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In January 2014, PacifiCorp filed a general rate case with the UPSC requesting an annual increase of $76 million, or an average price increase of 4%. The requested increase includes recovery of PacifiCorp's investments in the Mona-Oquirrh transmission line that was placed into service in May 2013 and Lake Side 2, which is expected to be placed into service in mid-2014. If approved by the UPSC, the new rates will be effective September 2014.
In March 2013, PacifiCorp filed a general rate case with the OPUC requesting an annual increase of $56 million, or an average price increase of 5%. The request was reduced to $45 million, or an average price increase of 4%, as a result of the OPUC's approval of a separate tariff rider for the Mona-Oquirrh transmission line that was effective June 1, 2013. PacifiCorp's general rate case filing also included a request for a separate tariff rider for Lake Side 2. In July 2013, a multi-party stipulation was filed with the OPUC resolving all issues in the general rate case. The stipulation provides for an annual increase of $24 million, or an average price increase of 2%, which includes the impact of the revised depreciation rates as described below. The stipulation also provides for the implementation of a separate tariff rider for Lake Side 2 when placed into service in mid-2014, with the final costs subject to a prudence determination. In addition, the stipulation specifies that January 2016 is the earliest effective date that PacifiCorp could seek an increase to customers' base rates through a general rate case. In December 2013, the OPUC approved the stipulation with the new rates effective January 2014.
In March 2013, PacifiCorp made its initial filing for the annual TAM with the OPUC for an annual decrease of $1 million based on forecasted net power costs for calendar year 2014. In October 2013, the OPUC approved the TAM, with certain adjustments and subject to net power costs updates in November 2013. In December 2013, the OPUC approved the final TAM update, resulting in an overall rate decrease of $3 million effective January 2014.
In March 2013, PacifiCorp filed its annual ECAM and RRA applications with the WPSC. The ECAM filing requested recovery of $18 million in deferred net power costs for the period January 1, 2012 to December 31, 2012 to be recovered over three years at $6 million per year pursuant to the settlement agreement in the 2012 ECAM case, which would result in a 1% increase in rates.
The RRA filing requested a $15 million reduction in the RRA surcredit, or an increase in rates of 2%, to be recovered over one year. In May 2013, the WPSC approved the requested adjustments to rates on an interim basis subject to further investigation and hearing. In August 2013, PacifiCorp filed a stipulation with the WPSC in which the parties agreed to recovery of $17 million in deferred net power costs over three years and a $15 million reduction in the RRA surcredit. In September 2013, the WPSC approved the stipulation with the new rates effective November 2013.
In December 2012, PacifiCorp submitted a compliance filing with the WUTC presenting Washington-allocated actual REC sales revenues of $17 million from January 2009 through March 2011. Also in December 2012, PacifiCorp filed for judicial review of the WUTC's August 2012 order requiring PacifiCorp to credit to its retail customers all proceeds from the sale of RECs attributable to Washington that were recorded on or after January 1, 2009, less any amounts already credited to retail customers, and the WUTC's November 2012 order denying PacifiCorp's petition for reconsideration and stay of the August 2012 order. In February 2013, PacifiCorp, WUTC staff and intervening parties submitted a joint filing with the WUTC proposing a tracking mechanism for REC sales revenues. In March 2013, the WUTC issued a notice stating that the February 2013 joint filing failed to comply with the WUTC's orders, primarily requiring PacifiCorp and other parties to clarify the period over which amortization of historical REC revenues (revenues from January 1, 2009 through April 2, 2011) would occur. In March 2013, PacifiCorp filed a response to the WUTC notice requesting that the WUTC not require amortization of historical REC revenues until after resolution of the pending judicial review of the WUTC's orders. WUTC staff and intervening parties submitted a joint response to the WUTC notice requesting the amortization of historical REC revenues begin on May 1, 2013 and be distributed as a one-time credit or amortized over one year. No action has been taken with regard to the parties' responses to the WUTC's notice. PacifiCorp is seeking judicial review of the WUTC's orders and in October 2013, filed its opening brief with the Washington State Court of Appeals. The parties' response briefs were filed in January 2014. PacifiCorp's reply brief will be filed in March 2014.
In January 2013, PacifiCorp filed a general rate case with the WUTC requesting an annual increase of $43 million, or an average price increase of 14%. The requested increase includes the impacts associated with investments in PacifiCorp's facilities since the last general rate case filing, projected increases in net power costs and revised depreciation rates. In August 2013, PacifiCorp submitted rebuttal testimony reducing the requested increase to $37 million, or an average price increase of 12%. In December 2013, the WUTC approved an annual increase of $17 million, or an average price increase of 6%, effective December 2013. In January 2014, PacifiCorp filed a petition for judicial review of the WUTC's December 2013 order, challenging the WUTC's rejection of PacifiCorp's proposed recovery of Washington's share of the costs associated with power purchase agreements with renewable energy qualified facilities located in California and Oregon and the WUTC's approval of a hypothetical capital structure for PacifiCorp.
In February 2013, PacifiCorp filed its annual ECAM application with the IPUC requesting recovery of $16 million of deferred net power costs, of which $9 million will be collected over a one-year period and the remainder collected over a three-year period.
In March 2013, the IPUC approved the new rates, which became effective April 2013.
In June 2013, PacifiCorp filed a multi-party stipulation with the IPUC that would increase base rates $2 million effective January 2014 and approve the deferral of any additional accrued removal costs and accelerated depreciation associated with the retirement of the Carbon Facility and any incremental depreciation expense associated with the revised depreciation rates reflected in the depreciation rate study, with timing of recovery to be determined in a future proceeding. Refer to "Depreciation Rate Study" for discussion of the depreciation rate impacts. In addition, the multi-party stipulation includes a resource adder to provide a means for recovery of costs associated with Lake Side 2 through the ECAM effective January 2015 for an estimated $5 million annually.
This deferral would continue until Lake Side 2 is included in base rates. The stipulation also specifies that January 2016 would be the earliest effective date that PacifiCorp could seek an increase to customers' base rates through a general rate case. In October 2013, the IPUC approved the stipulation.
In January 2014, PacifiCorp filed its annual ECAM application with the IPUC requesting recovery of $13 million of deferred net power costs, of which $7 million would be collected over a one-year period and the remainder collected over a two-year period.
If approved by the IPUC, the new rates will be effective April 2014.
In June 2013, PacifiCorp filed for a rate increase of $1 million, or 1%, pursuant to its PTAM for major capital additions to add Mona-Oquirrh to rates. In July 2013, the CPUC approved the rate increase effective July 2013.
In October 2013, PacifiCorp filed its annual PTAM attrition adjustment with the CPUC requesting an increase of $1 million, or an average price increase of 1%. In December 2013, the CPUC approved the new rates, which became effective January 2014.
Depreciation Rate Study In January 2013, PacifiCorp filed applications for depreciation rate changes with the UPSC, the OPUC, the WPSC, the WUTC and the IPUC based on PacifiCorp's most recent depreciation study. In September 2013, the OPUC issued an order approving a multi-party stipulation to implement revised depreciation rates that will result in an annual increase in depreciation expense of $30 million in Oregon. To the extent depreciation rates for other than coal-fueled generating facilities agreed to in PacifiCorp's other state jurisdictions are lower than those approved in the Oregon order, PacifiCorp is required to defer any excess revenue collected from Oregon customers until such time that customer rates are adjusted in a future proceeding. In Oregon, PacifiCorp is currently recovering costs associated with the Carbon Facility through 2015. In 2013, the UPSC, the WPSC and the IPUC approved all-party stipulations resulting in an annual increase in depreciation expense of $10 million in Utah, $10 million in Wyoming and $2 million in Idaho, which reflect recovery of the Carbon Facility through 2020, which is the end of the depreciation life previously used for setting rates in Utah, Wyoming and Idaho. In December 2013, the WUTC approved PacifiCorp's application for depreciation rate changes resulting in minimal changes to Washington's rates. The depreciation rate changes were effective January 1, 2014.
As a result of a 2007 multi-party settlement with the FERC regarding long-term shared usage, coordinated operation and maintenance, and planning of certain 500-kV transmission lines, PacifiCorp agreed to file a Federal Power Act Section 205 rate change filing for its system-wide transmission service rates no later than June 1, 2011. In May 2011, PacifiCorp filed its Federal Power Act Section 205 rate case seeking to modify its transmission and ancillary services rates and to adopt a formula transmission rate. In August 2011, the FERC issued an order accepting PacifiCorp's filing and allowing the proposed rates to become effective December 25, 2011, subject to refund. Billing using the new rates commenced in early 2012. The FERC established settlement proceedings to encourage the parties to reach agreement on final rates. In February 2013, agreement with the parties was reached and PacifiCorp filed a settlement agreement with the FERC. The settlement agreement includes modifications to the formula used to determine transmission rates. The FERC approved interim rates for real power loss factors and certain ancillary services to be effective March 1, 2013 and for a new reactive power service rate to be effective May 1, 2013. In May 2013, the FERC approved PacifiCorp's settlement agreement resolving all issues for the transmission rate case. The transmission rates will continue to be updated every June according to the formula rate process.
Environmental Laws and Regulations
PacifiCorp is subject to federal, state and local laws and regulations regarding air and water quality, RPS, emissions performance standards, climate change, coal combustion byproduct disposal, hazardous and solid waste disposal, protected species and other environmental matters that have the potential to impact PacifiCorp's current and future operations. In addition to imposing continuing compliance obligations, these laws and regulations provide regulators with the authority to levy substantial penalties for noncompliance including fines, injunctive relief and other sanctions. These laws and regulations are administered by the EPA and various state and local agencies. PacifiCorp believes it is in material compliance with all applicable laws and regulations, although many are subject to interpretation that may ultimately be resolved by the courts. Refer to "Liquidity and Capital Resources" for discussion of PacifiCorp's forecasted environmental-related capital expenditures.
Clean Air Act Regulations
The Clean Air Act is a federal law administered by the EPA that provides a framework for protecting and improving the nation's air quality and controlling sources of air emissions. The implementation of new standards is generally outlined in SIPs, which are a collection of regulations, programs and policies to be followed. SIPs vary by state and are subject to public hearings and EPA approval. Some states may adopt additional or more stringent requirements than those implemented by the EPA. The major Clean Air Act programs most directly affecting PacifiCorp's operations are described below.
National Ambient Air Quality Standards
Under the authority of the Clean Air Act, the EPA sets minimum national ambient air quality standards for six principal pollutants, consisting of carbon monoxide, lead, nitrogen oxides, particulate matter, ozone and sulfur dioxide, considered harmful to public health and the environment. Areas that achieve the standards, as determined by ambient air quality monitoring, are characterized as being in attainment, while those that fail to meet the standards are designated as being nonattainment areas. Generally, sources of emissions in a nonattainment area that are determined to contribute to the nonattainment are required to reduce emissions. Most air quality standards require measurement over a defined period of time to determine the average concentration of the pollutant present.
In December 2009, the EPA designated the Utah counties of Davis and Salt Lake, as well as portions of Box Elder, Cache, Tooele, Utah and Weber counties, to be in nonattainment of the fine particulate matter standard. While this designation has the potential to impact PacifiCorp's Lake Side and Gadsby generating facilities, the Utah SIP, as submitted to the EPA, did not impose significant new requirements on PacifiCorp's impacted generating facilities, nor did the EPA's comments on the Utah SIP identify requirements for PacifiCorp's existing generating facilities that would have a material impact on PacifiCorp's consolidated financial results.