0.5 | ) | (0.5 | ) | ||||||
Other | 0.6 | — | 0.1 | |||||||||
Effective income tax rate | 38.6 | % | 35.5 | % | 35.9 | % | ||||||
Significant components of deferred income taxes | ' | |||||||||||
Significant components of Questar's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 797.5 | $ | 767 | ||||||||
Employee benefits | 30.2 | 33.9 | ||||||||||
Other | 4.9 | 3.2 | ||||||||||
Deferred tax liabilities - noncurrent | 832.6 | 804.1 | ||||||||||
Deferred tax assets | ||||||||||||
Asset retirement obligations | 22.7 | 23.2 | ||||||||||
Pension and other postretirement benefits | 73.7 | 138.3 | ||||||||||
Deferred compensation | 14.5 | 8.6 | ||||||||||
Hedging activities | 13.4 | 13.6 | ||||||||||
State tax credits | 3.4 | 3.4 | ||||||||||
Net operating loss carryforward | — | 15.8 | ||||||||||
Valuation allowance | (2.3 | ) | (2.2 | ) | ||||||||
Deferred tax assets, net of allowance - noncurrent | 125.4 | 200.7 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 707.2 | $ | 603.4 | ||||||||
Deferred income taxes - current | ||||||||||||
Deferred tax assets - current | $ | 10.1 | $ | 17.6 | ||||||||
Deferred tax liabilities - current | 0.4 | 4.6 | ||||||||||
Net deferred income tax asset - current | $ | 9.7 | $ | 13 | ||||||||
Questar Gas [Member] | ' | |||||||||||
Components of income tax expense | ' | |||||||||||
The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 6 | $ | (18.7 | ) | $ | — | |||||
Deferred | 23.5 | 45.1 | 26.3 | |||||||||
State | ||||||||||||
Current | 0.6 | — | (1.6 | ) | ||||||||
Deferred | 2 | 1.2 | 3.2 | |||||||||
Deferred investment tax credit recognized | (0.2 | ) | (0.4 | ) | (0.4 | ) | ||||||
Total income tax expense | $ | 31.9 | $ | 27.2 | $ | 27.5 | ||||||
Difference between statutory federal income tax rate and the Company's effective income tax rate | ' | |||||||||||
The difference between the statutory federal income tax rate and Questar Gas's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase (decrease) in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 2.1 | 1 | 1.4 | |||||||||
Amortization of investment tax credits related to rate-regulated assets | (0.3 | ) | (0.4 | ) | (0.5 | ) | ||||||
Other | 0.9 | 1 | 1.5 | |||||||||
Effective income tax rate | 37.7 | % | 36.6 | % | 37.4 | % | ||||||
Significant components of deferred income taxes | ' | |||||||||||
Significant components of Questar Gas's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 322.6 | $ | 293 | ||||||||
Employee benefits | 14 | 17.2 | ||||||||||
Other | 4.9 | 3.4 | ||||||||||
Deferred tax liabilities - noncurrent | 341.5 | 313.6 | ||||||||||
Deferred tax assets | ||||||||||||
Deferred compensation | 0.8 | 0.9 | ||||||||||
Net operating loss carryforward | — | 11.1 | ||||||||||
Deferred tax assets - noncurrent | 0.8 | 12 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 340.7 | $ | 301.6 | ||||||||
Deferred income taxes - current | ||||||||||||
Deferred tax assets - current | $ | 3.3 | $ | 6.1 | ||||||||
Deferred tax liabilities - current | 0.4 | 4.6 | ||||||||||
Net deferred income tax asset - current | $ | 2.9 | $ | 1.5 | ||||||||
Questar Pipeline [Member] | ' | |||||||||||
Components of income tax expense | ' | |||||||||||
The components of income tax expense were as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Federal | ||||||||||||
Current | $ | 20.2 | $ | (5.4 | ) | $ | — | |||||
Deferred | (15.2 | ) | 40.4 | 37 | ||||||||
State | ||||||||||||
Current | 1.3 | 1.6 | (0.7 | ) | ||||||||
Deferred | 0.7 | 0.7 | 1.9 | |||||||||
Total income tax expense | $ | 7 | $ | 37.3 | $ | 38.2 | ||||||
Difference between statutory federal income tax rate and the Company's effective income tax rate | ' | |||||||||||
The difference between the statutory federal income tax rate and Questar Pipeline's effective income tax rate is explained as follows: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Federal income taxes statutory rate | 35 | % | 35 | % | 35 | % | ||||||
Increase in rate as a result of: | ||||||||||||
State income taxes, net of federal income tax benefit | 8.5 | 1.6 | 1 | |||||||||
Other | 2.6 | — | — | |||||||||
Effective income tax rate | 46.1 | % | 36.6 | % | 36 | % | ||||||
Significant components of deferred income taxes | ' | |||||||||||
Significant components of Questar Pipeline's deferred income taxes were as follows: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Deferred income taxes - noncurrent | ||||||||||||
Deferred tax liabilities | ||||||||||||
Property, plant and equipment | $ | 237.1 | $ | 250.8 | ||||||||
Employee benefits | 7.4 | 8.4 | ||||||||||
Deferred tax liabilities - noncurrent | 244.5 | 259.2 | ||||||||||
Deferred tax assets | ||||||||||||
Deferred compensation | 1.8 | 1.5 | ||||||||||
Hedging activities | 13.4 | 13.6 | ||||||||||
State tax credits | 0.7 | 0.7 | ||||||||||
Net operating loss carryforward | — | 1 | ||||||||||
Other | — | (0.1 | ) | |||||||||
Deferred tax assets - noncurrent | 15.9 | 16.7 | ||||||||||
Net deferred income tax liability - noncurrent | $ | 228.6 | $ | 242.5 | ||||||||
Net deferred income tax asset - current | $ | 1.8 | $ | 1.6 | ||||||||
Commitments_Contingencies_and_1
Commitments, Contingencies and Leases (Tables) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Commitments and Contingencies Disclosure [Abstract] | ' | |||
Schedule of Future Minimum Lease Payments for Capital Lease | ' | |||
Future minimum lease payments for the five years following 2013 and the years thereafter are shown in the table below. Also shown is the present value of minimum lease payments at December 31, 2013, which is reflected in the Consolidated Balance Sheets as current and noncurrent capital lease obligations of $0.9 million and $38.4 million, respectively. | ||||
Years Ending December 31, | ||||
(in millions) | ||||
2014 | $ | 3 | ||
2015 | 3.4 | |||
2016 | 3.5 | |||
2017 | 3.6 | |||
2018 | 3.7 | |||
After 2018 | 44.8 | |||
Total minimum lease payments | 62 | |||
Less: amount representing interest | (22.7 | ) | ||
Present value of minimum lease payments at December 31, 2013 | $ | 39.3 | ||
Wexpro_and_Wexpro_II_Agreement1
Wexpro and Wexpro II Agreements (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Wexpro Agreement [Abstract] | ' | |||||||||||
Net investment base, yearly average rate of return and oil and NGL income sharing | ' | |||||||||||
Wexpro's net investment base, yearly average rate of return, and oil and NGL income shared with Questar Gas are shown in the table below: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
Wexpro net investment base at December 31, (in millions) | $ | 589.7 | $ | 531.1 | $ | 474.4 | ||||||
Average annual rate of return (after tax) | 19.7 | % | 19.9 | % | 20 | % | ||||||
Oil and NGL income sharing (in millions) | $ | 0.6 | $ | 2.5 | $ | 3.3 | ||||||
Rate_Regulation_Tables
Rate Regulation (Tables) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Regulated Operations [Abstract] | ' | |||||||||||||||
Details of regulatory assets and liabilities | ' | |||||||||||||||
The following table details regulatory assets and liabilities: | ||||||||||||||||
December 31, 2013 | December 31, 2012 | |||||||||||||||
Current | Noncurrent | Current | Noncurrent | |||||||||||||
(in millions) | ||||||||||||||||
Regulatory assets: | ||||||||||||||||
Questar Gas | ||||||||||||||||
Purchased-gas adjustment | $ | — | $ | — | $ | 15.2 | $ | — | ||||||||
DSM | 11.2 | — | 11 | — | ||||||||||||
Deferred production taxes | 5.7 | — | 5 | — | ||||||||||||
Deferred royalties | 5.2 | — | 6.3 | — | ||||||||||||
Contract withholding | 8.1 | — | 3.5 | — | ||||||||||||
Cost of reacquired debt | — | 4.8 | — | 5.3 | ||||||||||||
Pipeline integrity costs | — | 9.3 | — | 8.7 | ||||||||||||
ARO cost-of-service gas wells | — | 2 | — | 2.4 | ||||||||||||
Total Questar Gas regulatory assets | 30.2 | 16.1 | 41 | 16.4 | ||||||||||||
Questar Pipeline | ||||||||||||||||
Gas imbalance | 5.3 | — | 4.4 | — | ||||||||||||
Revenue sharing | 0.3 | — | 1.3 | — | ||||||||||||
Cost of reacquired debt | — | 2.6 | — | 3 | ||||||||||||
Income taxes recoverable from customers | — | 0.6 | — | 0.9 | ||||||||||||
Other | — | 1.2 | — | 1.3 | ||||||||||||
Total Questar Pipeline regulatory assets | 5.6 | 4.4 | 5.7 | 5.2 | ||||||||||||
Total regulatory assets | $ | 35.8 | $ | 20.5 | $ | 46.7 | $ | 21.6 | ||||||||
Regulatory liabilities: | ||||||||||||||||
Questar Gas | ||||||||||||||||
Purchased-gas adjustment | $ | 7.4 | $ | — | $ | — | $ | — | ||||||||
CET | 3.3 | — | 4.2 | — | ||||||||||||
Cost of plant removal | — | 52.7 | — | 46.2 | ||||||||||||
Income taxes refundable to customers | — | 0.3 | — | 0.5 | ||||||||||||
Other | 0.4 | — | 0.1 | — | ||||||||||||
Total Questar Gas regulatory liabilities | 11.1 | 53 | 4.3 | 46.7 | ||||||||||||
Questar Pipeline | ||||||||||||||||
Gas imbalance | 3 | — | 1.4 | — | ||||||||||||
Revenue sharing | — | — | 0.1 | — | ||||||||||||
Postretirement medical | — | 8.2 | — | 7.7 | ||||||||||||
Total Questar Pipeline regulatory liabilities | 3 | 8.2 | 1.5 | 7.7 | ||||||||||||
Total regulatory liabilities | $ | 14.1 | $ | 61.2 | $ | 5.8 | $ | 54.4 | ||||||||
ShareBased_Compensation_Tables
Share-Based Compensation (Tables) | 12 Months Ended | ||||||||||||||||||||||
Dec. 31, 2013 | |||||||||||||||||||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ||||||||||||||||||||||
Transactions involving stock options under the terms of the LTSIP | ' | ||||||||||||||||||||||
Stock option transactions under the terms of the LTSIP are summarized for the year ended December 31, 2013, below: | |||||||||||||||||||||||
Options | Exercise | Weighted-Average Exercise Price | |||||||||||||||||||||
Outstanding | Price Range | ||||||||||||||||||||||
Balance at December 31, 2012 | 770,923 | $ | 4.37 | - | $ | 17.35 | $ | 11.35 | |||||||||||||||
Exercised | (53,083 | ) | 4.37 | - | 13.1 | 4.75 | |||||||||||||||||
Balance at December 31, 2013 | 717,840 | $ | 7.84 | - | $ | 17.35 | $ | 11.84 | |||||||||||||||
Options held under the LTSIP, by exercise price range | ' | ||||||||||||||||||||||
Options Outstanding | Options Exercisable | ||||||||||||||||||||||
Range of | Number outstanding at Dec. 31, 2013 | Weighted-average remaining term in years | Weighted-average exercise price | Number exercisable at Dec. 31, 2013 | Weighted-average exercise price | ||||||||||||||||||
exercise | |||||||||||||||||||||||
prices | |||||||||||||||||||||||
$ | 7.84 | - | $ | 11.4 | 404,174 | 1.9 | $ | 10.52 | 404,174 | $ | 10.52 | ||||||||||||
13.1 | - | 17.35 | 313,666 | 2.5 | 13.54 | 313,666 | 13.54 | ||||||||||||||||
717,840 | 2.2 | $ | 11.84 | 717,840 | $ | 11.84 | |||||||||||||||||
Transactions involving restricted shares and RSUs under the terms of the LTSIP | ' | ||||||||||||||||||||||
Transactions involving restricted shares under the terms of the LTSIP for the year ended December 31, 2013, are summarized below: | |||||||||||||||||||||||
Restricted Shares Outstanding | Price Range | Weighted- Average Price | |||||||||||||||||||||
Balance at December 31, 2012 | 810,342 | $ | 13.1 | - | $ | 20.9 | $ | 17.74 | |||||||||||||||
Granted | 658 | 21.53 | - | 21.53 | 21.53 | ||||||||||||||||||
Vested | (417,882 | ) | 13.1 | - | 20.9 | 17.24 | |||||||||||||||||
Forfeited | (791 | ) | 19.39 | - | 19.39 | 19.39 | |||||||||||||||||
Balance at December 31, 2013 | 392,327 | $ | 13.1 | - | $ | 21.53 | $ | 18.28 | |||||||||||||||
Transactions involving RSUs under the terms of the LTSIP are summarized below: | |||||||||||||||||||||||
RSUs | Price Range | Weighted-Average Price | |||||||||||||||||||||
Outstanding | |||||||||||||||||||||||
Granted | 330,061 | $ | 22.17 | - | $ | 25.44 | $ | 23.62 | |||||||||||||||
Vested | (12,522 | ) | 23.62 | - | 23.62 | 23.62 | |||||||||||||||||
Forfeited | (1,271 | ) | 23.62 | - | 23.62 | 23.62 | |||||||||||||||||
Balance at December 31, 2013 | 316,268 | $ | 22.17 | - | $ | 25.44 | $ | 23.62 | |||||||||||||||
Calculated fair value of performance shares granted and major assumptions used in the Monte Carlo simulation | ' | ||||||||||||||||||||||
The estimated fair value of performance shares granted and major assumptions used in the simulation at the date of grant are listed below: | |||||||||||||||||||||||
2013 | 2012 | 2011 | |||||||||||||||||||||
Performance Share | |||||||||||||||||||||||
Input Variables | |||||||||||||||||||||||
Fair value of performance shares at grant date | $ | 39.62 | $ | 25.42 | $ | 18.23 | |||||||||||||||||
Risk-free interest rate | 0.4 | % | 0.35 | % | 1.32 | % | |||||||||||||||||
Expected price volatility | 19 | % | 22 | % | 31.3 | % | |||||||||||||||||
Expected dividend yield | 2.88 | % | 3.35 | % | 3.39 | % | |||||||||||||||||
Expected life in years | 2.9 | 2.9 | 2.9 | ||||||||||||||||||||
Transactions involving performance shares under the terms of the LTSIP | ' | ||||||||||||||||||||||
Transactions involving performance shares under the terms of the LTSIP for the year ended December 31, 2013, are summarized below: | |||||||||||||||||||||||
Target Number of Performance Shares Outstanding | Grant-Date | Weighted- Average Grant-Date Fair Value | |||||||||||||||||||||
Fair Value Range | |||||||||||||||||||||||
Balance at December 31, 2012 | 264,867 | $ | 18.23 | - | $ | 25.42 | $ | 21.94 | |||||||||||||||
Granted | 126,606 | 39.62 | 39.62 | 39.62 | |||||||||||||||||||
Forfeited | (3,594 | ) | 18.23 | - | 39.62 | 33.09 | |||||||||||||||||
Balance at December 31, 2013 | 387,879 | $ | 18.23 | - | $ | 39.62 | $ | 27.61 | |||||||||||||||
Questar Pipeline and Questar Gas [Member] | ' | ||||||||||||||||||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ||||||||||||||||||||||
Options held under the LTSIP, by exercise price range | ' | ||||||||||||||||||||||
The following table summarizes the stock options held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013: | |||||||||||||||||||||||
Options Outstanding | Options Exercisable | ||||||||||||||||||||||
Range of | Number outstanding at Dec. 31, 2013 | Weighted-average remaining term in years | Weighted-average exercise price | Number exercisable at Dec. 31, 2013 | Weighted-average exercise price | ||||||||||||||||||
exercise | |||||||||||||||||||||||
prices | |||||||||||||||||||||||
Questar Gas | |||||||||||||||||||||||
$ | 11.4 | - | $ | 13.1 | 17,000 | 2.6 | $ | 12.1 | 17,000 | $ | 12.1 | ||||||||||||
Questar Pipeline | |||||||||||||||||||||||
$ | 7.84 | - | $ | 13.1 | 158,933 | 1.6 | $ | 9.36 | 158,933 | $ | 9.36 | ||||||||||||
Transactions involving restricted shares and RSUs under the terms of the LTSIP | ' | ||||||||||||||||||||||
The following table summarizes the restricted shares held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013. The weighted-average remaining vesting periods of unvested restricted shares at December 31, 2013, for Questar Gas and Questar Pipeline were 6 months and 7 months, respectively. | |||||||||||||||||||||||
Restricted | Price Range | Weighted-Average Price | |||||||||||||||||||||
Shares Outstanding | |||||||||||||||||||||||
Questar Gas | 58,837 | $ | 13.1 | - | $ | 19.39 | $ | 18.6 | |||||||||||||||
Questar Pipeline | 70,758 | $ | 13.1 | - | $ | 19.56 | $ | 18.78 | |||||||||||||||
The following table summarizes the RSUs held under the LTSIP by Questar Gas and Questar Pipeline officers and employees at December 31, 2013. The weighted-average remaining vesting period of unvested RSUs at December 31, 2013, for Questar Gas and Questar Pipeline was 14 months. | |||||||||||||||||||||||
RSUs Outstanding | Price Range | Weighted-Average Price | |||||||||||||||||||||
Questar Gas | 55,631 | $ | 22.17 | - | $ | 23.62 | $ | 23.54 | |||||||||||||||
Questar Pipeline | 50,230 | $ | 23.62 | - | $ | 23.62 | $ | 23.62 | |||||||||||||||
Transactions involving performance shares under the terms of the LTSIP | ' | ||||||||||||||||||||||
The following table summarizes the target number of performance shares held under the LTSIP by Questar Gas and Questar Pipeline officers at December 31, 2013. The weighted-average remaining vesting period of unvested performance shares at December 31, 2013, for Questar Gas and Questar Pipeline was 18 months. | |||||||||||||||||||||||
Target Number of Performance Shares Outstanding | Grant-Date | Weighted- Average Grant-Date Fair Value | |||||||||||||||||||||
Fair Value Range | |||||||||||||||||||||||
Questar Gas | 34,326 | $ | 18.23 | - | $ | 39.62 | $ | 27.91 | |||||||||||||||
Questar Pipeline | 65,283 | $ | 18.23 | - | $ | 39.62 | $ | 26.85 | |||||||||||||||
Employee_Benefits_Tables
Employee Benefits (Tables) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Compensation and Retirement Disclosure [Abstract] | ' | |||||||||||||||||||||||
Schedule of pension and other postretirement benefit plan asset allocation | ' | |||||||||||||||||||||||
Qualified pension and other postretirement benefit plan assets were invested as follows: | ||||||||||||||||||||||||
Actual Allocation | Policy Range | |||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2013 | 2012 | 2013 | 2012 | |||||||||||||||||||||
Total domestic equity securities | 38 | % | 34 | % | 35 | % | - | 45 | % | 35 | % | - | 45 | % | ||||||||||
Foreign equity securities | ||||||||||||||||||||||||
Developed market foreign equity securities | 20 | % | 20 | % | ||||||||||||||||||||
Emerging market foreign equity securities | 5 | % | 5 | % | ||||||||||||||||||||
Total foreign securities | 25 | % | 25 | % | 25 | % | - | 35 | % | 25 | % | - | 35 | % | ||||||||||
Debt securities | ||||||||||||||||||||||||
Investment-grade intermediate-term debt | 7 | % | 4 | % | ||||||||||||||||||||
Investment-grade long-term debt | 11 | % | 14 | % | ||||||||||||||||||||
Below-investment-grade debt | 9 | % | 10 | % | ||||||||||||||||||||
Total debt securities | 27 | % | 28 | % | 25 | % | - | 35 | % | 25 | % | - | 35 | % | ||||||||||
Inflation protection securities | 9 | % | 9 | % | — | % | - | 10 | % | — | % | - | 10 | % | ||||||||||
Cash and short-term investments | 1 | % | 4 | % | — | % | - | 3 | % | — | % | - | 3 | % | ||||||||||
Pension and postretirement benefit assets fair value by level | ' | |||||||||||||||||||||||
The following tables set forth, by level within the fair value hierarchy, qualified pension and other postretirement benefit plan assets at fair value as of December 31, 2013 and 2012: | ||||||||||||||||||||||||
Investments at Fair Value | ||||||||||||||||||||||||
December 31, 2013 | ||||||||||||||||||||||||
Level 1 | Level 2 | Total | ||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Corporate bonds | $ | — | $ | 1.7 | $ | 1.7 | ||||||||||||||||||
U.S. government securities | — | 1.6 | 1.6 | |||||||||||||||||||||
Registered investment companies: | ||||||||||||||||||||||||
Fixed income funds | 110.7 | — | 110.7 | |||||||||||||||||||||
Inflation protection fund | 29.4 | — | 29.4 | |||||||||||||||||||||
Domestic equity fund | 2 | — | 2 | |||||||||||||||||||||
Commingled funds: | ||||||||||||||||||||||||
Cash equivalent funds | — | 3.5 | 3.5 | |||||||||||||||||||||
Domestic equity index fund | — | 256.2 | 256.2 | |||||||||||||||||||||
Foreign equity growth fund | — | 42.9 | 42.9 | |||||||||||||||||||||
Foreign equity index funds | — | 76 | 76 | |||||||||||||||||||||
Corporate debt funds | — | 72.1 | 72.1 | |||||||||||||||||||||
Inflation protection fund | — | 28.8 | 28.8 | |||||||||||||||||||||
Foreign equity growth 103-12 investment entity | — | 47.1 | 47.1 | |||||||||||||||||||||
Total | $ | 142.1 | $ | 529.9 | $ | 672 | ||||||||||||||||||
Investments at Fair Value | ||||||||||||||||||||||||
December 31, 2012 | ||||||||||||||||||||||||
Level 1 | Level 2 | Total | ||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Corporate bonds | $ | — | $ | 1.9 | $ | 1.9 | ||||||||||||||||||
U.S. government securities | — | 2 | 2 | |||||||||||||||||||||
Registered investment companies: | ||||||||||||||||||||||||
Fixed income funds | 79.2 | — | 79.2 | |||||||||||||||||||||
Inflation protection fund | 25.5 | — | 25.5 | |||||||||||||||||||||
Domestic equity fund | 1.9 | — | 1.9 | |||||||||||||||||||||
Commingled funds: | ||||||||||||||||||||||||
Cash equivalent funds | — | 20.8 | 20.8 | |||||||||||||||||||||
Domestic equity index fund | — | 185.9 | 185.9 | |||||||||||||||||||||
Foreign equity growth fund | — | 37.3 | 37.3 | |||||||||||||||||||||
Foreign equity index funds | — | 60.1 | 60.1 | |||||||||||||||||||||
Corporate debt funds | — | 72.8 | 72.8 | |||||||||||||||||||||
Inflation protection fund | — | 24.5 | 24.5 | |||||||||||||||||||||
Foreign equity growth 103-12 investment entity | — | 36.5 | 36.5 | |||||||||||||||||||||
Total | $ | 106.6 | $ | 441.8 | $ | 548.4 | ||||||||||||||||||
Assumptions used to calculate benefit obligations | ' | |||||||||||||||||||||||
The qualified pension projected benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 4.9 | % | 4.2 | % | ||||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | ||||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | ||||||||||||||||||||||
The nonqualified pension projected benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 3.3 | % | 2.4 | % | ||||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | ||||||||||||||||||||||
The postretirement accumulated benefit obligation was measured using the following assumptions at December 31: | ||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
Discount rate | 4.7 | % | 4 | % | ||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | ||||||||||||||||||||||
Health-care inflation rate | 8 | 8.5 | ||||||||||||||||||||||
decreasing to | decreasing to | |||||||||||||||||||||||
4.5 | % | by | 2021 | 4.5 | % | by | 2021 | |||||||||||||||||
Changes in benefit obligation, changes in fair value of plan assets, and underfunded status | ' | |||||||||||||||||||||||
Plan obligations and fair value of all plan assets are shown in the following table: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2013 | 2012 | |||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Change in benefit obligation | ||||||||||||||||||||||||
Benefit obligation at beginning of year | $ | 760.3 | $ | 646.9 | $ | 94.4 | $ | 88.7 | ||||||||||||||||
Service cost | 13.9 | 13.2 | 0.7 | 0.7 | ||||||||||||||||||||
Interest cost | 30.6 | 31.1 | 3.7 | 3.8 | ||||||||||||||||||||
Change in plan assumptions | (73.6 | ) | 69 | (8.6 | ) | 7.3 | ||||||||||||||||||
Actuarial (gain) loss | (7.7 | ) | 18.2 | (0.5 | ) | (1.0 | ) | |||||||||||||||||
Benefits paid | (20.8 | ) | (18.1 | ) | (3.4 | ) | (5.1 | ) | ||||||||||||||||
Benefit obligation at end of year | 702.7 | 760.3 | 86.3 | 94.4 | ||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||
Fair value of plan assets at beginning of year | 510.8 | 390 | 37.6 | 34 | ||||||||||||||||||||
Actual gain on plan assets | 80.2 | 59.3 | 5.8 | 4.6 | ||||||||||||||||||||
Company contributions to the plan | 58 | 79.6 | 3.8 | 4.1 | ||||||||||||||||||||
Benefits paid | (20.8 | ) | (18.1 | ) | (3.4 | ) | (5.1 | ) | ||||||||||||||||
Fair value of plan assets at end of year | 628.2 | 510.8 | 43.8 | 37.6 | ||||||||||||||||||||
Underfunded status (current and long-term) | $ | (74.5 | ) | $ | (249.5 | ) | $ | (42.5 | ) | $ | (56.8 | ) | ||||||||||||
Estimated benefit plan payments for the next five years and the subsequent five years aggregated | ' | |||||||||||||||||||||||
Estimated benefit plan payments for the five years following 2013 and the subsequent five years aggregated are as follows: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Years Ending December 31, | ||||||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
2014 | $ | 26.7 | $ | 4.6 | ||||||||||||||||||||
2015 | 35.9 | 4.8 | ||||||||||||||||||||||
2016 | 27.9 | 4.9 | ||||||||||||||||||||||
2017 | 28.7 | 5.1 | ||||||||||||||||||||||
2018 | 31.1 | 5.2 | ||||||||||||||||||||||
2019 through 2023 | 195.7 | 27.4 | ||||||||||||||||||||||
Net pension and other postretirement benefit cost components | ' | |||||||||||||||||||||||
The components of the net pension and other postretirement benefit costs are as follows. The net pension cost includes both the qualified and nonqualified pension plans. | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2011 | 2013 | 2012 | 2011 | |||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Service cost | $ | 13.9 | $ | 13.2 | $ | 9.3 | $ | 0.7 | $ | 0.7 | $ | 0.5 | ||||||||||||
Interest cost | 30.6 | 31.1 | 28.5 | 3.7 | 3.8 | 4.2 | ||||||||||||||||||
Expected return on plan assets | (38.1 | ) | (31.8 | ) | (26.0 | ) | (2.6 | ) | (2.3 | ) | (2.6 | ) | ||||||||||||
Prior service and other costs | 1.1 | 1.1 | 1.1 | — | 1.6 | 1.9 | ||||||||||||||||||
Recognized net actuarial loss | 28.9 | 24.9 | 12.1 | 3 | 2.5 | 0.3 | ||||||||||||||||||
Curtailment charges | — | — | 0.8 | — | — | — | ||||||||||||||||||
Accretion of regulatory liability | — | — | — | 0.5 | 0.3 | 0.5 | ||||||||||||||||||
Net periodic cost | $ | 36.4 | $ | 38.5 | $ | 25.8 | $ | 5.3 | $ | 6.6 | $ | 4.8 | ||||||||||||
Assumptions used to calculate net benefit costs | ' | |||||||||||||||||||||||
Assumptions at January 1, used to calculate the qualified net pension cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 4.2 | % | 4.8 | % | 5.75 | % | ||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | 4 | |||||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | 7.25 | |||||||||||||||||||||
Assumptions at January 1, used to calculate the nonqualified net pension cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 2.4 | % | 3.3 | % | 5.75 | % | ||||||||||||||||||
Rate of increase in compensation | 5.5 | 5.5 | 4 | |||||||||||||||||||||
Assumptions at January 1, used to calculate the net postretirement benefit cost for the years, were as follows: | ||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||
Discount rate | 4 | % | 4.4 | % | 5.75 | % | ||||||||||||||||||
Long-term return on assets | 7.25 | 7.25 | 7.25 | |||||||||||||||||||||
Health-care inflation rate | 8.5 | 7 | 8 | |||||||||||||||||||||
decreasing to | decreasing to | decreasing to | ||||||||||||||||||||||
4.5 | % | by | 2021 | 5 | % | by | 2014 | 5 | % | by | 2014 | |||||||||||||
Subsidiary net cost and contribution information | ' | |||||||||||||||||||||||
Pension and other postretirement benefit net cost and plan contribution information for Questar Gas and Questar Pipeline are shown below: | ||||||||||||||||||||||||
Pension | Other Postretirement Benefits | |||||||||||||||||||||||
Year Ended December 31, | Year Ended December 31, | |||||||||||||||||||||||
2013 | 2012 | 2011 | 2013 | 2012 | 2011 | |||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
Questar Gas | ||||||||||||||||||||||||
Net periodic cost | $ | 18.1 | $ | 19.7 | $ | 13.4 | $ | 2.4 | $ | 3.3 | $ | 2.3 | ||||||||||||
Share of total plan contributions | 29.6 | 39.4 | 27.1 | 2 | 1.9 | 2.2 | ||||||||||||||||||
Questar Pipeline | ||||||||||||||||||||||||
Net periodic cost | $ | 6.7 | $ | 7.4 | $ | 5 | $ | 0.2 | $ | 1.2 | $ | 1 | ||||||||||||
Share of total plan contributions | 11.2 | 15.1 | 8.7 | 0.7 | 0.6 | 0.2 | ||||||||||||||||||
Operations_by_Line_of_Business1
Operations by Line of Business (Tables) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Segment Reporting [Abstract] | ' | |||||||||||||||||||||||
Summary of operations by line of business | ' | |||||||||||||||||||||||
The following is a summary of operations by line of business for the three years ended December 31, 2013: | ||||||||||||||||||||||||
Questar | Interco. | Questar | Wexpro | Questar | Corp and Other | |||||||||||||||||||
Consol. | Trans. | Gas | Pipeline | |||||||||||||||||||||
(in millions) | ||||||||||||||||||||||||
2013 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,220.00 | $ | — | $ | 985.2 | $ | 45.1 | $ | 189.5 | $ | 0.2 | ||||||||||||
From affiliated companies | — | (372.1 | ) | 0.6 | 294.8 | 76.7 | — | |||||||||||||||||
Total Revenues | 1,220.00 | (372.1 | ) | 985.8 | 339.9 | 266.2 | 0.2 | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 285.9 | (370.9 | ) | 650.6 | — | 6.1 | 0.1 | |||||||||||||||||
Operating and maintenance | 174.3 | — | 113.1 | 28.6 | 32.5 | 0.1 | ||||||||||||||||||
General and administrative | 121 | (0.6 | ) | 52.5 | 28.7 | 46.7 | (6.3 | ) | ||||||||||||||||
Production and other taxes | 57.4 | — | 18 | 28.3 | 9.3 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 194.8 | — | 49.7 | 85.8 | 55.5 | 3.8 | ||||||||||||||||||
Asset impairment | 80.6 | — | — | — | 80.6 | — | ||||||||||||||||||
Other operating expenses | — | (0.6 | ) | — | 0.6 | — | — | |||||||||||||||||
Total Operating Expenses | 914 | (372.1 | ) | 883.9 | 172 | 230.7 | (0.5 | ) | ||||||||||||||||
Net loss from asset sales | (0.2 | ) | — | — | (0.2 | ) | — | — | ||||||||||||||||
Operating Income | 305.8 | — | 101.9 | 167.7 | 35.5 | 0.7 | ||||||||||||||||||
Interest and other income (expense) | 9.9 | (0.7 | ) | 5.1 | 5 | 1.8 | (1.3 | ) | ||||||||||||||||
Income from unconsolidated affiliate | 3.7 | — | — | — | 3.7 | — | ||||||||||||||||||
Interest expense | (56.9 | ) | 0.7 | (22.3 | ) | (0.1 | ) | (25.8 | ) | (9.4 | ) | |||||||||||||
Income taxes | (101.3 | ) | — | (31.9 | ) | (62.0 | ) | (7.0 | ) | (0.4 | ) | |||||||||||||
Net Income (Loss) | $ | 161.2 | $ | — | $ | 52.8 | $ | 110.6 | $ | 8.2 | $ | (10.4 | ) | |||||||||||
Identifiable assets | $ | 4,054.30 | $ | — | $ | 1,762.00 | $ | 993.8 | $ | 1,222.80 | $ | 75.7 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 25.6 | — | — | — | 25.6 | — | ||||||||||||||||||
Cash capital expenditures including acquisitions | 503.7 | — | 166.2 | 249.5 | 73.4 | 14.6 | ||||||||||||||||||
Accrued capital expenditures including acquisitions | 505.6 | — | 177.3 | 240.7 | 70 | 17.6 | ||||||||||||||||||
2012 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,098.90 | $ | — | $ | 859.7 | $ | 36.1 | $ | 203.1 | $ | — | ||||||||||||
From affiliated companies | — | (351.0 | ) | 2.5 | 274.1 | 74.4 | — | |||||||||||||||||
Total Revenues | 1,098.90 | (351.0 | ) | 862.2 | 310.2 | 277.5 | — | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 192.3 | (347.7 | ) | 533.3 | — | 6.7 | — | |||||||||||||||||
Operating and maintenance | 180.8 | (0.2 | ) | 119 | 26.8 | 35.2 | — | |||||||||||||||||
General and administrative | 120.8 | (0.6 | ) | 51.2 | 26.8 | 50 | (6.6 | ) | ||||||||||||||||
Retirement incentive | 4.9 | — | 2.4 | 0.2 | 0.9 | 1.4 | ||||||||||||||||||
Production and other taxes | 47.9 | — | 16.2 | 20.8 | 9.1 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 181.6 | — | 47.2 | 77.4 | 54.3 | 2.7 | ||||||||||||||||||
Other operating expenses | — | (2.5 | ) | — | 2.5 | — | — | |||||||||||||||||
Total Operating Expenses | 728.3 | (351.0 | ) | 769.3 | 154.5 | 156.2 | (0.7 | ) | ||||||||||||||||
Net gain from asset sales | 5.1 | — | — | 2.4 | 2.7 | — | ||||||||||||||||||
Operating Income | 375.7 | — | 92.9 | 158.1 | 124 | 0.7 | ||||||||||||||||||
Interest and other income (expense) | 7 | (0.7 | ) | 5.5 | 2.8 | 0.6 | (1.2 | ) | ||||||||||||||||
Income from unconsolidated affiliate | 3.7 | — | — | — | 3.7 | — | ||||||||||||||||||
Interest expense | (57.9 | ) | 0.7 | (24.1 | ) | — | (26.3 | ) | (8.2 | ) | ||||||||||||||
Income taxes | (116.5 | ) | — | (27.2 | ) | (57.0 | ) | (37.3 | ) | 5 | ||||||||||||||
Net Income (Loss) | $ | 212 | $ | — | $ | 47.1 | $ | 103.9 | $ | 64.7 | $ | (3.7 | ) | |||||||||||
Identifiable assets | $ | 3,803.30 | $ | — | $ | 1,593.50 | $ | 836.1 | $ | 1,298.90 | $ | 74.8 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 26.5 | — | — | — | 26.5 | — | ||||||||||||||||||
Cash capital expenditures | 370.7 | — | 162.1 | 144.5 | 60.6 | 3.5 | ||||||||||||||||||
Accrued capital expenditures | 366.3 | — | 161.2 | 145.5 | 58.6 | 1 | ||||||||||||||||||
2011 | ||||||||||||||||||||||||
Revenues | ||||||||||||||||||||||||
From unaffiliated customers | $ | 1,194.40 | $ | — | $ | 965.5 | $ | 31.5 | $ | 197.4 | $ | — | ||||||||||||
From affiliated companies | — | (331.3 | ) | 3.3 | 253.6 | 74.4 | — | |||||||||||||||||
Total Revenues | 1,194.40 | (331.3 | ) | 968.8 | 285.1 | 271.8 | — | |||||||||||||||||
Operating Expenses | ||||||||||||||||||||||||
Cost of sales | 321.5 | (327.3 | ) | 645.7 | — | 3.1 | — | |||||||||||||||||
Operating and maintenance | 175.9 | (0.2 | ) | 118.5 | 22.3 | 35.3 | — | |||||||||||||||||
General and administrative | 117.9 | (0.5 | ) | 51 | 24.2 | 46.5 | (3.3 | ) | ||||||||||||||||
Production and other taxes | 52.5 | — | 15 | 25.6 | 10.1 | 1.8 | ||||||||||||||||||
Depreciation, depletion and amortization | 159.9 | — | 44.5 | 63.9 | 51.2 | 0.3 | ||||||||||||||||||
Other operating expenses | — | (3.3 | ) | — | 3.3 | — | — | |||||||||||||||||
Total Operating Expenses | 827.7 | (331.3 | ) | 874.7 | 139.3 | 146.2 | (1.2 | ) | ||||||||||||||||
Net gain (loss) from asset sales | 0.2 | — | — | (0.1 | ) | 0.3 | — | |||||||||||||||||
Operating Income | 366.9 | — | 94.1 | 145.7 | 125.9 | 1.2 | ||||||||||||||||||
Interest and other income | 10.4 | (0.6 | ) | 5.4 | 4.2 | 0.9 | 0.5 | |||||||||||||||||
Income from unconsolidated affiliate | 3.8 | — | — | — | 3.8 | — | ||||||||||||||||||
Interest expense | (56.8 | ) | 0.6 | (25.9 | ) | — | (24.5 | ) | (7.0 | ) | ||||||||||||||
Income taxes | (116.4 | ) | — | (27.5 | ) | (54.7 | ) | (38.2 | ) | 4 | ||||||||||||||
Net Income (Loss) | $ | 207.9 | $ | — | $ | 46.1 | $ | 95.2 | $ | 67.9 | $ | (1.3 | ) | |||||||||||
Identifiable assets | $ | 3,572.20 | $ | — | $ | 1,483.80 | $ | 768.2 | $ | 1,286.60 | $ | 33.6 | ||||||||||||
Goodwill | 9.8 | — | 5.6 | — | 4.2 | — | ||||||||||||||||||
Investment in unconsolidated affiliate | 27.3 | — | — | — | 27.3 | — | ||||||||||||||||||
Cash capital expenditures | 367.7 | — | 121.5 | 136.2 | 104.5 | 5.5 | ||||||||||||||||||
Accrued capital expenditures | 373.9 | — | 127.7 | 144.3 | 93.8 | 8.1 | ||||||||||||||||||
Wexpro_Acquisition_of_Producin1
Wexpro Acquisition of Producing Properties (Tables) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Wexpro Acquisition of Producing Properties [Abstract] | ' | |||
Summary information related to the Wexpro acquisition | ' | |||
Summary information related to the Trail acquisition is shown in the table below. Amounts reflect routine post-closing adjustments to the purchase price recorded in the fourth quarter of 2013. | ||||
(in millions) | ||||
Fair value of consideration transferred: | ||||
Net cash paid, after post-closing adjustments | $ | 104.3 | ||
Recognized amounts of identifiable assets acquired and liabilities assumed, at fair value: | ||||
Proved properties | $ | 106.4 | ||
Asset retirement obligations | (2.1 | ) | ||
Total fair value of identifiable net assets acquired | $ | 104.3 | ||
Quarterly_Financial_Informatio1
Quarterly Financial Information - Unaudited (Tables) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Selected Quarterly Financial Information [Abstract] | ' | |||||||||||||||||||
Summary of unaudited quarterly financial information | ' | |||||||||||||||||||
Following is a summary of unaudited quarterly financial information: | ||||||||||||||||||||
First | Second | Third | Fourth | Year | ||||||||||||||||
Quarter | Quarter | Quarter | Quarter | |||||||||||||||||
(in millions, except per-share amounts) | ||||||||||||||||||||
2013 | ||||||||||||||||||||
Revenues | $ | 476.9 | $ | 195.6 | $ | 149.6 | $ | 397.9 | $ | 1,220.00 | ||||||||||
Operating income (loss) | 131.4 | 71.2 | (19.4 | ) | 122.6 | 305.8 | ||||||||||||||
Net income (loss) | 72.9 | 39.4 | (19.2 | ) | 68.1 | 161.2 | ||||||||||||||
Asset impairment charge, before income taxes | — | — | 80.6 | — | 80.6 | |||||||||||||||
Basic earnings (loss) per common share | $ | 0.42 | $ | 0.22 | $ | (0.11 | ) | $ | 0.39 | $ | 0.92 | |||||||||
Diluted earnings (loss) per common share | 0.41 | 0.22 | (0.11 | ) | 0.39 | 0.92 | ||||||||||||||
2012 | ||||||||||||||||||||
Revenues | $ | 425.7 | $ | 188.4 | $ | 141.8 | $ | 343 | $ | 1,098.90 | ||||||||||
Operating income | 130.9 | 72.6 | 63.6 | 108.6 | 375.7 | |||||||||||||||
Net income | 75.2 | 39.2 | 33.8 | 63.8 | 212 | |||||||||||||||
Basic earnings per common share | $ | 0.42 | $ | 0.22 | $ | 0.2 | $ | 0.36 | $ | 1.2 | ||||||||||
Diluted earnings per common share | 0.42 | 0.22 | 0.19 | 0.36 | 1.19 | |||||||||||||||
Supplemental_Gas_and_Oil_Infor1
Supplemental Gas and Oil Information - Unaudited (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Extractive Industries [Abstract] | ' | |||||||||||
Capitalized costs of cost-of-service gas and oil properties net of the related accumulated depreciation and amortization | ' | |||||||||||
Capitalized costs of cost-of-service gas and oil properties net of the related accumulated depreciation, depletion and amortization are shown below: | ||||||||||||
December 31, | ||||||||||||
2013 | 2012 | |||||||||||
(in millions) | ||||||||||||
Wexpro | $ | 936.6 | $ | 780.4 | ||||||||
Questar Gas | 7.2 | 7.8 | ||||||||||
Total capitalized costs of cost-of-service activities | $ | 943.8 | $ | 788.2 | ||||||||
Cost incurred for cost-of-service gas and oil development activities | ' | |||||||||||
The costs incurred for cost-of-service gas and oil development activities are displayed in the table below. The costs incurred to develop proved undeveloped reserves were $106.3 million in 2013, $50.4 million in 2012 and $69.7 million in 2011. | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Property acquisition | ||||||||||||
Unproved | $ | 0.3 | $ | 0.6 | $ | — | ||||||
Proved | 106.4 | — | — | |||||||||
Development | 133.1 | 146.9 | 149.1 | |||||||||
Total costs incurred for cost-of-service activities | $ | 239.8 | $ | 147.5 | $ | 149.1 | ||||||
Results of operations for cost-of-service gas- and oil-producing activities, before corporate overhead and interest expenses | ' | |||||||||||
Following are the results of operations for cost-of-service gas- and oil-producing activities, before corporate overhead and interest expenses: | ||||||||||||
Year Ended December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(in millions) | ||||||||||||
Revenues | ||||||||||||
From unaffiliated customers | $ | 45.1 | $ | 36.1 | $ | 31.5 | ||||||
From affiliated company(1) | 294.8 | 274.1 | 253.6 | |||||||||
Total revenues | 339.9 | 310.2 | 285.1 | |||||||||
Production costs | 57.5 | 50.1 | 51.2 | |||||||||
Depreciation, depletion and amortization | 85.8 | 77.4 | 63.9 | |||||||||
Total expenses | 143.3 | 127.5 | 115.1 | |||||||||
Revenues less expenses | 196.6 | 182.7 | 170 | |||||||||
Income taxes | (70.5 | ) | (64.8 | ) | (62.0 | ) | ||||||
Results of operations for cost-of-service gas- and oil-producing activities excluding corporate overhead and interest expenses | $ | 126.1 | $ | 117.9 | $ | 108 | ||||||
(1) Primarily represents revenues received from Questar Gas pursuant to the Wexpro Agreement. Revenues include reimbursement of general and administrative expenses amounting to $27.5 million in 2013, $26.5 million in 2012 and $23.5 million in 2011. | ||||||||||||
Estimated quantities of cost-of-service proved gas and oil reserves | ' | |||||||||||
Estimated quantities of cost-of-service proved gas and oil reserves are set forth below: | ||||||||||||
Natural Gas | Oil and NGL | Natural Gas | ||||||||||
Equivalents | ||||||||||||
(Bcf) | (Mbbl) | (Bcfe) | ||||||||||
Proved Reserves | ||||||||||||
Balances at December 31, 2010 | 738.4 | 4,856 | 767.5 | |||||||||
Revisions - previous estimates | (153.9 | ) | (259 | ) | (155.5 | ) | ||||||
Extensions and discoveries | 224.7 | 1,214 | 232 | |||||||||
Production | (50.5 | ) | (467 | ) | (53.3 | ) | ||||||
Balances at December 31, 2011 | 758.7 | 5,344 | 790.7 | |||||||||
Revisions - previous estimates | (158.4 | ) | (122 | ) | (159.0 | ) | ||||||
Extensions and discoveries | 154.4 | 1,612 | 164 | |||||||||
Production | (57.5 | ) | (665 | ) | (61.5 | ) | ||||||
Balances at December 31, 2012 | 697.2 | 6,169 | 734.2 | |||||||||
Revisions - previous estimates | (112.8 | ) | (1,348 | ) | (120.8 | ) | ||||||
Extensions and discoveries | 153.5 | 857 | 158.6 | |||||||||
Purchase of reserves in place | 133.9 | 556 | 137.2 | |||||||||
Production | (60.6 | ) | (617 | ) | (64.3 | ) | ||||||
Balances at December 31, 2013 | 811.2 | 5,617 | 844.9 | |||||||||
Proved Developed Reserves | ||||||||||||
Balances at December 31, 2010 | 463.8 | 3,138 | 482.6 | |||||||||
Balances at December 31, 2011 | 491.2 | 4,420 | 517.7 | |||||||||
Balances at December 31, 2012 | 523.9 | 4,967 | 553.7 | |||||||||
Balances at December 31, 2013 | 560 | 4,384 | 586.3 | |||||||||
Proved Undeveloped Reserves | ||||||||||||
Balances at December 31, 2010 | 274.6 | 1,718 | 284.9 | |||||||||
Balances at December 31, 2011 | 267.5 | 924 | 273 | |||||||||
Balances at December 31, 2012 | 173.3 | 1,202 | 180.5 | |||||||||
Balances at December 31, 2013 | 251.2 | 1,233 | 258.6 | |||||||||
Schedule_of_Valuation_and_Qual1
Schedule of Valuation and Qualifying Accounts (Tables) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Valuation and Qualifying Accounts [Abstract] | ' | |||||||||||||||
Schedule of Valuation and Qualifying Accounts | ' | |||||||||||||||
QUESTAR CORPORATION | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 3.1 | $ | 0.2 | $ | (1.6 | ) | $ | 1.7 | |||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 3.2 | 1.2 | (1.3 | ) | 3.1 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 3.2 | 2.4 | (2.4 | ) | 3.2 | |||||||||||
QUESTAR GAS COMPANY | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 2.8 | $ | 0.2 | $ | (1.6 | ) | $ | 1.4 | |||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 2.9 | 1.1 | (1.2 | ) | 2.8 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 2.9 | 2.4 | (2.4 | ) | 2.9 | |||||||||||
QUESTAR PIPELINE COMPANY | ||||||||||||||||
Schedule of Valuation and Qualifying Accounts | ||||||||||||||||
Column A | Column B | Column C Amounts charged | Column D Deductions for accounts written off and other | Column E | ||||||||||||
Description | Beginning Balance | to expense | Ending Balance | |||||||||||||
(in millions) | ||||||||||||||||
Year Ended December 31, 2013 | ||||||||||||||||
Allowance for bad debts | $ | 0.3 | $ | — | $ | — | $ | 0.3 | ||||||||
Year Ended December 31, 2012 | ||||||||||||||||
Allowance for bad debts | 0.3 | 0.1 | (0.1 | ) | 0.3 | |||||||||||
Year Ended December 31, 2011 | ||||||||||||||||
Allowance for bad debts | 0.3 | — | — | 0.3 | ||||||||||||
Summary_of_Significant_Account3
Summary of Significant Accounting Policies (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||
Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
bbl | |||||||
lines_of_business | |||||||
Nature of Business [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Number Of Business Lines | ' | ' | ' | ' | 3 | ' | ' |
Revenue Recognition [Abstract] | ' | ' | ' | ' | ' | ' | ' |
After tax rate of return allowed per Wexpro agreement (In hundredths) | 20.00% | ' | ' | ' | 20.00% | ' | ' |
Percentage of operating income retained by Wexpro after expenses (in hundredths) | 46.00% | ' | ' | ' | 46.00% | ' | ' |
Cost of Sales [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Other cost of sales | ' | ' | ' | ' | $100,000 | $0 | $0 |
Total cost of sales | ' | ' | ' | ' | 285,900,000 | 192,300,000 | 321,500,000 |
Cash and Cash Equivalents [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Cash equivalent maturity maximum (months) | ' | ' | ' | ' | '3 months | ' | ' |
Depreciation, depletion and amortization [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Barrel of oil conversion to 6,000 cubic feet of natural gas | ' | ' | ' | ' | 1 | ' | ' |
Impairment of Long-Lived Assets [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Asset impairment | 0 | 80,600,000 | 0 | 0 | 80,600,000 | 0 | 0 |
Capitalized Interest and Allowance for Funds Used During Construction [Abstract] | ' | ' | ' | ' | ' | ' | ' |
AFUDC (recorded as an increase in interest and other income) | ' | ' | ' | ' | 6,300,000 | 2,300,000 | 4,400,000 |
Capitalized interest costs (recorded as a reduction of interest expense) | ' | ' | ' | ' | 800,000 | 200,000 | 600,000 |
Credit Risk [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Bad debt expense | ' | ' | ' | ' | 200,000 | 1,200,000 | 2,400,000 |
Allowance for bad debts | 1,700,000 | ' | ' | ' | 1,700,000 | 3,100,000 | ' |
Income Taxes [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Unrecognized tax benefits | 0 | ' | ' | ' | 0 | 0 | 0 |
Percent of capital expenditures deductible for federal income tax purposes under current statutes (in hundredths) | ' | ' | ' | ' | 50.00% | ' | 100.00% |
Estimated net operating loss (NOL) carryforward | 30,000,000 | ' | ' | ' | 30,000,000 | ' | ' |
Estimated taxable income | ' | ' | ' | ' | 153,800,000 | ' | ' |
Questar Gas [Member] | ' | ' | ' | ' | ' | ' | ' |
Revenue Recognition [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Rate Adjustment Time Period | '6 months | ' | ' | ' | '6 months | ' | ' |
Deferred CET adjustments amortization period | '12 months | ' | ' | ' | '12 months | ' | ' |
Rate adjustment limitation as a percent of non-gas revenues (In hundredths) | 5.00% | ' | ' | ' | 5.00% | ' | ' |
Cost of Sales [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Gas purchases | ' | ' | ' | ' | 186,600,000 | 104,200,000 | 221,200,000 |
Operator service fee | ' | ' | ' | ' | 294,600,000 | 274,000,000 | 253,400,000 |
Transportation and storage | ' | ' | ' | ' | 80,100,000 | 79,600,000 | 78,400,000 |
Gathering | ' | ' | ' | ' | 18,800,000 | 20,500,000 | 25,000,000 |
Royalties | ' | ' | ' | ' | 44,300,000 | 32,000,000 | 38,900,000 |
Storage (injection) withdrawal, net | ' | ' | ' | ' | -800,000 | 1,900,000 | 3,000,000 |
Purchased-gas account adjustment | ' | ' | ' | ' | 22,000,000 | 16,100,000 | 20,600,000 |
Other | ' | ' | ' | ' | 5,000,000 | 5,000,000 | 5,200,000 |
Total Questar Gas cost of natural gas sold | ' | ' | ' | ' | 650,600,000 | 533,300,000 | 645,700,000 |
Elimination of Questar Gas cost of natural gas sold - affiliated parties | ' | ' | ' | ' | -370,900,000 | -347,700,000 | -327,300,000 |
Total Questar Gas cost of natural gas sold - unaffiliated parties | ' | ' | ' | ' | 279,700,000 | 185,600,000 | 318,400,000 |
Contributions in aid of construction [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Time period contributions are refundable if other customers pay to connect to the line (in years) | ' | ' | ' | ' | '5 years | ' | ' |
Time period if no other customers connect to the line the funds are not refundable (in years) | ' | ' | ' | ' | '5 years | ' | ' |
Depreciation, depletion and amortization [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Questar Gas distribution plant | ' | ' | ' | ' | 2.70% | 2.80% | 2.80% |
Capitalized Interest and Allowance for Funds Used During Construction [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Capitalized interest costs (recorded as a reduction of interest expense) | ' | ' | ' | ' | 200,000 | 100,000 | 100,000 |
Credit Risk [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Time period in months uncollected accounts are written off | ' | ' | ' | ' | '6 months | ' | ' |
Wexpro [Member] | ' | ' | ' | ' | ' | ' | ' |
Depreciation, depletion and amortization [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Cost-of-service gas and oil properties, per Mcfe | ' | ' | ' | ' | 1.56 | 1.49 | 1.49 |
Capitalized Interest and Allowance for Funds Used During Construction [Abstract] | ' | ' | ' | ' | ' | ' | ' |
AFUDC (recorded as an increase in interest and other income) | ' | ' | ' | ' | 4,600,000 | 2,100,000 | 3,300,000 |
Questar Pipeline [Member] | ' | ' | ' | ' | ' | ' | ' |
Investment in Unconsolidated Affiliate [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Ownership percentage in unconsolidated affiliate (in hundredths) | 50.00% | ' | ' | ' | 50.00% | ' | ' |
Cost of Sales [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Total Questar Pipeline cost of sales | ' | ' | ' | ' | 6,100,000 | 6,700,000 | 3,100,000 |
Depreciation, depletion and amortization [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Questar Pipeline transportation, storage and other energy services | ' | ' | ' | ' | 3.40% | 3.40% | 3.50% |
Impairment of Long-Lived Assets [Abstract] | ' | ' | ' | ' | ' | ' | ' |
Asset impairment | ' | ' | ' | ' | 80,600,000 | 0 | 0 |
Capitalized Interest and Allowance for Funds Used During Construction [Abstract] | ' | ' | ' | ' | ' | ' | ' |
AFUDC (recorded as an increase in interest and other income) | ' | ' | ' | ' | 1,700,000 | 200,000 | 1,100,000 |
Capitalized interest costs (recorded as a reduction of interest expense) | ' | ' | ' | ' | $600,000 | $100,000 | $500,000 |
Earnings_Per_Share_Details
Earnings Per Share (Details) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Reconciliation of the components of basic and diluted shares in the EPS Calculation [Abstract] | ' | ' | ' |
Weighted-average basic common shares outstanding | 175,400,000 | 176,500,000 | 177,400,000 |
Potential number of shares issuable under the Company's LTSIP | 600,000 | 1,000,000 | 1,400,000 |
Weighted-average diluted common shares outstanding | 176,000,000 | 177,500,000 | 178,800,000 |
Dividend Reinvestment and Stock Purchase Plan (Reinvestment Plan) [Abstract] | ' | ' | ' |
Shares issued | 0 | 0 | 4,400 |
Shares reserved for future issuance | 20,210,415 | ' | ' |
Stock Options [Member] | ' | ' | ' |
Long-Term Stock Incentive Plan [Abstract] | ' | ' | ' |
Stock option minimum term (in years) | '5 years | ' | ' |
Stock option maximum term (in years) | '10 years | ' | ' |
Stock option majority minimum term (in years) | '7 years | ' | ' |
Stock option majority maximum term (in years) | '10 years | ' | ' |
Minimum number of installments for vesting of options held by employees | 3 | ' | ' |
Maximum number of installments for vesting of options held by employees | 4 | ' | ' |
Restricted Shares [Member] | ' | ' | ' |
Long-Term Stock Incentive Plan [Abstract] | ' | ' | ' |
Vesting period for share-based award (in years) | '3 years | ' | ' |
Performance Shares [Member] | ' | ' | ' |
Long-Term Stock Incentive Plan [Abstract] | ' | ' | ' |
Performance share performance period (in years) | '3 years | ' | ' |
Other_Comprehensive_Income_Det
Other Comprehensive Income (Details) (USD $) | 12 Months Ended | |||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | ($246.30) | ' | ' | |
OCI before reclassifications | 135.7 | ' | ' | |
Reclassified from AOCI | 33.5 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | -51.8 | ' | ' | |
Attributable to amounts reclassified from AOCI | -12.9 | [2] | ' | ' |
Income taxes | -64.7 | 12.3 | 75 | |
Net other comprehensive income | 104.5 | -20.2 | -122.1 | |
AOCI at end of year | -141.8 | -246.3 | ' | |
Reclassification Adjustment out of Accumulated Other Comphrensive Income [Abstract] | ' | ' | ' | |
Income Tax Expense (Benefit) | -101.3 | -116.5 | -116.4 | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Change in unrecognized actuarial loss | ' | 13.6 | 62.3 | |
Change in unrecognized prior service cost | ' | -1 | -1.1 | |
Change in fair value of long-term investment | ' | -0.1 | 0 | |
Income taxes | -64.7 | 12.3 | 75 | |
Pension, Actuarial loss [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -202.4 | ' | ' | |
OCI before reclassifications | 123.4 | ' | ' | |
Reclassified from AOCI | 28.9 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | -47.2 | ' | ' | |
Attributable to amounts reclassified from AOCI | -11.1 | [2] | ' | ' |
Income taxes | -58.3 | ' | ' | |
Net other comprehensive income | 94 | ' | ' | |
AOCI at end of year | -108.4 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | -58.3 | ' | ' | |
Pension, Prior service cost [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -1.1 | ' | ' | |
OCI before reclassifications | 0 | ' | ' | |
Reclassified from AOCI | 1.1 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | 0 | ' | ' | |
Attributable to amounts reclassified from AOCI | -0.4 | [2] | ' | ' |
Income taxes | -0.4 | ' | ' | |
Net other comprehensive income | 0.7 | ' | ' | |
AOCI at end of year | -0.4 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | -0.4 | ' | ' | |
Pension, Total [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -203.5 | ' | ' | |
OCI before reclassifications | 123.4 | ' | ' | |
Reclassified from AOCI | 30 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | -47.2 | ' | ' | |
Attributable to amounts reclassified from AOCI | -11.5 | [2] | ' | ' |
Income taxes | -58.7 | ' | ' | |
Net other comprehensive income | 94.7 | ' | ' | |
AOCI at end of year | -108.8 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | -58.7 | ' | ' | |
OPRB, Actuarial Loss [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -19.7 | ' | ' | |
OCI before reclassifications | 12.4 | ' | ' | |
Reclassified from AOCI | 3 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | -4.7 | ' | ' | |
Attributable to amounts reclassified from AOCI | -1.2 | [2] | ' | ' |
Income taxes | -5.9 | ' | ' | |
Net other comprehensive income | 9.5 | ' | ' | |
AOCI at end of year | -10.2 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | -5.9 | ' | ' | |
Long-term investment [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | 0.1 | ' | ' | |
OCI before reclassifications | -0.1 | ' | ' | |
Reclassified from AOCI | 0 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | 0.1 | ' | ' | |
Attributable to amounts reclassified from AOCI | 0 | [2] | ' | ' |
Income taxes | 0.1 | ' | ' | |
Net other comprehensive income | 0 | ' | ' | |
AOCI at end of year | 0.1 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | 0.1 | ' | ' | |
Questar Pipeline [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -23.2 | ' | ' | |
Income taxes | ' | ' | ' | |
Income taxes | -0.2 | -0.2 | 13.8 | |
Net other comprehensive income | 0.3 | 0.2 | -23.4 | |
AOCI at end of year | -22.9 | -23.2 | ' | |
Reclassification Adjustment out of Accumulated Other Comphrensive Income [Abstract] | ' | ' | ' | |
Income Tax Expense (Benefit) | -7 | -37.3 | -38.2 | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Interest rate cash flow hedges | ' | -0.2 | 13.8 | |
Income taxes | -0.2 | -0.2 | 13.8 | |
Questar Pipeline [Member] | Interest rate cash flow hedges [Member] | ' | ' | ' | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | ' | ' | ' | |
AOCI at beginning of year | -23.2 | ' | ' | |
OCI before reclassifications | 0 | ' | ' | |
Reclassified from AOCI | 0.5 | [1] | ' | ' |
Income taxes | ' | ' | ' | |
Attributable to OCI before reclassifications | 0 | ' | ' | |
Attributable to amounts reclassified from AOCI | -0.2 | [2] | ' | ' |
Income taxes | -0.2 | ' | ' | |
Net other comprehensive income | 0.3 | ' | ' | |
AOCI at end of year | -22.9 | ' | ' | |
Income taxes allocated to each component of other comprehensive income (loss) [Abstract] | ' | ' | ' | |
Income taxes | -0.2 | ' | ' | |
Questar Pipeline [Member] | Interest rate cash flow hedges [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | ' | ' | ' | |
Reclassification Adjustment out of Accumulated Other Comphrensive Income [Abstract] | ' | ' | ' | |
Interest Income (Expense), Net | -0.5 | ' | ' | |
Income Tax Expense (Benefit) | $0.20 | ' | ' | |
[1] | Interest rate cash flow hedge amounts are included in their entirety as charges to interest expense on the Consolidated Statements of Income. | |||
[2] | Interest rate cash flow hedge amounts are included in their entirety as credits to income taxes on the Consolidated Statements of Income. |
Asset_Retirement_Obligations_D
Asset Retirement Obligations (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
AROs at beginning of year | $67.20 | $63.80 |
Accretion | 3.3 | 3.4 |
Liabilities incurred | 6 | 3.1 |
Revisions in estimated cash flows | -6.9 | -1.7 |
Liabilities settled | -1.9 | -1.4 |
AROs at end of year | 67.7 | 67.2 |
Asset Retirement Obligations By Line Of Business [Abstract] | ' | ' |
AROs by line of business | 67.7 | 67.2 |
Questar Gas [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
AROs at end of year | 0.6 | 0.5 |
Asset Retirement Obligations By Line Of Business [Abstract] | ' | ' |
AROs by line of business | 0.6 | 0.5 |
Wexpro [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
AROs at end of year | 64.9 | 64.6 |
Asset Retirement Obligations By Line Of Business [Abstract] | ' | ' |
AROs by line of business | 64.9 | 64.6 |
Questar Pipeline [Member] | ' | ' |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' | ' |
AROs at end of year | 2.2 | 2.1 |
Asset Retirement Obligations By Line Of Business [Abstract] | ' | ' |
AROs by line of business | $2.20 | $2.10 |
Fair_Value_Measurements_Detail
Fair Value Measurements (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | Carrying Amount [Member] | Carrying Amount [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Gas [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] | Questar Pipeline [Member] |
Level 1 [Member] | Level 1 [Member] | Level 2 [Member] | Level 2 [Member] | Carrying Amount [Member] | Carrying Amount [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Fair Value, Measurements, Nonrecurring [Member] | Carrying Amount [Member] | Carrying Amount [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | Estimated Fair Value [Member] | |||
Level 1 [Member] | Level 1 [Member] | Level 2 [Member] | Level 2 [Member] | Fair Value, Inputs, Level 3 [Member] | Level 1 [Member] | Level 1 [Member] | Level 2 [Member] | Level 2 [Member] | |||||||||||
Financial assets [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cash and cash equivalents | $16 | $16.80 | $16 | $16.80 | ' | ' | $8.80 | $1.40 | $8.80 | $1.40 | ' | ' | ' | $2.70 | $7.10 | $2.70 | $7.10 | ' | ' |
Long-term investment | 17.3 | 15.5 | 17.3 | 15.5 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Notes receivable from Questar | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 29.4 | 38.7 | 29.4 | 38.7 | ' | ' |
Financial liabilities [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Short-term debt | 276 | 263 | 276 | 263 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Notes payable to Questar | ' | ' | ' | ' | ' | ' | 17.7 | 166.1 | 17.7 | 166.1 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Long-term debt, including current portion | 1,247.10 | 1,140.90 | ' | ' | 1,310.80 | 1,303.10 | 534.5 | 426.5 | ' | ' | 568 | 503.7 | ' | 458.9 | 458.9 | ' | ' | 486 | 536.6 |
Property, Plant, and Equipment, Fair Value Disclosure | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | $0 | ' | ' | ' | ' | ' | ' |
Derivative_Instruments_and_Hed2
Derivative Instruments and Hedging Activities Additional Information (Details) (USD $) | 12 Months Ended | 1 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2011 | Mar. 31, 2012 | Jun. 30, 2011 |
Cash Flow Hedging [Member] | Cash Flow Hedging [Member] | Fair Value Hedging [Member] | Fair Value Hedging [Member] | |
Questar Pipeline [Member] | Questar Pipeline [Member] | Interest Rate Swap [Member] | Interest Rate Swap [Member] | |
Forward Starting Interest Rate Swaps Terminated Q4 2011 [Member] | Forward Starting Interest Rate Swaps Terminated Q4 2011 [Member] | |||
Derivative [Line Items] | ' | ' | ' | ' |
Notional amount | ' | $150 | ' | $125 |
Weighted-average fixed interest rate (in hundredths) | ' | ' | ' | 2.75% |
Derivative, gain on derivative | ' | ' | 7.2 | ' |
Debt instrument, face amount | ' | 180 | ' | ' |
Interest payment for terminated derivative instrument | ' | $37.30 | ' | ' |
Life of long-term debt associated with cash flow hedges | '30 years | ' | ' | ' |
Derivative_Instruments_and_Hed3
Derivative Instruments and Hedging Activities Effects on Statements of Income and OCI (Details) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Fair Value Hedging [Member] | Interest Rate Derivative Instrument [Member] | Interest Expense [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Realized and unrealized gain | $0 | $0 | $9,800,000 |
Fair Value Hedging [Member] | Notes Due 2016, 2.75% [Member] | Interest Expense [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Unrealized loss | 0 | 0 | -9,800,000 |
Questar Pipeline [Member] | Cash Flow Hedging [Member] | Interest Rate Derivative Instrument [Member] | Other Comprehensive Income (Loss) [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Deferrals of effective portions | 0 | 0 | -37,300,000 |
Questar Pipeline [Member] | Cash Flow Hedging [Member] | Interest Rate Derivative Instrument [Member] | Interest Expense [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Losses reclassified from AOCI into earnings for effective portions | -500,000 | -400,000 | -100,000 |
Interest Rate Swap [Member] | Fair Value Hedging [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Ineffectiveness recognized on the fair value hedge | 0 | 0 | 0 |
Forward Starting Interest Rate Swaps Terminated Q4 2011 [Member] | Questar Pipeline [Member] | Cash Flow Hedging [Member] | ' | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' | ' |
Ineffectiveness recognized on the cash flow hedges | 0 | 0 | ' |
Interest rate cash flow hedge ineffectiveness is immaterial | ' | ' | 'Ineffectiveness recognized on the cash flow hedges was de minimis |
Date through which reclassifications into earnings from AOCI will take place | '2041 | ' | ' |
Pre-tax net losses expected to be reclassified from AOCI to earnings | $500,000 | ' | ' |
Reclassification from accumulated OCI to income, estimated time to transfer | '12 months | ' | ' |
Debt_Shortterm_Debt_Details
Debt Short-term Debt (Details) (USD $) | 12 Months Ended | |
Dec. 31, 2013 | Dec. 31, 2012 | |
Short-term Debt [Line Items] | ' | ' |
Commercial paper with various interest rates | $276,000,000 | $263,000,000 |
Revolving credit arrangement [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Revolving credit facility credit commitments | 750,000,000 | 500,000,000 |
Revolving credit facility, maturity date | 19-Apr-18 | 31-Aug-16 |
Additional long-term borrowing permitted under credit facility amendment | 150,000,000 | ' |
Consolidated funded debt percentage of consolidated capital permitted under credit facility amendment | 70.00% | ' |
Commercial paper with various interest rates | 0 | ' |
Commercial paper [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Commercial paper with various interest rates | 276,000,000 | 263,000,000 |
Weighted-average interest rate at end of year | 0.27% | 0.31% |
Questar Gas [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Notes payable to parent | 17,700,000 | 166,100,000 |
Questar Gas [Member] | Notes payable to Questar [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Notes payable to parent | 17,700,000 | 166,100,000 |
Weighted-average interest rate at end of year | 0.30% | 0.39% |
Questar Pipeline [Member] | Notes payable to Questar [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Notes payable to parent | $0 | $0 |
Debt_Longterm_Debt_Details
Debt Long-term Debt (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Debt Instrument [Line Items] | ' | ' |
Total long-term debt outstanding | $1,244.60 | $1,136.60 |
Less current portion | 0 | -42 |
Less unamortized-debt discount | -2.1 | -2.3 |
Plus unamortized-debt premium | 0.7 | 0.8 |
Plus fair value hedge adjustment | 3.9 | 5.8 |
Total long-term debt, less current portion | 1,247.10 | 1,098.90 |
Questar Corp [Member] | 2.75% Notes due 2016 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 2.75% | ' |
Debt Instrument, Maturity Date | 1-Feb-16 | ' |
Total long-term debt outstanding | 250 | 250 |
Questar Gas [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Total long-term debt outstanding | 534.5 | 426.5 |
Total long-term debt, less current portion | 534.5 | 384.5 |
Questar Gas [Member] | 5.00% and 6.89% Medium-term Notes due 2013 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum | 5.00% | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum | 6.89% | ' |
Debt Instrument, Maturity Date | 24-Jan-13 | ' |
Total long-term debt outstanding | 0 | 42 |
Questar Gas [Member] | 5.31% and 6.85% Medium-term Notes due 2017 and 2018 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum | 5.31% | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum | 6.85% | ' |
Debt Instrument, Maturity Date Range, Start | 10-Oct-17 | ' |
Debt Instrument, Maturity Date Range, End | 15-Mar-18 | ' |
Total long-term debt outstanding | 84.5 | 84.5 |
Questar Gas [Member] | 6.30% Notes due 2018 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 6.30% | ' |
Debt Instrument, Maturity Date | 1-Apr-18 | ' |
Total long-term debt outstanding | 50 | 50 |
Questar Gas [Member] | 2.98% Notes due 2024 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 2.98% | 2.98% |
Debt Instrument, Maturity Date | 1-Dec-24 | ' |
Debt instrument, face amount | ' | 40 |
Debt Instrument, Term | ' | '12 years |
Total long-term debt outstanding | 40 | 40 |
Questar Gas [Member] | 3.28% Notes due 2027 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 3.28% | 3.28% |
Debt Instrument, Maturity Date | 1-Dec-27 | ' |
Debt instrument, face amount | ' | 110 |
Debt Instrument, Term | ' | '15 years |
Total long-term debt outstanding | 110 | 110 |
Questar Gas [Member] | 7.20% Notes due 2038 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 7.20% | ' |
Debt Instrument, Maturity Date | 1-Apr-38 | ' |
Total long-term debt outstanding | 100 | 100 |
Questar Gas [Member] | 4.78% Notes due 2043 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 4.78% | ' |
Debt Instrument, Maturity Date | 1-Dec-43 | ' |
Debt instrument, face amount | 90 | ' |
Debt Instrument, Term | '30 years | ' |
Total long-term debt outstanding | 90 | 0 |
Questar Gas [Member] | 4.83% Notes due 2048 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 4.83% | ' |
Debt Instrument, Maturity Date | 1-Dec-48 | ' |
Debt instrument, face amount | 60 | ' |
Debt Instrument, Term | '35 years | ' |
Total long-term debt outstanding | 60 | 0 |
Questar Gas [Member] | Questar Gas Notes due 2012 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Maturity Date | ' | 1-Oct-12 |
Long-Term Debt Amounts Repaid During the Year | ' | 91.5 |
Questar Gas [Member] | Questar Gas Notes Due January 2013 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Maturity Date | ' | 24-Jan-13 |
Long-Term Debt Amounts Repaid During the Year | ' | 40 |
Questar Gas [Member] | Questar Gas Notes due September 2013 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Maturity Date | ' | 30-Sep-13 |
Long-Term Debt Amounts Repaid During the Year | ' | 2 |
Questar Gas [Member] | Questar Gas Notes refinanced in December 2012 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | ' | 6.06% |
Questar Gas [Member] | 2.98% and 3.28% Notes due 2024 and 2027 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Net Proceeds from Issuance of Long-Term Debt | ' | 148.8 |
Questar Gas [Member] | 4.78% and 4.83% Notes due 2043 and 2048 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Net Proceeds from Issuance of Long-Term Debt | 149 | ' |
Questar Pipeline [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Total long-term debt outstanding | 460.1 | 460.1 |
Total long-term debt, less current portion | 458.9 | 458.9 |
Questar Pipeline [Member] | 6.45% and 6.48% Medium-term Notes due 2015 and 2018 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum | 6.45% | ' |
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum | 6.48% | ' |
Debt Instrument, Maturity Date Range, Start | 15-Oct-15 | ' |
Debt Instrument, Maturity Date Range, End | 11-Dec-18 | ' |
Total long-term debt outstanding | 30.1 | 30.1 |
Questar Pipeline [Member] | 5.83% Notes due 2018 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 5.83% | ' |
Debt Instrument, Maturity Date | 1-Feb-18 | ' |
Total long-term debt outstanding | 250 | 250 |
Questar Pipeline [Member] | 4.875% Notes due 2041 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | 4.88% | ' |
Debt Instrument, Maturity Date | 1-Dec-41 | ' |
Total long-term debt outstanding | $180 | $180 |
Debt_Maturities_of_Longterm_De
Debt Maturities of Long-term Debt (Details) (USD $) | 12 Months Ended |
In Millions, unless otherwise specified | Dec. 31, 2013 |
Debt Maturities [Line Items] | ' |
Number of years of long-term debt maturities | '5 years |
Maturities of Long-term Debt [Abstract] | ' |
2014 | $0 |
2015 | 25.1 |
2016 | 250 |
2017 | 14.5 |
2018 | 375 |
Questar Corp [Member] | ' |
Maturities of Long-term Debt [Abstract] | ' |
2014 | 0 |
2015 | 0 |
2016 | 250 |
2017 | 0 |
2018 | 0 |
Questar Gas [Member] | ' |
Maturities of Long-term Debt [Abstract] | ' |
2014 | 0 |
2015 | 0 |
2016 | 0 |
2017 | 14.5 |
2018 | 120 |
Questar Pipeline [Member] | ' |
Maturities of Long-term Debt [Abstract] | ' |
2014 | 0 |
2015 | 25.1 |
2016 | 0 |
2017 | 0 |
2018 | $255 |
Income_Taxes_Details
Income Taxes (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Federal [Abstract] | ' | ' | ' |
Current | $66.50 | $1.30 | $0 |
Deferred | 18.4 | 112 | 110.8 |
State [Abstract] | ' | ' | ' |
Current | 10.7 | 0 | -1.3 |
Deferred | 5.9 | 3.6 | 7.3 |
Deferred investment tax credits recognized | -0.2 | -0.4 | -0.4 |
Total income tax expense | 101.3 | 116.5 | 116.4 |
Difference between the statutory federal income tax rate and the Company's effective income tax rate [Abstract] | ' | ' | ' |
Federal income taxes statutory rate (in hundredths) | 35.00% | 35.00% | 35.00% |
State income taxes, net of federal income tax benefit (in hundredths) | 4.00% | 1.00% | 1.30% |
Tax benefits from dividends paid to employee stock plan (in hundredths) | -1.00% | -0.50% | -0.50% |
Other (in hundredths) | 0.60% | 0.00% | 0.10% |
Effective income tax rate (in hundredths) | 38.60% | 35.50% | 35.90% |
Deferred tax liabilities [Abstract] | ' | ' | ' |
Property, plant and equipment | 797.5 | 767 | ' |
Employee benefits | 30.2 | 33.9 | ' |
Other | 4.9 | 3.2 | ' |
Deferred tax liabilities - noncurrent | 832.6 | 804.1 | ' |
Deferred tax assets [Abstract] | ' | ' | ' |
Asset retirement obligations | 22.7 | 23.2 | ' |
Pension and other postretirement benefits | 73.7 | 138.3 | ' |
Deferred compensation | 14.5 | 8.6 | ' |
Hedging activities | 13.4 | 13.6 | ' |
State tax credits | 3.4 | 3.4 | ' |
Net operating loss carryforward | 0 | 15.8 | ' |
Valuation allowance | -2.3 | -2.2 | ' |
Deferred tax assets, net of allowance - noncurrent | 125.4 | 200.7 | ' |
Net deferred income tax liability - noncurrent | 707.2 | 603.4 | ' |
Deferred income taxes - current [Abstract] | ' | ' | ' |
Deferred tax assets - current | 10.1 | 17.6 | ' |
Deferred tax liabilities - current | 0.4 | 4.6 | ' |
Net deferred income tax asset - current | 9.7 | 13 | ' |
Questar Gas [Member] | ' | ' | ' |
Federal [Abstract] | ' | ' | ' |
Current | 6 | -18.7 | 0 |
Deferred | 23.5 | 45.1 | 26.3 |
State [Abstract] | ' | ' | ' |
Current | 0.6 | 0 | -1.6 |
Deferred | 2 | 1.2 | 3.2 |
Deferred investment tax credits recognized | -0.2 | -0.4 | -0.4 |
Total income tax expense | 31.9 | 27.2 | 27.5 |
Difference between the statutory federal income tax rate and the Company's effective income tax rate [Abstract] | ' | ' | ' |
Federal income taxes statutory rate (in hundredths) | 35.00% | 35.00% | 35.00% |
State income taxes, net of federal income tax benefit (in hundredths) | 2.10% | 1.00% | 1.40% |
Amortization of investment tax credits related to rate-regulated assets (in hundredths) | -0.30% | -0.40% | -0.50% |
Other (in hundredths) | 0.90% | 1.00% | 1.50% |
Effective income tax rate (in hundredths) | 37.70% | 36.60% | 37.40% |
Deferred tax liabilities [Abstract] | ' | ' | ' |
Property, plant and equipment | 322.6 | 293 | ' |
Employee benefits | 14 | 17.2 | ' |
Other | 4.9 | 3.4 | ' |
Deferred tax liabilities - noncurrent | 341.5 | 313.6 | ' |
Deferred tax assets [Abstract] | ' | ' | ' |
Deferred compensation | 0.8 | 0.9 | ' |
Net operating loss carryforward | 0 | 11.1 | ' |
Deferred tax assets, net of allowance - noncurrent | 0.8 | 12 | ' |
Net deferred income tax liability - noncurrent | 340.7 | 301.6 | ' |
Deferred income taxes - current [Abstract] | ' | ' | ' |
Deferred tax assets - current | 3.3 | 6.1 | ' |
Deferred tax liabilities - current | 0.4 | 4.6 | ' |
Net deferred income tax asset - current | 2.9 | 1.5 | ' |
Questar Pipeline [Member] | ' | ' | ' |
Federal [Abstract] | ' | ' | ' |
Current | 20.2 | -5.4 | 0 |
Deferred | -15.2 | 40.4 | 37 |
State [Abstract] | ' | ' | ' |
Current | 1.3 | 1.6 | -0.7 |
Deferred | 0.7 | 0.7 | 1.9 |
Total income tax expense | 7 | 37.3 | 38.2 |
Difference between the statutory federal income tax rate and the Company's effective income tax rate [Abstract] | ' | ' | ' |
Federal income taxes statutory rate (in hundredths) | 35.00% | 35.00% | 35.00% |
State income taxes, net of federal income tax benefit (in hundredths) | 8.50% | 1.60% | 1.00% |
Other (in hundredths) | 2.60% | 0.00% | 0.00% |
Effective income tax rate (in hundredths) | 46.10% | 36.60% | 36.00% |
Deferred tax liabilities [Abstract] | ' | ' | ' |
Property, plant and equipment | 237.1 | 250.8 | ' |
Employee benefits | 7.4 | 8.4 | ' |
Deferred tax liabilities - noncurrent | 244.5 | 259.2 | ' |
Deferred tax assets [Abstract] | ' | ' | ' |
Deferred compensation | 1.8 | 1.5 | ' |
Hedging activities | 13.4 | 13.6 | ' |
State tax credits | 0.7 | 0.7 | ' |
Net operating loss carryforward | 0 | 1 | ' |
Other | 0 | -0.1 | ' |
Deferred tax assets, net of allowance - noncurrent | 15.9 | 16.7 | ' |
Net deferred income tax liability - noncurrent | 228.6 | 242.5 | ' |
Deferred income taxes - current [Abstract] | ' | ' | ' |
Net deferred income tax asset - current | $1.80 | $1.60 | ' |
Commitments_Contingencies_and_2
Commitments, Contingencies and Leases Commitments (Details) (Questar Gas [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Long-term Purchase Commitment [Line Items] | ' | ' | ' |
Natural gas purchased under agreements | $186.50 | $104.10 | $221 |
Gas purchase agreements [Member] | ' | ' | ' |
Long-term Purchase Commitment [Line Items] | ' | ' | ' |
2014 | 27.4 | ' | ' |
2015 | 21 | ' | ' |
2016 | 21.1 | ' | ' |
2017 | 25.3 | ' | ' |
2018 | 29.4 | ' | ' |
Transportation and storage commitments - Related party [Member] | ' | ' | ' |
Long-term Purchase Commitment [Line Items] | ' | ' | ' |
2014 | 74.4 | ' | ' |
2015 | 73.3 | ' | ' |
2016 | 73.3 | ' | ' |
2017 | 46.6 | ' | ' |
2018 | 13.4 | ' | ' |
Transportation and gathering commitments - Third party [Member] | ' | ' | ' |
Long-term Purchase Commitment [Line Items] | ' | ' | ' |
2014 | 27.2 | ' | ' |
2015 | 27.2 | ' | ' |
2016 | 27.2 | ' | ' |
2017 | 27.2 | ' | ' |
2018 | $24.20 | ' | ' |
Commitments_Contingencies_and_3
Commitments, Contingencies and Leases Leases (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Leases, Operating [Abstract] | ' | ' | ' |
Expiration date of lease on current headquarters building | ' | 30-Apr-12 | ' |
Rental expense | ' | $1.50 | $3.20 |
Leases, Capital [Abstract] | ' | ' | ' |
New headquarters building lease term | '17 years | ' | ' |
Commencement date of capital lease on new headquarters building | 1-May-12 | ' | ' |
Description of Lessee Leasing Arrangements, Capital Leases | 'Rental payments under the lease escalate at a rate of 3% per year during the lease term. The lease agreement does not include bargain renewal periods or material rent holidays and is not subject to contingent rent or other unusual provisions. | ' | ' |
Assets under capital lease included in other property, plant and equipment | 40.8 | 40.8 | ' |
Assets under capital lease included in other accumulated depreciation, depletion and amortization | 4.3 | 1.9 | ' |
Current capital lease obligation | 0.9 | 0.7 | ' |
Noncurrent capital lease obligation | 38.4 | 39.3 | ' |
Future minimum payments and present value of net minimum payments under capital lease [Abstract] | ' | ' | ' |
2014 | 3 | ' | ' |
2015 | 3.4 | ' | ' |
2016 | 3.5 | ' | ' |
2017 | 3.6 | ' | ' |
2018 | 3.7 | ' | ' |
After 2018 | 44.8 | ' | ' |
Total minimum lease payments | 62 | ' | ' |
Less: amount representing interest | -22.7 | ' | ' |
Present value of minimum lease payments at year-end | $39.30 | ' | ' |
Wexpro_and_Wexpro_II_Agreement2
Wexpro and Wexpro II Agreements (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Agreement [Line Items] | ' | ' | ' |
Percentage of Wexpro retention (in hundredths) | 46.00% | ' | ' |
Wexpro net investment base at December 31, (in millions) | $589.70 | $531.10 | $474.40 |
Average annual rate of return (after tax) (in hundredths) | 19.70% | 19.90% | 20.00% |
Oil and NGL income sharing (in millions) | 0.6 | 2.5 | 3.3 |
Net cash paid, after post-closing adjustments | $104.30 | ' | ' |
Trail acquisition specified Questar Gas supply percentage (in hundredths) | 65.00% | ' | ' |
Gas-development drilling [Member] | ' | ' | ' |
Agreement [Line Items] | ' | ' | ' |
Percentage of Wexpro after tax rate of return (in hundredths) | 20.20% | ' | ' |
Percentage of premium added to base after-tax rate of return (in hundredths) | 8.00% | ' | ' |
Natural Gas operations [Member] | ' | ' | ' |
Agreement [Line Items] | ' | ' | ' |
Percentage of Wexpro after tax rate of return (in hundredths) | 12.20% | ' | ' |
Developmental Oil Drilling [Member] | ' | ' | ' |
Agreement [Line Items] | ' | ' | ' |
Percentage of Wexpro after tax rate of return (in hundredths) | 17.20% | ' | ' |
Percentage of Wexpro retention (in hundredths) | 46.00% | ' | ' |
Percentage of Questar Gas retention (in hundredths) | 54.00% | ' | ' |
Percentage of premium added to base after-tax rate of return (in hundredths) | 5.00% | ' | ' |
Crude Oil Production [Member] | ' | ' | ' |
Agreement [Line Items] | ' | ' | ' |
Percentage of Wexpro after tax rate of return (in hundredths) | 12.20% | ' | ' |
Percentage of Wexpro retention (in hundredths) | 46.00% | ' | ' |
Rate_Regulation_Details
Rate Regulation (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | $35.80 | $46.70 |
Noncurrent regulatory assets | 20.5 | 21.6 |
Current regulatory liabilities | 14.1 | 5.8 |
Noncurrent regulatory liabilities | 61.2 | 54.4 |
Questar Gas [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 30.2 | 41 |
Noncurrent regulatory assets | 16.1 | 16.4 |
Current regulatory liabilities | 11.1 | 4.3 |
Noncurrent regulatory liabilities | 53 | 46.7 |
Rate Changes [Abstract] | ' | ' |
Current authorized return on equity in Utah | 10.35% | ' |
Amount of requested increase in rates in Utah | 19 | ' |
Requested return on equity in Utah | 10.35% | ' |
Future authorized return on equity in Utah | 9.85% | ' |
Amount of increase in annual revenues in Utah | 7.6 | ' |
Amount of increase in customer rates in Wyoming | 0.6 | ' |
Current authorized return on equity in Wyoming | 9.16% | ' |
Questar Gas [Member] | Purchased-gas adjustment [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 15.2 |
Noncurrent regulatory assets | 0 | 0 |
Current regulatory liabilities | 7.4 | 0 |
Noncurrent regulatory liabilities | 0 | 0 |
Questar Gas [Member] | DSM [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 11.2 | 11 |
Noncurrent regulatory assets | 0 | 0 |
Questar Gas [Member] | Deferred production taxes [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 5.7 | 5 |
Noncurrent regulatory assets | 0 | 0 |
Regulatory asset remaining recovery period (in years) | '12 months | ' |
Questar Gas [Member] | Deferred royalties [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 5.2 | 6.3 |
Noncurrent regulatory assets | 0 | 0 |
Questar Gas [Member] | Contract withholding [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 8.1 | 3.5 |
Noncurrent regulatory assets | 0 | 0 |
Questar Gas [Member] | Cost of reacquired debt [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | 4.8 | 5.3 |
Regulatory asset remaining recovery period (in years) | '9 years | ' |
Questar Gas [Member] | Pipeline integrity costs [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | 9.3 | 8.7 |
Amount of allowed yearly recovery through pipeline integrity regulations | 4.4 | ' |
Questar Gas [Member] | ARO cost-of-service gas wells [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | 2 | 2.4 |
Regulatory asset amortization period (in years) | '18-year | ' |
Questar Gas [Member] | CET [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory liabilities | 3.3 | 4.2 |
Noncurrent regulatory liabilities | 0 | 0 |
Questar Gas [Member] | Cost of plant removal [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory liabilities | 0 | 0 |
Noncurrent regulatory liabilities | 52.7 | 46.2 |
Questar Gas [Member] | Income taxes recoverable from/refundable to customers [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory liabilities | 0 | 0 |
Noncurrent regulatory liabilities | 0.3 | 0.5 |
Questar Gas [Member] | Other Regulatory Assets (Liabilities) [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory liabilities | 0.4 | 0.1 |
Noncurrent regulatory liabilities | 0 | 0 |
Questar Pipeline [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 5.6 | 5.7 |
Noncurrent regulatory assets | 4.4 | 5.2 |
Current regulatory liabilities | 3 | 1.5 |
Noncurrent regulatory liabilities | 8.2 | 7.7 |
Questar Pipeline [Member] | Cost of reacquired debt [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | 2.6 | 3 |
Regulatory asset remaining recovery period (in years) | '7 years | ' |
Questar Pipeline [Member] | Gas imbalance [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 5.3 | 4.4 |
Noncurrent regulatory assets | 0 | 0 |
Current regulatory liabilities | 3 | 1.4 |
Noncurrent regulatory liabilities | 0 | 0 |
Questar Pipeline [Member] | Revenue sharing [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0.3 | 1.3 |
Noncurrent regulatory assets | 0 | 0 |
Current regulatory liabilities | 0 | 0.1 |
Noncurrent regulatory liabilities | 0 | 0 |
Questar Pipeline [Member] | Income taxes recoverable from/refundable to customers [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | 0.6 | 0.9 |
Questar Pipeline [Member] | Postretirement medical [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory liabilities | 0 | 0 |
Noncurrent regulatory liabilities | 8.2 | 7.7 |
Questar Pipeline [Member] | Other Regulatory Assets (Liabilities) [Member] | ' | ' |
Regulatory Assets and Liabilities [Line Items] | ' | ' |
Current regulatory assets | 0 | 0 |
Noncurrent regulatory assets | $1.20 | $1.30 |
ShareBased_Compensation_Genera
Share-Based Compensation General (Details) (USD $) | 12 Months Ended | ||
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ' | ' |
Share-based compensation | $10.20 | $9.90 | $10.10 |
Deferred share-based compensation on restricted share awards | 4.8 | 5.1 | ' |
Cash flow from income tax benefits in excess of recognized compensation expense | 14 | 0 | 9.2 |
Shares available for future grant (in shares) | 5,568,160 | ' | ' |
Total unrecognized compensation cost related to all share-based award types | 7.9 | ' | ' |
Weighted-average period of recognition for total unrecognized compensation cost (in months) | '12 months | ' | ' |
Questar Gas [Member] | ' | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ' | ' |
Share-based compensation | 1.4 | 1.2 | 1.1 |
Questar Pipeline [Member] | ' | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ' | ' |
Share-based compensation | $2 | $2 | $1.80 |
ShareBased_Compensation_Stock_
Share-Based Compensation Stock options (Detail) (Stock Options [Member], USD $) | 12 Months Ended | |
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2013 |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' | ' |
Number of unvested options at end of period | 0 | ' |
Unvested stock options decrease in period (in shares) | 29,398 | ' |
Stock option transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' |
Balance at December 31, 2012 | 770,923 | ' |
Granted | 0 | ' |
Exercised | -53,083 | ' |
Forfeited | 0 | ' |
Balance at December 31, 2013 | 717,840 | ' |
Stock option transactions under the terms of the LTSIP - exercise price [Roll Forward] | ' | ' |
Balance at December 31, 2012 | $11.35 | ' |
Exercised | $4.75 | ' |
Balance at December 31, 2013 | $11.84 | ' |
Stock options outstanding, exercisable and unvested at end of period, by exercise price range [Abstract] | ' | ' |
Number of outstanding options at end of period (in shares) | ' | 717,840 |
Weighted-average remaining term (in years and months) | '2 years 2 months | ' |
Weighted-average exercise price (in dollars per share) | $11.84 | ' |
Number of exercisable options at end of period (in shares) | 717,840 | ' |
Weighted-average exercise price, options exercisable (in dollars per share) | $11.84 | ' |
Stock options, additional disclosures [Abstract] | ' | ' |
Aggregate intrinsic value of outstanding options (in shares) | $8 | ' |
Aggregate intrinsic value of exercisable options | $8 | ' |
Number of Questar stock options held by certain officers, employees and nonemployee directors of QEP (in shares) | 298,098 | ' |
Weighted-average exercise price of Questar stock options awarded to certain officers, employees and nonemployee directors of QEP (in dollars per share) | $11.41 | ' |
Weighted-average remaining life of Questar stock options held by certain officers, employees and nonemployee directors of QEP (in years) | '2 years 5 months | ' |
Options Outstanding Exercise Price Range 1 [Member] | ' | ' |
Stock options outstanding, exercisable and unvested at end of period, by exercise price range [Abstract] | ' | ' |
Minimum exercise price of options outstanding (in dollars per share) | $7.84 | ' |
Maximum exercise price of options outstanding (in dollars per share) | $11.40 | ' |
Number of outstanding options at end of period (in shares) | ' | 404,174 |
Weighted-average remaining term (in years and months) | '1 year 11 months | ' |
Weighted-average exercise price (in dollars per share) | $10.52 | ' |
Number of exercisable options at end of period (in shares) | 404,174 | ' |
Weighted-average exercise price, options exercisable (in dollars per share) | $10.52 | ' |
Options Outstanding Exercise Price Range 2 [Member] | ' | ' |
Stock options outstanding, exercisable and unvested at end of period, by exercise price range [Abstract] | ' | ' |
Minimum exercise price of options outstanding (in dollars per share) | $13.10 | ' |
Maximum exercise price of options outstanding (in dollars per share) | $17.35 | ' |
Number of outstanding options at end of period (in shares) | ' | 313,666 |
Weighted-average remaining term (in years and months) | '2 years 6 months | ' |
Weighted-average exercise price (in dollars per share) | $13.54 | ' |
Number of exercisable options at end of period (in shares) | 313,666 | ' |
Weighted-average exercise price, options exercisable (in dollars per share) | $13.54 | ' |
Minimum [Member] | ' | ' |
Stock option transactions under the terms of the LTSIP - exercise price [Roll Forward] | ' | ' |
Balance at December 31, 2012 | $4.37 | ' |
Exercised | $4.37 | ' |
Balance at December 31, 2013 | $7.84 | ' |
Maximum [Member] | ' | ' |
Stock option transactions under the terms of the LTSIP - exercise price [Roll Forward] | ' | ' |
Balance at December 31, 2012 | $17.35 | ' |
Exercised | $13.10 | ' |
Balance at December 31, 2013 | $17.35 | ' |
Questar Gas [Member] | ' | ' |
Stock options outstanding, exercisable and unvested at end of period, by exercise price range [Abstract] | ' | ' |
Minimum exercise price of options outstanding (in dollars per share) | $11.40 | ' |
Maximum exercise price of options outstanding (in dollars per share) | $13.10 | ' |
Number of outstanding options at end of period (in shares) | ' | 17,000 |
Weighted-average remaining term (in years and months) | '2 years 7 months | ' |
Weighted-average exercise price (in dollars per share) | $12.10 | ' |
Number of exercisable options at end of period (in shares) | 17,000 | ' |
Weighted-average exercise price, options exercisable (in dollars per share) | $12.10 | ' |
Questar Pipeline [Member] | ' | ' |
Stock options outstanding, exercisable and unvested at end of period, by exercise price range [Abstract] | ' | ' |
Minimum exercise price of options outstanding (in dollars per share) | $7.84 | ' |
Maximum exercise price of options outstanding (in dollars per share) | $13.10 | ' |
Number of outstanding options at end of period (in shares) | ' | 158,933 |
Weighted-average remaining term (in years and months) | '1 year 7 months | ' |
Weighted-average exercise price (in dollars per share) | $9.36 | ' |
Number of exercisable options at end of period (in shares) | 158,933 | ' |
Weighted-average exercise price, options exercisable (in dollars per share) | $9.36 | ' |
ShareBased_Compensation_Restri
Share-Based Compensation Restricted shares (Details) (Restricted Shares [Member], USD $) | 12 Months Ended |
Dec. 31, 2013 | |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' |
Balance at December 31, 2012 | 810,342 |
Granted | 658 |
Vested | -417,882 |
Forfeited | -791 |
Balance at December 31, 2013 | 392,327 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2012 | $17.74 |
Granted | $21.53 |
Vested | $17.24 |
Forfeited | $19.39 |
Balance at December 31, 2013 | $18.28 |
Share-based awards other than options, additional disclosures [Abstract] | ' |
Vesting period for share-based award (in years) | '3 years |
Weighted-average remaining vesting period of share-based awards issued (in months) | '7 months |
Minimum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2012 | $13.10 |
Granted | $21.53 |
Vested | $13.10 |
Forfeited | $19.39 |
Balance at December 31, 2013 | $13.10 |
Maximum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2012 | $20.90 |
Granted | $21.53 |
Vested | $20.90 |
Forfeited | $19.39 |
Balance at December 31, 2013 | $21.53 |
Questar Gas [Member] | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' |
Balance at December 31, 2013 | 58,837 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $18.60 |
Share-based awards other than options, additional disclosures [Abstract] | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | '6 months |
Questar Gas [Member] | Minimum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $13.10 |
Questar Gas [Member] | Maximum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $19.39 |
Questar Pipeline [Member] | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' |
Balance at December 31, 2013 | 70,758 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $18.78 |
Share-based awards other than options, additional disclosures [Abstract] | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | '7 months |
Questar Pipeline [Member] | Minimum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $13.10 |
Questar Pipeline [Member] | Maximum [Member] | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' |
Balance at December 31, 2013 | $19.56 |
ShareBased_Compensation_Restri1
Share-Based Compensation Restricted stock units (Details) (USD $) | 9 Months Ended | 12 Months Ended |
Sep. 30, 2013 | Dec. 31, 2013 | |
Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' |
Granted | ' | 330,061 |
Vested | ' | -12,522 |
Forfeited | ' | -1,271 |
Balance at December 31, 2013 | ' | 316,268 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Granted | ' | $23.62 |
Vested | ' | $23.62 |
Forfeited | ' | $23.62 |
Balance at December 31, 2013 | ' | $23.62 |
Share-based awards other than options, additional disclosures [Abstract] | ' | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | '14 months | ' |
Number of shares of common stock to be issued for each vested restricted stock unit (RSU) | 1 | ' |
Vesting period for share-based award (in years) | '3 years | ' |
Deferred Restricted Stock Units (RSUs) [Member] | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | 73,646 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $15.73 |
Share-based awards other than options, additional disclosures [Abstract] | ' | ' |
Number of shares of common stock to be issued for each vested restricted stock unit (RSU) | ' | 1 |
Vesting period for share-based award (in years) | ' | '3 years |
Minimum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Granted | ' | $22.17 |
Vested | ' | $23.62 |
Forfeited | ' | $23.62 |
Balance at December 31, 2013 | ' | $22.17 |
Maximum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Granted | ' | $25.44 |
Vested | ' | $23.62 |
Forfeited | ' | $23.62 |
Balance at December 31, 2013 | ' | $25.44 |
Questar Gas [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | 55,631 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $23.54 |
Share-based awards other than options, additional disclosures [Abstract] | ' | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | ' | '14 months |
Questar Gas [Member] | Minimum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $22.17 |
Questar Gas [Member] | Maximum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $23.62 |
Questar Pipeline [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | 50,230 |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $23.62 |
Share-based awards other than options, additional disclosures [Abstract] | ' | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | ' | '14 months |
Questar Pipeline [Member] | Minimum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $23.62 |
Questar Pipeline [Member] | Maximum [Member] | Restricted Stock Units [Member] | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' |
Balance at December 31, 2013 | ' | $23.62 |
ShareBased_Compensation_Perfor
Share-Based Compensation Performance shares (Details) (Performance Shares [Member], USD $) | 12 Months Ended | ||
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Major assumptions used in the calculation of fair value of performance shares granted [Abstract] | ' | ' | ' |
Weighted-average grant date fair value, performance shares granted (in dollars per share) | $39.62 | $25.42 | $18.23 |
Risk-free interest rate (in hundredths) | 0.40% | 0.35% | 1.32% |
Expected price volatility (in hundredths) | 19.00% | 22.00% | 31.30% |
Expected dividend yield (in hundredths) | 2.88% | 3.35% | 3.39% |
Expected life (in years and months) | '2 years 11 months | '2 years 11 months | '2 years 11 months |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' | ' |
Balance at December 31, 2012 | 264,867 | ' | ' |
Granted | 126,606 | ' | ' |
Forfeited | -3,594 | ' | ' |
Balance at December 31, 2013 | 387,879 | 264,867 | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2012 | $21.94 | ' | ' |
Granted | $39.62 | $25.42 | $18.23 |
Forfeited | $33.09 | ' | ' |
Balance at December 31, 2013 | $27.61 | $21.94 | ' |
Performance shares, additional disclosures [Abstract] | ' | ' | ' |
Performance period that the target number of performance shares for each exectutive officer is subject to adjustment based on the company's performance (in years) | '3 years | ' | ' |
Equity- and liability-based performance share compensation expense | $2 | $1.80 | $0.60 |
Weighted-average remaining vesting period of share-based awards issued (in months) | '18 months | ' | ' |
Vested Undistributed [Member] | ' | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | 130,221 | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $18.44 | ' | ' |
Performance shares, additional disclosures [Abstract] | ' | ' | ' |
The date the share-based award will be distributed | 'first quarter of 2014 | ' | ' |
Minimum [Member] | ' | ' | ' |
Major assumptions used in the calculation of fair value of performance shares granted [Abstract] | ' | ' | ' |
Weighted-average grant date fair value, performance shares granted (in dollars per share) | $39.62 | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2012 | $18.23 | ' | ' |
Granted | $39.62 | ' | ' |
Forfeited | $18.23 | ' | ' |
Balance at December 31, 2013 | $18.23 | ' | ' |
Maximum [Member] | ' | ' | ' |
Major assumptions used in the calculation of fair value of performance shares granted [Abstract] | ' | ' | ' |
Weighted-average grant date fair value, performance shares granted (in dollars per share) | $39.62 | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2012 | $25.42 | ' | ' |
Granted | $39.62 | ' | ' |
Forfeited | $39.62 | ' | ' |
Balance at December 31, 2013 | $39.62 | ' | ' |
Questar Gas [Member] | ' | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | 34,326 | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $27.91 | ' | ' |
Performance shares, additional disclosures [Abstract] | ' | ' | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | '18 months | ' | ' |
Questar Gas [Member] | Minimum [Member] | ' | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $18.23 | ' | ' |
Questar Gas [Member] | Maximum [Member] | ' | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $39.62 | ' | ' |
Questar Pipeline [Member] | ' | ' | ' |
Transactions under the terms of the LTSIP - shares [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | 65,283 | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $26.85 | ' | ' |
Performance shares, additional disclosures [Abstract] | ' | ' | ' |
Weighted-average remaining vesting period of share-based awards issued (in months) | '18 months | ' | ' |
Questar Pipeline [Member] | Minimum [Member] | ' | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $18.23 | ' | ' |
Questar Pipeline [Member] | Maximum [Member] | ' | ' | ' |
Transactions under the terms of LTSIP - grant-date fair value [Roll Forward] | ' | ' | ' |
Balance at December 31, 2013 | $39.62 | ' | ' |
Employee_Benefits_Defined_bene
Employee Benefits Defined benefit plans disclosures (Details) | 12 Months Ended | |
Dec. 31, 2013 | Dec. 31, 2012 | |
Total debt securities [Abstract] | ' | ' |
Time over which set performance objectives for each investment manager are expected to be met (in years) | '3 years | ' |
Minimum [Member] | ' | ' |
Total debt securities [Abstract] | ' | ' |
Average maturities for investment-grade intermediate-term debt (in years) | '5 years | ' |
Average maturities for investment-grade long-term debt (in years) | '10 years | ' |
Maximum [Member] | ' | ' |
Total debt securities [Abstract] | ' | ' |
Average maturities for investment-grade intermediate-term debt (in years) | '10 years | ' |
Average maturities for below-investment-grade debt (in years) | '10 years | ' |
Total domestic equity securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 38.00% | 34.00% |
Policy Range [Abstract] | ' | ' |
Total domestic equity securities - minimum range (in hundredths) | 35.00% | 35.00% |
Total domestic equity securities - maximum range (in hundredths) | 45.00% | 45.00% |
Total foreign securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 25.00% | 25.00% |
Policy Range [Abstract] | ' | ' |
Total domestic equity securities - minimum range (in hundredths) | 25.00% | 25.00% |
Total domestic equity securities - maximum range (in hundredths) | 35.00% | 35.00% |
Developed market foreign equity securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 20.00% | 20.00% |
Emerging market foreign equity securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 5.00% | 5.00% |
Total debt securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 27.00% | 28.00% |
Policy Range [Abstract] | ' | ' |
Total domestic equity securities - minimum range (in hundredths) | 25.00% | 25.00% |
Total domestic equity securities - maximum range (in hundredths) | 35.00% | 35.00% |
Investment grade intermediate term debt [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 7.00% | 4.00% |
Investment grade long-term debt [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 11.00% | 14.00% |
Below-Investment grade debt [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 9.00% | 10.00% |
Inflation protection securities [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 9.00% | 9.00% |
Policy Range [Abstract] | ' | ' |
Total domestic equity securities - minimum range (in hundredths) | 0.00% | 0.00% |
Total domestic equity securities - maximum range (in hundredths) | 10.00% | 10.00% |
Cash and short-term investments [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Total domestic equity securities (in hundredths) | 1.00% | 4.00% |
Policy Range [Abstract] | ' | ' |
Total domestic equity securities - minimum range (in hundredths) | 0.00% | 0.00% |
Total domestic equity securities - maximum range (in hundredths) | 3.00% | 3.00% |
Employee_Benefits_Schedule_of_
Employee Benefits Schedule of fair value of financial assets for pension and postretirement benefits (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $672 | $548.40 |
Corporate bonds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 1.7 | 1.9 |
U.S. government securities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 1.6 | 2 |
Fixed income registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 110.7 | 79.2 |
Inflation protection registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 29.4 | 25.5 |
Domestic equity registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 2 | 1.9 |
Cash equivalent commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 3.5 | 20.8 |
Domestic equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 256.2 | 185.9 |
Foreign equity growth commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 42.9 | 37.3 |
Foreign equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 76 | 60.1 |
Corporate debt commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 72.1 | 72.8 |
Inflation protection commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 28.8 | 24.5 |
Foreign equity growth 103-12 investment entities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 47.1 | 36.5 |
Level 1 [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 142.1 | 106.6 |
Level 1 [Member] | Corporate bonds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | U.S. government securities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Fixed income registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 110.7 | 79.2 |
Level 1 [Member] | Inflation protection registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 29.4 | 25.5 |
Level 1 [Member] | Domestic equity registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 2 | 1.9 |
Level 1 [Member] | Cash equivalent commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Domestic equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Foreign equity growth commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Foreign equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Corporate debt commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Inflation protection commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 1 [Member] | Foreign equity growth 103-12 investment entities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 2 [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 529.9 | 441.8 |
Level 2 [Member] | Corporate bonds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 1.7 | 1.9 |
Level 2 [Member] | U.S. government securities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 1.6 | 2 |
Level 2 [Member] | Fixed income registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 2 [Member] | Inflation protection registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 2 [Member] | Domestic equity registered investment companies [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 |
Level 2 [Member] | Cash equivalent commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 3.5 | 20.8 |
Level 2 [Member] | Domestic equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 256.2 | 185.9 |
Level 2 [Member] | Foreign equity growth commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 42.9 | 37.3 |
Level 2 [Member] | Foreign equity index commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 76 | 60.1 |
Level 2 [Member] | Corporate debt commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 72.1 | 72.8 |
Level 2 [Member] | Inflation protection commingled funds [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 28.8 | 24.5 |
Level 2 [Member] | Foreign equity growth 103-12 investment entities [Member] | ' | ' |
Defined Benefit Plan Disclosure Fair Value [Line Items] | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $47.10 | $36.50 |
Employee_Benefits_Pension_and_
Employee Benefits Pension and postretirement benefit plan disclosures (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
semimonthly_pay_periods | |||
Change in plan assets [Roll Forward] | ' | ' | ' |
Fair value of plan assets at end of year | $672 | $548.40 | ' |
Pension Plans, Defined Benefit [Member] | ' | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' | ' |
Number of consecutive semimonthly pay periods of highest earnings, on which pension plan benefits are based | 72 | ' | ' |
Number of final years of employment, during which the highest 72 consecutive semimonthly earnings periods for pension plan benefits are determined | '10 years | ' | ' |
Accumulated benefit obligation | 597.8 | ' | ' |
Change in benefit obligation [Roll Forward] | ' | ' | ' |
Benefit obligation at beginning of year | 760.3 | 646.9 | ' |
Service cost | 13.9 | 13.2 | 9.3 |
Interest cost | 30.6 | 31.1 | 28.5 |
Change in plan assumptions | -73.6 | 69 | ' |
Actuarial (gain) loss | -7.7 | 18.2 | ' |
Benefits paid | -20.8 | -18.1 | ' |
Benefit obligation at end of year | 702.7 | 760.3 | 646.9 |
Change in plan assets [Roll Forward] | ' | ' | ' |
Fair value of plan assets at beginning of year | 510.8 | 390 | ' |
Actual gain on plan assets | 80.2 | 59.3 | ' |
Company contributions to the plan | 58 | 79.6 | ' |
Fair value of plan assets at end of year | 628.2 | 510.8 | 390 |
Funded status of plan [Abstract] | ' | ' | ' |
Underfunded status (current and long-term) | -74.5 | -249.5 | ' |
Estimated benefit-plan payments for the next five years and subsequent five years aggregated [Abstract] | ' | ' | ' |
2014 | 26.7 | ' | ' |
2015 | 35.9 | ' | ' |
2016 | 27.9 | ' | ' |
2017 | 28.7 | ' | ' |
2018 | 31.1 | ' | ' |
2019 through 2023 | 195.7 | ' | ' |
Components of pension and postretirement benefits expense [Abstract] | ' | ' | ' |
Service cost | 13.9 | 13.2 | 9.3 |
Interest cost | 30.6 | 31.1 | 28.5 |
Expected return on plan assets | -38.1 | -31.8 | -26 |
Prior service and other costs | 1.1 | 1.1 | 1.1 |
Recognized net actuarial loss | 28.9 | 24.9 | 12.1 |
Curtailment charges | 0 | 0 | 0.8 |
Accretion of regulatory liability | 0 | 0 | 0 |
Net periodic cost | 36.4 | 38.5 | 25.8 |
Pension Plans, Defined Benefit, Qualified Only [Member] | ' | ' | ' |
Assumptions used to calculate benefit obligations [Abstract] | ' | ' | ' |
Discount rate used to calculate benefit obligation (in hundredths) | 4.90% | 4.20% | ' |
Rate of increase in compensation used to calculate benefit obligation (in hundredths) | 5.50% | 5.50% | ' |
Long-term return on assets used to calculate benefit obligation (in hundredths) | 7.25% | 7.25% | ' |
Funded status of plan [Abstract] | ' | ' | ' |
Projected pension funding in the next fiscal year | 18 | ' | ' |
Pension Plans, Defined Benefit, Nonqualified Only [Member] | ' | ' | ' |
Assumptions used to calculate benefit obligations [Abstract] | ' | ' | ' |
Discount rate used to calculate benefit obligation (in hundredths) | 3.30% | 2.40% | ' |
Rate of increase in compensation used to calculate benefit obligation (in hundredths) | 5.50% | 5.50% | ' |
Other Postretirement Benefit Plans, Defined Benefit [Member] | ' | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' | ' |
Percent of 1992 contribution, to which the Company's portion of health-care benefits is generally limited for employees who retired after January 1, 1993 | 170.00% | ' | ' |
Period of time over which the transition obligation was amortized that began in 1992 and ended in 2012 (in years) | '20 years | ' | ' |
Assumptions used to calculate benefit obligations [Abstract] | ' | ' | ' |
Discount rate used to calculate benefit obligation (in hundredths) | 4.70% | 4.00% | ' |
Long-term return on assets used to calculate benefit obligation (in hundredths) | 7.25% | 7.25% | ' |
Assumed health care cost trend rates used to calculate benefit obligation [Abstract] | ' | ' | ' |
Health-care inflation rate used to calculate benefit obligation (in hundredths) | 8.00% | 8.50% | ' |
Ultimate health care cost trend rate used to calculate benefit obligation (in hundredths) | 4.50% | 4.50% | ' |
Year that rate reaches ultimate trend rate, used to calculate benefit obligation | '2021 | '2021 | ' |
Change in benefit obligation [Roll Forward] | ' | ' | ' |
Benefit obligation at beginning of year | 94.4 | 88.7 | ' |
Service cost | 0.7 | 0.7 | 0.5 |
Interest cost | 3.7 | 3.8 | 4.2 |
Change in plan assumptions | -8.6 | 7.3 | ' |
Actuarial (gain) loss | -0.5 | -1 | ' |
Benefits paid | -3.4 | -5.1 | ' |
Benefit obligation at end of year | 86.3 | 94.4 | 88.7 |
Change in plan assets [Roll Forward] | ' | ' | ' |
Fair value of plan assets at beginning of year | 37.6 | 34 | ' |
Actual gain on plan assets | 5.8 | 4.6 | ' |
Company contributions to the plan | 3.8 | 4.1 | ' |
Fair value of plan assets at end of year | 43.8 | 37.6 | 34 |
Funded status of plan [Abstract] | ' | ' | ' |
Underfunded status (current and long-term) | -42.5 | -56.8 | ' |
Estimated benefit-plan payments for the next five years and subsequent five years aggregated [Abstract] | ' | ' | ' |
2014 | 4.6 | ' | ' |
2015 | 4.8 | ' | ' |
2016 | 4.9 | ' | ' |
2017 | 5.1 | ' | ' |
2018 | 5.2 | ' | ' |
2019 through 2023 | 27.4 | ' | ' |
Components of pension and postretirement benefits expense [Abstract] | ' | ' | ' |
Service cost | 0.7 | 0.7 | 0.5 |
Interest cost | 3.7 | 3.8 | 4.2 |
Expected return on plan assets | -2.6 | -2.3 | -2.6 |
Prior service and other costs | 0 | 1.6 | 1.9 |
Recognized net actuarial loss | 3 | 2.5 | 0.3 |
Curtailment charges | 0 | 0 | 0 |
Accretion of regulatory liability | 0.5 | 0.3 | 0.5 |
Net periodic cost | $5.30 | $6.60 | $4.80 |
Employee_Benefits_Assumptions_
Employee Benefits Assumptions used to calculate net pension and postretirement benefit costs (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Pension Plans, Defined Benefit [Member] | ' | ' | ' |
Assumed health care cost trend rates used to calculate net benefit costs [Abstract] | ' | ' | ' |
Estimated net benefit cost for next fiscal year | 19.1 | ' | ' |
Estimated amortization of actuarial loss from AOCI for next fiscal year | 15.7 | ' | ' |
Estimated amortization of prior service cost from AOCI for next fiscal year | 0.6 | ' | ' |
Pension Plans, Defined Benefit, Qualified Only [Member] | ' | ' | ' |
Assumptions used to calculate net pension and postretirement benefit costs [Abstract] | ' | ' | ' |
Discount rate used to calculate net benefit costs (in hundredths) | 4.20% | 4.80% | 5.75% |
Rate of increase in compensation used to calculate net benefit costs (in hundredths) | 5.50% | 5.50% | 4.00% |
Long-term return on assets used to calculate net benefit costs (in hundredths) | 7.25% | 7.25% | 7.25% |
Pension Plans, Defined Benefit, Nonqualified Only [Member] | ' | ' | ' |
Assumptions used to calculate net pension and postretirement benefit costs [Abstract] | ' | ' | ' |
Discount rate used to calculate net benefit costs (in hundredths) | 2.40% | 3.30% | 5.75% |
Rate of increase in compensation used to calculate net benefit costs (in hundredths) | 5.50% | 5.50% | 4.00% |
Other Postretirement Benefit Plans, Defined Benefit [Member] | ' | ' | ' |
Assumptions used to calculate net pension and postretirement benefit costs [Abstract] | ' | ' | ' |
Discount rate used to calculate net benefit costs (in hundredths) | 4.00% | 4.40% | 5.75% |
Long-term return on assets used to calculate net benefit costs (in hundredths) | 7.25% | 7.25% | 7.25% |
Assumed health care cost trend rates used to calculate net benefit costs [Abstract] | ' | ' | ' |
Health-care inflation rate used to calculate net benefit costs (in hundredths) | 8.50% | 7.00% | 8.00% |
Ultimate health care cost trend rate used to calculate net benefit costs (in hundredths) | 4.50% | 5.00% | 5.00% |
Year that rate reaches ultimate trend rate, used to calculate net benefit costs | '2021 | '2014 | '2014 |
Estimated net benefit cost for next fiscal year | 2.8 | ' | ' |
Estimated amortization of actuarial loss from AOCI for next fiscal year | 1.2 | ' | ' |
Effect of 1% increase in the health care inflation rate on the yearly service and interest cost | 0 | ' | ' |
Effect of 1% increase in the health care inflation rate on the accumulated post-retirement benefit obligation | 0.8 | ' | ' |
Effect of 1% decrease in the health care inflation rate on the yearly service and interest cost | 0 | ' | ' |
Effect of 1% decrease in the health care inflation rate on the accumulated post-retirement benefit obligation | 0.7 | ' | ' |
Employee_Benefits_Subsidiary_p
Employee Benefits Subsidiary plan participation and Employee Investment Plan (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Percentage of employer contribution match on employees' pre-tax purchase of common stock (in hundredths) | 100.00% | ' | ' |
The maximum percentage of an employees' qualifying earnings used to purchase pre-tax purchases of common stock (in hundredths) | 6.00% | ' | ' |
Yearly EIP contribution expense amount recognized in the current period | $7.20 | $7.30 | $7 |
Pension Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 36.4 | 38.5 | 25.8 |
Other Postretirement Benefit Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 5.3 | 6.6 | 4.8 |
Questar Gas [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Yearly EIP contribution expense amount recognized in the current period | 3.4 | 3.6 | 3.4 |
Questar Gas [Member] | Pension Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 18.1 | 19.7 | 13.4 |
Share of total defined benefit plan contributions | 29.6 | 39.4 | 27.1 |
Questar Gas [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 2.4 | 3.3 | 2.3 |
Share of total defined benefit plan contributions | 2 | 1.9 | 2.2 |
Questar Pipeline [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Yearly EIP contribution expense amount recognized in the current period | 1.4 | 1.4 | 1.4 |
Questar Pipeline [Member] | Pension Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 6.7 | 7.4 | 5 |
Share of total defined benefit plan contributions | 11.2 | 15.1 | 8.7 |
Questar Pipeline [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member] | ' | ' | ' |
Subsidiary plan participation and Employee Investment Plan [Line Items] | ' | ' | ' |
Net periodic cost | 0.2 | 1.2 | 1 |
Share of total defined benefit plan contributions | $0.70 | $0.60 | $0.20 |
Operations_by_Line_of_Business2
Operations by Line of Business (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||||||
In Millions, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
lines_of_business | |||||||||||
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Number of complementary lines of business | ' | ' | ' | ' | ' | ' | ' | ' | 3 | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | $397.90 | $149.60 | $195.60 | $476.90 | $343 | $141.80 | $188.40 | $425.70 | $1,220 | $1,098.90 | $1,194.40 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | 285.9 | 192.3 | 321.5 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 174.3 | 180.8 | 175.9 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | 121 | 120.8 | 117.9 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 4.9 | 0 |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 57.4 | 47.9 | 52.5 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 194.8 | 181.6 | 159.9 |
Asset impairment | 0 | 80.6 | 0 | 0 | ' | ' | ' | ' | 80.6 | 0 | 0 |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | 914 | 728.3 | 827.7 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | -0.2 | 5.1 | 0.2 |
OPERATING INCOME | 122.6 | -19.4 | 71.2 | 131.4 | 108.6 | 63.6 | 72.6 | 130.9 | 305.8 | 375.7 | 366.9 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | 9.9 | 7 | 10.4 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 3.7 | 3.7 | 3.8 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | -56.9 | -57.9 | -56.8 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | -101.3 | -116.5 | -116.4 |
NET INCOME | 68.1 | -19.2 | 39.4 | 72.9 | 63.8 | 33.8 | 39.2 | 75.2 | 161.2 | 212 | 207.9 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 4,054.30 | ' | ' | ' | 3,803.30 | ' | ' | ' | 4,054.30 | 3,803.30 | 3,572.20 |
Goodwill | 9.8 | ' | ' | ' | 9.8 | ' | ' | ' | 9.8 | 9.8 | 9.8 |
Investment in unconsolidated affiliate | 25.6 | ' | ' | ' | 26.5 | ' | ' | ' | 25.6 | 26.5 | 27.3 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 503.7 | 370.7 | 367.7 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 505.6 | 366.3 | 373.9 |
From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 1,220 | 1,098.90 | 1,194.40 |
From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Operating Segments [Member] | Questar Gas [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 985.8 | 862.2 | 968.8 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | 650.6 | 533.3 | 645.7 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 113.1 | 119 | 118.5 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | 52.5 | 51.2 | 51 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | ' | 2.4 | ' |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 18 | 16.2 | 15 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 49.7 | 47.2 | 44.5 |
Asset impairment | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | 883.9 | 769.3 | 874.7 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
OPERATING INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 101.9 | 92.9 | 94.1 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | 5.1 | 5.5 | 5.4 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | -22.3 | -24.1 | -25.9 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | -31.9 | -27.2 | -27.5 |
NET INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 52.8 | 47.1 | 46.1 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 1,762 | ' | ' | ' | 1,593.50 | ' | ' | ' | 1,762 | 1,593.50 | 1,483.80 |
Goodwill | 5.6 | ' | ' | ' | 5.6 | ' | ' | ' | 5.6 | 5.6 | 5.6 |
Investment in unconsolidated affiliate | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 166.2 | 162.1 | 121.5 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 177.3 | 161.2 | 127.7 |
Operating Segments [Member] | Questar Gas [Member] | From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 985.2 | 859.7 | 965.5 |
Operating Segments [Member] | Questar Gas [Member] | From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0.6 | 2.5 | 3.3 |
Operating Segments [Member] | Wexpro [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 339.9 | 310.2 | 285.1 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 28.6 | 26.8 | 22.3 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | 28.7 | 26.8 | 24.2 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | ' | 0.2 | ' |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 28.3 | 20.8 | 25.6 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 85.8 | 77.4 | 63.9 |
Asset impairment | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | 0.6 | 2.5 | 3.3 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | 172 | 154.5 | 139.3 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | -0.2 | 2.4 | -0.1 |
OPERATING INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 167.7 | 158.1 | 145.7 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | 5 | 2.8 | 4.2 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | -0.1 | 0 | 0 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | -62 | -57 | -54.7 |
NET INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 110.6 | 103.9 | 95.2 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 993.8 | ' | ' | ' | 836.1 | ' | ' | ' | 993.8 | 836.1 | 768.2 |
Goodwill | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Investment in unconsolidated affiliate | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 249.5 | 144.5 | 136.2 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 240.7 | 145.5 | 144.3 |
Operating Segments [Member] | Wexpro [Member] | From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 45.1 | 36.1 | 31.5 |
Operating Segments [Member] | Wexpro [Member] | From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 294.8 | 274.1 | 253.6 |
Operating Segments [Member] | Questar Pipeline [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 266.2 | 277.5 | 271.8 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | 6.1 | 6.7 | 3.1 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 32.5 | 35.2 | 35.3 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | 46.7 | 50 | 46.5 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | ' | 0.9 | ' |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 9.3 | 9.1 | 10.1 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 55.5 | 54.3 | 51.2 |
Asset impairment | ' | ' | ' | ' | ' | ' | ' | ' | 80.6 | ' | ' |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | 230.7 | 156.2 | 146.2 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 2.7 | 0.3 |
OPERATING INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 35.5 | 124 | 125.9 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | 1.8 | 0.6 | 0.9 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 3.7 | 3.7 | 3.8 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | -25.8 | -26.3 | -24.5 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | -7 | -37.3 | -38.2 |
NET INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 8.2 | 64.7 | 67.9 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 1,222.80 | ' | ' | ' | 1,298.90 | ' | ' | ' | 1,222.80 | 1,298.90 | 1,286.60 |
Goodwill | 4.2 | ' | ' | ' | 4.2 | ' | ' | ' | 4.2 | 4.2 | 4.2 |
Investment in unconsolidated affiliate | 25.6 | ' | ' | ' | 26.5 | ' | ' | ' | 25.6 | 26.5 | 27.3 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 73.4 | 60.6 | 104.5 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 70 | 58.6 | 93.8 |
Operating Segments [Member] | Questar Pipeline [Member] | From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 189.5 | 203.1 | 197.4 |
Operating Segments [Member] | Questar Pipeline [Member] | From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 76.7 | 74.4 | 74.4 |
Corporate and Other [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0.2 | 0 | 0 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | 0.1 | 0 | 0 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 0.1 | 0 | 0 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | -6.3 | -6.6 | -3.3 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | ' | 1.4 | ' |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 1.8 | 1.8 | 1.8 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 3.8 | 2.7 | 0.3 |
Asset impairment | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | -0.5 | -0.7 | -1.2 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
OPERATING INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 0.7 | 0.7 | 1.2 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | -1.3 | -1.2 | 0.5 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | -9.4 | -8.2 | -7 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | -0.4 | 5 | 4 |
NET INCOME | ' | ' | ' | ' | ' | ' | ' | ' | -10.4 | -3.7 | -1.3 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 75.7 | ' | ' | ' | 74.8 | ' | ' | ' | 75.7 | 74.8 | 33.6 |
Goodwill | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Investment in unconsolidated affiliate | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 14.6 | 3.5 | 5.5 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 17.6 | 1 | 8.1 |
Corporate and Other [Member] | From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0.2 | 0 | 0 |
Corporate and Other [Member] | From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interco. Trans. [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | -372.1 | -351 | -331.3 |
Operating Expenses [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Cost of sales | ' | ' | ' | ' | ' | ' | ' | ' | -370.9 | -347.7 | -327.3 |
Operating and maintenance | ' | ' | ' | ' | ' | ' | ' | ' | 0 | -0.2 | -0.2 |
General and administrative | ' | ' | ' | ' | ' | ' | ' | ' | -0.6 | -0.6 | -0.5 |
Retirement incentive | ' | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' |
Production and other taxes | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Depreciation, depletion and amortization | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Asset impairment | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' |
Other operating expenses | ' | ' | ' | ' | ' | ' | ' | ' | -0.6 | -2.5 | -3.3 |
Total Operating Expenses | ' | ' | ' | ' | ' | ' | ' | ' | -372.1 | -351 | -331.3 |
Net gain (loss) from asset sales | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
OPERATING INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest and other income | ' | ' | ' | ' | ' | ' | ' | ' | -0.7 | -0.7 | -0.6 |
Income from unconsolidated affiliate | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest expense | ' | ' | ' | ' | ' | ' | ' | ' | 0.7 | 0.7 | 0.6 |
Income taxes | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
NET INCOME | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Additional Line-of-Business Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Identifiable assets | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Goodwill | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Investment in unconsolidated affiliate | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Cash capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Accrued capital expenditures including acquisitions | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interco. Trans. [Member] | From unaffiliated customers [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interco. Trans. [Member] | From affiliated companies [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Total Revenues | ' | ' | ' | ' | ' | ' | ' | ' | ($372.10) | ($351) | ($331.30) |
RelatedParty_Transaction_Detai
Related-Party Transaction (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Related Party Transaction [Line Items] | ' | ' | ' |
Oil and NGL income sharing (in millions) | $0.60 | $2.50 | $3.30 |
Questar Gas [Member] | Revenues [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Revenue | 76.3 | 74 | 74.1 |
Questar Gas [Member] | General and Administrative Expense [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 3.5 | 8.8 | 9.6 |
Questar Corp [Member] | General and Administrative Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 48.4 | 49.3 | 47.4 |
Questar Corp [Member] | General and Administrative Expense [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 28.2 | 24.5 | 22.6 |
Questar Corp [Member] | Interest Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 0.5 | 0.6 | 0.3 |
Questar Corp [Member] | Interest Expense [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | ' | ' | 0.1 |
Questar Corp [Member] | Interest Income [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Revenue | 0.2 | 0.1 | 0.1 |
Affiliated Entity [Member] | Rent Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | ' | 0.4 | 1.1 |
Affiliated Entity [Member] | Rent Expense [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | ' | 0.3 | 0.9 |
Questar And Other Affiliates [Member] | General and Administrative Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 6.7 | 13.6 | 14 |
Questar And Other Affiliates [Member] | General and Administrative Expense [Member] | Questar Pipeline [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 4.9 | ' | ' |
Questar Pipeline [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Amount of Mdth per day reserved transportation capacity on Questar Pipeline - peak months | 916 | ' | ' |
Amount of Mdth per day reserved transportation capacity on Questar Pipeline - off-peak months | 841 | ' | ' |
Questar Pipeline [Member] | General and Administrative Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 3.7 | ' | ' |
Questar Pipeline [Member] | Transportation Storage And Processing Expense [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | 73 | 73.6 | 73.7 |
Wexpro [Member] | Revenues [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Oil and NGL income sharing (in millions) | 0.6 | 2.5 | 3.3 |
Wexpro [Member] | Cost of Sales [Member] | Questar Gas [Member] | ' | ' | ' |
Related Party Transaction [Line Items] | ' | ' | ' |
Related Party Expense | $294.60 | $274 | $253.40 |
Strategic_Review_of_Questar_So1
Strategic Review of Questar Southern Trails Pipeline and Impairment of Eastern Segment (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||
In Millions, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Property, Plant and Equipment [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Net book value of Questar Southern Trails Pipeline | $3,603 | ' | ' | ' | $3,603 | $3,363.20 | ' |
Asset impairment charge, before income taxes | 0 | 80.6 | 0 | 0 | 80.6 | 0 | 0 |
Questar Pipeline [Member] | ' | ' | ' | ' | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Net book value of Questar Southern Trails Pipeline | 1,147.10 | ' | ' | ' | 1,147.10 | 1,210.80 | ' |
Asset impairment charge, before income taxes | ' | ' | ' | ' | 80.6 | 0 | 0 |
Questar Pipeline [Member] | Questar Southern Trails Pipeline - Western Segment [Member] | ' | ' | ' | ' | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Net book value of Questar Southern Trails Pipeline | 22 | ' | ' | ' | 22 | ' | ' |
Questar Pipeline [Member] | Questar Southern Trails Pipeline - Eastern Segment [Member] | ' | ' | ' | ' | ' | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Asset impairment charge, before income taxes | ' | ' | ' | ' | 80.6 | ' | ' |
After-tax asset impairment charge | ' | ' | ' | ' | $52.40 | ' | ' |
Wexpro_Acquisition_of_Producin2
Wexpro Acquisition of Producing Properties (Details) (USD $) | 12 Months Ended |
In Millions, unless otherwise specified | Dec. 31, 2013 |
Business Acquisition [Line Items] | ' |
Business Acquisition, Effective Date of Acquisition | 4-Sep-13 |
Business Acquisition, Date of Acquisition Agreement | 25-Jul-13 |
Business Acquisition, Description of Acquired Entity | 'an additional interest in natural gas-producing properties in the Trail Unit of southwestern Wyoming's Vermillion Basin |
Business Combination, Consideration Transferred [Abstract] | ' |
Net cash paid, after post-closing adjustments | $104.30 |
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Net [Abstract] | ' |
Proved properties | 106.4 |
Asset retirement obligations | -2.1 |
Total fair value of identifiable net assets acquired | 104.3 |
Business Acquisition, Pro Forma Information [Abstract] | ' |
Revenue of Acquiree since Acquisition Date, Actual | 6 |
Earnings or Loss of Acquiree since Acquisition Date, Actual | 1.3 |
Business Combination, Separately recognized Transactions, Additional Disclosures [Abstract] | ' |
Acquisition Cost Expensed | $0.30 |
Acquisition Cost Expensed, Financial Statement Caption | 'general and administrative expense |
Quarterly_Financial_Informatio2
Quarterly Financial Information - Unaudited (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||||||
In Millions, except Per Share data, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Selected Quarterly Financial Information [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenues | $397.90 | $149.60 | $195.60 | $476.90 | $343 | $141.80 | $188.40 | $425.70 | $1,220 | $1,098.90 | $1,194.40 |
Operating income (loss) | 122.6 | -19.4 | 71.2 | 131.4 | 108.6 | 63.6 | 72.6 | 130.9 | 305.8 | 375.7 | 366.9 |
Net income (loss) | 68.1 | -19.2 | 39.4 | 72.9 | 63.8 | 33.8 | 39.2 | 75.2 | 161.2 | 212 | 207.9 |
Asset impairment charge, before income taxes | $0 | $80.60 | $0 | $0 | ' | ' | ' | ' | $80.60 | $0 | $0 |
Basic earnings (loss) per common share | $0.39 | ($0.11) | $0.22 | $0.42 | $0.36 | $0.20 | $0.22 | $0.42 | $0.92 | $1.20 | $1.17 |
Diluted earnings (loss) per common share | $0.39 | ($0.11) | $0.22 | $0.41 | $0.36 | $0.19 | $0.22 | $0.42 | $0.92 | $1.19 | $1.16 |
Supplemental_Gas_and_Oil_Infor2
Supplemental Gas and Oil Information - Unaudited Capitalized Costs of Cost-of-Service Activities (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Capitalized Costs Relating to Cost-of-Service Gas and Oil Producing Activities, by Segment [Line Items] | ' | ' |
Total capitalized costs of cost-of-service activities | $943.80 | $788.20 |
Wexpro [Member] | ' | ' |
Capitalized Costs Relating to Cost-of-Service Gas and Oil Producing Activities, by Segment [Line Items] | ' | ' |
Total capitalized costs of cost-of-service activities | 936.6 | 780.4 |
Questar Gas [Member] | ' | ' |
Capitalized Costs Relating to Cost-of-Service Gas and Oil Producing Activities, by Segment [Line Items] | ' | ' |
Total capitalized costs of cost-of-service activities | $7.20 | $7.80 |
Supplemental_Gas_and_Oil_Infor3
Supplemental Gas and Oil Information - Unaudited Costs Incurred for Cost-of-Service Activities (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Property Acquisition [Abstract] | ' | ' | ' |
Unproved | $0.30 | $0.60 | $0 |
Proved | 106.4 | 0 | 0 |
Development | 133.1 | 146.9 | 149.1 |
Total costs incurred for cost-of-service activities | 239.8 | 147.5 | 149.1 |
Cost incurred to develop proved undeveloped reserves | $106.30 | $50.40 | $69.70 |
Supplemental_Gas_and_Oil_Infor4
Supplemental Gas and Oil Information - Unaudited Results of Operations for Oil and Gas Producing Activities (Details) (USD $) | 12 Months Ended | |||||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |||
Revenues [Abstract] | ' | ' | ' | |||
From unaffiliated customers | $45.10 | $36.10 | $31.50 | |||
From affiliated company | 294.8 | [1] | 274.1 | [1] | 253.6 | [1] |
Total revenues | 339.9 | 310.2 | 285.1 | |||
Production costs | 57.5 | 50.1 | 51.2 | |||
Depreciation, depletion and amortization | 85.8 | 77.4 | 63.9 | |||
Total expenses | 143.3 | 127.5 | 115.1 | |||
Revenues less expenses | 196.6 | 182.7 | 170 | |||
Income taxes | -70.5 | -64.8 | -62 | |||
Results of operations for cost-of-service gas- and oil-producing activities excluding corporate overhead and interest expenses | 126.1 | 117.9 | 108 | |||
Reimbursement of general and administrative expenses from Questar Gas included in affiliated-company revenues | $27.50 | $26.50 | $23.50 | |||
[1] | Primarily represents revenues received from Questar Gas pursuant to the Wexpro Agreement. Revenues include reimbursement of general and administrative expenses amounting to $27.5 million in 2013, $26.5 million in 2012 and $23.5 million in 2011. |
Supplemental_Gas_and_Oil_Infor5
Supplemental Gas and Oil Information - Unaudited Proved Developed and Undeveloped Oil and Gas Reserve Quantities (Details) | 12 Months Ended | |||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Dec. 31, 2010 | |
Mcf | Mcf | Mcf | Mcf | |
Reserve Quantities [Line Items] | ' | ' | ' | ' |
Number of years for development plan | '5 years | ' | ' | ' |
Percent of prior year-end proved undeveloped reserves converted to developed status | 42.00% | 15.00% | 19.00% | ' |
Natural Gas (in Mcf) [Member] | ' | ' | ' | ' |
Proved Reserves [Abstract] | ' | ' | ' | ' |
Beginning balance | 697,200,000 | 758,700,000 | 738,400,000 | ' |
Revisions - previous estimates | -112,800,000 | -158,400,000 | -153,900,000 | ' |
Extensions and discoveries | 153,500,000 | 154,400,000 | 224,700,000 | ' |
Purchase of reserves in place | 133,900,000 | ' | ' | ' |
Production | -60,600,000 | -57,500,000 | -50,500,000 | ' |
Ending balance | 811,200,000 | 697,200,000 | 758,700,000 | ' |
Proved Developed Reserves [Abstract] | ' | ' | ' | ' |
Proved Developed Reserves (Volume) | 560,000,000 | 523,900,000 | 491,200,000 | 463,800,000 |
Proved Undeveloped Reserves [Abstract] | ' | ' | ' | ' |
Proved Undeveloped Reserves (Volume) | 251,200,000 | 173,300,000 | 267,500,000 | 274,600,000 |
Oil and NGL (in bbl) [Member] | ' | ' | ' | ' |
Proved Reserves [Abstract] | ' | ' | ' | ' |
Beginning balance | 6,169,000 | 5,344,000 | 4,856,000 | ' |
Revisions - previous estimates | -1,348,000 | -122,000 | -259,000 | ' |
Extensions and discoveries | 857,000 | 1,612,000 | 1,214,000 | ' |
Purchase of reserves in place | 556,000 | ' | ' | ' |
Production | -617,000 | -665,000 | -467,000 | ' |
Ending balance | 5,617,000 | 6,169,000 | 5,344,000 | ' |
Proved Developed Reserves [Abstract] | ' | ' | ' | ' |
Proved Developed Reserves (Volume) | 4,384,000 | 4,967,000 | 4,420,000 | 3,138,000 |
Proved Undeveloped Reserves [Abstract] | ' | ' | ' | ' |
Proved Undeveloped Reserves (Volume) | 1,233,000 | 1,202,000 | 924,000 | 1,718,000 |
Natural Gas Equivalents (in Mcfe) [Member] | ' | ' | ' | ' |
Proved Reserves [Abstract] | ' | ' | ' | ' |
Beginning balance, natural gas equivalent | 844,900,000 | 734,200,000 | 790,700,000 | 767,500,000 |
Revisions - previous estimates, natural gas equivalent | -120,800,000 | -159,000,000 | -155,500,000 | ' |
Extensions and discoveries, natural gas equivalent | 158,600,000 | 164,000,000 | 232,000,000 | ' |
Purchase of reserves in place, natural gas equivalent | 137,200,000 | ' | ' | ' |
Production, natural gas equivalent | -64,300,000 | -61,500,000 | -53,300,000 | ' |
Ending balance, natural gas equivalent | 844,900,000 | 734,200,000 | 790,700,000 | 767,500,000 |
Proved Developed Reserves [Abstract] | ' | ' | ' | ' |
Proved Developed Reserves (BOE) | 586,300,000 | 553,700,000 | 517,700,000 | 482,600,000 |
Proved Undeveloped Reserves [Abstract] | ' | ' | ' | ' |
Proved Undeveloped Reserve (BOE) | 258,600,000 | 180,500,000 | 273,000,000 | 284,900,000 |
Schedule_of_Valuation_and_Qual2
Schedule of Valuation and Qualifying Accounts (Details) (Allowance for Bad Debt [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Movement in Valuation Allowances and Reserves [Roll Forward] | ' | ' | ' |
Beginning Balance | $3.10 | $3.20 | $3.20 |
Amounts charged to expense | 0.2 | 1.2 | 2.4 |
Deductions for accounts written off and other | -1.6 | -1.3 | -2.4 |
Ending Balance | 1.7 | 3.1 | 3.2 |
Questar Gas [Member] | ' | ' | ' |
Movement in Valuation Allowances and Reserves [Roll Forward] | ' | ' | ' |
Beginning Balance | 2.8 | 2.9 | 2.9 |
Amounts charged to expense | 0.2 | 1.1 | 2.4 |
Deductions for accounts written off and other | -1.6 | -1.2 | -2.4 |
Ending Balance | 1.4 | 2.8 | 2.9 |
Questar Pipeline [Member] | ' | ' | ' |
Movement in Valuation Allowances and Reserves [Roll Forward] | ' | ' | ' |
Beginning Balance | 0.3 | 0.3 | 0.3 |
Amounts charged to expense | 0 | 0.1 | 0 |
Deductions for accounts written off and other | 0 | -0.1 | 0 |
Ending Balance | $0.30 | $0.30 | $0.30 |