Regulatory Matters	12 Months Ended
Dec. 31, 2014
Regulated Operations [Abstract]
Regulatory Matters	Regulatory Matters Hydro Transaction See Note 3 - Hydro Transaction. South Dakota Electric Rate Filing In December 2014, we filed a request with the SDPUC for an annual increase to electric rates totaling approximately $26.5 million . Our request was based on a return on equity of 10%, a capital structure consisting of 46% debt and 54% equity and rate base of $447.4 million. The SDPUC has not yet issued a procedural schedule and we do not anticipate implementing new rates until at least July 2015. We have not filed an electric rate case in South Dakota since 1980. This filing requests recovery of capital expenditures related to improvements to our transmission and distribution delivery systems over time, the Aberdeen Generating Station, and additions (including estimated 2015 additions) to comply with additional emission reduction requirements at two of our jointly owned electric generating units that serve our South Dakota customers. Dave Gates Generating Station at Mill Creek (DGGS) FERC Filing - In April 2014, the FERC issued an order affirming a FERC Administrative Law Judge's (ALJ) initial decision in September 2012, regarding cost allocation at DGGS between retail and wholesale customers. This decision concluded we should allocate only a fraction of the costs we believe, based on facts and the law, should be allocated to FERC jurisdictional customers. We have been recognizing revenue consistent with the ALJ's initial decision. As of December 31, 2014, we have cumulative deferred revenue of approximately $27.3 million, which is subject to refund and recorded within current regulatory liabilities in the Consolidated Balance Sheets. The order included a requirement to issue customer refunds (included in deferred revenue) within 30 days. In May 2014, we filed a request for rehearing, which remains pending. In our request for rehearing, we have argued that no refunds are due even if the cost allocation method is modified prospectively. There is no deadline by which FERC must act on our rehearing petition, but it could occur during the first quarter of 2015. Customer refunds, if any, will not be due until 30 days after a FERC order on rehearing. If unsuccessful on rehearing, we may appeal to a United States Circuit Court of Appeals. The time line for any such appeal could, depending on when the FERC issues a rehearing order, extend into 2016 or beyond. The FERC order was assessed as a triggering event as to whether an impairment charge should be recorded with respect to DGGS. We continue to evaluate options to use DGGS in combination with other generation resources, including our newly acquired hydro facilities, to ensure cost recovery. Any alternative use of DGGS would be subject to regulatory approval and we cannot provide assurance of such approval. We do not believe an impairment loss is probable at this time; however, we will continue to evaluate recovery of this asset in the future as facts and circumstances change. Montana Electric Tracker Filings Each year we submit an electric tracker filing for recovery of supply costs for the 12-month period ended June 30 and for the projected supply costs for the next 12-month period. The MPSC reviews such filings and makes its cost recovery determination based on whether or not our electric supply procurement activities were prudent. In May 2014, we filed our annual electric supply tracker filing for the 2013/2014 tracker period. The MPSC approved this filing on an interim basis and consolidated it with our pending electric supply filing for the 2012/2013 tracker period. Our 2014 electric tracker filing includes market purchases made between July 2013 and January 2014 for replacement power during an outage at Colstrip Unit 4. Inclusion of these costs in the tracker filing is consistent with the treatment of replacement power during previous outages. During a June 2014 MPSC work session, approximately $11 million of these incremental market purchases related to the Colstrip Unit 4 outage were identified by the MPSC for additional prudency review. In July 2014, the Montana Environmental Information Center and Sierra Club filed a petition to intervene in the consolidated 2013 and 2014 tracker dockets to challenge our recovery of costs associated with Colstrip Unit 4, particularly the costs incurred as a result of the outage, as imprudent. A procedural schedule has not yet been established for the consolidated electric supply tracker docket. Montana Lost Revenue Adjustment Mechanism Demand-side management (DSM) lowers our sales to customers. In 2005, the MPSC created a Lost Revenue Adjustment Mechanism (LRAM) by which we collect revenue that we would have collected without any DSM. In an order issued in October 2013, which was related to our 2011 / 2012 electric supply tracker, the MPSC required us to lower our LRAM revenue recovery and imposed a new burden of proof on us for future LRAM recovery. We appealed the October 2013 order to Montana District Court. The appeal is pending. The District Court approved a partial settlement of our appeal, in which the MPSC agreed to remove from the October 2013 order the sentence that imposed the new burden and to initiate a separate docket to review lost revenue policy issues. The MPSC initiated the new proceeding regarding LRAM in June 2014, discovery is currently in process and a hearing is scheduled for May 2015. Based on the MPSC's October 2013 order, we have recognized $7.1 million of DSM lost revenues for each annual electric supply tracker period. However, since the 2012/2013 and 2013/2014 annual electric tracker filings are still subject to final approval, the MPSC may ultimately require us to refund a portion of the DSM lost revenues we have recognized since July 2012. Montana Natural Gas Tracker Filings Each year we submit a natural gas tracker filing for recovery of supply costs for the 12-month period ended June 30 and for the projected supply costs for the next 12-month period. The MPSC reviews such filings and makes its cost recovery determination based on whether or not our natural gas supply procurement activities were prudent. In May 2014, we filed our annual natural gas supply tracker filing for the 2013/2014 tracker period. During June 2014, the MPSC approved this filing on an interim basis and consolidated it with our pending natural gas filing for the 2012/2013 tracker period. During December 2014, we filed supplemental testimony to correct an allocation error in our initial tracker filing related to our owned production. The financial impact of this correction was not material for any period presented. Discovery is currently in process and a hearing is scheduled for May 2015. Natural Gas Production Assets In 2012 and 2013, we purchased natural gas production interests in northern Montana's Bear Paw Basin (Bear Paw). We are collecting the cost of service for natural gas produced from these assets, including a return on our investment, through our natural gas supply tracker on an interim basis. As a result, we do not expect to file an application with the MPSC to place these assets in natural gas rate base until our next natural gas rate case. We are recognizing Bear Paw related revenue based on the precedent established by the MPSC's approval of Battle Creek in the fourth quarter of 2012. Since acquisition, we have recognized approximately $29.3 million of revenue, a portion of which may be subject to refund.

Regulatory Matters

Hydro Transaction

See Note 3 - Hydro Transaction.

South Dakota Electric Rate Filing

In December 2014, we filed a request with the SDPUC for an annual increase to electric rates totaling approximately $26.5 million . Our request was based on a return on equity of 10%, a capital structure consisting of 46% debt and 54% equity and rate base of $447.4 million. The SDPUC has not yet issued a procedural schedule and we do not anticipate implementing new rates until at least July 2015.

We have not filed an electric rate case in South Dakota since 1980. This filing requests recovery of capital expenditures related to improvements to our transmission and distribution delivery systems over time, the Aberdeen Generating Station, and additions (including estimated 2015 additions) to comply with additional emission reduction requirements at two of our jointly owned electric generating units that serve our South Dakota customers.

Dave Gates Generating Station at Mill Creek (DGGS)

FERC Filing - In April 2014, the FERC issued an order affirming a FERC Administrative Law Judge's (ALJ) initial decision in September 2012, regarding cost allocation at DGGS between retail and wholesale customers. This decision concluded we should allocate only a fraction of the costs we believe, based on facts and the law, should be allocated to FERC jurisdictional customers. We have been recognizing revenue consistent with the ALJ's initial decision. As of December 31, 2014, we have cumulative deferred revenue of approximately $27.3 million, which is subject to refund and recorded within current regulatory liabilities in the Consolidated Balance Sheets. The order included a requirement to issue customer refunds (included in deferred revenue) within 30 days.

In May 2014, we filed a request for rehearing, which remains pending. In our request for rehearing, we have argued that no refunds are due even if the cost allocation method is modified prospectively. There is no deadline by which FERC must act on our rehearing petition, but it could occur during the first quarter of 2015. Customer refunds, if any, will not be due until 30 days after a FERC order on rehearing. If unsuccessful on rehearing, we may appeal to a United States Circuit Court of Appeals. The time line for any such appeal could, depending on when the FERC issues a rehearing order, extend into 2016 or beyond.

The FERC order was assessed as a triggering event as to whether an impairment charge should be recorded with respect to DGGS. We continue to evaluate options to use DGGS in combination with other generation resources, including our newly acquired hydro facilities, to ensure cost recovery. Any alternative use of DGGS would be subject to regulatory approval and we cannot provide assurance of such approval. We do not believe an impairment loss is probable at this time; however, we will continue to evaluate recovery of this asset in the future as facts and circumstances change.

Montana Electric Tracker Filings

Each year we submit an electric tracker filing for recovery of supply costs for the 12-month period ended June 30 and for the projected supply costs for the next 12-month period. The MPSC reviews such filings and makes its cost recovery determination based on whether or not our electric supply procurement activities were prudent.

In May 2014, we filed our annual electric supply tracker filing for the 2013/2014 tracker period. The MPSC approved this filing on an interim basis and consolidated it with our pending electric supply filing for the 2012/2013 tracker period. Our 2014 electric tracker filing includes market purchases made between July 2013 and January 2014 for replacement power during an outage at Colstrip Unit 4. Inclusion of these costs in the tracker filing is consistent with the treatment of replacement power during previous outages. During a June 2014 MPSC work session, approximately $11 million of these incremental market purchases related to the Colstrip Unit 4 outage were identified by the MPSC for additional prudency review. In July 2014, the Montana Environmental Information Center and Sierra Club filed a petition to intervene in the consolidated 2013 and 2014 tracker dockets to challenge our recovery of costs associated with Colstrip Unit 4, particularly the costs incurred as a result of the outage, as imprudent. A procedural schedule has not yet been established for the consolidated electric supply tracker docket.

Montana Lost Revenue Adjustment Mechanism

Demand-side management (DSM) lowers our sales to customers. In 2005, the MPSC created a Lost Revenue Adjustment Mechanism (LRAM) by which we collect revenue that we would have collected without any DSM. In an order issued in October 2013, which was related to our 2011 / 2012 electric supply tracker, the MPSC required us to lower our LRAM revenue recovery and imposed a new burden of proof on us for future LRAM recovery. We appealed the October 2013 order to Montana District Court. The appeal is pending. The District Court approved a partial settlement of our appeal, in which the MPSC agreed to remove from the October 2013 order the sentence that imposed the new burden and to initiate a separate docket to review lost revenue policy issues. The MPSC initiated the new proceeding regarding LRAM in June 2014, discovery is currently in process and a hearing is scheduled for May 2015.

Based on the MPSC's October 2013 order, we have recognized $7.1 million of DSM lost revenues for each annual electric supply tracker period. However, since the 2012/2013 and 2013/2014 annual electric tracker filings are still subject to final approval, the MPSC may ultimately require us to refund a portion of the DSM lost revenues we have recognized since July 2012.

Montana Natural Gas Tracker Filings

Each year we submit a natural gas tracker filing for recovery of supply costs for the 12-month period ended June 30 and for the projected supply costs for the next 12-month period. The MPSC reviews such filings and makes its cost recovery determination based on whether or not our natural gas supply procurement activities were prudent.

In May 2014, we filed our annual natural gas supply tracker filing for the 2013/2014 tracker period. During June 2014, the MPSC approved this filing on an interim basis and consolidated it with our pending natural gas filing for the 2012/2013 tracker period. During December 2014, we filed supplemental testimony to correct an allocation error in our initial tracker filing related to our owned production. The financial impact of this correction was not material for any period presented. Discovery is currently in process and a hearing is scheduled for May 2015.

Natural Gas Production Assets

In 2012 and 2013, we purchased natural gas production interests in northern Montana's Bear Paw Basin (Bear Paw). We are collecting the cost of service for natural gas produced from these assets, including a return on our investment, through our natural gas supply tracker on an interim basis. As a result, we do not expect to file an application with the MPSC to place these assets in natural gas rate base until our next natural gas rate case. We are recognizing Bear Paw related revenue based on the precedent established by the MPSC's approval of Battle Creek in the fourth quarter of 2012. Since acquisition, we have recognized approximately $29.3 million of revenue, a portion of which may be subject to refund.