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x
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ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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¨
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TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
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001-03280
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84-0296600
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(Commission File Number)
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(I.R.S. Employer Identification No.)
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(Registrant, State of Incorporation or Organization, Address of Principal Executive Officers and Telephone Number)
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Public Service Company of Colorado
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(a Colorado corporation)
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1800 Larimer, Suite 1100
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Denver, CO 80202
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303-571-7511
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PART I
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Item 1 —
Business
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Item 1A —
Risk Factors
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Item 1B —
Unresolved Staff Comments
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Item 2 —
Properties
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Item 3 —
Legal Proceedings
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Item 4 —
Mine Safety Disclosures
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PART II
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Item 6 —
Selected Financial Data
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Item 9A —
Controls and Procedures
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Item 9B —
Other Information
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PART III
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Item 11 —
Executive Compensation
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Item 14 —
Principal Accountant Fees and Services
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PART IV
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Item 15 —
Exhibits, Financial Statement Schedules
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Item 16 —
Form 10-K Summary
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GAAP
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Generally accepted accounting principles
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GHG
|
Greenhouse gas
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IPP
|
Independent power producing entity
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ITC
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Investment tax credit
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MGP
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Manufactured gas plant
|
Moody’s
|
Moody’s Investor Services
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Native load
|
Customer demand of retail and wholesale customers whereby a utility has an obligation to serve under statute or long-term contract.
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NAV
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Net asset value
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NOL
|
Net operating loss
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O&M
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Operating and maintenance
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Post-65
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Post-Medicare
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PPA
|
Purchased power agreement
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Pre-65
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Pre-Medicare
|
PTC
|
Production tax credit
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PV
|
Photovoltaic
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REC
|
Renewable energy credit
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ROE
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Return on equity
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RTO
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Regional Transmission Organization
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SERP
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Supplemental executive retirement plan
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SPP
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Southwest Power Pool, Inc.
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Standard & Poor’s
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Standard & Poor’s Ratings Services
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TCJA
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2017 federal tax reform enacted as Public Law No: 115-97, commonly referred to as the Tax Cuts and Jobs Act
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VaR
|
Value at Risk
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VIE
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Variable interest entity
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WOTUS
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Waters of the U.S.
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Measurements
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|
Bcf
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Billion cubic feet
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KV
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Kilovolts
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KWh
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Kilowatt hours
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MMBtu
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Million British thermal units
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MW
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Megawatts
|
MWh
|
Megawatt hours
|
|
|
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PSCo
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||
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Electric customers
|
1.5 million
|
|
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Natural gas customers
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1.4 million
|
|
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Consolidated earnings contribution
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35% to 45%
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Total assets
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$17.3 billion
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|
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Electric generating capacity
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5,685 MW
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|
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Gas storage capacity
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27.1 Bcf
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|
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|
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Year Ended Dec. 31
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||||||||||
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2018
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2017
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|
2016
|
||||||
Electric sales (Millions of KWh)
|
|
|
|
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|
||||||
Residential
|
9,438
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|
|
9,107
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|
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9,272
|
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|||
Large C&I
|
6,566
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|
|
6,449
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|
|
6,371
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|||
Small C&I
|
12,973
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|
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12,796
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|
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12,890
|
|
|||
Public authorities and other
|
270
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|
|
274
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|
|
268
|
|
|||
Total retail
|
29,247
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|
|
28,626
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|
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28,801
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|||
Sales for resale
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7,403
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4,851
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|
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4,672
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|||
Total energy sold
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36,650
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33,477
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33,473
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||||||
Number of customers at end of period
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|
|
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||||||
Residential
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1,271,423
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1,252,376
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1,235,378
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|||
Large C&I
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337
|
|
|
340
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|
|
337
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|||
Small C&I
|
161,713
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160,406
|
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159,299
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|||
Public authorities and other
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54,160
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54,110
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54,048
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|||
Total retail
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1,487,633
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1,467,232
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1,449,062
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|||
Wholesale
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52
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|
|
43
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34
|
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|||
Total customers
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1,487,685
|
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1,467,275
|
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1,449,096
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|||
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||||||
Electric revenues (Millions of Dollars)
|
|
|
|
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|
||||||
Residential
|
$
|
1,025.1
|
|
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$
|
1,033.3
|
|
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$
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1,063.5
|
|
Large C&I
|
406.8
|
|
|
421.1
|
|
|
414.8
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|||
Small C&I
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1,191.2
|
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1,227.9
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|
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1,204.9
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Public authorities and other
|
50.5
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|
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52.8
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54.1
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|||
Total retail
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2,673.6
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2,735.1
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|
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2,737.3
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|||
Wholesale
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179.4
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|
168.0
|
|
|
152.4
|
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|||
Other electric revenues
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178.2
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|
|
100.7
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|
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159.7
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|||
Total electric revenues
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$
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3,031.2
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$
|
3,003.8
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|
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$
|
3,049.4
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||||||
KWh sales per retail customer
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19,660
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19,510
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19,876
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Revenue per retail customer
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$
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1,797
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$
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1,864
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$
|
1,889
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Residential revenue per KWh
|
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10.86
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¢
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11.35
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¢
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11.47
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¢
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Large C&I revenue per KWh
|
6.20
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|
|
6.53
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|
|
6.51
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Small C&I revenue per KWh
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9.18
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9.60
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9.35
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|||
Total retail revenue per KWh
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9.14
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9.55
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9.50
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Wholesale revenue per KWh
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2.42
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3.46
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|
|
3.26
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2018
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|
2017
|
||
Wind
|
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23.8
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%
|
|
23.7
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%
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Hydroelectric and solar
|
|
3.6
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|
|
3.9
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Renewable
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27.4
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%
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27.6
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%
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•
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PSCo had approximately 3,160 MW and 2,560 MW of wind energy on its system at the end of 2018 and 2017, respectively.
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•
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Average cost per MWh of wind energy under these contracts was approximately $43 and $42 for 2018 and 2017, respectively.
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•
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Rush Creek became operational in December 2018. The 2019 average cost per MWh is expected to be $29.
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Coal
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Natural Gas
|
||||||||||
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Cost
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Percent
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|
Cost
|
|
Percent
|
||||||
2018
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|
$
|
1.45
|
|
|
62
|
%
|
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$
|
3.74
|
|
|
38
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%
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2017
|
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1.56
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|
|
70
|
|
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3.82
|
|
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30
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|
Normal
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Dec. 31, 2018 Actual
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|
Dec. 31, 2017 Actual
(a)
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35 - 50
|
|
48
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|
48
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(a)
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Milder weather, purchase commitments and low power and natural gas prices impacted coal inventory levels.
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(Millions of Dollars)
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|
Gas
Supply
(a)
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|
Gas Transportation and Storage
(b)
|
||||
2018
|
|
$
|
412
|
|
|
$
|
589
|
|
2017
|
|
545
|
|
|
620
|
|
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Year of Expiration
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2021 - 2023
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2019 - 2040
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(a)
|
The majority of natural gas supply under contract is covered by a long-term agreement with Anadarko Energy Services Company and the balance of natural gas supply contracts have variable pricing features tied to changes in various natural gas indices. PSCo hedges a portion of that risk through financial instruments. See Note 9 to the consolidated financial statements for further information.
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(b)
|
For incremental supplies, there are limited on-site fuel storage facilities, with a primary reliance on the spot market.
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System Peak Demand (in MW)
|
||||||||
2018
|
|
2017
|
||||||
6,718
|
|
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July 10
|
|
6,671
|
|
|
July 19
|
•
|
ECA
— Recovers fuel and purchased energy costs. Short-term sales margins are shared with retail customers through the ECA. The ECA is revised quarterly.
|
•
|
PCCA
— Recovers purchased capacity payments.
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•
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SCA
— Recovers the difference between PSCo’s actual cost of fuel and costs recovered under its steam service rates. The SCA rate is revised quarterly.
|
•
|
DSMCA
— Recovers DSM, interruptible service costs and performance initiatives for achieving energy savings goals.
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•
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RESA
— Recovers the incremental costs of compliance with the RES with a maximum of 2% of the customer’s bill.
|
•
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WCA
— Recovers costs for customers who choose renewable resources.
|
•
|
TCA
— Recovers costs for transmission investment outside of rate cases.
|
•
|
CACJA
— Recovers costs associated with the CACJA.
|
|
Year Ended Dec. 31
|
||||||||||
|
2018
|
|
2017
|
|
2016
|
||||||
Natural gas deliveries (Thousands of MMBtu)
|
|
|
|
|
|
||||||
Residential
|
97,409
|
|
|
88,843
|
|
|
90,941
|
|
|||
C&I
|
40,467
|
|
|
37,305
|
|
|
38,093
|
|
|||
Total retail
|
137,876
|
|
|
126,148
|
|
|
129,034
|
|
|||
Transportation and other
|
155,281
|
|
|
124,211
|
|
|
117,462
|
|
|||
Total deliveries
|
293,157
|
|
|
250,359
|
|
|
246,496
|
|
|||
|
|
|
|
|
|
||||||
Number of customers at end of period
|
|
|
|
|
|
||||||
Residential
|
1,300,826
|
|
|
1,284,644
|
|
|
1,269,338
|
|
|||
C&I
|
101,036
|
|
|
100,802
|
|
|
100,718
|
|
|||
Total retail
|
1,401,862
|
|
|
1,385,446
|
|
|
1,370,056
|
|
|||
Transportation and other
|
7,891
|
|
|
7,649
|
|
|
7,261
|
|
|||
Total customers
|
1,409,753
|
|
|
1,393,095
|
|
|
1,377,317
|
|
|||
|
|
|
|
|
|
||||||
Natural gas revenues (Millions of Dollars)
|
|
|
|
|
|
||||||
Residential
|
$
|
649.9
|
|
|
$
|
652.9
|
|
|
$
|
611.8
|
|
C&I
|
244.5
|
|
|
247.6
|
|
|
228.1
|
|
|||
Total retail
|
894.4
|
|
|
900.5
|
|
|
839.9
|
|
|||
Transportation and other
|
120.2
|
|
|
94.7
|
|
|
117.8
|
|
|||
Total natural gas revenues
|
$
|
1,014.6
|
|
|
$
|
995.2
|
|
|
$
|
957.7
|
|
|
|
|
|
|
|
||||||
MMBtu sales per retail customer
|
98.35
|
|
|
91.05
|
|
|
94.18
|
|
|||
Revenue per retail customer
|
$
|
638
|
|
|
$
|
650
|
|
|
$
|
613
|
|
Residential revenue per MMBtu
|
6.67
|
|
|
7.35
|
|
|
6.73
|
|
|||
C&I revenue per MMBtu
|
6.04
|
|
|
6.64
|
|
|
5.99
|
|
|||
Transportation and other revenue per MMBtu
|
0.77
|
|
|
0.76
|
|
|
1.00
|
|
2018
|
|
2017
|
||||||
MMBtu
|
|
Date
|
|
MMBtu
|
|
Date
|
||
1,903,878
|
|
(a)
|
Feb. 20
|
|
1,948,167
|
|
|
Jan. 5
|
(a)
|
Decrease in MMBtu output due to milder winter temperatures in 2018.
|
•
|
GCA
— Recovers the costs of purchased natural gas and transportation to meet customer requirements and is revised quarterly to allow for changes in natural gas rates.
|
•
|
DSMCA
— Recovers costs of DSM and performance initiatives to achieve various energy savings goals.
|
•
|
PSIA
— Recovers costs for transmission and distribution pipeline integrity management programs.
|
Station, Location and Unit
|
|
Fuel
|
|
Installed
|
|
MW
(a)
|
|
|
Steam:
|
|
|
|
|
|
|
|
|
Comanche-Pueblo, CO
(b)
|
|
|
|
|
|
|
|
|
Unit 1
|
|
Coal
|
|
1973
|
|
325
|
|
|
Unit 2
|
|
Coal
|
|
1975
|
|
335
|
|
|
Unit 3
|
|
Coal
|
|
2010
|
|
500
|
|
(c)
|
Craig-Craig, CO, 2 Units
(d)
|
|
Coal
|
|
1979 - 1980
|
|
82
|
|
(e)
|
Hayden-Hayden, CO, 2 Units
|
|
Coal
|
|
1965 - 1976
|
|
233
|
|
(f)
|
Pawnee-Brush, CO, 1 Unit
|
|
Coal
|
|
1981
|
|
505
|
|
|
Cherokee-Denver, CO, 1 Unit
|
|
Natural Gas
|
|
1968
|
|
310
|
|
|
Combustion Turbine:
|
|
|
|
|
|
|
|
|
Blue Spruce-Aurora, CO, 2 Units
|
|
Natural Gas
|
|
2003
|
|
264
|
|
|
Cherokee-Denver, CO, 3 Units
|
|
Natural Gas
|
|
2015
|
|
576
|
|
|
Fort St. Vrain-Platteville, CO, 6 Units
|
|
Natural Gas
|
|
1972 - 2009
|
|
968
|
|
|
Rocky Mountain-Keenesburg, CO, 3 Units
|
|
Natural Gas
|
|
2004
|
|
580
|
|
|
Various locations, 6 Units
|
|
Natural Gas
|
|
Various
|
|
171
|
|
|
Hydro:
|
|
|
|
|
|
|
|
|
Cabin Creek-Georgetown, CO
|
|
|
|
|
|
|
|
|
Pumped Storage, 2 Units
|
|
Hydro
|
|
1967
|
|
210
|
|
|
Various locations, 9 Units
|
|
Hydro
|
|
Various
|
|
26
|
|
|
Wind:
|
|
|
|
|
|
|
|
|
Rush Creek, CO, 300 units
|
|
Wind
|
|
2018
|
|
600
|
|
(g)
|
|
|
|
|
Total
|
|
5,685
|
|
|
(a)
|
Summer 2018 net dependable capacity.
|
(b)
|
In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in 2022 and 2025, respectively.
|
(c)
|
Based on PSCo’s ownership interest of
67%
of Unit 3.
|
(d)
|
Craig Unit 1 is expected to be retired early in 2025.
|
(e)
|
Based on PSCo’s ownership interest of
10%
. Craig Unit 1 is expected to be retired early in 2025.
|
(f)
|
Based on PSCo’s ownership interest of
76%
of Unit 1 and
37%
of Unit 2.
|
(g)
|
Generation capability is based on the maximum output level of wind units, including the Rush Creek Wind Project. Capacity is attainable only when wind conditions are sufficiently available (on-demand net dependable capacity is zero).
|
Miles
|
|
|
Transmission
|
2,081
|
|
Distribution
|
22,518
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
First quarter
|
|
$
|
95.4
|
|
|
$
|
87.1
|
|
Second quarter
|
|
100.3
|
|
|
84.0
|
|
||
Third quarter
|
|
103.5
|
|
|
88.6
|
|
||
Fourth quarter
|
|
91.5
|
|
|
76.2
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
Electric revenues before TCJA impact
|
|
$
|
3,095.4
|
|
|
$
|
3,003.8
|
|
Electric fuel and purchased power
|
|
(1,157.2
|
)
|
|
(1,126.7
|
)
|
||
Electric margin before TCJA impact
|
|
$
|
1,938.2
|
|
|
$
|
1,877.1
|
|
TCJA impact (offset as a reduction in income tax)
|
|
(64.2
|
)
|
|
—
|
|
||
Electric margin
|
|
$
|
1,874.0
|
|
|
$
|
1,877.1
|
|
(Millions of Dollars)
|
|
2018 vs. 2017
|
||
Retail sales growth (excluding weather impact)
|
|
$
|
16.4
|
|
DSM program revenues (offset by expenses)
|
|
14.1
|
|
|
Non-fuel riders
|
|
12.9
|
|
|
Estimated impact of weather
|
|
12.8
|
|
|
Other, net
|
|
4.9
|
|
|
Total increase in electric margin before TCJA impact
|
|
$
|
61.1
|
|
TCJA impact (offset as a reduction in income tax)
|
|
(64.2
|
)
|
|
Total decrease in electric margin
|
|
$
|
(3.1
|
)
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
Natural gas revenues before TCJA impact
|
|
$
|
1,044.8
|
|
|
$
|
995.2
|
|
Cost of natural gas sold and transported
|
|
(428.4
|
)
|
|
(458.7
|
)
|
||
Natural gas margin before TCJA impact
|
|
$
|
616.4
|
|
|
$
|
536.5
|
|
TCJA impact (offset as a reduction in income tax)
|
|
(30.2
|
)
|
|
—
|
|
||
Natural gas margin
|
|
$
|
586.2
|
|
|
$
|
536.5
|
|
(Millions of Dollars)
|
|
2018 vs. 2017
|
||
Retail rate increase
|
|
$
|
50.1
|
|
Infrastructure and integrity riders
|
|
14.9
|
|
|
Estimated impact of weather
|
|
8.0
|
|
|
Retail sales growth (excluding weather impact)
|
|
2.8
|
|
|
DSM program revenues (offset by expenses)
|
|
2.6
|
|
|
Other, net
|
|
1.5
|
|
|
Total increase in natural gas margin before TCJA impact
|
|
$
|
79.9
|
|
TCJA impact (offset as a reduction in income tax)
|
|
(30.2
|
)
|
|
Total increase in natural gas margin
|
|
$
|
49.7
|
|
(Millions of Dollars)
|
|
2018 vs. 2017
|
||
Distribution costs
|
|
$
|
13.0
|
|
Natural gas systems damage prevention
|
|
7.2
|
|
|
Business systems and contract labor
|
|
6.7
|
|
|
Plant generation costs
|
|
(1.4
|
)
|
|
Other, net
|
|
1.2
|
|
|
Total increase in O&M expenses
|
|
$
|
26.7
|
|
•
|
Distribution costs reflect higher maintenance expenses, including vegetation management; and
|
•
|
Business systems and contract labor costs increased due to growing network and storage needs, cybersecurity, initiatives to support our customer strategy, and initiatives to improve business processes.
|
Utility Service
|
|
Approval Date
|
|
Additional Information
|
Natural Gas
|
|
December 2018
|
|
In February 2018, the administrative law judge recommended approval of a TCJA settlement agreement, which included a $20 million reduction to PSCo’s provisional rates effective March 1, 2018. In September 2018, PSCo revised its 2018 TCJA benefit estimate to $24 million and requested an equity ratio of 56% to offset the negative impact of the TCJA on credit metrics. In December 2018, the CPUC approved an equity ratio of 54.6% and utilized the remainder of the TCJA benefit to reduce an existing prepaid pension asset. The CPUC also ordered 2018 excess non-plant ADIT benefits of $11.1 million be utilized to accelerate amortization of the prepaid pension asset.
|
Electric
|
|
June 2018
October 2018
|
|
In 2018, the CPUC approved a TCJA settlement agreement that included a customer refund of $42 million in 2018, with the remainder of the $59 million of TCJA benefits to be used to accelerate the amortization of an existing prepaid pension asset. For 2019, the expected customer refund is estimated to be $67 million, and amortization of the prepaid pension asset is estimated to be $34 million. Impacts of the TCJA for 2020 and future years are expected to be addressed in a future electric rate case.
|
Mechanism
|
|
Utility Service
|
|
Amount Requested
(in millions)
|
|
Filing
Date
|
|
Approval
|
|
Additional Information
|
PSCo (CPUC)
|
||||||||||
Multi-Year Rate Case
|
|
Natural Gas
|
|
$139
|
|
June
2017
|
|
Received
|
|
Proposed annual revenue request of $139 million over three years, $63 million for 2018. Requested an ROE of 10.0% and an equity ratio of 55.25%. In August 2018, CPUC approved an increase of $46 million (prior to TCJA impacts). The interim decision included application of a 2016 historic test year, a 13-month average rate base, an ROE of 9.35%, an equity ratio of 54.6% and provided no return on the prepaid pension asset. In December 2018, CPUC issued the final ruling which upheld the interim decision and finalized the TCJA impacts.
In October 2018, the CPUC approved a settlement to extend the PSIA rider through 2021.
|
DSM Incentive
|
|
Electric & Natural Gas
|
|
$11
|
|
April 2018
|
|
Received
|
|
PSCo earned an electric and natural gas DSM incentive of $9 million and $2 million, respectively, for achieving its 2017 savings goals.
|
|
|
Futures / Forwards
|
|||||||||||||||||||||
(Millions
of Dollars)
|
|
Source of
Fair Value
|
|
Maturity
Less Than
1 Year
|
|
Maturity
1 to 3
Years
|
|
Maturity
4 to 5
Years
|
|
Maturity
Greater Than
5 Years
|
|
Total Futures/
Forwards
Fair Value
|
|||||||||||
PSCo
|
|
2
|
|
|
$
|
0.8
|
|
|
$
|
0.5
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
1.3
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
Fair value of commodity trading net contract assets outstanding at Jan. 1
|
|
$
|
0.5
|
|
|
$
|
(0.2
|
)
|
Contracts realized or settled during the period
|
|
(7.8
|
)
|
|
(0.8
|
)
|
||
Commodity trading contract additions and changes during the period
|
|
8.6
|
|
|
1.5
|
|
||
Fair value of commodity trading net contract assets outstanding at Dec. 31
|
|
$
|
1.3
|
|
|
$
|
0.5
|
|
(Millions of Dollars)
|
|
Year Ended
Dec. 31
|
|
VaR Limit
|
|
Average
|
|
High
|
|
Low
|
||||||||||
2018
|
|
$
|
4.83
|
|
|
$
|
6.00
|
|
|
$
|
0.62
|
|
|
$
|
5.63
|
|
|
$
|
0.06
|
|
2017
|
|
0.18
|
|
|
3.00
|
|
|
0.21
|
|
|
0.66
|
|
|
0.04
|
|
/s/ BEN FOWKE
|
|
/s/ ROBERT C. FRENZEL
|
Ben Fowke
|
|
Robert C. Frenzel
|
Chairman and Chief Executive Officer
|
|
Executive Vice President, Chief Financial Officer
|
Feb. 22, 2019
|
|
Feb. 22, 2019
|
/s/ DELOITTE & TOUCHE LLP
|
Minneapolis, Minnesota
|
February 22, 2019
|
|
We have served as the Company’s auditor since 2002.
|
|
|
Year Ended Dec. 31
|
||||||||||
|
|
2018
|
|
2017
|
|
2016
|
||||||
Operating revenues
|
|
|
|
|
|
|
||||||
Electric
|
|
$
|
3,031.2
|
|
|
$
|
3,003.8
|
|
|
$
|
3,049.4
|
|
Natural gas
|
|
1,014.6
|
|
|
995.2
|
|
|
957.7
|
|
|||
Steam and other
|
|
40.4
|
|
|
43.5
|
|
|
40.7
|
|
|||
Total operating revenues
|
|
4,086.2
|
|
|
4,042.5
|
|
|
4,047.8
|
|
|||
|
|
|
|
|
|
|
||||||
Operating expenses
|
|
|
|
|
|
|
||||||
Electric fuel and purchased power
|
|
1,157.2
|
|
|
1,126.7
|
|
|
1,196.4
|
|
|||
Cost of natural gas sold and transported
|
|
428.4
|
|
|
458.7
|
|
|
425.4
|
|
|||
Cost of sales — steam and other
|
|
15.3
|
|
|
16.1
|
|
|
15.9
|
|
|||
Operating and maintenance expenses
|
|
787.5
|
|
|
760.8
|
|
|
759.7
|
|
|||
Demand side management program expenses
|
|
142.2
|
|
|
125.0
|
|
|
118.2
|
|
|||
Depreciation and amortization
|
|
561.1
|
|
|
471.5
|
|
|
443.6
|
|
|||
Taxes (other than income taxes)
|
|
201.9
|
|
|
195.7
|
|
|
196.3
|
|
|||
Total operating expenses
|
|
3,293.6
|
|
|
3,154.5
|
|
|
3,155.5
|
|
|||
|
|
|
|
|
|
|
||||||
Operating income
|
|
792.6
|
|
|
888.0
|
|
|
892.3
|
|
|||
|
|
|
|
|
|
|
||||||
Other income, net
|
|
2.1
|
|
|
7.8
|
|
|
1.1
|
|
|||
Allowance for funds used during construction — equity
|
|
56.4
|
|
|
29.8
|
|
|
18.6
|
|
|||
|
|
|
|
|
|
|
||||||
Interest charges and financing costs
|
|
|
|
|
|
|
||||||
Interest charges — includes other financing costs of
$6.5, $6.3 and $6.3, respectively
|
|
207.9
|
|
|
190.7
|
|
|
181.6
|
|
|||
Allowance for funds used during construction — debt
|
|
(22.2
|
)
|
|
(11.4
|
)
|
|
(7.0
|
)
|
|||
Total interest charges and financing costs
|
|
185.7
|
|
|
179.3
|
|
|
174.6
|
|
|||
|
|
|
|
|
|
|
||||||
Income before income taxes
|
|
665.4
|
|
|
746.3
|
|
|
737.4
|
|
|||
Income taxes
|
|
113.7
|
|
|
252.2
|
|
|
273.9
|
|
|||
Net income
|
|
$
|
551.7
|
|
|
$
|
494.1
|
|
|
$
|
463.5
|
|
|
|
Year Ended Dec. 31
|
||||||||||
|
|
2018
|
|
2017
|
|
2016
|
||||||
Net income
|
|
$
|
551.7
|
|
|
$
|
494.1
|
|
|
$
|
463.5
|
|
|
|
|
|
|
|
|
||||||
Other comprehensive income (loss)
|
|
|
|
|
|
|
||||||
|
|
|
|
|
|
|
||||||
Pension and retiree medical benefits:
|
|
|
|
|
|
|
||||||
Net pension and retiree medical losses arising during the period, net of tax of $0, $0, and ($0.1), respectively
|
|
—
|
|
|
—
|
|
|
(0.2
|
)
|
|||
|
|
—
|
|
|
—
|
|
|
(0.2
|
)
|
|||
|
|
|
|
|
|
|
||||||
Derivative instruments:
|
|
|
|
|
|
|
||||||
Reclassification of losses to net income, net of tax of $0.4, $0.6, and $0.7, respectively
|
|
1.2
|
|
|
1.0
|
|
|
1.0
|
|
|||
|
|
1.2
|
|
|
1.0
|
|
|
1.0
|
|
|||
|
|
|
|
|
|
|
||||||
Other comprehensive income
|
|
1.2
|
|
|
1.0
|
|
|
0.8
|
|
|||
Comprehensive income
|
|
$
|
552.9
|
|
|
$
|
495.1
|
|
|
$
|
464.3
|
|
|
Year Ended Dec. 31
|
||||||||||
|
2018
|
|
2017
|
|
2016
|
||||||
Operating activities
|
|
|
|
|
|
||||||
Net income
|
$
|
551.7
|
|
|
$
|
494.1
|
|
|
$
|
463.5
|
|
Adjustments to reconcile net income to cash provided by operating activities:
|
|
|
|
|
|
||||||
Depreciation and amortization
|
566.1
|
|
|
475.6
|
|
|
446.2
|
|
|||
Deferred income taxes
|
23.8
|
|
|
207.8
|
|
|
222.0
|
|
|||
Allowance for equity funds used during construction
|
(56.4
|
)
|
|
(29.8
|
)
|
|
(18.6
|
)
|
|||
Provision for bad debts
|
16.4
|
|
|
14.3
|
|
|
14.1
|
|
|||
Net realized and unrealized hedging and derivative transactions
|
(6.2
|
)
|
|
2.4
|
|
|
1.3
|
|
|||
Changes in operating assets and liabilities:
|
|
|
|
|
|
||||||
Accounts receivable
|
(42.8
|
)
|
|
(2.2
|
)
|
|
(14.2
|
)
|
|||
Accrued unbilled revenues
|
(17.7
|
)
|
|
1.3
|
|
|
(20.9
|
)
|
|||
Inventories
|
(20.1
|
)
|
|
(9.1
|
)
|
|
0.2
|
|
|||
Prepayments and other
|
12.8
|
|
|
0.2
|
|
|
68.7
|
|
|||
Accounts payable
|
68.7
|
|
|
20.4
|
|
|
38.4
|
|
|||
Net regulatory assets and liabilities
|
(14.6
|
)
|
|
(22.6
|
)
|
|
4.2
|
|
|||
Other current liabilities
|
(12.9
|
)
|
|
71.8
|
|
|
1.9
|
|
|||
Pension and other employee benefit obligations
|
(44.2
|
)
|
|
(16.5
|
)
|
|
(10.6
|
)
|
|||
Other, net
|
(16.3
|
)
|
|
(5.9
|
)
|
|
(29.9
|
)
|
|||
Net cash provided by operating activities
|
1,008.3
|
|
|
1,201.8
|
|
|
1,166.3
|
|
|||
|
|
|
|
|
|
||||||
Investing activities
|
|
|
|
|
|
||||||
Utility capital/construction expenditures
|
(1,577.2
|
)
|
|
(1,445.9
|
)
|
|
(1,095.2
|
)
|
|||
Proceeds from insurance recoveries
|
—
|
|
|
—
|
|
|
0.6
|
|
|||
Investments in utility money pool arrangement
|
(634.0
|
)
|
|
(954.0
|
)
|
|
(444.0
|
)
|
|||
Repayments from utility money pool arrangement
|
654.0
|
|
|
934.0
|
|
|
444.0
|
|
|||
Other, net
|
—
|
|
|
(0.7
|
)
|
|
(1.5
|
)
|
|||
Net cash used in investing activities
|
(1,557.2
|
)
|
|
(1,466.6
|
)
|
|
(1,096.1
|
)
|
|||
|
|
|
|
|
|
||||||
Financing activities
|
|
|
|
|
|
||||||
Proceeds from (repayments of) short-term borrowings, net
|
307.0
|
|
|
(129.0
|
)
|
|
115.0
|
|
|||
Borrowings under utility money pool arrangement
|
780.0
|
|
|
40.0
|
|
|
524.5
|
|
|||
Repayments under utility money pool arrangement
|
(780.0
|
)
|
|
(40.0
|
)
|
|
(524.5
|
)
|
|||
Proceeds from issuance of long-term debt
|
691.1
|
|
|
393.8
|
|
|
244.5
|
|
|||
Repayments of long-term debt
|
(300.0
|
)
|
|
—
|
|
|
(129.5
|
)
|
|||
Capital contributions from parent
|
252.1
|
|
|
335.6
|
|
|
38.8
|
|
|||
Dividends paid to parent
|
(375.3
|
)
|
|
(333.9
|
)
|
|
(336.6
|
)
|
|||
Other, net
|
(0.1
|
)
|
|
(0.1
|
)
|
|
—
|
|
|||
Net cash provided by (used in) financing activities
|
574.8
|
|
|
266.4
|
|
|
(67.8
|
)
|
|||
|
|
|
|
|
|
||||||
Net change in cash and cash equivalents
|
25.9
|
|
|
1.6
|
|
|
2.4
|
|
|||
Cash and cash equivalents at beginning of period
|
7.5
|
|
|
5.9
|
|
|
3.5
|
|
|||
Cash and cash equivalents at end of period
|
$
|
33.4
|
|
|
$
|
7.5
|
|
|
$
|
5.9
|
|
|
|
|
|
|
|
||||||
Supplemental disclosure of cash flow information:
|
|
|
|
|
|
||||||
Cash paid for interest (net of amounts capitalized)
|
$
|
(187.2
|
)
|
|
$
|
(175.0
|
)
|
|
$
|
(171.7
|
)
|
Cash (paid) received for income taxes, net
|
(115.8
|
)
|
|
(7.7
|
)
|
|
22.8
|
|
|||
Supplemental disclosure of non-cash investing transactions:
|
|
|
|
|
|
||||||
Accrued property, plant and equipment additions
|
$
|
142.1
|
|
|
$
|
199.1
|
|
|
$
|
81.1
|
|
Inventory transfers to property, plant and equipment
|
37.2
|
|
|
26.6
|
|
|
40.8
|
|
|||
Allowance for equity funds used during construction
|
56.4
|
|
|
29.8
|
|
|
18.6
|
|
|||
|
|
|
|
|
|
|
|
Dec. 31
|
||||||
|
|
2018
|
|
2017
|
||||
Assets
|
|
|
|
|
||||
Current assets
|
|
|
|
|
||||
Cash and cash equivalents
|
|
$
|
33.4
|
|
|
$
|
7.5
|
|
Accounts receivable, net
|
|
310.3
|
|
|
294.4
|
|
||
Accounts receivable from affiliates
|
|
80.8
|
|
|
14.7
|
|
||
Investments in utility money pool arrangement
|
|
—
|
|
|
20.0
|
|
||
Accrued unbilled revenues
|
|
313.5
|
|
|
295.8
|
|
||
Inventories
|
|
197.4
|
|
|
214.5
|
|
||
Regulatory assets
|
|
120.6
|
|
|
77.3
|
|
||
Derivative instruments
|
|
42.6
|
|
|
3.2
|
|
||
Prepayments and other
|
|
23.8
|
|
|
35.7
|
|
||
Total current assets
|
|
1,122.4
|
|
|
963.1
|
|
||
|
|
|
|
|
||||
Property, plant and equipment, net
|
|
15,120.0
|
|
|
14,025.8
|
|
||
|
|
|
|
|
||||
Other assets
|
|
|
|
|
|
|
||
Regulatory assets
|
|
1,010.7
|
|
|
950.3
|
|
||
Derivative instruments
|
|
1.2
|
|
|
1.0
|
|
||
Other
|
|
37.2
|
|
|
27.4
|
|
||
Total other assets
|
|
1,049.1
|
|
|
978.7
|
|
||
Total assets
|
|
$
|
17,291.5
|
|
|
$
|
15,967.6
|
|
|
|
|
|
|
||||
Liabilities and Equity
|
|
|
|
|
|
|
||
Current liabilities
|
|
|
|
|
|
|
||
Current portion of long-term debt
|
|
$
|
406.2
|
|
|
$
|
305.6
|
|
Short-term debt
|
|
307.0
|
|
|
—
|
|
||
Accounts payable
|
|
503.4
|
|
|
492.9
|
|
||
Accounts payable to affiliates
|
|
46.0
|
|
|
58.7
|
|
||
Regulatory liabilities
|
|
67.3
|
|
|
66.1
|
|
||
Taxes accrued
|
|
202.0
|
|
|
222.5
|
|
||
Accrued interest
|
|
43.2
|
|
|
48.6
|
|
||
Dividends payable to parent
|
|
91.5
|
|
|
76.2
|
|
||
Derivative instruments
|
|
34.6
|
|
|
7.3
|
|
||
Other
|
|
101.5
|
|
|
92.3
|
|
||
Total current liabilities
|
|
1,802.7
|
|
|
1,370.2
|
|
||
|
|
|
|
|
||||
Deferred credits and other liabilities
|
|
|
|
|
|
|
||
Deferred income taxes
|
|
1,719.3
|
|
|
1,644.5
|
|
||
Deferred investment tax credits
|
|
25.3
|
|
|
27.8
|
|
||
Regulatory liabilities
|
|
2,021.5
|
|
|
1,933.5
|
|
||
Asset retirement obligations
|
|
338.7
|
|
|
347.8
|
|
||
Derivative instruments
|
|
0.6
|
|
|
3.5
|
|
||
Customer advances
|
|
168.1
|
|
|
162.6
|
|
||
Pension and employee benefit obligations
|
|
275.3
|
|
|
287.8
|
|
||
Other
|
|
50.4
|
|
|
58.9
|
|
||
Total deferred credits and other liabilities
|
|
4,599.2
|
|
|
4,466.4
|
|
||
|
|
|
|
|
||||
Commitments and contingencies
|
|
|
|
|
|
|
||
Capitalization
|
|
|
|
|
|
|
||
Long-term debt
|
|
4,591.4
|
|
|
4,302.7
|
|
||
Common stock — 100 shares authorized of $0.01 par value; 100 shares
outstanding at Dec. 31, 2018 and 2017, respectively
|
|
—
|
|
|
—
|
|
||
Additional paid in capital
|
|
4,340.5
|
|
|
4,032.8
|
|
||
Retained earnings
|
|
1,983.2
|
|
|
1,822.2
|
|
||
Accumulated other comprehensive loss
|
|
(25.5
|
)
|
|
(26.7
|
)
|
||
Total common stockholder’s equity
|
|
6,298.2
|
|
|
5,828.3
|
|
||
Total liabilities and equity
|
|
$
|
17,291.5
|
|
|
$
|
15,967.6
|
|
|
Common Stock
|
|
|
|
Accumulated
Other
Comprehensive
Income (Loss)
|
|
Total Common
Stockholder’s
Equity
|
|||||||||||||||
|
Shares
|
|
Par Value
|
|
Additional
Paid In
Capital
|
|
Retained
Earnings
|
|
|
|||||||||||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Balance at Dec. 31, 2015
|
100
|
|
|
$
|
—
|
|
|
$
|
3,620.8
|
|
|
$
|
1,523.2
|
|
|
$
|
(23.8
|
)
|
|
$
|
5,120.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Net income
|
|
|
|
|
|
|
463.5
|
|
|
|
|
463.5
|
|
|||||||||
Other comprehensive income
|
|
|
|
|
|
|
|
|
0.8
|
|
|
0.8
|
|
|||||||||
Common dividends declared to parent
|
|
|
|
|
|
|
(327.4
|
)
|
|
|
|
(327.4
|
)
|
|||||||||
Contribution of capital by parent
|
|
|
|
|
12.4
|
|
|
|
|
|
|
12.4
|
|
|||||||||
Balance at Dec. 31, 2016
|
100
|
|
|
$
|
—
|
|
|
$
|
3,633.2
|
|
|
$
|
1,659.3
|
|
|
$
|
(23.0
|
)
|
|
$
|
5,269.5
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Net income
|
|
|
|
|
|
|
494.1
|
|
|
|
|
494.1
|
|
|||||||||
Other comprehensive income
|
|
|
|
|
|
|
|
|
1.0
|
|
|
1.0
|
|
|||||||||
Common dividends declared to parent
|
|
|
|
|
|
|
(335.9
|
)
|
|
|
|
(335.9
|
)
|
|||||||||
Contribution of capital by parent
|
|
|
|
|
399.6
|
|
|
|
|
|
|
399.6
|
|
|||||||||
Adoption of ASU No. 2018-02
|
|
|
|
|
|
|
4.7
|
|
|
(4.7
|
)
|
|
—
|
|
||||||||
Balance at Dec. 31, 2017
|
100
|
|
|
$
|
—
|
|
|
$
|
4,032.8
|
|
|
$
|
1,822.2
|
|
|
$
|
(26.7
|
)
|
|
$
|
5,828.3
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
Net income
|
|
|
|
|
|
|
551.7
|
|
|
|
|
551.7
|
|
|||||||||
Other comprehensive income
|
|
|
|
|
|
|
|
|
1.2
|
|
|
1.2
|
|
|||||||||
Common dividends declared to parent
|
|
|
|
|
|
|
(390.7
|
)
|
|
|
|
(390.7
|
)
|
|||||||||
Contribution of capital by parent
|
|
|
|
|
307.7
|
|
|
|
|
|
|
307.7
|
|
|||||||||
Balance at Dec. 31, 2018
|
100
|
|
|
$
|
—
|
|
|
$
|
4,340.5
|
|
|
$
|
1,983.2
|
|
|
$
|
(25.5
|
)
|
|
$
|
6,298.2
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||||||||
See Notes to Consolidated Financial Statements
|
1.
|
Summary of Significant Accounting Policies
|
•
|
Certain costs, which would otherwise be charged to expense or other comprehensive income, are deferred as regulatory assets based on the expected ability to recover the costs in future rates; and
|
•
|
Certain credits, which would otherwise be reflected as income or other comprehensive income, are deferred as regulatory liabilities based on the expectation the amounts will be returned to customers in future rates, or because the amounts were collected in rates prior to the costs being incurred.
|
2.
|
Accounting Pronouncements
|
3.
|
Plant, Property and Equipment
|
(Millions of Dollars)
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||
Property, plant and equipment
|
|
|
|
|
||||
Electric plant
|
|
$
|
13,604.5
|
|
|
$
|
12,627.6
|
|
Natural gas plant
|
|
4,387.6
|
|
|
4,102.1
|
|
||
Common and other property
|
|
1,023.7
|
|
|
1,022.3
|
|
||
Plant to be retired
(a)
|
|
321.9
|
|
|
11.0
|
|
||
CWIP
|
|
573.3
|
|
|
1,014.3
|
|
||
Total property, plant and equipment
|
|
19,911.0
|
|
|
18,777.3
|
|
||
Less accumulated depreciation
|
|
(4,791.0
|
)
|
|
(4,751.5
|
)
|
||
|
|
$
|
15,120.0
|
|
|
$
|
14,025.8
|
|
(a)
|
In 2018, the CPUC approved early retirement of PSCo’s Comanche Units 1 and 2 in approximately 2022 and 2025, respectively. PSCo also expects Craig Unit 1 to be retired early in 2025. Amounts are presented net of accumulated depreciation.
|
(Millions of Dollars)
|
|
Plant in
Service
|
|
Accumulated
Depreciation |
|
CWIP
|
|
Percent Owned
|
|||||||
Electric Generation:
|
|
|
|
|
|
|
|
|
|||||||
Hayden Unit 1
|
|
$
|
152.8
|
|
|
$
|
76.5
|
|
|
$
|
—
|
|
|
76
|
%
|
Hayden Unit 2
|
|
148.9
|
|
|
68.0
|
|
|
—
|
|
|
37
|
|
|||
Hayden Common Facilities
|
|
40.8
|
|
|
20.9
|
|
|
—
|
|
|
53
|
|
|||
Craig Units 1 and 2
|
|
81.0
|
|
|
40.0
|
|
|
—
|
|
|
10
|
|
|||
Craig Common Facilities
|
|
39.1
|
|
|
20.9
|
|
|
—
|
|
|
7
|
|
|||
Comanche Unit 3
|
|
886.3
|
|
|
130.7
|
|
|
—
|
|
|
67
|
|
|||
Comanche Common Facilities
|
|
27.9
|
|
|
2.5
|
|
|
0.1
|
|
|
82
|
|
|||
Electric Transmission:
|
|
|
|
|
|
|
|
|
|||||||
Transmission and other facilities
|
|
182.8
|
|
|
63.2
|
|
|
0.7
|
|
|
Various
|
|
|||
Gas Transportation:
|
|
|
|
|
|
|
|
|
|||||||
Rifle, CO to Avon, CO
|
|
21.5
|
|
|
7.2
|
|
|
0.1
|
|
|
60
|
|
|||
Gas Tran Compressor
|
|
8.4
|
|
|
0.9
|
|
|
—
|
|
|
50
|
|
|||
Total
|
|
$
|
1,589.5
|
|
|
$
|
430.8
|
|
|
$
|
0.9
|
|
|
|
4.
|
Regulatory Assets and Liabilities
|
(Millions of Dollars)
|
|
See Note(s)
|
|
Remaining
Amortization Period |
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
|||||||||||||
Regulatory Assets
|
|
|
|
|
|
Current
|
|
Noncurrent
|
|
Current
|
|
Noncurrent
|
|||||||||
Pension and retiree medical obligations
|
|
10
|
|
|
Various
|
|
$
|
26.1
|
|
|
$
|
559.0
|
|
|
$
|
28.0
|
|
|
$
|
565.3
|
|
Depreciation differences
|
|
|
|
One to thirteen years
|
|
17.5
|
|
|
107.0
|
|
|
19.8
|
|
|
69.4
|
|
|||||
Recoverable deferred taxes on AFUDC recorded in plant
|
|
|
|
Plant lives
|
|
—
|
|
|
101.9
|
|
|
—
|
|
|
87.0
|
|
|||||
Net AROs
(a)
|
|
1, 11
|
|
|
Plant lives
|
|
—
|
|
|
98.9
|
|
|
—
|
|
|
80.5
|
|
||||
Excess deferred taxes - TCJA
|
|
8
|
|
|
Various
|
|
—
|
|
|
62.0
|
|
|
—
|
|
|
53.9
|
|
||||
Purchased power contract costs
|
|
|
|
Term of related contract
|
|
1.7
|
|
|
26.3
|
|
|
1.3
|
|
|
28.0
|
|
|||||
Property tax
|
|
|
|
Various
|
|
5.6
|
|
|
9.8
|
|
|
—
|
|
|
16.1
|
|
|||||
Conservation programs
(b)
|
|
1
|
|
|
One to two years
|
|
7.3
|
|
|
6.5
|
|
|
7.0
|
|
|
5.5
|
|
||||
Losses on reacquired debt
|
|
|
|
Term of related debt
|
|
1.2
|
|
|
3.7
|
|
|
1.2
|
|
|
4.9
|
|
|||||
Gas pipeline inspection costs
|
|
|
|
One to two years
|
|
0.7
|
|
|
3.1
|
|
|
1.8
|
|
|
7.8
|
|
|||||
Contract valuation adjustments
(c)
|
|
1, 9
|
|
|
Term of related contract
|
|
2.6
|
|
|
—
|
|
|
6.0
|
|
|
2.6
|
|
||||
Recoverable purchased natural gas and electric energy costs
|
|
|
|
Less than one year
|
|
51.2
|
|
|
—
|
|
|
7.6
|
|
|
—
|
|
|||||
Other
|
|
|
|
Various
|
|
6.7
|
|
|
32.5
|
|
|
4.6
|
|
|
29.3
|
|
|||||
Total regulatory assets
|
|
|
|
|
|
$
|
120.6
|
|
|
$
|
1,010.7
|
|
|
$
|
77.3
|
|
|
$
|
950.3
|
|
(a)
|
Includes amounts recorded for future recovery of AROs.
|
(b)
|
Includes costs for conservation programs, as well as incentives allowed in certain jurisdictions.
|
(c)
|
Includes the fair value of certain long-term PPAs used to meet energy capacity requirements and valuation adjustments on natural gas commodity purchases.
|
(Millions of Dollars)
|
|
See Note(s)
|
|
Remaining
Amortization Period |
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||||||||||
Regulatory Liabilities
|
|
|
|
|
|
Current
|
|
Noncurrent
|
|
Current
|
|
Noncurrent
|
||||||||
Deferred income tax adjustments and TCJA refunds
(a)
|
|
8
|
|
Various
|
|
$
|
0.8
|
|
|
$
|
1,441.6
|
|
|
$
|
—
|
|
|
$
|
1,469.3
|
|
Plant removal costs
|
|
1, 11
|
|
Plant lives
|
|
—
|
|
|
344.4
|
|
|
—
|
|
|
346.2
|
|
||||
Effects of regulation on employee benefit costs
(b)
|
|
|
|
Various
|
|
—
|
|
|
126.9
|
|
|
—
|
|
|
35.7
|
|
||||
Renewable resources and environmental initiatives
|
|
|
|
Various
|
|
—
|
|
|
54.0
|
|
|
—
|
|
|
56.2
|
|
||||
ITC deferrals
(c)
|
|
1
|
|
Various
|
|
—
|
|
|
27.5
|
|
|
—
|
|
|
9.1
|
|
||||
Deferred electric, natural gas and steam production costs
|
|
|
|
Less than one year
|
|
7.2
|
|
|
—
|
|
|
29.0
|
|
|
—
|
|
||||
Conservation programs
(d)
|
|
1
|
|
Less than one year
|
|
29.8
|
|
|
—
|
|
|
21.2
|
|
|
—
|
|
||||
Other
|
|
|
|
Various
|
|
29.5
|
|
|
27.1
|
|
|
15.9
|
|
|
17.0
|
|
||||
Total regulatory liabilities
(e)
|
|
|
|
|
|
$
|
67.3
|
|
|
$
|
2,021.5
|
|
|
$
|
66.1
|
|
|
$
|
1,933.5
|
|
(a)
|
Includes the revaluation of recoverable/regulated plant ADIT and revaluation impact of non-plant ADIT due to the TCJA.
|
(b)
|
Includes regulatory amortization and certain TCJA benefits approved by the CPUC to offset the prepaid pension asset at Dec. 31, 2018.
|
(c)
|
Includes impact of lower federal tax rate due to the TCJA.
|
(d)
|
Includes costs for conservation programs, as well as incentives allowed in certain jurisdictions.
|
(e)
|
Revenue subject to refund of
$16.2 million
and
$0.0 million
for 2018 and 2017, respectively, is included in other current liabilities.
|
5.
|
Borrowings and Other Financing Instruments
|
|
|
Three Months Ended Dec. 31, 2018
|
|
Year Ended Dec. 31
|
||||||||||||
(Amounts in Millions, Except Interest Rates)
|
|
|
2018
|
|
2017
|
|
2016
|
|||||||||
Borrowing limit
|
|
$
|
250
|
|
|
$
|
250
|
|
|
$
|
250
|
|
|
$
|
250
|
|
Amount outstanding at period end
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||
Average amount outstanding
|
|
26
|
|
|
25
|
|
|
—
|
|
|
21
|
|
||||
Maximum amount outstanding
|
|
96
|
|
|
156
|
|
|
20
|
|
|
141
|
|
||||
Weighted average interest rate, computed on a daily basis
|
|
2.27
|
%
|
|
1.93
|
%
|
|
0.92
|
%
|
|
0.73
|
%
|
||||
Weighted average interest rate at end of period
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
|
|
Three Months Ended Dec. 31, 2018
|
|
Year Ended Dec. 31
|
||||||||||||
(Amounts in Millions, Except Interest Rates)
|
|
|
2018
|
|
2017
|
|
2016
|
|||||||||
Borrowing limit
|
|
$
|
700
|
|
|
$
|
700
|
|
|
$
|
700
|
|
|
$
|
700
|
|
Amount outstanding at period end
|
|
307
|
|
|
307
|
|
|
—
|
|
|
129
|
|
||||
Average amount outstanding
|
|
87
|
|
|
55
|
|
|
54
|
|
|
24
|
|
||||
Maximum amount outstanding
|
|
309
|
|
|
309
|
|
|
268
|
|
|
154
|
|
||||
Weighted average interest rate, computed on a daily basis
|
|
2.64
|
%
|
|
2.28
|
%
|
|
1.08
|
%
|
|
0.70
|
%
|
||||
Weighted average interest rate at end of period
|
|
2.95
|
|
|
2.95
|
|
|
N/A
|
|
|
0.95
|
|
Debt-to-Total Capitalization Ratio
(a)
|
|
Amount Facility May Be Increased (millions)
|
|
Additional Periods For Which a One-Year Extension May Be Requested
(b)
|
||||||
2018
|
|
2017
|
|
|
|
|
||||
46
|
%
|
|
44
|
%
|
|
$
|
100
|
|
|
2
|
(a)
|
The PSCo financial covenant requires that the debt-to-total capitalization ratio be less than or equal to
65%
.
|
(b)
|
All extension requests are subject to majority bank group approval.
|
Credit Facility
(a)
|
|
Drawn
(b)
|
|
Available
|
||||||
$
|
700
|
|
|
$
|
317
|
|
|
$
|
383
|
|
(a)
|
This credit facility matures in
June 2021
.
|
(b)
|
Includes letters of credit and outstanding commercial paper.
|
(Millions of Dollars)
|
|
Maturity Range
|
|
Interest Rate Range 2018
|
|
Interest Rate Range 2017
|
|
2018
|
|
2017
|
||||
Capital lease obligations
|
|
2025-2060
|
|
11.20% - 14.30%
|
|
11.20% - 14.30%
|
|
$
|
145
|
|
|
$
|
151
|
|
Mortgage bonds
|
|
2019-2048
|
|
2.25% - 6.50%
|
|
2.25% - 6.50%
|
|
4,900
|
|
|
4,500
|
|
||
Unamortized discount
|
|
|
|
|
|
|
|
(14
|
)
|
|
(13
|
)
|
||
Unamortized debt issuance cost
|
|
|
|
|
|
|
|
(33
|
)
|
|
(29
|
)
|
||
Current maturities
|
|
|
|
|
|
|
|
(406
|
)
|
|
(306
|
)
|
||
Total
|
|
|
|
|
|
|
|
$
|
4,592
|
|
|
$
|
4,303
|
|
Amount
|
|
Financing Instrument
|
|
Interest Rate
|
|
Maturity Date
|
|
$350 million
|
|
First mortgage bonds
|
|
3.70
|
%
|
|
June 15, 2028
|
350 million
|
|
First mortgage bonds
|
|
4.10
|
|
|
June 15, 2048
|
Amount
|
|
Financing Instrument
|
|
Interest Rate
|
|
Maturity Date
|
|
$400 million
|
|
First mortgage bonds
|
|
3.80
|
%
|
|
June 15, 2047
|
6.
|
Revenues
|
|
|
Year Ended Dec. 31, 2018
|
||||||||||||||
(Millions of Dollars)
|
|
Electric
|
|
Natural Gas
|
|
All Other
|
|
Total
|
||||||||
Major revenue types
|
|
|
|
|
|
|
|
|
||||||||
Revenue from contracts with customers:
|
|
|
|
|
|
|
|
|
||||||||
Residential
|
|
$
|
991.2
|
|
|
$
|
606.5
|
|
|
$
|
10.7
|
|
|
$
|
1,608.4
|
|
C&I
|
|
1,560.6
|
|
|
223.5
|
|
|
25.3
|
|
|
1,809.4
|
|
||||
Other
|
|
47.6
|
|
|
—
|
|
|
0.1
|
|
|
47.7
|
|
||||
Total retail
|
|
2,599.4
|
|
|
830.0
|
|
|
36.1
|
|
|
3,465.5
|
|
||||
Wholesale
|
|
174.6
|
|
|
—
|
|
|
—
|
|
|
174.6
|
|
||||
Transmission
|
|
54.2
|
|
|
—
|
|
|
—
|
|
|
54.2
|
|
||||
Other
|
|
54.9
|
|
|
84.0
|
|
|
—
|
|
|
138.9
|
|
||||
Total revenue from contracts with customers
|
|
2,883.1
|
|
|
914.0
|
|
|
36.1
|
|
|
3,833.2
|
|
||||
Alternative revenue and other
|
|
148.1
|
|
|
100.6
|
|
|
4.3
|
|
|
253.0
|
|
||||
Total revenues
|
|
$
|
3,031.2
|
|
|
$
|
1,014.6
|
|
|
$
|
40.4
|
|
|
$
|
4,086.2
|
|
7.
|
Preferred Stock
|
Preferred
Shares Authorized |
|
Par Value
|
|
Preferred
Shares Outstanding |
||||
10,000,000
|
|
|
$
|
0.01
|
|
|
—
|
|
8.
|
Income Taxes
|
•
|
Corporate federal tax rate reduction from
35%
to
21%
;
|
•
|
Normalization of resulting plant-related excess deferred taxes;
|
•
|
Elimination of the corporate alternative minimum tax;
|
•
|
Continued interest expense deductibility and discontinued bonus depreciation for regulated public utilities;
|
•
|
Limitations on certain executive compensation deductions;
|
•
|
Limitations on certain deductions for NOLs arising after Dec. 31, 2017 (limited to
80%
of taxable income);
|
•
|
Repeal of the section 199 manufacturing deduction; and
|
•
|
Reduced deductions for meals and entertainment as well as state and local lobbying.
|
•
|
$1.1 billion
(
$1.5 billion
grossed-up for tax) of reclassifications of plant-related excess deferred taxes to regulatory liabilities upon valuation at the new
21%
federal rate. The regulatory liabilities will be amortized consistent with IRS normalization requirements, resulting in customer refunds over the average remaining life of the related property;
|
•
|
$54 million
and
$50 million
of reclassifications (grossed-up for tax) of excess deferred taxes for non-plant related deferred tax assets and liabilities, respectively, to regulatory assets and liabilities; and
|
•
|
$18 million
of total estimated income tax benefit related to the federal tax reform implementation, and a
$4 million
reduction to net income related to the allocation of Xcel Energy Services Inc.’s tax rate change on its deferred taxes.
|
Tax Year(s)
|
|
Expiration
|
2009 - 2014
|
|
October 2019
|
2015
|
|
September 2019
|
2016
|
|
September 2020
|
2017
|
|
September 2021
|
(Millions of Dollars)
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||
Unrecognized tax benefit — Permanent tax positions
|
|
$
|
5.4
|
|
|
$
|
4.0
|
|
Unrecognized tax benefit — Temporary tax positions
|
|
4.9
|
|
|
6.1
|
|
||
Total unrecognized tax benefit
|
|
$
|
10.3
|
|
|
$
|
10.1
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Balance at Jan. 1
|
|
$
|
10.1
|
|
|
$
|
19.7
|
|
|
$
|
17.4
|
|
Additions based on tax positions related to the current year
|
|
1.1
|
|
|
1.9
|
|
|
2.7
|
|
|||
Reductions based on tax positions related to the current year
|
|
(0.3
|
)
|
|
(1.5
|
)
|
|
—
|
|
|||
Additions for tax positions of prior years
|
|
0.4
|
|
|
4.4
|
|
|
0.5
|
|
|||
Reductions for tax positions of prior years
|
|
(0.1
|
)
|
|
(14.4
|
)
|
|
(0.9
|
)
|
|||
Settlements with taxing authorities
|
|
(0.9
|
)
|
|
—
|
|
|
—
|
|
|||
Balance at Dec. 31
|
|
$
|
10.3
|
|
|
$
|
10.1
|
|
|
$
|
19.7
|
|
(Millions of Dollars)
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||
NOL and tax credit carryforwards
|
|
$
|
(5.6
|
)
|
|
$
|
(4.0
|
)
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Payable for interest related to unrecognized tax benefits at Jan. 1
|
|
$
|
(0.3
|
)
|
|
$
|
(1.1
|
)
|
|
$
|
(0.4
|
)
|
Interest (expense) income related to unrecognized tax benefits
|
|
(0.4
|
)
|
|
0.8
|
|
|
(0.7
|
)
|
|||
Payable for interest related to unrecognized tax benefits at Dec. 31
|
|
$
|
(0.7
|
)
|
|
$
|
(0.3
|
)
|
|
$
|
(1.1
|
)
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
Federal NOL carryforward
|
|
$
|
—
|
|
|
$
|
67.6
|
|
Federal tax credit carryforwards
|
|
35.0
|
|
|
29.8
|
|
||
State NOL carryforwards
|
|
484.7
|
|
|
679.2
|
|
||
State tax credit carryforwards, net of federal detriment
(a)
|
|
16.9
|
|
|
16.8
|
|
||
Valuation allowances for state credit carryforwards, net of federal benefit
(b)
|
|
(8.9
|
)
|
|
(7.3
|
)
|
(a)
|
State tax credit carryforwards are net of federal detriment of
$4.5 million
as of Dec. 31, 2018 and 2017.
|
(b)
|
Valuation allowances for state tax credit carryforwards were net of federal benefit of
$2.4 million
and
$1.9 million
as of Dec. 31, 2018 and 2017, respectively.
|
|
|
2018
|
|
2017
(a)
|
|
2016
(a)
|
|||
Federal statutory rate
|
|
21.0
|
%
|
|
35.0
|
%
|
|
35.0
|
%
|
State income tax on pretax income, net of federal tax effect
|
|
3.7
|
%
|
|
3.0
|
%
|
|
3.0
|
%
|
Increases (decreases) in tax from:
|
|
|
|
|
|
|
|
|
|
Regulatory differences - ARAM
(b)
|
|
(3.0
|
)
|
|
(0.1
|
)
|
|
(0.1
|
)
|
Regulatory differences - other utility plant items
|
|
(1.7
|
)
|
|
(0.9
|
)
|
|
(0.5
|
)
|
Amortization of excess nonplant deferred taxes
|
|
(1.4
|
)
|
|
—
|
|
|
—
|
|
Tax credits recognized, net of federal income tax expense
|
|
(0.9
|
)
|
|
(0.9
|
)
|
|
(0.7
|
)
|
Wind PTCs recognized
|
|
(0.6
|
)
|
|
—
|
|
|
—
|
|
Regulatory differences - Deferral of ARAM
(c)
|
|
0.2
|
|
|
—
|
|
|
—
|
|
Change in unrecognized tax benefits
|
|
0.1
|
|
|
0.2
|
|
|
—
|
|
Tax reform
|
|
—
|
|
|
(2.4
|
)
|
|
—
|
|
Other, net
|
|
(0.3
|
)
|
|
(0.1
|
)
|
|
0.4
|
|
Effective income tax rate
|
|
17.1
|
%
|
|
33.8
|
%
|
|
37.1
|
%
|
(a)
|
Prior periods have been reclassified to conform to current year presentation.
|
(b)
|
ARAM is a method to flow back excess deferred taxes to customers.
|
(c)
|
ARAM has been deferred when regulatory treatment has not been established. As Xcel Energy received direction from its regulatory commissions regarding the return of excess deferred taxes to customers, the ARAM deferral was reversed. This resulted in a reduction to tax expense with a corresponding reduction to revenue.
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Current federal tax expense
|
|
$
|
79.5
|
|
|
$
|
40.4
|
|
|
$
|
45.3
|
|
Current state tax expense
|
|
14.2
|
|
|
14.6
|
|
|
8.7
|
|
|||
Current change in unrecognized tax (benefit) expense
|
|
(1.3
|
)
|
|
(7.8
|
)
|
|
0.7
|
|
|||
Deferred federal tax expense
|
|
4.9
|
|
|
176.4
|
|
|
195.1
|
|
|||
Deferred state tax expense
|
|
16.6
|
|
|
22.5
|
|
|
27.2
|
|
|||
Deferred change in unrecognized tax expense (benefit)
|
|
2.3
|
|
|
8.9
|
|
|
(0.3
|
)
|
|||
Deferred ITCs
|
|
(2.5
|
)
|
|
(2.8
|
)
|
|
(2.8
|
)
|
|||
Total income tax expense
|
|
$
|
113.7
|
|
|
$
|
252.2
|
|
|
$
|
273.9
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Deferred tax expense (benefit) excluding items below
|
|
$
|
74.8
|
|
|
$
|
(1,244.7
|
)
|
|
$
|
230.9
|
|
Amortization and adjustments to deferred income taxes on income tax regulatory assets and liabilities
|
|
(50.6
|
)
|
|
1,453.1
|
|
|
(8.4
|
)
|
|||
Tax expense allocated to other comprehensive income, net of adoption of ASU No. 2018-02, and other
|
|
(0.4
|
)
|
|
(0.6
|
)
|
|
(0.5
|
)
|
|||
Deferred tax expense
|
|
$
|
23.8
|
|
|
$
|
207.8
|
|
|
$
|
222.0
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
||||
Deferred tax liabilities:
|
|
|
|
|
||||
Differences between book and tax bases of property
|
|
$
|
1,860.1
|
|
|
$
|
1,790.1
|
|
Regulatory assets
|
|
251.1
|
|
|
252.4
|
|
||
Pension expense
|
|
33.9
|
|
|
60.0
|
|
||
Other
|
|
13.1
|
|
|
3.7
|
|
||
Total deferred tax liabilities
|
|
$
|
2,158.2
|
|
|
$
|
2,106.2
|
|
|
|
|
|
|
||||
Deferred tax assets:
|
|
|
|
|
|
|
||
Regulatory liabilities
|
|
$
|
336.3
|
|
|
$
|
338.0
|
|
NOL carryforward
|
|
18.2
|
|
|
39.3
|
|
||
Tax credit carryforward
|
|
51.9
|
|
|
39.3
|
|
||
Tax credit valuation allowances
|
|
(8.9
|
)
|
|
—
|
|
||
Deferred ITCs
|
|
6.3
|
|
|
6.9
|
|
||
Other employee benefits
|
|
2.8
|
|
|
6.8
|
|
||
Rate refund
|
|
9.3
|
|
|
0.9
|
|
||
Other
|
|
23.0
|
|
|
30.5
|
|
||
Total deferred tax assets
|
|
$
|
438.9
|
|
|
$
|
461.7
|
|
Net deferred tax liability
|
|
$
|
1,719.3
|
|
|
$
|
1,644.5
|
|
9.
|
Fair Value of Financial Assets and Liabilities
|
•
|
Level 1
—
Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. The types of assets and liabilities included in Level 1 are highly liquid and actively traded instruments with quoted prices.
|
•
|
Level 2
—
Pricing inputs are other than quoted prices in active markets, but are either directly or indirectly observable as of the reporting date. The types of assets and liabilities included in Level 2 are typically either comparable to actively traded securities or contracts, or priced with models using highly observable inputs.
|
•
|
Level 3
—
Significant inputs to pricing have little or no observability as of the reporting date. The types of assets and liabilities included in Level 3 are those valued with models requiring significant management judgment or estimation.
|
(Amounts in Millions)
(a)(b)
|
|
2018
|
|
2017
|
||
MWh of electricity
|
|
24.4
|
|
|
22.3
|
|
MMBtu of natural gas
|
|
48.4
|
|
|
13.4
|
|
(a)
|
Amounts are not reflective of net positions in the underlying commodities.
|
(b)
|
Notional amounts for options are included on a gross basis, but are weighted for the probability of exercise.
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Accumulated other comprehensive loss related to cash flow hedges at Jan. 1
|
|
$
|
(26.5
|
)
|
|
$
|
(22.8
|
)
|
|
$
|
(23.8
|
)
|
After-tax net realized losses on derivative transactions reclassified into earnings
|
|
1.2
|
|
|
1.0
|
|
|
1.0
|
|
|||
Adoption of ASU. 2018-02
(a)
|
|
—
|
|
|
(4.7
|
)
|
|
—
|
|
|||
Accumulated other comprehensive loss related to cash flow hedges at Dec. 31
|
|
$
|
(25.3
|
)
|
|
$
|
(26.5
|
)
|
|
$
|
(22.8
|
)
|
(a)
|
In 2017, PSCo implemented ASU No. 2018-02 related to TCJA, which resulted in reclassification of certain credit balances within net accumulated other comprehensive loss to retained earnings.
|
|
|
Pre-Tax Fair Value Gains (Losses) Recognized During the Period in:
|
||||||
(Millions of Dollars)
|
|
Accumulated Other
Comprehensive Loss |
|
Regulatory(Assets) and Liabilities
|
||||
Year Ended Dec. 31, 2018
|
|
|
|
|
||||
Other derivative instruments
|
|
|
|
|
||||
Natural gas commodity
|
|
$
|
—
|
|
|
$
|
8.0
|
|
Total
|
|
$
|
—
|
|
|
$
|
8.0
|
|
|
|
|
|
|
||||
Year Ended Dec. 31, 2017
|
|
|
|
|
||||
Other derivative instruments
|
|
|
|
|
||||
Natural gas commodity
|
|
$
|
—
|
|
|
$
|
(10.9
|
)
|
Total
|
|
$
|
—
|
|
|
$
|
(10.9
|
)
|
|
|
|
|
|
||||
Year Ended Dec. 31, 2016
|
|
|
|
|
||||
Other derivative instruments
|
|
|
|
|
||||
Natural gas commodity
|
|
—
|
|
|
2.1
|
|
||
Total
|
|
$
|
—
|
|
|
$
|
2.1
|
|
|
|
Pre-Tax (Gains) Losses
Reclassified into Income During the Period from: |
|
|
|
||||||||
(Millions of Dollars)
|
|
Accumulated
Other Comprehensive
Loss
|
|
Regulatory
Assets and
(Liabilities)
|
|
Pre-Tax Gains (Losses) Recognized
During the Period in Income |
|
||||||
Year Ended Dec. 31, 2018
|
|
|
|
|
|
|
|
||||||
Derivatives designated as cash flow hedges
|
|
|
|
|
|
|
|
||||||
Interest rate
|
|
$
|
1.6
|
|
(a)
|
$
|
—
|
|
|
$
|
—
|
|
|
Total
|
|
$
|
1.6
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Other derivative instruments
|
|
|
|
|
|
|
|
||||||
Commodity trading
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
3.1
|
|
(c)
|
Natural gas commodity
|
|
—
|
|
|
(4.1
|
)
|
(d)
|
(2.9
|
)
|
(d)
|
|||
Total
|
|
$
|
—
|
|
|
$
|
(4.1
|
)
|
|
$
|
0.2
|
|
|
|
|
|
|
|
|
|
|
||||||
Year Ended Dec. 31, 2017
|
|
|
|
|
|
|
|
||||||
Derivatives designated as cash flow hedges
|
|
|
|
|
|
|
|
||||||
Interest rate
|
|
$
|
1.6
|
|
(a)
|
$
|
—
|
|
|
$
|
—
|
|
|
Total
|
|
$
|
1.6
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Other derivative instruments
|
|
|
|
|
|
|
|
||||||
Commodity trading
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
0.4
|
|
(c)
|
Natural gas commodity
|
|
—
|
|
|
1.9
|
|
(d)
|
(4.2
|
)
|
(d)
|
|||
Total
|
|
$
|
—
|
|
|
$
|
1.9
|
|
|
$
|
(3.8
|
)
|
|
|
|
|
|
|
|
|
|
||||||
Year Ended Dec. 31, 2016
|
|
|
|
|
|
|
|
||||||
Derivatives designated as cash flow hedges
|
|
|
|
|
|
|
|
||||||
Interest rate
|
|
$
|
1.6
|
|
(a)
|
$
|
—
|
|
|
$
|
—
|
|
|
Vehicle fuel and other commodity
|
|
0.1
|
|
(b)
|
—
|
|
|
—
|
|
|
|||
Total
|
|
$
|
1.7
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
Other derivative instruments
|
|
|
|
|
|
|
|
||||||
Commodity trading
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
(0.3
|
)
|
(c)
|
Natural gas commodity
|
|
—
|
|
|
10.3
|
|
(d)
|
(5.8
|
)
|
(d)
|
|||
Total
|
|
$
|
—
|
|
|
$
|
10.3
|
|
|
$
|
(6.1
|
)
|
|
(a)
|
Amounts are recorded to interest charges.
|
(b)
|
Amounts are recorded to O&M expenses.
|
(c)
|
Amounts are recorded to electric operating revenues. Portions of these gains and losses are subject to sharing with electric customers through margin-sharing mechanisms and deducted from gross revenue, as appropriate.
|
(d)
|
Amounts for the year ended Dec. 31, 2018, 2017 and 2016 included
$1.2 million
of settlement losses,
$0.4 million
of settlement gains and
$0.2 million
of settlement losses, respectively, on derivatives entered to mitigate natural gas price risk for electric generation recorded to electric fuel and purchased power, subject to cost-recovery mechanisms and reclassified to a regulatory asset or liability, as appropriate. Remaining settlement losses for the years ended Dec. 31, 2018, 2017 and 2016 relate to natural gas operations and are recorded to cost of natural gas sold and transported. These losses are subject to cost-recovery mechanisms and reclassified out of income to a regulatory asset or liability, as appropriate.
|
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||||||||||||||||||||||||||||||||||||||||||
|
|
Fair Value
|
|
|
|
|
|
|
|
Fair Value
|
|
|
|
|
|
|
||||||||||||||||||||||||||||||||
(Millions of Dollars)
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Fair Value
Total
|
|
Netting
(a)
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Fair Value
Total
|
|
Netting
(a)
|
|
Total
|
||||||||||||||||||||||||
Current derivative assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Other derivative instruments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Commodity trading
|
|
$
|
2.3
|
|
|
$
|
65.0
|
|
|
$
|
0.1
|
|
|
$
|
67.4
|
|
|
$
|
(28.2
|
)
|
|
$
|
39.2
|
|
|
$
|
0.5
|
|
|
$
|
4.5
|
|
|
$
|
—
|
|
|
$
|
5.0
|
|
|
$
|
(3.5
|
)
|
|
$
|
1.5
|
|
Natural gas commodity
|
|
—
|
|
|
3.4
|
|
|
—
|
|
|
3.4
|
|
|
—
|
|
|
3.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||||||||
Total current derivative assets
|
|
$
|
2.3
|
|
|
$
|
68.4
|
|
|
$
|
0.1
|
|
|
$
|
70.8
|
|
|
$
|
(28.2
|
)
|
|
42.6
|
|
|
$
|
0.5
|
|
|
$
|
4.5
|
|
|
$
|
—
|
|
|
$
|
5.0
|
|
|
$
|
(3.5
|
)
|
|
1.5
|
|
||
PPAs
(b)
|
|
|
|
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
1.7
|
|
||||||||||||||||||||||
Current derivative instruments
|
|
|
|
|
|
|
|
|
|
|
|
$
|
42.6
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
3.2
|
|
||||||||||||||||||||
Noncurrent derivative assets
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Other derivative instruments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Commodity trading
|
|
$
|
—
|
|
|
$
|
1.6
|
|
|
$
|
—
|
|
|
$
|
1.6
|
|
|
$
|
(0.4
|
)
|
|
$
|
1.2
|
|
|
$
|
—
|
|
|
$
|
1.5
|
|
|
$
|
—
|
|
|
$
|
1.5
|
|
|
$
|
(0.5
|
)
|
|
$
|
1.0
|
|
Total noncurrent derivative assets
|
|
$
|
—
|
|
|
$
|
1.6
|
|
|
$
|
—
|
|
|
$
|
1.6
|
|
|
$
|
(0.4
|
)
|
|
1.2
|
|
|
$
|
—
|
|
|
$
|
1.5
|
|
|
$
|
—
|
|
|
$
|
1.5
|
|
|
$
|
(0.5
|
)
|
|
1.0
|
|
||
PPAs
(b)
|
|
|
|
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
—
|
|
||||||||||||||||||||||
Noncurrent derivative instruments
|
|
|
|
|
|
|
|
|
|
|
|
$
|
1.2
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
1.0
|
|
||||||||||||||||||||
Current derivative liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Other derivative instruments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Commodity trading
|
|
$
|
2.4
|
|
|
$
|
64.2
|
|
|
$
|
—
|
|
|
$
|
66.6
|
|
|
$
|
(34.7
|
)
|
|
$
|
31.9
|
|
|
$
|
0.4
|
|
|
$
|
4.3
|
|
|
$
|
—
|
|
|
$
|
4.7
|
|
|
$
|
(3.4
|
)
|
|
$
|
1.3
|
|
Natural gas commodity
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
1.0
|
|
|
—
|
|
|
1.0
|
|
|
—
|
|
|
1.0
|
|
||||||||||||
Total current derivative liabilities
|
|
$
|
2.4
|
|
|
$
|
64.2
|
|
|
$
|
—
|
|
|
$
|
66.6
|
|
|
$
|
(34.7
|
)
|
|
31.9
|
|
|
$
|
0.4
|
|
|
$
|
5.3
|
|
|
$
|
—
|
|
|
$
|
5.7
|
|
|
$
|
(3.4
|
)
|
|
2.3
|
|
||
PPAs
(b)
|
|
|
|
|
|
|
|
|
|
|
|
2.7
|
|
|
|
|
|
|
|
|
|
|
|
|
5.0
|
|
||||||||||||||||||||||
Current derivative instruments
|
|
|
|
|
|
|
|
|
|
|
|
$
|
34.6
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
7.3
|
|
||||||||||||||||||||
Noncurrent derivative liabilities
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Other derivative instruments:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||||||||||||||
Commodity trading
|
|
$
|
—
|
|
|
$
|
1.1
|
|
|
$
|
—
|
|
|
$
|
1.1
|
|
|
$
|
(0.5
|
)
|
|
$
|
0.6
|
|
|
$
|
—
|
|
|
$
|
1.4
|
|
|
$
|
—
|
|
|
$
|
1.4
|
|
|
$
|
(0.6
|
)
|
|
$
|
0.8
|
|
Total noncurrent derivative liabilities
|
|
$
|
—
|
|
|
$
|
1.1
|
|
|
$
|
—
|
|
|
$
|
1.1
|
|
|
$
|
(0.5
|
)
|
|
0.6
|
|
|
$
|
—
|
|
|
$
|
1.4
|
|
|
$
|
—
|
|
|
$
|
1.4
|
|
|
$
|
(0.6
|
)
|
|
0.8
|
|
||
PPAs
(b)
|
|
|
|
|
|
|
|
|
|
|
|
—
|
|
|
|
|
|
|
|
|
|
|
|
|
2.7
|
|
||||||||||||||||||||||
Noncurrent derivative instruments
|
|
|
|
|
|
|
|
|
|
|
|
$
|
0.6
|
|
|
|
|
|
|
|
|
|
|
|
|
$
|
3.5
|
|
(a)
|
PSCo nets derivative instruments and related collateral in its consolidated balance sheet when supported by a legally enforceable master netting agreement, and all derivative instruments and related collateral amounts were subject to master netting agreements at Dec. 31, 2018 and 2017. At both Dec. 31, 2018 and 2017, derivative assets and liabilities include
no
obligations to return cash collateral. At Dec. 31, 2018 and 2017, derivative assets and liabilities include the rights to reclaim cash collateral of
$6.5 million
and
$0 million
, respectively. The counterparty netting amounts presented exclude settlement receivables and payables and non-derivative amounts that may be subject to the same master netting agreements.
|
(b)
|
During 2006, PSCo qualified these contracts under the normal purchase exception. Based on
this qualification, the contracts are no longer adjusted to fair value and the previous carrying value of these contracts will be amortized over the remaining contract lives along with the offsetting regulatory assets and liabilities.
|
|
|
2018
|
|
2017
|
||||||||||||
(Millions of Dollars)
|
|
Carrying
Amount
|
|
Fair Value
|
|
Carrying
Amount
|
|
Fair Value
|
||||||||
Long-term debt, including current portion
|
|
$
|
4,997.6
|
|
|
$
|
5,123.2
|
|
|
$
|
4,608.3
|
|
|
$
|
5,024.8
|
|
10.
|
Benefit Plans and Other Postretirement Benefits
|
•
|
Xcel Energy discontinued subsidizing health care benefits for nonbargaining employees of the former NCE, which includes PSCo employees, who retired after June 30, 2003.
|
•
|
Investment returns in
2018
were below the assumed level of
6.84%
;
|
•
|
Investment returns in
2017
were above the assumed level of
6.84%
;
|
•
|
Investment returns in
2016
were below the assumed level of
6.84%
; and
|
•
|
In
2019
, PSCo’s expected investment-return assumption is
6.84%
.
|
|
|
Dec. 31, 2018
(a)
|
|
Dec. 31, 2017
(a)
|
||||||||||||||||||||||||||||||||||||
(Millions of Dollars)
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured
at NAV |
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured
at NAV |
|
Total
|
||||||||||||||||||||
Cash equivalents
|
|
$
|
53.0
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
53.0
|
|
|
$
|
67.2
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
67.2
|
|
Commingled funds
|
|
316.2
|
|
|
—
|
|
|
—
|
|
|
326.1
|
|
|
642.3
|
|
|
363.4
|
|
|
—
|
|
|
—
|
|
|
355.5
|
|
|
718.9
|
|
||||||||||
Debt securities
|
|
—
|
|
|
242.3
|
|
|
—
|
|
|
—
|
|
|
242.3
|
|
|
—
|
|
|
263.8
|
|
|
—
|
|
|
—
|
|
|
263.8
|
|
||||||||||
Equity securities
|
|
35.2
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
35.2
|
|
|
37.8
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
37.8
|
|
||||||||||
Other
|
|
0.6
|
|
|
2.0
|
|
|
—
|
|
|
(9.9
|
)
|
|
(7.3
|
)
|
|
(9.9
|
)
|
|
1.4
|
|
|
—
|
|
|
0.2
|
|
|
(8.3
|
)
|
||||||||||
Total
|
|
$
|
405.0
|
|
|
$
|
244.3
|
|
|
$
|
—
|
|
|
$
|
316.2
|
|
|
$
|
965.5
|
|
|
$
|
458.5
|
|
|
$
|
265.2
|
|
|
$
|
—
|
|
|
$
|
355.7
|
|
|
$
|
1,079.4
|
|
(a)
|
See Note 9 for further information on fair value measurement inputs and methods.
|
|
|
Dec. 31, 2018
(a)
|
|
Dec. 31, 2017
(a)
|
||||||||||||||||||||||||||||||||||||
(Millions of Dollars)
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV
|
|
Total
|
|
Level 1
|
|
Level 2
|
|
Level 3
|
|
Measured at NAV
|
|
Total
|
||||||||||||||||||||
Cash equivalents
|
|
$
|
17.0
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
17.0
|
|
|
$
|
25.7
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
25.7
|
|
Insurance contracts
|
|
—
|
|
|
40.2
|
|
|
—
|
|
|
—
|
|
|
40.2
|
|
|
—
|
|
|
43.5
|
|
|
—
|
|
|
—
|
|
|
43.5
|
|
||||||||||
Commingled funds
|
|
118.7
|
|
|
—
|
|
|
—
|
|
|
35.8
|
|
|
154.5
|
|
|
130.2
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
130.2
|
|
||||||||||
Debt securities
|
|
—
|
|
|
159.7
|
|
|
—
|
|
|
—
|
|
|
159.7
|
|
|
—
|
|
|
175.4
|
|
|
—
|
|
|
—
|
|
|
175.4
|
|
||||||||||
Equity securities
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
30.7
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
30.7
|
|
||||||||||
Other
|
|
—
|
|
|
0.7
|
|
|
—
|
|
|
—
|
|
|
0.7
|
|
|
—
|
|
|
0.9
|
|
|
—
|
|
|
—
|
|
|
0.9
|
|
||||||||||
Total
|
|
$
|
135.7
|
|
|
$
|
200.6
|
|
|
$
|
—
|
|
|
$
|
35.8
|
|
|
$
|
372.1
|
|
|
$
|
186.6
|
|
|
$
|
219.8
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
406.4
|
|
(a)
|
See Note 9 for further information on fair value measurement inputs and methods.
|
|
|
Pension Benefits
|
|
Postretirement Benefits
|
||||||||||||
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Change in Benefit Obligation:
|
|
|
|
|
|
|
|
|
||||||||
Obligation at Jan. 1
|
|
$
|
1,334.2
|
|
|
$
|
1,251.8
|
|
|
$
|
429.2
|
|
|
$
|
421.8
|
|
Service cost
|
|
29.0
|
|
|
27.3
|
|
|
0.7
|
|
|
0.7
|
|
||||
Interest cost
|
|
47.3
|
|
|
50.6
|
|
|
15.0
|
|
|
16.8
|
|
||||
Plan amendments
|
|
—
|
|
|
(1.1
|
)
|
|
—
|
|
|
—
|
|
||||
Actuarial loss
|
|
(96.5
|
)
|
|
83.5
|
|
|
(40.6
|
)
|
|
18.3
|
|
||||
Plan participants’ contributions
|
|
—
|
|
|
—
|
|
|
6.5
|
|
|
6.0
|
|
||||
Medicare subsidy reimbursements
|
|
—
|
|
|
—
|
|
|
0.9
|
|
|
1.0
|
|
||||
Benefit payments
|
|
(84.7
|
)
|
|
(77.9
|
)
|
|
(35.2
|
)
|
|
(35.4
|
)
|
||||
Obligation at Dec. 31
|
|
$
|
1,229.3
|
|
|
$
|
1,334.2
|
|
|
$
|
376.5
|
|
|
$
|
429.2
|
|
Change in Fair Value of Plan Assets:
|
|
|
|
|
|
|
|
|
||||||||
Fair value of plan assets at Jan. 1
|
|
$
|
1,079.4
|
|
|
$
|
1,004.2
|
|
|
$
|
406.4
|
|
|
$
|
393.5
|
|
Actual return on plan assets
|
|
(50.9
|
)
|
|
135.6
|
|
|
(11.1
|
)
|
|
37.0
|
|
||||
Employer contributions
|
|
21.7
|
|
|
17.5
|
|
|
5.5
|
|
|
5.3
|
|
||||
Plan participants’ contributions
|
|
—
|
|
|
—
|
|
|
6.5
|
|
|
6.0
|
|
||||
Benefit payments
|
|
(84.7
|
)
|
|
(77.9
|
)
|
|
(35.2
|
)
|
|
(35.4
|
)
|
||||
Fair value of plan assets at Dec. 31
|
|
$
|
965.5
|
|
|
$
|
1,079.4
|
|
|
$
|
372.1
|
|
|
$
|
406.4
|
|
Funded status of plans at Dec. 31
|
|
$
|
(263.8
|
)
|
|
$
|
(254.8
|
)
|
|
$
|
(4.4
|
)
|
|
$
|
(22.8
|
)
|
Amounts recognized in the Consolidated Balance Sheet at Dec. 31:
|
|
|
|
|
|
|
|
|
||||||||
Noncurrent liabilities
|
|
(263.8
|
)
|
|
(254.8
|
)
|
|
(4.4
|
)
|
|
(22.8
|
)
|
||||
Net amounts recognized
|
|
$
|
(263.8
|
)
|
|
$
|
(254.8
|
)
|
|
$
|
(4.4
|
)
|
|
$
|
(22.8
|
)
|
Significant Assumptions Used to Measure Benefit Obligations:
|
|
|
|
|
|
|
|
|
||||||||
Discount rate for year-end valuation
|
|
4.31
|
%
|
|
3.63
|
%
|
|
4.32
|
%
|
|
3.62
|
%
|
||||
Expected average long-term increase in compensation level
|
|
3.75
|
|
|
3.75
|
|
|
N/A
|
|
|
N/A
|
|
||||
Mortality table
|
|
RP-2014
|
|
|
RP-2014
|
|
|
RP-2014
|
|
|
RP-2014
|
|
||||
Health care costs trend rate
—
initial: Pre-65
|
|
N/A
|
|
|
N/A
|
|
|
6.50
|
%
|
|
7.00
|
%
|
||||
Health care costs trend rate
—
initial: Post-65
|
|
N/A
|
|
|
N/A
|
|
|
5.30
|
%
|
|
5.50
|
%
|
||||
Ultimate trend assumption
—
initial: Pre-65
|
|
N/A
|
|
|
N/A
|
|
|
4.50
|
%
|
|
4.50
|
%
|
||||
Ultimate trend assumption
—
initial: Post-65
|
|
N/A
|
|
|
N/A
|
|
|
4.50
|
%
|
|
4.50
|
%
|
||||
Years until ultimate trend is reached
|
|
N/A
|
|
|
N/A
|
|
|
4
|
|
|
5
|
|
|
|
Pension Benefits
|
|
Postretirement Benefits
|
||||||||||||||||||||
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
|
2018
|
|
2017
|
|
2016
|
||||||||||||
Service cost
|
|
$
|
29.0
|
|
|
$
|
27.3
|
|
|
$
|
25.9
|
|
|
$
|
0.7
|
|
|
$
|
0.7
|
|
|
$
|
0.8
|
|
Interest cost
|
|
47.3
|
|
|
50.6
|
|
|
55.4
|
|
|
15.0
|
|
|
16.8
|
|
|
18.1
|
|
||||||
Expected return on plan assets
|
|
(68.5
|
)
|
|
(68.5
|
)
|
|
(70.8
|
)
|
|
(22.7
|
)
|
|
(21.9
|
)
|
|
(22.3
|
)
|
||||||
Amortization of prior service credit
|
|
(3.4
|
)
|
|
(3.2
|
)
|
|
(3.2
|
)
|
|
(6.2
|
)
|
|
(6.2
|
)
|
|
(6.3
|
)
|
||||||
Amortization of net loss
|
|
31.2
|
|
|
28.3
|
|
|
26.8
|
|
|
4.0
|
|
|
3.8
|
|
|
1.9
|
|
||||||
Settlement charge
(a)
|
|
4.5
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
—
|
|
||||||
Net periodic pension cost (credit)
|
|
40.1
|
|
|
34.5
|
|
|
34.1
|
|
|
(9.2
|
)
|
|
(6.8
|
)
|
|
(7.8
|
)
|
||||||
Costs (credits) not recognized due to effects of regulation
|
|
(3.9
|
)
|
|
(2.7
|
)
|
|
3.4
|
|
|
1.8
|
|
|
—
|
|
|
—
|
|
||||||
Net benefit cost (credit) recognized for financial reporting
|
|
$
|
36.2
|
|
|
$
|
31.8
|
|
|
$
|
37.5
|
|
|
$
|
(7.4
|
)
|
|
$
|
(6.8
|
)
|
|
$
|
(7.8
|
)
|
Significant Assumptions Used to Measure Costs:
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Discount rate
|
|
3.63
|
%
|
|
4.13
|
%
|
|
4.66
|
%
|
|
3.62
|
%
|
|
4.13
|
%
|
|
4.65
|
%
|
||||||
Expected average long-term increase in compensation level
|
|
3.75
|
|
|
3.75
|
|
|
4.00
|
|
|
N/A
|
|
|
N/A
|
|
|
N/A
|
|
||||||
Expected average long-term rate of return on assets
|
|
6.84
|
|
|
6.84
|
|
|
6.84
|
|
|
5.80
|
|
|
5.80
|
|
|
5.80
|
|
(a)
|
A settlement charge is required when the amount of all lump-sum distributions during the year is greater than the sum of the service and interest cost components of the annual net periodic pension cost. In 2018, as a result of lump-sum distributions during the 2018 plan years, PSCo recorded a total pension settlement charge of
$4.5 million
in 2018, the majority of which was not recognized due to the effects of regulation.
|
|
|
Pension Benefits
|
|
Postretirement Benefits
|
||||||||||||
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||||||
Amounts Not Yet Recognized as Components of Net Periodic Benefit Cost:
|
|
|
|
|
|
|
|
|
||||||||
Net loss
|
|
$
|
530.8
|
|
|
$
|
543.7
|
|
|
$
|
66.9
|
|
|
$
|
77.8
|
|
Prior service credit
|
|
(7.2
|
)
|
|
(10.6
|
)
|
|
(15.3
|
)
|
|
(21.5
|
)
|
||||
Total
|
|
$
|
523.6
|
|
|
$
|
533.1
|
|
|
$
|
51.6
|
|
|
$
|
56.3
|
|
Amounts Not Yet Recognized as Components of Net Periodic Benefit Cost Have Been Recorded as Follows Based Upon Expected Recovery in Rates:
|
|
|
|
|
|
|
|
|
||||||||
Current regulatory assets
|
|
$
|
25.8
|
|
|
$
|
27.7
|
|
|
|
|
$
|
—
|
|
||
Noncurrent regulatory assets
|
|
497.5
|
|
505.1
|
|
|
51.6
|
|
56.3
|
|
||||||
Deferred income taxes
|
|
0.1
|
|
|
0.1
|
|
|
—
|
|
|
—
|
|
||||
Net-of-tax accumulated other comprehensive income
|
|
0.2
|
|
0.2
|
|
|
—
|
|
|
—
|
|
|||||
Total
|
|
$
|
523.6
|
|
|
$
|
533.1
|
|
|
$
|
51.6
|
|
|
$
|
56.3
|
|
Measurement date
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
•
|
$150 million
in January 2019, of which
$43 million
was attributable to PSCo;
|
•
|
$150 million
in 2018, of which
$22 million
was attributable to PSCo;
|
•
|
$162 million
in 2017, of which
$18 million
was attributable to PSCo; and
|
•
|
$125 million
in 2016, of which
$17 million
was attributable to PSCo.
|
•
|
$11 million
during
2018
, of which
$5 million
was attributable to PSCo;
|
•
|
$20 million
during
2017
, of which
$5 million
was attributable to PSCo; and
|
•
|
$18 million
during
2016
, of which
$5 million
was attributable to PSCo.
|
|
|
Pension Benefits
|
|
Postretirement Benefits
|
||||||||
|
|
2018
|
|
2017
|
|
2018
|
|
2017
|
||||
Domestic and international equity securities
|
|
35
|
%
|
|
34
|
%
|
|
18
|
%
|
|
24
|
%
|
Long-duration fixed income securities
|
|
32
|
|
|
32
|
|
|
—
|
|
|
—
|
|
Short-to-intermediate fixed income securities
|
|
16
|
|
|
18
|
|
|
70
|
|
|
60
|
|
Alternative investments
|
|
15
|
|
|
14
|
|
|
8
|
|
|
9
|
|
Cash
|
|
2
|
|
|
2
|
|
|
4
|
|
|
7
|
|
Total
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
|
100
|
%
|
(Millions of Dollars)
|
|
Projected Pension
Benefit Payments |
|
Gross Projected
Postretirement Health Care Benefit Payments |
|
Expected Medicare
Part D Subsidies |
|
Net Projected
Postretirement Health Care Benefit Payments |
||||||||
2019
|
|
$
|
81.2
|
|
|
$
|
31.6
|
|
|
$
|
2.0
|
|
|
$
|
29.6
|
|
2020
|
|
80.9
|
|
|
31.7
|
|
|
2.1
|
|
|
29.6
|
|
||||
2021
|
|
82.4
|
|
|
31.6
|
|
|
2.2
|
|
|
29.4
|
|
||||
2022
|
|
82.8
|
|
|
31.5
|
|
|
2.3
|
|
|
29.2
|
|
||||
2023
|
|
83.4
|
|
|
31.0
|
|
|
2.4
|
|
|
28.6
|
|
||||
2024-2028
|
|
410.2
|
|
|
141.5
|
|
|
13.0
|
|
|
128.5
|
|
11.
|
Commitments and Contingencies
|
|
|
Dec. 31, 2018
|
||||||||||||||||||||||
(Millions
of Dollars)
|
|
Jan. 1, 2018
|
|
Amounts Incurred
(a)
|
|
Amounts Settled
(b)
|
|
Accretion
|
|
Cash Flow Revisions
(c)
|
|
Dec. 31, 2018
|
||||||||||||
Electric
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Steam, hydro, and other production
|
|
$
|
103.2
|
|
|
$
|
—
|
|
|
$
|
(7.1
|
)
|
|
$
|
4.7
|
|
|
$
|
1.4
|
|
|
$
|
102.2
|
|
Wind
|
|
2.1
|
|
|
12.3
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
14.5
|
|
||||||
Distribution
|
|
7.9
|
|
|
—
|
|
|
—
|
|
|
0.3
|
|
|
5.2
|
|
|
13.4
|
|
||||||
Miscellaneous
|
|
1.4
|
|
|
—
|
|
|
(0.1
|
)
|
|
0.1
|
|
|
1.8
|
|
|
3.2
|
|
||||||
Natural gas
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Transmission and distribution
|
|
228.9
|
|
|
—
|
|
|
—
|
|
|
9.3
|
|
|
(37.3
|
)
|
|
200.9
|
|
||||||
Miscellaneous
|
|
3.9
|
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
4.0
|
|
||||||
Common
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||||||||
Miscellaneous
|
|
0.4
|
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
—
|
|
|
0.5
|
|
||||||
Total liability
|
|
$
|
347.8
|
|
|
$
|
12.3
|
|
|
$
|
(7.2
|
)
|
|
$
|
14.7
|
|
|
$
|
(28.9
|
)
|
|
$
|
338.7
|
|
(a)
|
Amounts incurred related to the Rush Creek wind farm, which was placed in service in 2018.
|
(b)
|
Amounts settled related to closure of certain ash containment facilities.
|
(c)
|
In 2018, AROs were revised for changes in timing and estimates of cash flows. Changes in gas transmission and distribution AROs were primarily related to increased gas line mileage and number of services, which were more than offset by increased discount rates. Changes in electric distribution AROs were primarily related to increased labor costs.
|
|
|
Dec. 31, 2017
|
||||||||||||||||||
(Millions of
Dollars)
|
|
Jan. 1, 2017
|
|
Amounts Settled
(a)
|
|
Accretion
|
|
Cash Flow Revisions
(b)
|
|
Dec. 31, 2017
(c)
|
||||||||||
Electric
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Steam, hydro, and other production
|
|
$
|
113.1
|
|
|
$
|
(24.1
|
)
|
|
$
|
5.1
|
|
|
$
|
9.1
|
|
|
$
|
103.2
|
|
Wind
|
|
2.1
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
2.1
|
|
|||||
Distribution
|
|
7.7
|
|
|
—
|
|
|
0.2
|
|
|
—
|
|
|
7.9
|
|
|||||
Miscellaneous
|
|
1.5
|
|
|
(0.2
|
)
|
|
0.1
|
|
|
—
|
|
|
1.4
|
|
|||||
Natural gas
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Transmission and distribution
|
|
160.7
|
|
|
—
|
|
|
6.7
|
|
|
61.5
|
|
|
228.9
|
|
|||||
Miscellaneous
|
|
4.1
|
|
|
(0.4
|
)
|
|
0.2
|
|
|
—
|
|
|
3.9
|
|
|||||
Common
|
|
|
|
|
|
|
|
|
|
|
||||||||||
Miscellaneous
|
|
0.4
|
|
|
—
|
|
|
—
|
|
|
—
|
|
|
0.4
|
|
|||||
Total liability
|
|
$
|
289.6
|
|
|
$
|
(24.7
|
)
|
|
$
|
12.3
|
|
|
$
|
70.6
|
|
|
$
|
347.8
|
|
(a)
|
Amounts settled related to asbestos abatement projects, closure of certain ash containment facilities, and removal and proper disposal of storage tanks and other above ground equipment.
|
(b)
|
In 2017, AROs were revised for changes in timing and estimates of cash flows. Changes in gas transmission and distribution AROs were primarily related to increased labor costs.
|
(c)
|
There were no ARO amounts incurred in 2017.
|
(Millions of Dollars)
|
|
Dec. 31, 2018
|
|
Dec. 31, 2017
|
||||
Gas storage facilities
|
|
$
|
200.5
|
|
|
$
|
200.5
|
|
Gas pipeline
|
|
20.7
|
|
|
20.7
|
|
||
Property held under capital leases
|
|
221.2
|
|
|
221.2
|
|
||
Accumulated depreciation
|
|
(76.2
|
)
|
|
(70.6
|
)
|
||
Total property held under capital leases, net
|
|
$
|
145.0
|
|
|
$
|
150.6
|
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Total expense
|
|
$
|
110.6
|
|
|
$
|
108.6
|
|
|
$
|
118.2
|
|
Capacity payments
|
|
96.6
|
|
|
96.1
|
|
|
102.4
|
|
(Millions of Dollars)
|
|
Operating
Leases
|
|
PPA
(a) (b)
Operating
Leases
|
|
Total
Operating
Leases
|
|
Capital
Leases
|
||||||||
2019
|
|
$
|
10.8
|
|
|
$
|
95.5
|
|
|
$
|
106.3
|
|
|
$
|
24.9
|
|
2020
|
|
10.7
|
|
|
95.9
|
|
|
106.6
|
|
|
24.8
|
|
||||
2021
|
|
9.5
|
|
|
96.4
|
|
|
105.9
|
|
|
23.6
|
|
||||
2022
|
|
8.4
|
|
|
82.6
|
|
|
91.0
|
|
|
20.5
|
|
||||
2023
|
|
8.1
|
|
|
70.0
|
|
|
78.1
|
|
|
20.3
|
|
||||
Thereafter
|
|
53.4
|
|
|
288.6
|
|
|
342.0
|
|
|
420.4
|
|
||||
Total minimum obligation
|
534.5
|
|
||||||||||||||
Interest component of obligation
|
(389.5
|
)
|
||||||||||||||
Present value of minimum obligation
|
$
|
145.0
|
|
(a)
|
Amounts do not include PPAs accounted for as executory contracts.
|
(b)
|
PPA operating leases contractually expire through
2034
.
|
(Millions of Dollars)
|
|
Capacity
|
||
2019
|
|
$
|
12.3
|
|
2020
|
|
3.3
|
|
|
2021
|
|
3.2
|
|
|
2022
|
|
3.2
|
|
|
2023
|
|
3.2
|
|
|
Thereafter
|
|
9.8
|
|
|
Total
|
|
$
|
35.0
|
|
(Millions of Dollars)
|
|
Coal
|
|
Natural gas supply
|
|
Natural gas
storage and transportation |
||||||
2019
|
|
$
|
133.1
|
|
|
$
|
342.6
|
|
|
$
|
116.7
|
|
2020
|
|
86.4
|
|
|
261.6
|
|
|
115.1
|
|
|||
2021
|
|
55.6
|
|
|
251.8
|
|
|
113.0
|
|
|||
2022
|
|
32.5
|
|
|
113.0
|
|
|
113.1
|
|
|||
2023
|
|
24.8
|
|
|
59.9
|
|
|
65.5
|
|
|||
Thereafter
|
|
104.3
|
|
|
—
|
|
|
544.0
|
|
|||
Total
|
|
$
|
436.7
|
|
|
$
|
1,028.9
|
|
|
$
|
1,067.4
|
|
12.
|
Other Comprehensive Income
|
|
|
2018
|
||||||||||
(Millions of Dollars)
|
|
Gains and Losses on Cash Flow Hedges
|
|
Defined Benefit and Postretirement Items
|
|
Total
|
||||||
Accumulated other comprehensive loss at Jan. 1
|
|
$
|
(26.5
|
)
|
|
$
|
(0.2
|
)
|
|
$
|
(26.7
|
)
|
Losses reclassified from net accumulated other comprehensive loss:
|
|
|
|
|
|
|
||||||
Interest rate derivatives (net of taxes of $0.4 and $0, respectively)
|
|
1.2
|
|
(a)
|
—
|
|
|
1.2
|
|
|||
Net current period other comprehensive income
|
|
1.2
|
|
|
—
|
|
|
1.2
|
|
|||
Accumulated other comprehensive loss at Dec. 31
|
|
$
|
(25.3
|
)
|
|
$
|
(0.2
|
)
|
|
$
|
(25.5
|
)
|
|
|
2017
|
||||||||||
(Millions of Dollars)
|
|
Gains and Losses on Cash Flow Hedges
|
|
Defined Benefit and Postretirement Items
|
|
Total
|
||||||
Accumulated other comprehensive loss at Jan. 1
|
|
$
|
(22.8
|
)
|
|
$
|
(0.2
|
)
|
|
$
|
(23.0
|
)
|
Losses reclassified from net accumulated other comprehensive loss:
|
|
|
|
|
|
|
|
|
|
|||
Interest rate derivatives (net of taxes of $0.6 and $0, respectively)
|
|
1.0
|
|
(a)
|
—
|
|
|
1.0
|
|
|||
Net current period other comprehensive income
|
|
1.0
|
|
|
—
|
|
|
1.0
|
|
|||
Adoption of ASU No. 2018-02
(b)
|
|
(4.7
|
)
|
|
—
|
|
|
(4.7
|
)
|
|||
Accumulated other comprehensive loss at Dec. 31
|
|
$
|
(26.5
|
)
|
|
$
|
(0.2
|
)
|
|
$
|
(26.7
|
)
|
(a)
|
Included in interest charges.
|
(b)
|
In 2017, PSCo implemented ASU No. 2018-02 related to the TCJA, which resulted in reclassification of certain credit balances within net accumulated other comprehensive loss to retained earnings.
|
13.
|
Segments and Related Information
|
•
|
Regulated Electric
- The regulated electric utility segment generates electricity which is transmitted and distributed in Colorado. This segment includes sales for resale and provides wholesale transmission service to various entities in the United States. Regulated electric utility also includes PSCo’s wholesale commodity and trading operations.
|
•
|
Regulated Natural Gas
- The regulated natural gas utility segment transports, stores and distributes natural gas in portions of Colorado.
|
•
|
All Other
- Revenues from operating segments not included above are below the necessary quantitative thresholds are included in the all other category. Those primarily include steam revenue, appliance repair services and nonutility real estate activities.
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Regulated Electric
|
|
|
|
|
|
|
||||||
Operating revenues
(a)
|
|
$
|
3,031.2
|
|
|
$
|
3,003.8
|
|
|
$
|
3,049.4
|
|
Intersegment revenues
|
|
0.3
|
|
|
0.3
|
|
|
0.3
|
|
|||
Total operating revenue
|
|
$
|
3,031.5
|
|
|
$
|
3,004.1
|
|
|
$
|
3,049.7
|
|
Depreciation and amortization
|
|
415.6
|
|
|
353.6
|
|
|
337.6
|
|
|||
Interest charges and financing costs
|
|
142.3
|
|
|
138.6
|
|
|
136.3
|
|
|||
Income tax expense
|
|
103.0
|
|
|
243.6
|
|
|
228.8
|
|
|||
Net income
|
|
428.6
|
|
|
370.6
|
|
|
384.0
|
|
|||
Regulated Natural Gas
|
|
|
|
|
|
|
||||||
Operating revenues
(a)
|
|
$
|
1,014.6
|
|
|
$
|
995.2
|
|
|
$
|
957.7
|
|
Intersegment revenues
|
|
0.6
|
|
|
0.4
|
|
|
0.1
|
|
|||
Total operating revenue
|
|
$
|
1,015.2
|
|
|
$
|
995.6
|
|
|
$
|
957.8
|
|
Depreciation and amortization
|
|
140.6
|
|
|
113.2
|
|
|
101.7
|
|
|||
Interest charges and financing costs
|
|
42.9
|
|
|
40.2
|
|
|
37.9
|
|
|||
Income tax expense
|
|
13.1
|
|
|
18.4
|
|
|
46.0
|
|
|||
Net income
|
|
121.4
|
|
|
107.8
|
|
|
75.4
|
|
|||
All Other
|
|
|
|
|
|
|
||||||
Operating revenues
(a)
|
|
$
|
40.4
|
|
|
$
|
43.5
|
|
|
$
|
40.7
|
|
Depreciation and amortization
|
|
4.9
|
|
|
4.7
|
|
|
4.3
|
|
|||
Interest charges and financing costs
|
|
0.5
|
|
|
0.5
|
|
|
0.4
|
|
|||
Income tax (benefit)
|
|
(2.4
|
)
|
|
(9.8
|
)
|
|
(0.9
|
)
|
|||
Net income
|
|
1.7
|
|
|
15.7
|
|
|
4.1
|
|
|||
|
|
|
|
|
|
|
||||||
Consolidated Total
|
|
|
|
|
|
|
||||||
Operating revenues
(a)
|
|
$
|
4,087.1
|
|
|
$
|
4,043.2
|
|
|
$
|
4,048.2
|
|
Intersegment revenues
|
|
(0.9
|
)
|
|
(0.7
|
)
|
|
(0.4
|
)
|
|||
Total operating revenue
|
|
$
|
4,086.2
|
|
|
$
|
4,042.5
|
|
|
$
|
4,047.8
|
|
Depreciation and amortization
|
|
561.1
|
|
|
471.5
|
|
|
443.6
|
|
|||
Interest charges and financing costs
|
|
185.7
|
|
|
179.3
|
|
|
174.6
|
|
|||
Income tax expense
|
|
113.7
|
|
|
252.2
|
|
|
273.9
|
|
|||
Net income
|
|
551.7
|
|
|
494.1
|
|
|
463.5
|
|
(a)
|
Operating revenues include
$4.4 million
,
$5.9 million
and
$13.3 million
of intercompany revenue for the years ended Dec. 31,
2018
,
2017
and
2016
, respectively. See Note 14 for further information.
|
14.
|
Related Party Transactions
|
(Millions of Dollars)
|
|
2018
|
|
2017
|
|
2016
|
||||||
Operating revenues:
|
|
|
|
|
|
|
||||||
Electric
|
|
$
|
—
|
|
|
$
|
1.4
|
|
|
$
|
8.8
|
|
Other
|
|
4.4
|
|
|
4.5
|
|
|
4.5
|
|
|||
Operating expenses:
|
|
|
|
|
|
|
||||||
Other operating expenses — paid to Xcel Energy Services Inc.
|
|
518.7
|
|
|
485.1
|
|
|
446.1
|
|
|||
Interest expense
|
|
—
|
|
|
—
|
|
|
0.1
|
|
|
|
2018
|
|
2017
|
||||||||||||
(Millions of Dollars)
|
|
Accounts
Receivable |
|
Accounts
Payable |
|
Accounts
Receivable |
|
Accounts
Payable |
||||||||
NSP-Minnesota
|
|
$
|
17.9
|
|
|
$
|
—
|
|
|
$
|
7.7
|
|
|
$
|
—
|
|
NSP-Wisconsin
|
|
—
|
|
|
0.2
|
|
|
—
|
|
|
—
|
|
||||
SPS
|
|
0.7
|
|
|
—
|
|
|
0.3
|
|
|
—
|
|
||||
Other subsidiaries of Xcel Energy Inc.
|
|
62.2
|
|
|
45.8
|
|
|
6.7
|
|
|
58.7
|
|
||||
|
|
$
|
80.8
|
|
|
$
|
46.0
|
|
|
$
|
14.7
|
|
|
$
|
58.7
|
|
15.
|
Summarized Quarterly Financial Data (Unaudited)
|
|
|
Quarter Ended
|
||||||||||||||
(Millions of Dollars)
|
|
March 31, 2018
|
|
June 30, 2018
|
|
Sept. 30, 2018
|
|
Dec. 31, 2018
|
||||||||
Operating revenues
|
|
$
|
1,073.3
|
|
|
$
|
911.9
|
|
|
$
|
1,060.7
|
|
|
$
|
1,040.3
|
|
Operating income
|
|
206.9
|
|
|
189.3
|
|
|
276.9
|
|
|
119.5
|
|
||||
Net income
|
|
133.7
|
|
|
122.3
|
|
|
207.1
|
|
|
88.6
|
|
|
|
Quarter Ended
|
||||||||||||||
(Millions of Dollars)
|
|
March 31, 2017
|
|
June 30, 2017
|
|
Sept. 30, 2017
|
|
Dec. 31, 2017
|
||||||||
Operating revenues
|
|
$
|
1,080.5
|
|
|
$
|
930.9
|
|
|
$
|
1,030.3
|
|
|
$
|
1,000.8
|
|
Operating income
(a)
|
|
212.9
|
|
|
193.3
|
|
|
326.5
|
|
|
155.3
|
|
||||
Net income
|
|
111.5
|
|
|
100.6
|
|
|
186.1
|
|
|
95.9
|
|
(a)
|
In 2018, PSCo implemented ASU No. 2017-07 related to net periodic benefit cost, which resulted in retrospective reclassification of pension costs from O&M expense to other income.
|
Exhibit Number
|
Description
|
Report or Registration Statement
|
SEC File or Registration Number
|
Exhibit Reference
|
3.01
*
|
PSCo Form 10-Q for the quarter ended Sept. 30, 2017
|
001-03280
|
3.01
|
|
|
|
|
||
4.01
*
|
Xcel Energy Inc. Form S-3 dated April 18, 2018
|
001-03034
|
4(d)(3)
|
|
4.02
*
|
PSCo Form 8-K dated July 13, 1999
|
001-03280
|
4.1
4.2
|
|
4.03
*
|
PSCo Form 8-K dated Aug. 8, 2007
|
001-03280
|
4.01
|
|
4.04
*
|
PSCo Form 8-K dated Aug. 6, 2008
|
001-03280
|
4.01
|
|
4.05
*
|
PSCo Form 8-K dated May 28, 2009
|
001-03280
|
4.01
|
|
4.06
*
|
PSCo Form 8-K dated Nov. 8, 2010
|
001-03280
|
4.01
|
|
4.07
*
|
PSCo Form 8-K dated Aug. 9, 2011
|
001-03280
|
4.01
|
|
4.08
*
|
PSCo Form 8-K dated Sept. 11, 2012
|
001-03280
|
4.01
|
|
4.09
*
|
PSCo Form 8-K dated March 26, 2013
|
001-03280
|
4.01
|
|
4.10
*
|
PSCo Form 8-K dated March 10, 2014
|
001-03280
|
4.01
|
|
4.11
*
|
PSCo Form 8-K dated May 12, 2015
|
001-03280
|
4.01
|
|
4.12
*
|
PSCo Form 8-K dated June 13, 2016
|
001-03280
|
4.01
|
|
4.13
*
|
PSCo Form 8-K dated June 19, 2017
|
001-03280
|
4.01
|
|
4.14
*
|
PSCo Form 8-K dated June 21, 2018
|
001-03280
|
4.01
|
|
10.01
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2008
|
001-03034
|
10.02
|
10.02
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2008
|
001-03034
|
10.05
|
|
10.03
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2008
|
001-03034
|
10.08
|
|
10.04
*+
|
Xcel Energy Inc. Form U5B dated Nov. 16, 2000
|
001-03034
|
H-1
|
|
10.05
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2008
|
001-03034
|
10.17
|
|
10.06
*
|
Xcel Energy Inc. Form 8-K dated Dec. 3, 2004
|
001-03034
|
99.02
|
|
10.07
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended Sept. 30, 2009
|
001-03034
|
10.06
|
|
10.08
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended Sept. 30, 2009
|
001-03034
|
10.08
|
|
10.09
*+
|
Xcel Energy Inc. Definitive Proxy Statement dated April 6, 2010
|
001-03034
|
Schedule 14A
|
|
10.10
*+
|
Xcel Energy Inc. Definitive Proxy Statement dated April 6, 2010
|
001-03034
|
Schedule 14A
|
|
10.11
*+
|
Xcel Energy Inc. Definitive Proxy Statement dated April 5, 2011
|
001-03034
|
Schedule 14A
|
|
10.12
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2008
|
001-03034
|
10.07
|
|
10.13
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2011
|
001-03034
|
10.17
|
|
10.14
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2011
|
001-03034
|
10.18
|
|
10.15
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended March 31, 2013
|
001-03034
|
10.01
|
|
10.16
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended March 31, 2013
|
001-03034
|
10.02
|
|
10.17
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2013
|
001-03034
|
10.21
|
|
10.18
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2013
|
001-03034
|
10.22
|
|
10.19
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2013
|
001-03034
|
10.23
|
|
10.20
*+
|
Xcel Energy Inc. Definitive Proxy Statement dated April 6, 2015
|
001-03034
|
Schedule 14A
|
|
10.21
*+
|
Xcel Energy Inc. Form 8-K dated May 20, 2015
|
001-03034
|
10.02
|
|
10.22
*+
|
Xcel Energy Inc. Form 8-K dated May 20, 2015
|
001-03034
|
10.03
|
|
10.23
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2015
|
001-03034
|
10.28
|
|
10.24
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2015
|
001-03034
|
10.29
|
|
10.25
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended June 30, 2016
|
001-03034
|
10.01
|
|
10.26
*
|
Xcel Energy Inc. Form 8-K dated June 20, 2016
|
001-03034
|
99.03
|
|
10.27
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended Sept. 30, 2016
|
001-03034
|
10.01
|
|
10.28
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2016
|
001-03034
|
10.27
|
|
10.29
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended Sept. 30, 2017
|
001-03034
|
10.1
|
|
10.30
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2017
|
001-03034
|
10.30
|
|
10.31
*+
|
Xcel Energy Inc. Form 10-Q for the quarter ended June 30, 2018
|
001-03034
|
10.01
|
|
10.32
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2018
|
001-03034
|
10.34
|
|
10.33
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2018
|
001-03034
|
10.35
|
|
10.34
*+
|
Xcel Energy Inc. Form 10-K for the year ended Dec. 31, 2018
|
001-03034
|
10.36
|
101
|
The following materials from PSCo’s Annual Report on Form 10-K for the year ended Dec. 31, 2018 are formatted in XBRL (eXtensible Business Reporting Language): (i) the Consolidated Statements of Income, (ii) the Consolidated Statements of Comprehensive Income, (iii) the Consolidated Statements of Cash Flows, (iv) the Consolidated Balance Sheets, (v) the Consolidated Statements of Stockholder’s Equity, (vi) Notes to Consolidated Financial Statements, (vii) document and entity information, and (viii) Schedule II.
|
|
Allowance for bad debts
|
||||||||||
(Millions of Dollars)
|
2018
|
|
2017
|
|
2016
|
||||||
Balance at Jan. 1
|
$
|
19.6
|
|
|
$
|
19.6
|
|
|
$
|
20.1
|
|
Additions Charged to Costs and Expenses
|
16.4
|
|
|
14.3
|
|
|
14.1
|
|
|||
Additions Charged to Other Accounts
(a)
|
4.7
|
|
|
4.0
|
|
|
4.5
|
|
|||
Deductions from Reserves
(b)
|
(20.2
|
)
|
|
(18.3
|
)
|
|
(19.1
|
)
|
|||
Balance at Dec. 31
|
$
|
20.5
|
|
|
$
|
19.6
|
|
|
$
|
19.6
|
|
(a)
|
Recovery of amounts previously written off.
|
(b)
|
Deductions relate primarily to bad debt write-offs.
|
|
|
PUBLIC SERVICE COMPANY OF COLORADO
|
|
|
|
Feb. 22, 2019
|
|
/s/ ROBERT C. FRENZEL
|
|
|
Robert C. Frenzel
|
|
|
Executive Vice President, Chief Financial Officer and Director
|
|
|
(Principal Financial Officer)
|
/s/ BEN FOWKE
|
|
/s/ ALICE K. JACKSON
|
Ben Fowke
|
|
Alice K. Jackson
|
Chairman, Chief Executive Officer and Director
|
|
President and Director
|
(Principal Executive Officer)
|
|
|
|
|
|
/s/ ROBERT C. FRENZEL
|
|
/s/ JEFFREY S. SAVAGE
|
Robert C. Frenzel
|
|
Jeffrey S. Savage
|
Executive Vice President, Chief Financial Officer and Director
|
|
Senior Vice President, Controller
|
(Principal Financial Officer)
|
|
(Principal Accounting Officer)
|
|
|
|
/s/ DAVID L. EVES
|
|
|
David L. Eves
|
|
|
Executive Vice President and Director
|
|
|
/s/
DELOITTE & TOUCHE LLP
|
Minneapolis, Minnesota
|
February 22, 2019
|
1.
|
I have reviewed this report on Form 10-K of Public Service Company of Colorado;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
a.
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
b.
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
c.
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
d.
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
a.
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
b.
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
|
/s/ BEN FOWKE
|
|
Ben Fowke
|
|
Chairman, Chief Executive Officer and Director
|
1.
|
I have reviewed this report on Form 10-K of Public Service Company of Colorado;
|
2.
|
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
|
3.
|
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
|
4.
|
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
|
a.
|
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
|
b.
|
Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
|
c.
|
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
|
d.
|
Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
|
5.
|
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
|
a.
|
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
|
b.
|
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
|
|
/s/ ROBERT C. FRENZEL
|
|
Robert C. Frenzel
|
|
Executive Vice President, Chief Financial Officer and Director
|
(1)
|
The Form 10-K fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
|
(2)
|
The information contained in the Form 10-K fairly presents, in all material respects, the financial condition and results of operations of PSCo as of the dates and for the periods expressed in the Form 10-K.
|
|
/s/ BEN FOWKE
|
|
Ben Fowke
|
|
Chairman, Chief Executive Officer and Director
|
|
|
|
/s/ ROBERT C. FRENZEL
|
|
Robert C. Frenzel
|
|
Executive Vice President, Chief Financial Officer and Director
|