Regulatory Assets and Liabilities

3 Months Ended

Mar. 31, 2013

3. Regulatory Assets and Liabilities

In accordance with GAAP, regulatory assets and liabilities are recorded in the Condensed Consolidated Balance Sheets for our regulated electric transmission and distribution businesses. Regulatory assets are the deferral of costs expected to be recovered in future customer rates and regulatory liabilities represent current recovery of expected future costs or gains probable of being reflected in future rates.

We evaluate our regulatory assets each period and believe that recovery of these assets is probable. We have received or requested a return on certain regulatory assets for which we are currently recovering or seeking recovery through rates. We record a return after it has been authorized in an order by a regulator.

Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected.

Regulatory assets and liabilities for DPL are as follows:



$ in millions	Type of Recovery ^(a)	Amortization through	At March 31, 2013		At December 31, 2012
Regulatory assets, current:
TCRR, transmission, ancillary and other PJM-related costs	F	Ongoing	$	6.6	$	7.0
Fuel and purchased power recovery costs	C	Ongoing		11.4		14.1
Total regulatory assets, current			$	18.0	$	21.1

Regulatory assets, non-current:
Deferred recoverable income taxes	B/C	Ongoing	$	34.3	$	35.1
Pension benefits	C	Ongoing		87.3		88.9
Unamortized loss on reacquired debt	C	Ongoing		11.7		11.9
Regional transmission organization costs	D	2014		2.2		2.6
Deferred storm costs	D			24.7		24.4
CCEM smart grid and advanced metering infrastructure costs	D			6.6		6.6
CCEM energy efficiency program costs	F	Ongoing		3.4		5.2
Consumer education campaign	D			3.0		3.0
Retail settlement system costs	D			3.1		3.1
Other costs				4.6		4.7
Total regulatory assets, non-current			$	180.9	$	185.5

Regulatory liabilities, current:
Other			$	-	$	0.1
Total regulatory liabilities, current			$	-	$	0.1

Regulatory liabilities, non-current:
Estimated costs of removal - regulated property			$	113.6	$	112.1
Postretirement benefits				4.8		5.0
Other				0.4		0.2
Total regulatory liabilities, non-current			$	118.8	$	117.3

(a)B – Balance has an offsetting liability resulting in no effect on rate base.

C – Recovery of incurred costs without a rate of return.

D – Recovery not yet determined, but is probable of occurring in future rate proceedings.

F – Recovery of incurred costs plus rate of return.

Regulatory Assets

TCRR, transmission, ancillary and other PJM-related costs represent the costs related to transmission, ancillary service and other PJM-related charges that have been incurred as a member of PJM. On an annual basis, retail rates are adjusted to true-up costs with recovery in rates.

Fuel and purchased power recovery costs represent prudently incurred fuel, purchased power, derivative, emission and other related costs which will be recovered from or returned to customers in the future through the operation of the fuel and purchased power recovery rider. The fuel and purchased power recovery rider fluctuates based on actual costs and recoveries and is modified at the start of each seasonal quarter. DP&L implemented the fuel and purchased power recovery rider on January 1, 2010. As part of the PUCO approval process, an outside auditor is hired to review fuel costs and the fuel procurement process.

Deferred recoverable income taxes represent deferred income tax assets recognized from the normalization of flow through items as the result of tax benefits previously provided to customers. This is the cumulative flow through benefit given to regulated customers that will be collected from them in future years. Since currently existing temporary differences between the financial statements and the related tax basis of assets will reverse in subsequent periods, these deferred recoverable income taxes will decrease over time.

Pension benefits represent the qualifying FASC 715 “Compensation – Retirement Benefits” costs of our regulated operations that for ratemaking purposes are deferred for future recovery. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of other comprehensive income (OCI), the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory asset represents the regulated portion that would otherwise be charged as a loss to OCI.

Unamortized loss on reacquired debt represents losses on long-term debt reacquired or redeemed in prior periods. These costs are being amortized over the lives of the original issues in accordance with FERC and PUCO rules.

Regional transmission organization costs represent costs incurred to join an RTO. The recovery of these costs will be requested in a future FERC rate case. In accordance with FERC precedence, we are amortizing these costs over a 10-year period that began in 2004 when we joined the PJM RTO.

Deferred storm costs relate to costs incurred to repair the damage caused by storms in the following years:

·	2008 – related to costs incurred to repair the damage caused by hurricane force winds in September 2008, as well as other 2008 storms. On January 14, 2009, the PUCO granted DP&L the authority to defer these costs with a return until such time that DP&L seeks recovery in a future rate proceeding.

·	2011 – related to five major storms in 2011. On December 21, 2012, DP&L filed a request with the PUCO for an accounting order to defer costs and a request for recovery of costs associated with these storms. At March 31, 2013, DP&L believes the recovery of these costs is probable.

2012 – related to storm damage that occurred during the final weekend of June 2012. On August 10, 2012, DP&L filed a request with the PUCO, which was modified on October 19, 2012, for an accounting order to defer the costs associated with this storm damage. On December 19, 2012, the PUCO issued an order permitting partial deferral.

On December 21, 2012, DP&L filed a request for recovery of all of these deferred storm costs with the PUCO.

CCEM smart grid and AMI costs represent costs incurred as a result of studying and developing distribution system upgrades and implementation of AMI. On October 19, 2010, DP&L elected to withdraw its case pertaining to the Smart Grid and AMI programs. The PUCO accepted the withdrawal in an order issued on January 5, 2011. The PUCO also indicated that it expects DP&L to continue to monitor other utilities’ Smart Grid and AMI programs and to explore the potential benefits of investing in Smart Grid and AMI programs and that DP&L will, when appropriate, file new Smart Grid and/or AMI business cases in the future. We plan to file to recover these deferred costs in a future regulatory rate proceeding. Based on PUCO precedent, we believe these costs are probable of future recovery in rates.

CCEM energy efficiency program costs represent costs incurred to develop and implement various new customer programs addressing energy efficiency. These costs are being recovered through an energy efficiency rider that began July 1, 2009 and is subject to a two-year true-up for any over/under recovery of costs. On April 29, 2011, DP&L filed to true-up the energy efficiency rider which was approved by the PUCO on October 18, 2011. DP&L made its true-up filing on April 30, 2013.

Consumer education campaign represents costs for consumer education advertising regarding electric deregulation. DP&L will be seeking recovery of these costs as part of our next distribution rate case filing at the PUCO. The timing of such a filing has not yet been determined.

Retail settlement system costs represent costs to implement a retail settlement system that reconciles the energy a CRES supplier delivers to its customers with what its customers actually use. Based on case precedent in other utilities’ cases, the costs are most likely recoverable through a future DP&L rate proceeding.

Other costs primarily include RPM capacity, other PJM and rate case costs and alternative energy costs that are being recovered or are expected to be recovered over various periods.

Regulatory Liabilities

Estimated costs of removal – regulated property reflect an estimate of amounts collected in customer rates for costs that are expected to be incurred in the future to remove existing transmission and distribution property from service when the property is retired.

Postretirement benefits represent the qualifying FASC 715 “Compensation – Retirement Benefits” gains related to our regulated operations that, for ratemaking purposes, are probable of being reflected in future rates. We recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status, and recognize, as a component of OCI, the changes in the funded status of the plan that arise during the year that are not recognized as a component of net periodic benefit cost. This regulatory liability represents the regulated portion that would otherwise be reflected as a gain to OCI.

DP&L [Member]

Regulatory Matters

3. Regulatory Assets and Liabilities

In accordance with GAAP, regulatory assets and liabilities are recorded in the Condensed Balance Sheets for our regulated electric transmission and distribution businesses. Regulatory assets are the deferral of costs expected to be recovered in future customer rates and regulatory liabilities represent current recovery of expected future costs or gains probable of recovery being reflected in future rates.

We evaluate our regulatory assets each period and believe recovery of these assets is probable. We have received or requested a return on certain regulatory assets for which we are currently recovering or seeking recovery through rates. We record a return after it has been authorized in an order by a regulator.

Regulatory assets and liabilities are classified as current or non-current based on the term in which recovery is expected.

Regulatory assets and liabilities for DP&L are as follows:



$ in millions	Type of Recovery ^(a)	Amortization through	At March 31, 2013		At December 31, 2012

Regulatory assets, current:
TCRR, transmission, ancillary and other PJM-related costs	F	Ongoing	$	6.6	$	7.0
Fuel and purchased power recovery costs	C	Ongoing		10.0		11.3
Total regulatory assets, current			$	16.6	$	18.3

Regulatory assets, non-current:
Deferred recoverable income taxes	B/C	Ongoing	$	34.3	$	35.1
Pension benefits	C	Ongoing		87.3		88.9
Unamortized loss on reacquired debt	C	Ongoing		11.7		11.9
Regional transmission organization costs	D	2014		2.2		2.6
Deferred storm costs	D			24.7		24.4
CCEM smart grid and advanced metering infrastructure costs	D			6.6		6.6
CCEM energy efficiency program costs	F	Ongoing		3.4		5.2
Consumer education campaign	D			3.0		3.0
Retail settlement system costs	D			3.1		3.1
Other costs				4.6		4.7
Total regulatory assets, non-current			$	180.9	$	185.5

Regulatory liabilities, current:
Other			$	-	$	0.1
Total regulatory liabilities, current			$	-	$	0.1

Regulatory liabilities, non-current:
Estimated costs of removal - regulated property			$	113.6	$	112.1
Postretirement benefits				4.8		5.0
Other				0.4		0.2
Total regulatory liabilities, non-current			$	118.8	$	117.3

(a)B – Balance has an offsetting liability resulting in no effect on rate base.

C – Recovery of incurred costs without a rate of return.

D – Recovery not yet determined, but is probable of occurring in future rate proceedings.

F – Recovery of incurred costs plus rate of return.

Regulatory Assets

Deferred recoverable income taxes represent deferred income tax assets recognized from the normalization of flow through items as the result of amounts previously provided to customers. This is the cumulative flow through benefit given to regulated customers that will be collected from them in future years. Since currently existing temporary differences between the financial statements and the related tax basis of assets will reverse in subsequent periods, these deferred recoverable income taxes will decrease over time.

Regional transmission organization costs represent costs incurred to join an RTO. The recovery of these costs will be requested in a future FERC rate case.

Deferred storm costs relate to costs incurred to repair the damage caused by storms in the following years:

·	2008 – related to costs incurred to repair the damage caused by hurricane force winds in September 2008, as well as other 2008 storms. On January 14, 2009, the PUCO granted DP&L the authority to defer these costs with a return until such time that DP&L seeks recovery in a future rate proceeding.

·	2011 – related to five major storms in 2011. On December 21, 2012, DP&L filed a request with the PUCO for an accounting order to defer costs and a request for recovery of costs associated with these storms. At March 31, 2013, DP&L believes the recovery of these costs is probable.

On December 21, 2012, DP&L filed a request for recovery of all of these deferred storm costs with the PUCO.

CCEM smart grid and AMI costs represent costs incurred as a result of studying and developing distribution system upgrades and implementation of AMI. On October 19, 2010, DP&L elected to withdraw its case pertaining to the Smart Grid and AMI programs. The PUCO accepted the withdrawal in an order issued on January 5, 2011. The PUCO also indicated that it expects DP&L to continue to monitor other utilities’ Smart Grid and AMI programs and to explore the potential benefits of investing in Smart Grid and AMI programs and that DP&L will, when appropriate, file new Smart Grid and/or AMI business cases in the future. We plan to file to recover these deferred costs in a future regulatory rate proceeding. Based on past PUCO precedent, we believe these costs are probable of future recovery in rates.

Retail settlement system costs represent costs to implement a retail settlement system that reconciles the energy a CRES supplier delivers to its customers and what its customers actually use. Based on case precedent in other utilities’ cases, the costs are most likely recoverable through a future DP&L rate proceeding.

Other costs primarily include RPM capacity, other PJM and rate case costs and alternative energy costs that are being recovered or are expected to be recovered over various periods.

Regulatory Liabilities