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Rate Matters (Tables)
 3 Months Ended
Mar. 31, 2015
Public Utilities, General Disclosures [Abstract]  
Colorado 2014 Electric Rate Case [Table Text Block]
The components of the overall 2015 revenue increase are as follows:
(Millions of Dollars)
 
Approved Settlement
Total base rate decrease
 
$
(39.4
)
CACJA rider mechanism
 
97.0

TCA rider mechanism
 
15.6

Transfer from TCA rider to base rates
 
(19.9
)
Total revenue increase
 
$
53.3
Colorado 2015 Multi-Year Gas Rate Case [Table Text Block]
The following table summarizes the request:
(Millions of Dollars)
 
2015
 
2016 Step
 
2017 Step
Net plant and plant related expenses
 
$
24.4

 
$
12.4

 
$
12.0

Operating and maintenance expenses
 
23.9

 
(5.2
)
 
0.6

Property and payroll taxes
 
4.7

 
2.6

 
4.0

ROE
 
4.5

 
—

 
2.4

Capital structure
 
(1.0
)
 
—

 
0.1

Sales forecast
 
(17.1
)
 
(2.2
)
 
(1.0
)
Other, net
 
1.1

 
—

 
—

Total base rate increase
 
40.5

 
7.6

 
18.1

Incremental PSIA rider revenues
 
(0.1
)
 
21.7

 
21.2

Total revenue impact
 
$
40.4

 
$
29.3

 
$
39.3
NSP-Minnesota's 2014 Electric Rate Case [Table Text Block]
The following table reconciles NSP-Minnesota’s original request to the MPUC's March 26, 2015 verbal decision, including the estimated ongoing impact of their March 6, 2015 verbal decision in the Monticello Prudence Review on the Minnesota retail electric jurisdiction:
2014 Rate Request (Millions of Dollars)
 
NSP-Minnesota
 
ALJ
 
MPUC Decision
NSP-Minnesota’s filed rate request
 
$
192.7

 
$
192.7

 
$
192.7

Sales forecast (with true-up to 12 months of actual weather-normalized sales)
 
(38.5
)
 
(38.5
)
 
(38.5
)
ROE
 
—

 
(28.4
)
 
(31.9
)
Monticello extended power uprate (EPU) cost recovery
 
(12.2
)
 
(31.3
)
 
(37.6
)
Property taxes (with true-up to actual 2014 accruals)
 
(13.2
)
 
(13.2
)
 
(13.2
)
Prairie Island EPU cost recovery
 
(5.1
)
 
(5.1
)
 
(5.1
)
Health care, pension and other benefits
 
(1.9
)
 
(1.9
)
 
(3.0
)
Other, net
 
(6.5
)
 
(5.2
)
 
(5.3
)
Total 2014
 
$
115.3

 
$
69.1

 
$
58.1

2015 Rate Request (Millions of Dollars)
 
NSP-Minnesota
 
ALJ
 
MPUC Decision
NSP-Minnesota’s filed rate request
 
$
98.5

 
$
98.5

 
$
98.5

Monticello EPU cost recovery
 
11.7

 
29.1

 
35.4

Depreciation / Retirements
 
—

 
—

 
(0.5
)
Property taxes
 
(3.3
)
 
(3.3
)
 
(3.3
)
Production tax credits to be included in base rates
 
(11.1
)
 
(11.1
)
 
(11.1
)
U.S. Department of Energy (DOE) settlement proceeds
 
10.1

 
10.1

 
10.1

Emission chemicals
 
(1.6
)
 
(1.6
)
 
(1.6
)
Other, net
 
1.7

 
0.7

 
0.2

Total 2015 step increase - prior to Monticello EPU cost disallowance
 
$
106.0

 
$
122.4

 
$
127.7

 
 
 
 
 
 
 
Total for 2014 and 2015 step increase - prior to Monticello EPU cost disallowance
 
$
221.3

 
$
191.5

 
$
185.8

Monticello EPU cost disallowance - ongoing impact
 
—

 
—

 
(18.2
)
Total for 2014 and 2015 step increase - including Monticello EPU cost disallowance
 
$
221.3

 
$
191.5

 
$
167.6
Nuclear Project Prudence Investigation [Table Text Block]
In addition, the decision would reduce the 2015 revenue requirement and pre-tax income for Xcel Energy (assuming other state commissions adopt the MPUC decision) and the Minnesota retail electric jurisdiction as follows:
(Millions of Dollars)
 
Revenue
 
Pre-tax Income (a)
Xcel Energy
 
$
25

 
$
16

Minnesota retail electric jurisdiction
 
18

 
12


(a) 
Pre-tax income reflects the net impact of the reductions in revenue and depreciation expense.
SPS' Texas 2015 Electric Rate Case [Table Text Block]
The following table summarizes the net request:
(Millions of Dollars)
 
Request
Investment for capital expenditures — post-test year adjustments
 
$
23.7

Depreciation expense
 
13.9

Wholesale load reductions
 
12.0

Purchased power capacity costs
 
3.2

Other, net
 
6.1

Total
 
$
58.9
FERC Wholesale Rate Complaints [Table Text Block]
The FERC established effective dates for the refunds as April 20, 2012 (first refund period) and July 19, 2013 (second refund period). Settlement judge procedures were unsuccessful and the complaints were set for hearings. In the first quarter of 2015, Golden Spread, SPS and FERC staff filed their initial testimonies recommending the following ROEs:
 
 
Refund Period
 
Production ROE
 
Transmission ROE (a)
Golden Spread
 
1
 
8.78
%
 
9.28
%
 
 
2
 
8.51

 
9.01

SPS
 
1
 
10.25

 
10.39

 
 
2
 
10.25

 
11.20

FERC Staff
 
1
 
8.97

 
9.47

 
 
2
 
8.64

 
9.14


(a) 
Includes a Southwest Power Pool, Inc. (SPP) RTO membership adder up to 50 basis points.