form8k.htm
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported) May 25, 2011
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Commission File
Number
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Exact Name of Registrant as Specified in its Charter; State of
Incorporation; Address of Principal Executive Offices; and
Telephone Number
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IRS Employer
Identification
Number
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001-3034
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XCEL ENERGY
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41-0448030
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(a Minnesota corporation)
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414 Nicollet Mall
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Minneapolis, Minnesota 55401
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(612) 330-5500
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001-3280
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PUBLIC SERVICE COMPANY OF COLORADO
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84-0296600
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(a Colorado corporation)
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1800 Larimer Street Suite 1100
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Denver, Colorado 80202
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(303) 571-7511
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Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
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Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
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Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
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Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
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Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
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In December 2010, Public Service Company of Colorado (PSCo) a Colorado corporation and a wholly owned subsidiary of Xcel Energy Inc., filed a request with the Colorado Public Utilities Commission (CPUC) to increase Colorado retail gas rates by $27.5 million, effective in the summer of 2011. In March 2011, PSCo revised its requested rate increase to $25.6 million.
The revised request was based on a 2011 forecast test year, a 10.90 percent return on equity (ROE), a rate base of $1.1 billion and an equity ratio of 57.10 percent. PSCo proposed recovering $23.2 million of test year capital and operating and maintenance (O&M) expenses associated with several pipeline integrity costs plus an amortization of similar costs that have been accumulated and deferred since the last rate case in 2006. PSCo also proposed removing the earnings on gas in underground storage from base rates.
On April 11, 2011, intervenors filed answer testimony. The CPUC Staff recommended a rate decrease of approximately $20.1 million, based on the use of an historic test year (HTY), an ROE of 9.375 percent and an equity ratio of 51.82 percent. The CPUC Staff also recommended certain adjustments to pipeline integrity costs, rate base items and pension and benefits. On May 2, 2011, the CPUC Staff revised their recommendation to a $21.9 million rate decrease.
The Colorado Office of Consumer Counsel (OCC) recommended a rate decrease of approximately $1 million, based on an ROE of 9.0 percent, an equity ratio of 57.20 percent and by reducing cash working capital to reflect adjustments to interest on long-term debt. The OCC also recommended adjustments to some O&M expenses, use of a HTY and recommended that gas stored underground remain in base rates rather than move to a rider. The impact of including gas inventory in base rates would reduce PSCo’s fuel recovery by an additional $9 million.
In May 2011, PSCo filed rebuttal testimony revising its request to a $20.4 million base revenue increase, based on a 2011 forecast test year, a 10.80 percent ROE, a rate base of $1.1 billion, an equity ratio of 57.10 percent and updated information.
On May 25, 2011, PSCo filed a comprehensive settlement with CPUC Staff and the OCC to increase rates by $10.9 million, to institute rider recovery of future integrity management costs, and remove underground storage from base rates and recover those costs in the Gas Cost Adjustment (GCA) rider. The GCA recovery of the return on gas in storage is expected to recover another $10 million of annual incremental revenue. Rates were set on a test year ending June 30, 2011 with an equity ratio of 56 percent and an ROE of 10.1 percent. If the settlement is approved by the CPUC, new base rates and the GCA recovery will go into effect on Sept. 5, 2011 and the rider for integrity management costs will go into effect on Jan. 1, 2012. The rider for integrity management costs is expected to recover an estimated $14 million of incremental revenue in 2012. The CPUC is expected to reach a decision in June 2011.
Except for the historical statements contained in this 8-K, the matters discussed herein, including the expected impact of rate cases, are forward-looking statements that are subject to certain risks, uncertainties and assumptions. Such forward-looking statements are intended to be identified in this document by the words “anticipate,” “believe,” “estimate,” “expect,” “intend,” “may,” “objective,” “outlook,” “plan,” “project,” “possible,” “potential,” “should” and similar expressions. Actual results may vary materially. Forward-looking statements speak only as of the date they are made, and we do not undertake any obligation to update them to reflect changes that occur after that date. Factors that could cause actual results to differ materially include, but are not limited to: general economic conditions, including inflation rates, monetary fluctuations and their impact on capital expenditures and the ability of Xcel Energy and its subsidiaries to obtain financing on favorable terms; business conditions in the energy industry; including the risk of a slow down in the U.S. economy or delay in growth recovery; trade, fiscal, taxation and environmental policies in areas where Xcel Energy and NSP-Minnesota have a financial interest; customer business conditions; actions of credit rating agencies; competitive factors including the extent and timing of the entry of additional competition in the markets served by Xcel Energy and its subsidiaries; unusual weather; effects of geopolitical events, including war and acts of terrorism; state, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rates or have an impact on asset operation or ownership; or imposed environmental compliance conditions; structures that affect the speed and degree to which competition enters the electric and natural gas markets; costs and other effects of legal and administrative proceedings, settlements, investigations and claims; financial or regulatory accounting policies imposed by regulatory bodies; availability of cost of capital; employee work force factors; and the other risk factors listed from time to time by Xcel Energy and PSCo in reports filed with the Securities and Exchange Commission (SEC), including Risk Factors in Item 1A and Exhibit 99.01 of Xcel Energy’s and PSCo’s Annual Report on Form 10-K for the year ended Dec. 31, 2010 and Quarterly Report on Form 10-Q for the quarter ended March 31, 2011.
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
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May 26, 2011
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Xcel Energy Inc.
(a Minnesota corporation)
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Public Service Company of Colorado
(a Colorado corporation)
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/s/ DAVID M. SPARBY
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David M. Sparby
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Vice President and Chief Financial Officer
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