APPENDIX 8B. TECHNICAL ASPECTS OF THE TARIFF-BASED APPROACH 

TABLE OF CONTENTS
 

8B.1 REVIEW OF DATASETS AND CALCULATION METHODS...........................8B-1
 

8B.2 THE TAP DATABASE AND CALCULATION TOOLS......................................8B-2
 

LIST OF TABLES 

Table 8B.1.1 List of data sources that could be used to estimate electricity prices ..........8B-1
 

Table 8B.1.2 Residential average prices estimated from EIA Form 861 ..........................8B-2
 

LIST OF FIGURES 

Figure 8B.2.1 Comparison of average prices for summer (July) calculated using TAP 

and EEI data.................................................................................................8B-4 

Figure 8B.2.2 Comparison of average prices for winter (January) calculated using 

TAP and EEI data ........................................................................................8B-4
 

 8B-i 
 

 

 

 

 

APPENDIX 8B. TECHNICAL ASPECTS OF THE TARIFF-BASED APPROACH 

8B.1 REVIEW OF DATASETS AND CALCULATION METHODS 

The methodology used to calculate electricity prices is dependent on the data set. Table 

8B.1.1 lists the data that was available as this analysis was being completed, and the type of 

methodology that goes with the data. The table includes information on the resolution of the 

data both geographically and in terms of the ability to distinguish customer type, and the degree 

of complexity and accuracy of the calculation methods. 

Table 8B.1.1 List of data sources that could be used to estimate electricity prices 

Method Data Source/Year 

Resolution 

Complexity Accuracy 

Customer 

Type Geographic 

Average price EIA 861 2006a Low High Low Low 

Price by consumption 

block EEI 2007 Low Medium Low Low 

Average or marginal price 

by household/building RECS/CBECS 2001 High Low Low Low 

Tariff-based prices using 

existing data (2004) LBNL-TAP 2004 High Medium Low Medium 

Tariff-based prices using 

updated data (2008) LBNL-TAP 2008 High Medium Medium High 

If EIA 861 or EEI data are used, only average prices can be estimatedb. Residential 

average prices are likely to be slightly above residential marginal prices due to the relatively 

large fixed charges on residential bills. However, many areas use ascending block rates, and in 

these cases the marginal price may be higher than the average price. Commercial average prices 

are typically lower than commercial marginal prices. Due to the complexity and diversity of 

commercial rate structures, it can be very difficult to relate an average electricity price to the 

actual bill savings that may occur under an efficiency scenario in which both the electricity 

consumption and demand are reduced. This is especially true for peak-coincident end uses. The 

only method that allows the direct estimation of marginal prices is the tariff-based approach. 

Both the RECS and CBECS datasets provide monthly billing data (consumption and 

expenditures, and demand for commercial buildings) for some survey years (1992 and 1995 for 

CBECS, 1997 and 2001 for RECS). While these data can in principle be used to estimate prices, 

the age of the expenditure data and the size of recent price increases make this approach 

problematic. In particular, in many areas tariff structures (not just rates) may have changed 

a

 EIA Form 861 data for 2007 became available in May 2009, too late for use in this analysis. 

b

 The average price is defined as the ratio of expenditure to energy use. 

 8B-1
 
 

 

significantly in the last 5-10 years. The EEI dataset covers only investor-owned utilities and does 

not include publicly-owned companies. In some regions, a significant fraction of consumers are 

served by publicly-owned utilities; EIA data show that on average residential prices tend to be 

lower, and commercial prices somewhat higher, for publicly-owned vs. investor-owned utilities. 

It is therefore important to include these utilities in the analysis. 

Table 8B.1.2 illustrates some of these points using EIA form 861 data for the residential 

sector.1 In each of the years 2004, 2005 and 2006, the consumer-weighted average revenues 

divided by sales is calculated over all utilities in a given region, for different market sectors. 

These numbers are an estimate of the average price paid by a customer in the given sector. The 

table shows the average price estimated in this way for 2006 (in nominal dollars) for publiclyand privately- owned utilities separately. The growth rate is calculated from the price ratios 

between year 2004 and 2005, 2005 and 2006, and the compound increase between 2004 and 

2006. The table illustrates the variability in growth rates by region. Commercial prices show 

similar characteristics. 

Table 8B.1.2 Residential average prices estimated from EIA Form 861 

Residential Average Price ¢/kWh (2006) Increase 2004 to 2006 

Code Area All Private Public All 

1 New England 16.0 16.3 13.1 33.3% 

2 Mid-Atlantic 14.1 13.9 16.6 12.4% 

3 ENC 9.3 9.3 9.1 10.2% 

4 WNC 8.3 8.3 8.3 7.6% 

5 South Atlantic 9.8 9.7 10.0 17.2% 

6 ESC 8.2 8.2 8.1 14.3% 

7 WSC 11.5 12.4 9.6 26.9% 

8 Mountain 9.0 9.1 8.9 8.4% 

9 Pacific 12.6 13.8 9.2 15.3% 

HI & AK 20.6 22.8 17.2 25.5% 

8B.2 THE TAP DATABASE AND CALCULATION TOOLS 

The core of the current TAP database is a statistically representative sample of 

approximately 90 electric utilities that reflect industry diversity in geographic region, ownership 

type, and company size.2

 The finest level of regional variation is currently a set of seventeen 

regions, constructed from the intersection of census divisions with major climate zones.3,4 The 

region definitions resolve three sources of variability: 1) For datasets such as CBECS and RECS, 

general demographic variability is represented at the census division level. To facilitate the use 

of these data in the tariff-based electricity price analysis, the TAP regions are defined as subsectors of census divisions. (2) Weather variability plays an important role in determining load 

characteristics, which in turn can influence prices, as utilities will try to encourage or discourage 

certain behaviors to make their system operations more efficient. Therefore, the census divisions 

are subdivided according to how they overlap with the nine climate regions defined by the 

 8B-2
 
 

 

National Climatic Data Center. (3) Since the onset of deregulation, different areas of the country 

can have very different electricity market structures, which can affect prices and billing 

practices. To capture this variability, states or regions with independent markets have been 

broken out into separate regions. In practice this means that California, New York, Texas and 

Florida are defined as separate regions. 

Within each region, the number of utilities chosen was determined by the relative 

population living in that area, and the proportion of customers served by privately- vs. publiclyowned companies. With the current database, variability in prices is well represented at the level 

of these seventeen regions. For the current analysis, regional variation is actually somewhat 

coarser, consisting of nine census divisions plus four large states as is used in RECS. 

Electricity tariffs are typically classed as residential or non-residential. Non-residential 

may be further subdivided into general service, and special-use tariffs such as street-lighting, 

agricultural, etc. For the general service category, some utilities explicitly distinguish between 

commercial and industrial, but most do not. There are usually several general-service tariffs for 

different customer sizes, where size is defined here by the value of the annual peak load, and in 

each size class there is generally a default tariff. TAP currently contains the default residential 

and commercial tariffs for each customer size and market. Given the importance of residential 

tariffs for the current analysis, these data were updated in 2008. TAP also includes any optional 

time-of-use (TOU) residential tariffs that offered by the utilities in the sample. On the 

commercial side, TOU tariffs are always included when they are the default tariff. Tariffs have 

been collected for both primary and secondary delivery voltage. As commercial users of 

residential-style equipment are a small portion of the total customer base, it was not considered 

necessary to update the commercial data for this analysis. Hence, the commercial tariffs used 

here were collected in 2004. The resulting prices are rescaled to reflect recent price increases. 

Tariff data are collected using a series of spreadsheet forms which automatically populate 

the set of normalized tables that comprise the TAP database. Most of the tariff features (various 

types of block rates, TOU rates, seasonal rates, demand charges, etc.) are captured without 

approximation (a complete discussion of the level of detail in the data can be found in published 

work5,3). Given a standardized data format, it is relatively straightforward to develop bill 

calculation tools. These tools take as input the monthly electricity use data, consisting of 

consumption and demand, by TOU period if necessary. The bill calculation then produces the 

monthly bill. 

To validate the tariff data and bill calculation tools, we perform a series of diagnostic 

tests which make use of the electricity price information described above, particularly the EEI 

data. We present a detailed discussion here of the validation for the residential data; the 

commercial data has been validated in a similar manner through previous work.5,3 EEI provides a 

“typical” bill at three monthly consumption levels (500 kWh, 750 kWh and 1000 kWh for 

residential). These are reported by utility for summer and winter separately. It is straightforward 

to use TAP to calculate bills at each of these consumption levels, for the summer and winter 

seasonal rates as appropriate. The corresponding average prices can then be directly compared to 

the EEI data. The results are presented graphically in Figures 8B.2.1 and 8B.2.2, for bills 

 8B-3
 
calculated with 750 kWh of consumption. In these plots, the horizontal axis shows the state and 

data for all the utilities within a given state are used in the determination of the values plotted 

along the vertical axis. The figures show the median average price calculated from the EEI data, 

and the range (high, low and median) of average prices for all the tariffs in TAP. All prices are 

given in cents per kWh. Note the TAP data include publicly-owned utilities, which introduces 

more variability than is in the EEI dataset. 

Summer Avg Prices for 750kwh 

0 

5 

10 

15 

20 

25 

30 

AK 

AL 

AR 

AZ 

CA 

CO 

CT 

DC 

DE 

FL 

GA 

HI 

IA 

ID 

IL 

IN 

KS 

KY 

LA 

MA 

MD 

ME 

MI 

MN 

MO 

MS 

MT 

NC 

ND 

NE 

NH 

NJ 

NM 

NV 

NY 

OH 

OK 

OR 

PA 

RI 

SC 

SD 

TN 

TX 

UT 

VA 

VT 

WA 

WI 

WV 

WY 

0 

5 

10 

15 

20 

25 

30 

E E I 2008 S S um H i S u m L o S u mMe d 

Figure 8B.2.1 Comparison of average prices for summer (July) calculated using TAP and EEI data 

Winter Avg Prices for 750kwh 

0 

5 

10 

15 

20 

25 

30 

AK 

AL 

AR 

AZ 

CA 

CO 

CT 

DC 

DE 

FL 

GA 

HI 

IA 

ID 

IL 

IN 

KS 

KY 

LA 

MA 

MD 

ME 

MI 

MN 

MO 

MS 

MT 

NC 

ND 

NE 

NH 

NJ 

NM 

NV 

NY 

OH 

OK 

OR 

PA 

RI 

SC 

SD 

TN 

TX 

UT 

VA 

VT 

WA 

WI 

WV 

WY 

0 

5 

10 

15 

20 

25 

30 

E E I 200 8W W i n H i W i n Lo Wi n M e d 

Figure 8B.2.2 Comparison of average prices for winter (January) calculated using TAP and EEI data 

 8B-4
 
 

 

 

 

 

 

 

REFERENCES 

1	 Regulatory Research Associates. Average Regulated Retail Price of Electricity, 2007 & 

Comparative Historical Data. 2008. Jersey City NJ. 

2	 U.S. Department of Energy -- Office of Energy Efficiency and Renewable Energy. 

Commercial Unitary Air Conditioners and Heat Pumps Technical Support Document. 

Including: Appendix M: Sample Utilities. July, 2004. Washington, D.C. 

http://www1.eere.energy.gov/buildings/appliance_standards/commercial/pdfs/cuac_tsd_app_ 

m.pdf 

3	 Coughlin, K., C. Bolduc, R. Van Buskirk, G. Rosenquist & J. E. McMahon. Tariff-based 

Analysis of Commercial Building Electricity Prices. 2008. Lawrence Berkeley National 

Laboratory: Berkeley, CA. Report No. LBNL-55551. 

4	 U.S. Department of Energy -- Office of Energy Efficiency and Renewable Energy. 

Commercial Unitary Air Conditioners and Heat Pumps Technical Support Document. 

Including: Life-Cycle Cost and Pay-back Period Analysis. July, 2004. Washington, D.C. 

http://www1.eere.energy.gov/buildings/appliance_standards/commercial/pdfs/cuac_tsd_chp_ 

8.pdf 

5	 Coughlin, Katie, Richard White, Chris Bolduc, Diane Fisher & Greg Rosenquist. The Tariff 

Analysis Project: A database and analysis platform for electricity tariffs. 2006. Lawrence 

Berkeley National Laboratory: Berkeley, CA. Report No. LBNL-55680. For data updates 

see the website <tariffs.lbl.gov>. 

 8B-5