$IDA
IDACORP INC

2012 Q4 Form 10-Q Financial Statement

#000105787712000154 Filed on November 01, 2012

View on sec.gov

Income Statement

Concept 2012 Q4 2012 Q3 2011 Q3
Revenue $250.8M $334.0M $309.6M
YoY Change 8.76% 7.88% 0.09%
Cost Of Revenue $57.80M $69.10M $66.10M
YoY Change 61.9% 4.54% 6.27%
Gross Profit $193.0M $264.9M $243.5M
YoY Change -0.97% 8.79% -1.5%
Gross Profit Margin 76.95% 79.31% 78.64%
Selling, General & Admin
YoY Change
% of Gross Profit
Research & Development
YoY Change
% of Gross Profit
Depreciation & Amortization $32.70M $33.00M $31.20M
YoY Change 1.87% 5.77% 2.97%
% of Gross Profit 16.94% 12.46% 12.81%
Operating Expenses $168.5M $224.7M $238.2M
YoY Change -13.77% -5.66% 8.11%
Operating Profit $24.50M $109.3M $71.39M
YoY Change -5000.0% 53.06% -19.78%
Interest Expense $1.800M $19.40M $17.45M
YoY Change -111.69% 11.21% -6.93%
% of Operating Profit 7.35% 17.75% 24.44%
Other Income/Expense, Net $5.300M $1.453M $6.010M
YoY Change -80.94% -75.82% 69.3%
Pretax Income $31.70M $96.17M $62.04M
YoY Change 161.98% 55.01% -19.68%
Income Tax $11.00M $3.910M -$45.37M
% Of Pretax Income 34.7% 4.07% -73.13%
Net Earnings $20.70M $92.07M $107.1M
YoY Change 68.29% -14.01% 59.48%
Net Earnings / Revenue 8.25% 27.56% 34.58%
Basic Earnings Per Share $1.84 $2.16
Diluted Earnings Per Share $413.2K $1.84 $2.16
COMMON SHARES
Basic Shares Outstanding 50.16M shares 49.97M shares 49.52M shares
Diluted Shares Outstanding 50.08M shares 49.62M shares

Balance Sheet

Concept 2012 Q4 2012 Q3 2011 Q3
SHORT-TERM ASSETS
Cash & Short-Term Investments $26.50M $20.20M $31.30M
YoY Change -4.68% -35.46% -83.11%
Cash & Equivalents $26.53M $20.23M $31.31M
Short-Term Investments
Other Short-Term Assets $4.948M $5.628M $4.507M
YoY Change 7.43% 24.87% -95.2%
Inventory $93.40M $101.2M $96.30M
Prepaid Expenses $12.82M $13.01M $11.25M
Receivables $66.11M $80.15M $75.54M
Other Receivables $25.40M $21.10M $10.70M
Total Short-Term Assets $367.3M $366.0M $309.3M
YoY Change 18.1% 18.35% -33.91%
LONG-TERM ASSETS
Property, Plant & Equipment $3.536B $3.507B $3.356B
YoY Change 3.8% 4.49% 8.71%
Goodwill
YoY Change
Intangibles
YoY Change
Long-Term Investments $11.60M $190.7M $192.3M
YoY Change 7.55% -0.83% -3.32%
Other Assets $49.26M $48.33M $39.48M
YoY Change 22.08% 22.41% -95.03%
Total Long-Term Assets $4.924B $4.842B $4.518B
YoY Change 6.71% 7.17% 10.01%
TOTAL ASSETS
Total Short-Term Assets $367.3M $366.0M $309.3M
Total Long-Term Assets $4.924B $4.842B $4.518B
Total Assets $5.291B $5.208B $4.827B
YoY Change 7.43% 7.89% 5.52%
SHORT-TERM LIABILITIES
YoY Change
Accounts Payable $90.17M $93.41M $90.09M
YoY Change 10.27% 3.69% 11.36%
Accrued Expenses $64.70M $23.90M $23.40M
YoY Change 5.2% 2.14% -11.03%
Deferred Revenue
YoY Change
Short-Term Debt $69.70M $51.40M $51.50M
YoY Change 28.6% -0.19% 1187.5%
Long-Term Debt Due $71.06M $1.064M $1.667M
YoY Change -29.68% -36.17% -98.68%
Total Short-Term Liabilities $351.3M $268.3M $254.5M
YoY Change -4.6% 5.42% -33.47%
LONG-TERM LIABILITIES
Long-Term Debt $1.467B $1.537B $1.487B
YoY Change 5.7% 3.3% -0.05%
Other Long-Term Liabilities $65.23M $63.82M $341.4M
YoY Change -13.95% -81.31% -43.06%
Total Long-Term Liabilities $1.727B $1.629B $1.424B
YoY Change 11.94% 14.36% -31.79%
TOTAL LIABILITIES
Total Short-Term Liabilities $351.3M $268.3M $254.5M
Total Long-Term Liabilities $1.727B $1.629B $1.424B
Total Liabilities $2.079B $1.897B $1.679B
YoY Change 8.75% 13.0% -45.09%
SHAREHOLDERS EQUITY
Retained Earnings $924.0M $943.6M $846.9M
YoY Change 12.73% 11.42%
Common Stock $834.9M $835.7M $820.3M
YoY Change 0.79% 1.89%
Preferred Stock
YoY Change
Treasury Stock (at cost) $21.00K $21.00K $29.00K
YoY Change -27.59% -27.59%
Treasury Stock Shares 1.817K shares 1.513K shares 11.68K shares
Shareholders Equity $1.742B $1.770B $1.657B
YoY Change
Total Liabilities & Shareholders Equity $5.291B $5.208B $4.827B
YoY Change 6.67% 7.89% 5.52%

Cashflow Statement

Concept 2012 Q4 2012 Q3 2011 Q3
OPERATING ACTIVITIES
Net Income $20.70M $92.07M $107.1M
YoY Change 68.29% -14.01% 59.48%
Depreciation, Depletion And Amortization $32.70M $33.00M $31.20M
YoY Change 1.87% 5.77% 2.97%
Cash From Operating Activities $67.80M $98.50M $78.00M
YoY Change -9.96% 26.28% 120.96%
INVESTING ACTIVITIES
Capital Expenditures -$52.00M -$64.70M -$81.00M
YoY Change -26.55% -20.12% -2.06%
Acquisitions
YoY Change
Other Investing Activities -$6.600M $2.100M $3.400M
YoY Change 450.0% -38.24% 277.78%
Cash From Investing Activities -$58.50M -$62.70M -$77.40M
YoY Change -18.86% -18.99% -5.49%
FINANCING ACTIVITIES
Cash Dividend Paid
YoY Change
Common Stock Issuance & Retirement, Net
YoY Change
Debt Paid & Issued, Net
YoY Change
Cash From Financing Activities -2.900M -30.00M -27.50M
YoY Change -57.35% 9.09% -113.58%
NET CHANGE
Cash From Operating Activities 67.80M 98.50M 78.00M
Cash From Investing Activities -58.50M -62.70M -77.40M
Cash From Financing Activities -2.900M -30.00M -27.50M
Net Change In Cash 6.400M 5.800M -26.90M
YoY Change -277.78% -121.56% -117.25%
FREE CASH FLOW
Cash From Operating Activities $67.80M $98.50M $78.00M
Capital Expenditures -$52.00M -$64.70M -$81.00M
Free Cash Flow $119.8M $163.2M $159.0M
YoY Change -18.0% 2.64% 34.75%

Facts In Submission

Frame Concept Type Concept / XBRL Key Value Unit
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us-gaap Comparability Of Prior Year Financial Data
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">In the opinion of management of IDACORP and Idaho Power, the accompanying unaudited condensed consolidated financial statements contain all adjustments necessary to present fairly each company's consolidated financial position as of </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">September&#160;30, 2012</font><font style="font-family:inherit;font-size:10pt;">, consolidated results of operations for the </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">three and nine months ended</font><font style="font-family:inherit;font-size:10pt;"> </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">September&#160;30, 2012</font><font style="font-family:inherit;font-size:10pt;"> and </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">2011</font><font style="font-family:inherit;font-size:10pt;">, and consolidated cash flows for the </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">nine months ended</font><font style="font-family:inherit;font-size:10pt;"> </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">September&#160;30, 2012</font><font style="font-family:inherit;font-size:10pt;"> and </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">2011</font><font style="font-family:inherit;font-size:10pt;">.&#160; These adjustments are of a normal and recurring nature.&#160; These financial statements do not contain the complete detail or footnote disclosure concerning accounting policies and other matters that would be included in full-year financial statements and should be read in conjunction with the audited consolidated financial statements included in IDACORP&#8217;s and Idaho Power&#8217;s Annual Report on Form 10-K for the year ended </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">December&#160;31, 2011</font><font style="font-family:inherit;font-size:10pt;">.&#160; The results of operations for the interim period are not necessarily indicative of the results to be expected for the full year. A change in management's estimates or assumptions could have a material impact on IDACORP's or Idaho Power's respective financial condition and results of operations during the period in which such change occurred.</font></div></div>
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">All commodity-related derivative instruments not meeting the normal purchases and normal sales exception to derivative accounting are recorded at fair value on the balance sheet.&#160; Because of Idaho Power's PCA mechanisms, unrealized gains and losses associated with the changes in fair value of these derivative instruments are recorded as regulatory assets or liabilities. With the exception of forward contracts for the purchase of natural gas for use at Idaho Power&#8217;s natural gas generation facilities, Idaho Power&#8217;s physical forward contracts qualify for the normal purchases and normal sales exception.</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">All of Idaho Power's derivative instruments have been entered into for the purpose of economically hedging forecasted purchases and sales, though none of these instruments have been designated as cash flow hedges under derivative accounting guidance. Idaho Power offsets fair value amounts recognized on its balance sheet related to derivative instruments executed with the same counterparty under the same master netting agreement.</font></div></div>
us-gaap Derivatives Reporting Of Derivative Activity
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Settlement gains and losses on electricity swap contracts are recorded on the income statement in off-system sales or purchased power depending on the forecasted position being economically hedged by the derivative contract.&#160; Settlement gains and losses on both financial and physical contracts for natural gas are reflected in fuel expense.&#160; Settlement gains and losses on diesel derivatives are recorded in other operations and maintenance expense.</font></div></div>
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">CONTINGENCIES</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">&#160;</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">IDACORP and Idaho Power have in the past and expect in the future to become involved in various claims, controversies, disputes, and other contingent matters, including the items described in this Note 9.&#160; Some of these claims, controversies, disputes, and other contingent matters involve litigation and regulatory or other contested proceedings.&#160; IDACORP and Idaho Power intend to vigorously protect and defend their interests and pursue their rights.&#160; However, the ultimate resolution and outcome of litigation and regulatory proceedings is inherently difficult to determine, particularly where (a)&#160;the remedies or penalties sought are indeterminate, (b)&#160;the proceedings are in the early stages or the substantive issues have not been well developed, or (c)&#160;the matters involve complex or novel legal theories or a large number of parties. In accordance with applicable accounting guidance, IDACORP and Idaho Power, as applicable, establish an accrual for legal proceedings when those matters proceed to a stage where they present loss contingencies that are both probable and reasonably estimable. In such cases, there may be a possible exposure to loss in excess of any amounts accrued. IDACORP and Idaho Power monitor those matters for developments that could affect the likelihood of a loss and the accrued amount, if any, thereof, and adjust the amount as appropriate. If the loss contingency at issue is not both probable and reasonably estimable, IDACORP and Idaho Power do not establish an accrual and the matter will continue to be monitored for any developments that would make the loss contingency both probable and reasonably estimable. As of the date of this report, IDACORP's and Idaho Power's accruals for loss contingencies are not material to their financial statements as a whole; however, future accruals could be material in a given period. IDACORP's and Idaho Power's determination is based on currently available information, and estimates presented in financial statements and other financial disclosures involve significant judgment and may be subject to significant uncertainty. As available information changes, the matters for which IDACORP and Idaho Power are able to estimate the loss may change, and the estimates themselves may change.</font></div><div style="line-height:120%;text-align:left;padding-left:96px;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">For certain of those matters described in this report for which IDACORP or Idaho Power have determined a loss contingency may, in the future, be at least reasonably possible, IDACORP and Idaho Power have stated that they are unable to estimate the possible loss or a range of possible loss that may result from those matters. Depending on a range of factors, such as the complexity of the facts, the unique nature of the legal theories, the pace of discovery, the timing of decisions of the court or arbiter, and the adverse party's willingness to negotiate towards a resolution, it may be months or years after the filing of a case or commencement of a proceeding before IDACORP or Idaho Power may be in a position to estimate the possible loss or range of possible loss for those matters. For matters that affect Idaho Power&#8217;s operations, Idaho Power intends to seek, to the extent permissible and appropriate, recovery of incurred costs through the ratemaking process.</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">Pacific Northwest Refund Proceedings</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">On July 25, 2001, the FERC issued an order establishing a proceeding to determine whether there may have been unjust and unreasonable charges for spot market sales in the Pacific Northwest during the period December 25, 2000 through June 20, 2001, because the spot market in the Pacific Northwest was affected by the dysfunction in the California market.&#160; During that period, Idaho Power or IE both sold and purchased electricity in the Pacific Northwest. In 2003, the FERC terminated the proceeding and declined to order refunds, but in 2007 the Ninth Circuit issued an opinion, in </font><font style="font-family:inherit;font-size:10pt;font-style:italic;">Port of Seattle, Washington v. FERC</font><font style="font-family:inherit;font-size:10pt;">, remanding to the FERC the orders that declined to require refunds.&#160; The Ninth Circuit's opinion instructed the FERC to consider whether evidence of market manipulation would have altered the agency's conclusions about refunds and directed the FERC to include sales originating in the Pacific Northwest to the California Department of Water Resources (CDWR) in the scope of the proceeding.&#160; The Ninth Circuit officially returned the case to the FERC on April 16, 2009.&#160; </font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">On October 3, 2011, the FERC issued its order on remand. The FERC ordered that the record be re-opened to permit parties seeking refunds to submit seller-specific evidence in support of their claims for sales made during the period confined to December 25, 2000 through June 20, 2001. The seller-specific claims must show that a seller engaged in unlawful market activity with a causal connection to have directly affected the negotiation of the specific contract or contracts to which the seller was a party. IE and Idaho Power understand the order to provide that neither claims of general dysfunction in the California markets nor in the Pacific Northwest market will be sufficient to support claims. While directing a trial-type hearing, the FERC also directed that the hearings be held in abeyance so that the matter may be presented to a settlement judge. In an order issued on November 23, 2011, the FERC's Chief Administrative Law Judge memorialized certain settlement procedures. IE and Idaho Power had reached a settlement with the California Parties in 2006 that disposed of their claims in the Pacific Northwest refund proceeding, as well as in California refund cases. </font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">During the first three quarters of 2012, Idaho Power and each of the only two known direct claimants in the Pacific Northwest refund proceedings negotiated and entered into settlement agreements. The FERC approved the first settlement subject to conditions, which Idaho Power and IE have requested be removed on rehearing. Idaho Power and IE do not know when or how the FERC will rule on that request. The FERC approved the second settlement without conditions on October 19, 2012. The aggregate amount of the settlements was not material to the companies' financial statements. By the time established for the filing of testimony in the proceedings no other party presented any direct claims against Idaho Power or IE. While disposing of direct claims from both known claimants, the settlements and associated FERC orders did not eliminate the potential for so-called "ripple claims," which involve potential claims for refunds from an upstream seller of power based on a finding that its downstream buyer was liable for refunds as a seller of power during the relevant period. However, in its order approving one of Idaho Power's settlements, the FERC characterized the potential for such claims as "speculative." Based on its settlement of all known direct claims and the FERC's assessment of the potential for ripple claims as speculative, Idaho Power and IE have no remaining amount accrued for financial statement purposes relating to the Pacific Northwest refund proceedings. However, to the extent the availability of any ripple claims materializes, Idaho Power and IE will continue to vigorously defend their positions in the proceedings.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">Water Rights - Snake River Basin Adjudication</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Idaho Power holds water rights, acquired under applicable state law, for its hydroelectric projects.&#160; In addition, Idaho Power holds water rights for domestic, irrigation, commercial, and other necessary purposes related to project lands and other holdings within the states of Idaho and Oregon.&#160; Idaho Power's water rights for power generation are, to varying degrees, subordinated to future upstream appropriations for irrigation and other authorized consumptive uses.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Over time, increased irrigation development and other consumptive uses within the Snake River watershed led to a reduction in flows of the Snake River.&#160; In the late 1970s and early 1980s these reduced flows resulted in a conflict between the exercise of Idaho Power's water rights at certain hydroelectric projects on the Snake River and upstream consumptive diversions.&#160; The Swan Falls Agreement, signed by Idaho Power and the State of Idaho on October 25, 1984, resolved the conflict and provided a level of protection for Idaho Power's hydropower water rights at specified projects on the Snake River through the establishment of minimum stream flows and an administrative process governing future development of water rights that may affect those minimum stream flows.&#160; In 1987, Congress enacted legislation directing the FERC to issue an order approving the Swan Falls settlement together with a finding that the agreement was neither inconsistent with the terms and conditions of Idaho Power's project licenses nor the Federal Power Act.&#160; The FERC entered an order implementing the legislation in March 1988.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">The Swan Falls Agreement provided that the resolution and recognition of Idaho Power's water rights together with the State Water Plan provided a sound comprehensive plan for management of the Snake River watershed.&#160; The Swan Falls Agreement also recognized, however, that in order to effectively manage the waters of the Snake River basin, a general adjudication to determine the nature, extent, and priority of the rights of all water uses in the basin was necessary.&#160; Consistent with that recognition, in 1987 the State of Idaho initiated the Snake River Basin Adjudication (SRBA), and pursuant to the commencement order issued by the SRBA court that same year, all claimants to water rights within the basin were required to file water rights claims in the SRBA.&#160; Idaho Power has filed claims to its water rights and has been actively participating in the SRBA since its commencement.&#160; Questions concerning the effect of the Swan Falls Agreement on Idaho Power's water rights claims, including the nature and extent of the subordination of Idaho Power's rights to upstream uses, resulted in the filing of litigation in the SRBA in 2007 between Idaho Power and the State of Idaho.&#160; This litigation was resolved by the Framework Reaffirming the Swan Falls Settlement (Framework) signed by Idaho Power and the State of Idaho on March 25, 2009.&#160; In that Framework, the parties acknowledged that the effective management of Idaho's water resources remains critical to the public interest of the State of Idaho by sustaining economic growth, maintaining reasonable electric rates, protecting and preserving existing water rights, and protecting water quality and environmental values.&#160; The Framework further provided that the State of Idaho and Idaho Power would cooperate in exploring approaches to resolve issues of mutual concern relating to the management of Idaho's water resources.&#160; Idaho Power continues to work with the State of Idaho and other interested parties on these issues.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">One such issue involves the management of the Eastern Snake Plain Aquifer (ESPA), a large underground aquifer in southeastern Idaho that is hydrologically connected to the Snake River.&#160; House Concurrent Resolution No. 28, adopted by the Idaho Legislature in 2007, directed the Idaho Water Resource Board to pursue the development of a comprehensive management plan for the ESPA, to include measures that would enhance aquifer levels, springs, and river flows on the eastern Snake River plain to the benefit of both agricultural development and hydropower generation.&#160; In May of 2007, the Idaho Water Resource Board appointed an advisory committee, charged with the responsibility of developing a management plan for the ESPA.&#160; Idaho Power was a member of that committee.&#160; In January 2009, the Idaho Water Resource Board, based on the committee's recommendations, adopted a Comprehensive Aquifer Management Plan (CAMP) for the ESPA.&#160; The Idaho Legislature approved the CAMP that same year.&#160; Idaho Power is a member of the CAMP Implementation Committee and continues to work with the Idaho Water Resource Board, other stakeholders, and the Idaho Legislature in exploring opportunities for implementation of the CAMP management plan.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">Idaho Power also continues its active participation in the SRBA in seeking to ensure that its water rights are protected and that the operation of its hydroelectric projects is not adversely impacted.&#160; While Idaho Power cannot predict the outcome, Idaho Power does not anticipate any material modification of its water rights as a result of the SRBA process.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;">Other Proceedings</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">&#160;</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">IDACORP and Idaho Power are parties to legal claims and legal and regulatory actions and proceedings in the ordinary course of business that are in addition to those discussed above and, as noted above, records an accrual for associated loss contingencies when they are probable and reasonably estimable.&#160; However, as of the date of this report the companies believe that resolution of those matters will not have a material adverse effect on their consolidated financial statements. Idaho Power is also actively monitoring various environmental regulations that may have a significant impact on its future operations. Given uncertainties regarding the outcome, timing, and compliance plans for these environmental matters, Idaho Power is unable to determine the financial impact of these regulations but does believe that future capital investment for infrastructure and modifications to its electric generating facilities to comply with these regulations could be significant.</font></div></div>
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">IDACORP is a holding company formed in 1998 whose principal operating subsidiary is Idaho Power.&#160; Idaho Power is an electric utility with a service territory covering approximately </font><font style="font-family:inherit;font-size:10pt;color:#000000;text-decoration:none;">24,000</font><font style="font-family:inherit;font-size:10pt;"> square miles in southern Idaho and eastern Oregon.&#160; Idaho Power's utility operations are regulated primarily by the Federal Energy Regulatory Commission (FERC) and the state regulatory commissions of Idaho and Oregon.&#160; Idaho Power is the parent of Idaho Energy Resources Co. (IERCo), a joint venturer in Bridger Coal Company (BCC), which mines and supplies coal to the Jim Bridger generating plant owned in part by Idaho Power.</font></div><div style="line-height:120%;font-size:12pt;"><font style="font-family:inherit;font-size:12pt;">&#160;</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">IDACORP&#8217;s other subsidiaries include IDACORP Financial Services, Inc. (IFS), an investor in affordable housing and other real estate investments; Ida-West Energy Company (Ida-West), an operator of small hydroelectric generation projects that satisfy the requirements of the Public Utility Regulatory Policies Act of 1978 (PURPA); and IDACORP Energy (IE), a marketer of energy commodities, which wound down operations in 2003.</font></div><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;font-weight:bold;"></font></div></div>
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us-gaap Proceeds From Issuance Of Common Stock
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us-gaap Proceeds From Sale Of Intangible Assets
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us-gaap Public Utilities Allowance For Funds Used During Construction Additions
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us-gaap Public Utilities Allowance For Funds Used During Construction Additions
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CY2011Q4 us-gaap Public Utilities Property Plant And Equipment Construction Work In Progress
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CY2012Q3 us-gaap Ratio Of Indebtedness To Net Capital1
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us-gaap Regulatory Assets And Liabilities Recognition Criteria
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">IDACORP's and Idaho Power's financial statements reflect the effects of the different ratemaking principles followed by the jurisdictions regulating Idaho Power.&#160; The application of accounting principles related to regulated operations sometimes results in Idaho Power recording expenses and revenues in a different period than when an unregulated enterprise would otherwise record expenses and revenues.&#160; In these instances, the amounts are deferred as regulatory assets or regulatory liabilities on the balance sheet and recorded on the income statement when recovered or returned in rates.&#160; Additionally, regulators can impose regulatory liabilities upon a regulated company for amounts previously collected from customers and for amounts that are expected to be refunded to customers.</font></div></div>
CY2012Q3 us-gaap Regulatory Assets Current
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953068000 USD
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101064000 USD
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840916000 USD
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RetainedEarningsAccumulatedDeficit
943575000 USD
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SalesRevenueNet
309630000 USD
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SalesRevenueNet
334019000 USD
us-gaap Sales Revenue Net
SalesRevenueNet
829862000 USD
us-gaap Sales Revenue Net
SalesRevenueNet
796107000 USD
CY2012Q3 us-gaap Share Based Compensation Arrangement By Share Based Payment Award Options Outstanding Number
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16706 shares
CY2011Q4 us-gaap Short Term Borrowings
ShortTermBorrowings
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CY2012Q3 us-gaap Short Term Borrowings
ShortTermBorrowings
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0.0047
CY2012Q3 us-gaap Short Term Debt Weighted Average Interest Rate
ShortTermDebtWeightedAverageInterestRate
0.0047
us-gaap Stock Issued During Period Shares New Issues
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StockholdersEquity
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TaxesExcludingIncomeAndExciseTaxes
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CY2011Q3 us-gaap Taxes Excluding Income And Excise Taxes
TaxesExcludingIncomeAndExciseTaxes
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CY2012Q3 us-gaap Trading Securities Fair Value Disclosure
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CY2011Q4 us-gaap Trading Securities Fair Value Disclosure
TradingSecuritiesFairValueDisclosure
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CY2012Q3 us-gaap Treasury Stock Shares
TreasuryStockShares
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CY2011Q4 us-gaap Treasury Stock Shares
TreasuryStockShares
12177 shares
CY2012Q3 us-gaap Treasury Stock Value
TreasuryStockValue
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CY2011Q4 us-gaap Treasury Stock Value
TreasuryStockValue
29000 USD
us-gaap Use Of Estimates
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<div style="font-family:Times New Roman;font-size:10pt;"><div style="line-height:120%;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;">The preparation of financial statements in accordance with generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosures of contingent liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods.&#160; Actual results experienced could differ materially from those estimates.</font></div><div style="line-height:120%;text-align:left;font-size:10pt;"><font style="font-family:inherit;font-size:10pt;"><br clear="none"/></font></div></div>
us-gaap Utilities Operating Expense
UtilitiesOperatingExpense
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UtilitiesOperatingExpense
237630000 USD
CY2012Q3 us-gaap Utilities Operating Expense
UtilitiesOperatingExpense
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us-gaap Utilities Operating Expense
UtilitiesOperatingExpense
614413000 USD
us-gaap Utilities Operating Expense Depreciation And Amortization
UtilitiesOperatingExpenseDepreciationAndAmortization
89272000 USD
CY2011Q3 us-gaap Utilities Operating Expense Depreciation And Amortization
UtilitiesOperatingExpenseDepreciationAndAmortization
30115000 USD
CY2012Q3 us-gaap Utilities Operating Expense Depreciation And Amortization
UtilitiesOperatingExpenseDepreciationAndAmortization
31607000 USD
us-gaap Utilities Operating Expense Depreciation And Amortization
UtilitiesOperatingExpenseDepreciationAndAmortization
92028000 USD
CY2011Q3 us-gaap Utilities Operating Expense Fuel Used
UtilitiesOperatingExpenseFuelUsed
41195000 USD
CY2012Q3 us-gaap Utilities Operating Expense Fuel Used
UtilitiesOperatingExpenseFuelUsed
55978000 USD
us-gaap Utilities Operating Expense Fuel Used
UtilitiesOperatingExpenseFuelUsed
110014000 USD
us-gaap Utilities Operating Expense Fuel Used
UtilitiesOperatingExpenseFuelUsed
90801000 USD
us-gaap Utilities Operating Expense Maintenance And Operations
UtilitiesOperatingExpenseMaintenanceAndOperations
240695000 USD
CY2012Q3 us-gaap Utilities Operating Expense Maintenance And Operations
UtilitiesOperatingExpenseMaintenanceAndOperations
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us-gaap Utilities Operating Expense Maintenance And Operations
UtilitiesOperatingExpenseMaintenanceAndOperations
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CY2011Q3 us-gaap Utilities Operating Expense Maintenance And Operations
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us-gaap Utilities Operating Expense Purchased Power
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us-gaap Utilities Operating Expense Purchased Power
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CY2011Q3 us-gaap Utilities Operating Expense Purchased Power
UtilitiesOperatingExpensePurchasedPower
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us-gaap Weighted Average Number Of Diluted Shares Outstanding
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CY2012Q3 us-gaap Weighted Average Number Of Diluted Shares Outstanding
WeightedAverageNumberOfDilutedSharesOutstanding
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us-gaap Weighted Average Number Of Diluted Shares Outstanding
WeightedAverageNumberOfDilutedSharesOutstanding
49990000 shares
CY2011Q3 us-gaap Weighted Average Number Of Diluted Shares Outstanding
WeightedAverageNumberOfDilutedSharesOutstanding
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us-gaap Weighted Average Number Of Shares Outstanding Basic
WeightedAverageNumberOfSharesOutstandingBasic
49411000 shares
CY2011Q3 us-gaap Weighted Average Number Of Shares Outstanding Basic
WeightedAverageNumberOfSharesOutstandingBasic
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dei Current Fiscal Year End Date
CurrentFiscalYearEndDate
--12-31
CY2012Q3 us-gaap Weighted Average Number Of Shares Outstanding Basic
WeightedAverageNumberOfSharesOutstandingBasic
49966000 shares
us-gaap Weighted Average Number Of Shares Outstanding Basic
WeightedAverageNumberOfSharesOutstandingBasic
49918000 shares
CY2012Q3 ida Accrued Unbilled Revenue
AccruedUnbilledRevenue
49872000 USD
CY2011Q4 ida Accrued Unbilled Revenue
AccruedUnbilledRevenue
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ida Defined Benefit Plan Net Periodic Benefit Cost After Regulatory Adjustments
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28689000 USD
ida Defined Benefit Plan Net Periodic Benefit Cost After Regulatory Adjustments
DefinedBenefitPlanNetPeriodicBenefitCostAfterRegulatoryAdjustments
17279000 USD
CY2012Q3 ida Dividend Distribution Restriction Amount
DividendDistributionRestrictionAmount
913000000 USD
ida Energy Efficiency Programs
EnergyEfficiencyPrograms
31011000 USD
CY2012Q3 ida Energy Efficiency Programs
EnergyEfficiencyPrograms
8410000 USD
CY2011Q3 ida Energy Efficiency Programs
EnergyEfficiencyPrograms
18504000 USD
ida Energy Efficiency Programs
EnergyEfficiencyPrograms
20971000 USD
CY2012Q3 ida Extension Period Of Credit Agreements
ExtensionPeriodOfCreditAgreements
P1Y
ida Increase Decrease In Accounts Receivable And Prepayments
IncreaseDecreaseInAccountsReceivableAndPrepayments
-12121000 USD
ida Increase Decrease In Accounts Receivable And Prepayments
IncreaseDecreaseInAccountsReceivableAndPrepayments
-16099000 USD
ida Incremental Common Shares Attributable To Restricted Stock
IncrementalCommonSharesAttributableToRestrictedStock
67000 shares
ida Incremental Common Shares Attributable To Restricted Stock
IncrementalCommonSharesAttributableToRestrictedStock
73000 shares
CY2012Q3 ida Incremental Common Shares Attributable To Restricted Stock
IncrementalCommonSharesAttributableToRestrictedStock
110000 shares
CY2011Q3 ida Incremental Common Shares Attributable To Restricted Stock
IncrementalCommonSharesAttributableToRestrictedStock
90000 shares
CY2012Q3 ida Maximum Leverage Ratio Requirement
MaximumLeverageRatioRequirement
0.65
CY2012Q3 ida Number Of Credit Agreement Extensions
NumberOfCreditAgreementExtensions
2 credit_agreement_extensions
CY2012Q3 ida Other Electric Utility Revenue
OtherElectricUtilityRevenue
21865000 USD
CY2011Q3 ida Other Electric Utility Revenue
OtherElectricUtilityRevenue
31649000 USD
ida Other Electric Utility Revenue
OtherElectricUtilityRevenue
58810000 USD
ida Other Electric Utility Revenue
OtherElectricUtilityRevenue
68502000 USD
ida Other Interest Expense Net Of Afudc
OtherInterestExpenseNetOfAfudc
-5209000 USD
CY2011Q3 ida Other Interest Expense Net Of Afudc
OtherInterestExpenseNetOfAfudc
-2053000 USD
ida Other Interest Expense Net Of Afudc
OtherInterestExpenseNetOfAfudc
-5876000 USD
CY2012Q3 ida Other Interest Expense Net Of Afudc
OtherInterestExpenseNetOfAfudc
-269000 USD
ida Power Cost Adjustment
PowerCostAdjustment
36618000 USD
CY2011Q3 ida Power Cost Adjustment
PowerCostAdjustment
-10189000 USD
CY2012Q3 ida Power Cost Adjustment
PowerCostAdjustment
-42871000 USD
ida Power Cost Adjustment
PowerCostAdjustment
-37074000 USD
CY2012Q3 ida Remaining Shares Available Under Current Sales Agency Agreement
RemainingSharesAvailableUnderCurrentSalesAgencyAgreement
3000000 shares
dei Amendment Flag
AmendmentFlag
false
dei Document Fiscal Period Focus
DocumentFiscalPeriodFocus
Q3
dei Document Fiscal Year Focus
DocumentFiscalYearFocus
2012
dei Document Period End Date
DocumentPeriodEndDate
2012-09-30
dei Document Type
DocumentType
10-Q
dei Entity Central Index Key
EntityCentralIndexKey
0001057877
CY2012Q4 dei Entity Common Stock Shares Outstanding
EntityCommonStockSharesOutstanding
50156973 shares
dei Entity Filer Category
EntityFilerCategory
Large Accelerated Filer
dei Entity Registrant Name
EntityRegistrantName
IDACORP INC.
dei Trading Symbol
TradingSymbol
IDA

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