EIA Short Term Energy Outlook

June 2021
Short-Term Energy Outlook

Forecast highlights
Global liquid fuels
• The June Short-Term Energy Outlook (STEO) remains subject to heightened levels of
uncertainty related to the ongoing economic recovery from the COVID-19 pandemic.
The U.S. economy continues to rise after reaching multiyear lows in the second quarter
of 2020 (2Q20). The increase in economic activity and easing of the COVID-19 pandemic
have contributed to rising energy use. U.S. gross domestic product (GDP) declined by
3.5% in 2020 from 2019 levels. This STEO assumes U.S. GDP will grow by 6.7% in 2021
and by 4.9% in 2022. The U.S. macroeconomic assumptions in this outlook are based on
forecasts by IHS Markit. Our forecast assumes continuing economic growth and
increasing mobility as a result of the easing of the COVID-19 pandemic. Any
developments that would cause deviations from these assumptions would likely cause
energy consumption and prices to deviate from our forecast.
• Brent crude oil spot prices averaged $68 per barrel (b) in May, up $4/b from April. Brent
prices were higher in May as global oil inventories continued to decline, albeit at a
slower pace than in the first four months of the year. In the coming months, we expect
that global oil production will increase to match rising levels of global oil consumption.
The rising oil production in the forecast is largely a result of the OPEC+ decision to raise
production. We expect rising production will end the persistent global oil inventory
draws that have occurred for much of the past year and lead to relatively balanced
global oil markets in the second half of 2021 (2H21). We expect Brent prices will remain
near current levels in 3Q21, averaging $68/b. However, in 2022, we expect that
continuing growth in production from OPEC+ and accelerating growth in U.S. tight oil
production—along with other supply growth—will outpace decelerating growth in
global oil consumption and contribute to declining oil prices. Based on these factors, we
expect Brent to average $60/b in 2022.
• We expect U.S. gasoline consumption will average 9.1 million barrels per day (b/d) this
summer (April–September), which is 1.3 million b/d more than last summer but still
more than 0.4 million b/d less than summer 2019. Weekly consumption data reflect the
Colonial Pipeline outage and subsequent increase in gasoline demand, but consumption
both before and after this event indicate more gasoline demand than we had previously
forecast. Our latest forecast also reflects IHS Markit’s increased employment forecast.
U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 1

Note: EIA completed modeling and analysis for this report on Thursday June 3, 2021
We expect U.S. gasoline consumption to average 8.7 million b/d in for all of 2021 and
9.0 million b/d in 2022.
• For the 2021 April–September summer driving season, we forecast U.S. regular gasoline
retail prices will average $2.92 per gallon (gal), up from an average of $2.07/gal last
summer. The higher forecast gasoline prices reflect higher crude oil prices and higher
wholesale gasoline margins. Wholesale gasoline margins have risen as a result of
relatively low inventories and rising gasoline demand. Margins also temporarily widened
because of outages on the Colonial Pipeline. These developments caused U.S. average
regular gasoline retail prices to reach a monthly average of $2.99/gal in May, peaking at
$3.03/gal on May 17, which were the highest monthly and weekly prices since 2014. We
expect that prices will average $3.03/gal in June before falling to $2.76/gal by
September. The drop in forecast retail gasoline prices reflects our forecast that gasoline
margins will fall this summer in response to rising refinery utilization. For all of 2021, we
expect U.S. regular gasoline retail prices to average $2.77/gal and gasoline retail prices
for all grades to average $2.87/gal. Higher prices and more gasoline consumption would
result in the average U.S. household spending about $570 (38%) more on motor fuel in
2021 compared with 2020.
• We estimate that 96.2 million b/d of petroleum and liquid fuels was consumed globally
in May, an increase of 11.9 million b/d from May 2020 but 3.7 million b/d less than in
May 2019. We forecast that global consumption of petroleum and liquid fuels will
average 97.7 million b/d for all of 2021, which is a 5.4 million b/d increase from 2020.
We forecast that global consumption of petroleum and liquid fuels will increase by 3.6
million b/d in 2022 to average 101.3 million b/d.
• We forecast OPEC crude oil production will average 26.9 million b/d in 2021 and 28.7
million b/d in 2022. OPEC crude oil production in the forecast rises from 25.0 million b/d
in April to an average of 28.0 million b/d in 3Q21. Our expectation of rising OPEC
production is primarily based on our assumption that OPEC will raise production by
about 1 million b/d in both June and in July in response to rising global oil demand and
seasonal increases in oil consumption for power generation for some OPEC members. It
also reflects an assumption that Iran’s crude oil production will continue to increase this
year. Although sanctions that target Iran’s crude oil exports remain in place, crude oil
exports—according to ClipperData, LLC.—and production from Iran are up from most of
2020.
• According to our most recent data, U.S. crude oil production averaged 11.2 million b/d
in March 2021, an increase of 1.4 million b/d from February. The March rise indicates
that the production outages caused by the February winter freeze were temporary and
that production came back online quickly. Because prices of West Texas Intermediate
crude oil remain above $60/b during 2021 in the current forecast, we expect that
producers will drill and complete enough wells to raise 2022 production from 2021

levels. We estimate that 2022 production will average 11.8 million b/d, up from a
forecast average of 11.1 million b/d in 2021.
Natural Gas
• In May, the natural gas spot price at Henry Hub averaged $2.91 per million British
thermal units (MMBtu), which is up from the April average of $2.66/MMBtu. We expect
the Henry Hub spot price will average $2.92/MMBtu in 3Q21 and $3.07/MMBtu for all
of 2021, which is up from the 2020 average of $2.03/MMBtu. Higher natural gas prices
this year primarily reflect two factors: growth in liquefied natural gas (LNG) exports and
rising domestic natural gas consumption outside of the power sector. In 2022, we
expect the Henry Hub price will average $2.93/MMBtu amid slowing growth in LNG
exports and rising U.S. natural gas production.
• We expect that U.S. consumption of natural gas will average 82.9 billion cubic feet per
day (Bcf/d) in 2021, down 0.5% from 2020. U.S. natural gas consumption declines in the
forecast, in part, because electric power generators switch to coal from natural gas as a
result of rising natural gas prices. In 2021, we expect residential and commercial natural
gas consumption combined will rise by 1.2 Bcf/d from 2020 and industrial consumption
will rise by 0.7 Bcf/d from 2020. Rising consumption outside of the power sector results
from expanding economic activity and colder winter temperatures in 2021 compared
with 2020. We expect U.S. natural gas consumption will average 82.8 Bcf/d in 2022.
• We estimate that natural gas inventories ended May 2021 at almost 2.4 trillion cubic
feet (Tcf), which is 3% lower than the five-year (2016–20) average. More natural gas was
withdrawn from storage during the winter of 2020–21 than the previous five-year
average, largely as a result of the colder-than-average February temperatures that
contributed to a drop in natural gas production. We forecast that inventories will end
the 2021 injection season (end of October) at 3.6 Tcf, which would be 4% below the
five-year average.
• Following a significant weather-related decline in U.S. natural gas production in

February, U.S. dry natural gas production rose by 6.0 Bcf/d in March to 92.3 Bcf/d. We
expect dry natural gas production will average 92.9 Bcf/d in 2H21 and then rise to 93.9
Bcf/d in 2022.
Electricity, coal, renewables, and emissions
• We forecast that retail sales of electricity in the United States will increase by 2.3% in
2021 after falling by 3.9% in 2020. The largest increase in consumption will occur in the
residential sector, where we forecast retail sales of electricity will grow by 2.8% this
year. This growth is primarily a result of colder temperatures in the first quarter of 2021
compared with the same period in 2020. Much of the forecast increase in electricity
consumption in the commercial and industrial sectors reflects improving economic

conditions in 2021. We expect retail electricity sales to these two sectors combined will
increase by 2.0% in 2021. For 2022, we forecast that U.S. retail sales of electricity will
grow by another 1.4%.
• We expect the share of electric power generation produced by natural gas in the United
States will average 36% in 2021 and 35% in 2022, down from 39% in 2020. The forecast
share for natural gas as a generation fuel declines in response to our expectation of a
higher delivered natural gas price for electricity generators, which we forecast will
average $4.09/MMBtu in 2021 compared with an average of $2.39/MMBtu in 2020. As a
result of the higher expected natural gas prices, the forecast share of generation from
coal rises from 20% in 2020 to 23% this year but falls to 22% next year. New additions of
solar and wind generating capacity support our expectation that the renewables share
of U.S. generation will rise from 20% in 2020 to 21% in 2021 and to 23% in 2022. The
nuclear share of U.S. electricity generation declines from 21% in 2020 to 20% in 2021
and to 19% in 2022 as a result of retiring capacity at some nuclear power plants.
• We forecast that planned additions to U.S. wind and solar generating capacity in 2021
and 2022 will contribute to rising electricity generation from those sources. We
estimate that the U.S. electric power sector added 14.8 gigawatts (GW) of new wind
capacity in 2020. We expect 16.0 GW of new wind capacity will come online in 2021 and
5.3 GW in 2022. Utility-scale solar capacity rose by an estimated 10.5 GW in 2020. Our
forecast for added utility-scale solar capacity is 15.5 GW 2021 and 16.6 GW for 2022.
We expect significant solar capacity additions in Texas during the forecast period. In
addition, 4 GW to 5 GW of small-scale solar capacity (systems less than 1 megawatt) will
come online each year during the 2021–22 STEO forecast.
• We expect U.S. coal production to total 600 million short tons (MMst) in 2021, which is
61 MMst (11%) more than in 2020. The increase is driven primarily by rising electricity
demand. In 2022, we expect coal production to grow by an additional 5 MMst (1%).
• We expect U.S. coal exports to be about 81 MMst in 2021, 12 MMst (17%) more than in
2020. We expect most of this growth to come from rising demand for steam coal in
Europe and Asia as increased steel prices during 2021 and 2022 drive exports. Forecast
U.S. coal exports in 2022 rise by an additional 12 MMst (14%).
• We estimate that U.S. energy-related carbon dioxide (CO2) emissions decreased by 11%
in 2020 as a result of less energy consumption related to reduced economic activity and
responses to COVID-19. In 2021, we forecast energy-related CO2 emissions will increase
about 6% from the 2020 level as economic activity increases and leads to rising energy
use. We also expect energy-related CO2 emissions to rise in 2022, but by a slower rate of
2%. We forecast that after declining by 19% in 2020, coal-related CO2 emissions will rise
by 15% in 2021 and then decrease by 1% in 2022.

Petroleum and natural gas markets review
Prices: The front month futures price for Brent crude oil settled at $71.31 per barrel (b) on June
3, up $3.75/b from $67.56/b on May 3. The front-month futures price for West Texas
Intermediate (WTI) crude oil for delivery at Cushing, Oklahoma, increased by $4.32/b during the
same period, settling at $68.81/b on June 3 (Figure 1).
After declining in April, crude oil prices in May moved toward post-pandemic daily highs at
nearly $70/b. Continuing draws on global oil inventories contributed to upward crude oil price
pressures. Despite rising COVID-19 case counts in some countries, particularly India, global oil
demand remained higher than supply in May, contributing to continued global withdrawals from
inventories of crude oil and petroleum products. However, we estimate withdrawals fell to 1.2
million barrels per day (b/d) in May, compared with average monthly withdrawals of 2.1 million
b/d since June 2020.
On June 1, front-month Brent futures prices closed above $70/b for the first time since January
2020. At its June 1 meeting, OPEC+ reaffirmed its commitment to continued production
increases in the coming months. Despite the group’s plans to raise production, prices increased
as the market weighed the planned increases relative to expected increases in consumption.
Scheduled increases in production targets contributed to OPEC crude oil production reaching
25.5 million barrels per day (b/d) in May, its highest level since April 2020. This increase brought
global supply to an estimated 95.0 million b/d compared with consumption of 96.2 million b/d.
We expect OPEC crude oil production will increase to an average of 28.0 million b/d in the third
quarter of 2021 (3Q21).
In the June STEO, we raised our Brent price forecast for the coming months. We now expect
Brent prices to average $69/b in June and $68/b in 3Q21, which are $4/b and $5/b higher,
respectively, than in last month’s forecast. This price forecast keeps prices near or slightly below

current levels through 3Q21, and it incorporates the recent price increases and our forecast of
mostly balanced oil markets in the coming months. Given announced increases in OPEC crude oil
production, we expect production to increase more rapidly in the second half of 2021 (2H21) to
keep pace with rising demand. In the forecast, global oil consumption rises by 2.8 million b/d
from 2Q21 to 2H21 while global oil production rises by 4.3 million b/d during the same period,
balancing out the 1.5 million b/d of global oil inventory draws from 2Q21. We expect more
significant downward oil price pressures to emerge later in 2021 and into 2022 as forecast
global oil supply outpaces slowing oil demand growth.
U.S. oil rigs and WTI prices: Baker Hughes’ U.S. crude oil rotary rig count, which serves as an
indicator of active U.S. crude oil production capacity, reached a low of 172 active rigs on August
14, 2020 (Figure 2). Since then, the number of U.S. oil rigs has more than doubled, increasing by
187 rigs to a total of 359 rigs as of May 28. The pace at which crude oil producers deploy drilling
rigs at any price level is an important driver of crude oil production in U.S. tight oil basins.
We expect that the rig count is likely to continue to increase in response to WTI crude oil prices
rising from less than $50/b in late 2020 to a monthly average of $65/b in May. Our models show
changes in rig counts typically lag behind changes in the WTI price from between three and six
months, and production typically comes online about two months after rig deployment.
Assuming that other factors remain constant, price increases over the past month will likely
continue to drive rig deployments through much of the rest of 2021. However, the recent
changes in rig counts indicate operators, notably in the Permian, could be deploying fewer rigs
at current oil prices than they have previously deployed when oil prices were at similar levels. In
the forecast, we have slightly reduced the responsiveness of rig deployments in the Permian to
upward oil price movements.

Although U.S. crude oil producers have some incentive to remain cautious about deploying rigs
and increasing production because of overall market uncertainty, if WTI crude oil prices remain
near $65/b in the coming months, as we forecast, prices will continue to provide an incentive for
producers to deploy additional rigs and resume production. Onshore U.S. crude oil production in
the Lower 48 states during May 2021 was 8.9 million b/d, near its highest level so far in 2021,
and we expect production to reach almost 9.3 million b/d by December 2021 with further
increases into 2022. However, our crude oil production forecast is lower than in recent STEOs
because of relatively fewer rig deployments at existing price levels, particularly in the Permian.
In the March STEO, we forecast slightly more onshore U.S. crude oil production at almost 9.4
million b/d by December 2021, while we forecast WTI prices in 2Q21 and 3Q21 to average $6/b
less than in our current forecast. Assumptions about the oil price levels at which rigs are
deployed are one of the key uncertainties in our forecast.
Brent Price and S&P 500 correlation: In 2020, the widespread impact of the COVID-19 pandemic
across sectors resulted in an increased correlation between the Brent crude oil price and S&P
500, an equity index of widely traded U.S. public companies (Figure 3). Historically, the
relationship between Brent prices and publicly traded equities is often mixed. Among many
factors, rising oil prices present the risk of inflation and can increase transportation fuel costs for
most firms, contributing to negative correlation. However, rising oil prices can also reflect strong
economic growth, which leads to rising profitability for many companies, contributing to
positive correlation. Rising oil prices can also indicate potentially higher earnings for many large
companies in the S&P 500 that produce and refine petroleum, also contributing to a positive
correlation. A positive correlation between the two can suggest that both asset prices are being
determined primarily by demand-side factors, such as global economic growth, which can
influence both demand for crude oil and for goods and services from other sectors. The rolling
30-day correlation between the Brent price and the S&P 500 reached a high point of 0.77 during
July 2020, the highest correlation between the two series since December 2010.

Uneven increases in crude oil prices and equity values contributed to a gradual decrease in the
correlation since July 2020, suggesting that drivers of the crude oil price are driven more by
sector-specific, supply-side factors and less by macroeconomic conditions or global demand. In
March 2021, the correlation decreased when crude oil prices increased more rapidly than the
S&P 500 overall, which was after OPEC+ producers announced they would maintain production
curtailments amid rising crude oil demand. After crude oil prices decreased later in March, and
remained relatively flat through April, the S&P 500 climbed to record highs. The opposite
directional movements between the two series resulted in a shift to a negative correlation
between them. The correlation between the Brent crude oil price and the S&P 500 index
reached -0.32 on May 13, the largest negative correlation since July 2014.
Crude oil and inflation expectations: The percentage difference in yields for five-year Treasury
Inflation-Protected Securities (TIPS) compared with U.S. treasury bonds is often used to measure
market expectations of inflation. Responses to the COVID-19 pandemic resulted in a dramatic
decline in demand for goods, which significantly reduced petroleum and other commodity
prices in early 2020. Because crude oil and other commodity prices are inputs to other sectors of
the economy, changes in crude oil prices can also affect inflation expectations. The TIPS-
Treasury spread decreased to an average of 0.7% in March 2020, reflecting low inflation
expectations as a result of lower prices and reduced economic activity (Figure 4).
Inflation expectations have generally increased since August 2020. The TIPS-Treasury spread
increased from 2.55% on April 1, 2021, to 2.60% on May 3 (the first trading day of May), before
reaching a high of 2.72% on May 12, the spread’s highest point since 2008. The increasing
inflation expectations correspond to increases in the Brent crude oil price, which increased from
$65/b on April 1 to $68/b on May 3 and $69/b on May 12. Fuel price increases for consumers
and firms as a result of high crude oil prices are an important contributor to inflation
expectations. However, the TIPS-Treasury spread also increased at the end of March and into

April, while Brent prices remained below their mid-March levels. Differing directional
movements between the spread and the crude oil price reflect the effects of other goods and
commodity prices on inflation expectations.
Petroleum products
Gasoline prices: The front-month futures price of RBOB (the petroleum component of gasoline
used in many parts of the country) settled at $2.20 per gallon (gal) on June 3, up 10 cents/gal
from May 3 (Figure 5). The RBOB–Brent crack spread (the difference between the price of RBOB
and the price of Brent crude oil) increased by 1 cent/gal to settle at 50 cents/gal during the
same period.
The average RBOB–Brent crack spread of 50 cents/gal in May was the highest since July 2015.
The high spread reflected increasing demand, low inventories, and disruptions to the flow of
gasoline along the U.S. East Coast because of the Colonial Pipeline outage. We estimate U.S.
gasoline consumption averaged 9.1 million b/d in May, a 4% increase from April and the highest
level since November 2019. The increase in gasoline demand likely reflected typical seasonal
factors such as Memorial Day travel, as well as increased willingness to travel as a result of rising
vaccinations, rising employment, and increased gasoline purchases in response to outages at
many gas stations during the Colonial Pipeline disruption in early May. In addition, refinery
production has not kept up with the increases in demand the past few months. Gasoline stocks
fell sharply because of weather-related outages in February. Those disruptions were followed by
increasing gasoline consumption from March through May. The increase in gasoline
consumption and supply disruptions have resulted in gasoline inventories being below the five-
year average for every month in 2021. Low gasoline inventories have supported the high
gasoline crack spread, and helped push retail gasoline prices above $3.00/gal. We forecast that
as refineries increase runs in the coming months and increases in gasoline consumption slow, it

will put some downward pressure on gasoline crack spreads and contribute to U.S. average
retail gasoline prices falling to $2.76/gal by September. However, we expect gasoline stocks to
remain near five-year lows for the rest of 2021, keeping gasoline crack spreads higher than the
five-year average.
Regional gasoline prices: The Colonial Pipeline outage interrupted the flow of gasoline from the
U.S. Gulf Coast to the East Coast and led to a short-term increase in the spread between New
York Harbor gasoline spot prices and Gulf Coast conventional gasoline spot prices (Figure 6). The
spread peaked on May 13 at 11.5 cents/gal, the highest spread since December 16, 2019. The
New York Harbor gasoline price increased relative to the Gulf Coast conventional gasoline price
likely because of a combination of increasing stocks in the U.S. Gulf Coast, decreasing stocks in
the East Coast, and increased demand in the Lower Atlantic. The Lower Atlantic, which receives
much of its gasoline from the pipeline, had lower-than-average gasoline stocks at the time of
the pipeline outage, and as a result had the highest demand for substitute supply sources.
Although the spread exceeded 10 cents/gal for only four days in the month, the spread
remained slightly elevated through May, averaging 8 cents/gal, which is higher than the five-
year May average of 5 cents/gal and higher than the April 2021 average of 3 cents/gal. The
spread decreased in early June, settling at 6 cents/gal on June 3.
Ultra-low sulfur diesel prices: The front-month futures price for ultra-low sulfur diesel (ULSD)
for delivery in New York Harbor settled at $2.10/gal on June 3, up 15 cent/gal from May 3
(Figure 7). The ULSD–Brent crack spread (the difference between the price of ULSD and the
price of Brent crude oil) increased 6 cents/gal, settling at 40 cents/gal during the same period.

May had the highest average ULSD–Brent crack spread since December 2019. The crack spread
increase was likely the result of the most U.S. consumption of distillate fuel since November
2019 and relatively low distillate production. We estimate May distillate consumption of 4.1
million b/d, an increase of 0.5 million b/d (15%) from the May 2020 levels and 3% higher than
the average from the five previous years (2015–2019). Although distillate consumption has
increased above the five-year average for May, distillate production was at its lowest May level
since 2012.
Because increases in distillate consumption have been outpacing increases in production and
net imports in recent months, distillate inventories have been decreasing, which has supported
increases in the ULSD–Brent crack spread (Figure 8). From August 2020 to April 2021, distillate
inventories decreased from 179 million barrels, the highest level since 1982, to approximately
136 million barrels. During that same period, the ULSD–Brent crack spread increased from 17
cents/gal to 31 cents/gal. In May, we estimate inventories fell to about 133 million barrels,
which is lower than the five-year average, and this reduction has coincided with steeper
increases in the crack spread. On May 11, the crack spread exceeded 40 cents/gal for the first
time since March 2020 and remained close to 40 cents/gal through June 3.

Natural Gas
Prices: The front-month natural gas futures contract for delivery at the Henry Hub settled at
$3.04 per million British thermal units (MMBtu) on June 3, 2021, which was up 7 cents/MMBtu
from May 3, 2021 (Figure 9). The average price for front-month natural gas futures contracts in
May was $2.96/MMBtu, the highest May average since 2017.
High levels of U.S. LNG exports continued in May and supported Henry Hub natural gas futures
prices above $3.00/MMBtu. We estimate U.S. LNG exports of 10.0 billion cubic feet per day
(Bcf/d) in May, the most on record for the month. Every month since November 2020 has been
among the 10 highest months for U.S. LNG exports on record. Stable U.S. production during this

period in combination with high exports reduced storage levels below their previous five-year
average. Although natural gas stocks were 191 Bcf higher than the five-year (2016–20) average
at the start of the year, they were 61 Bcf lower than the five-year average as of the week ending
May 28. Front-month natural gas futures prices have increased as stocks have decreased,
starting the year at $2.58/MMBtu and closing at $3.04/MMBtu on June 3.
Although U.S. natural gas futures prices have risen, futures price volatility has declined to low
levels. Historical volatility measures the magnitude of daily changes in closing prices for a
commodity during a given time in the past. Based on rolling front-month contracts, the 30-day
historical volatility of U.S. natural gas futures prices was 27.9% on June 3, a significant decrease
from 73.5% a year ago. (Figure 10). However, the May 2020 historical volatility was unusually
high as a result of COVID-19-related disruptions, and historical volatility tends to be low around
May because of less demand for natural gas as a fuel for heating or cooling. The previous five-
year (2015–19) average historical volatility for the first trading day of June was 35.7%. This year,
historical volatility has been even lower so far than the seasonal average. Prices have hovered
within a somewhat narrow range around $3.00/MMBtu, likely because of stable U.S. production
and relatively stable U.S. consumption as a result of slightly below-average cooling demand
during May.
International natural gas prices: International LNG spot prices often reach yearly lows in May,
but this year they have climbed to the high prices typically seen in winter months. The Japan-
Korea Marker (JKM) price exceeded $10/MMBtu this May, compared with May 2019 and 2020
averages near $5/MMBtu and $2/MMBtu, respectively. The Title Transfer Facility (TTF) and
National Balancing Point (NBP) prices in Europe have shown similar trends (Figure 11). In Asia,
efforts to build stocks in anticipation of demand for summer electricity and to prepare for
heating demand next winter has increased demand for LNG imports and supported high prices.
Because LNG stocks in Asia have been lower than usual this year as a result of significant draws

during the extremely cold winter, demand in Asia for LNG imports has been much greater than
usual. In Europe, the coldest April in nearly a century and low inventories also supported higher
global demand and higher prices for LNG. Because of this strong global demand for LNG, we
forecast that U.S. LNG exports will continue to be high and average more than 9.0 Bcf/d during
the remainder of 2021.

Notable forecast changes
• We forecast Brent and WTI crude oil spot prices will average $65/b and $62/b,
respectively, in 2021. Both of these forecasts are $3/b higher than forecast in the May
STEO. The higher forecasts reflect the incorporation of higher-than-forecast actual
prices during May, along with our expectation that crude oil markets will be in balance
through much of the second half of the year, limiting downward price pressures.
However, we expect that Brent crude oil prices will decline to $60/b on average in 2022
as global oil supply begins to outpace global oil demand.
• We expect global oil inventories will build by 0.5 million b/d in 2022, compared with our
expectation of generally unchanged inventories in the May STEO. Our forecast of
inventory growth is the result of our expectation of higher global oil supply in 2022. We
raised expectations of supply growth across several key producers in the June STEO
including OPEC, China, and Mexico.
• We forecast U.S. coal production to total 600 MMst in 2021, up 18 MMst (3%) from last
month’s STEO. High U.S. coal production in this forecast is the result of our expectation
of higher inventory levels and more exports compared with the May STEO.
This report was prepared by the U.S. Energy Information Administration (EIA), the statistical
and analytical agency within the U.S. Department of Energy. By law, EIA's data, analyses, and
forecasts are independent of approval by any other officer or employee of the United States
Government. The views in this report therefore should not be construed as representing
those of the U.S. Department of Energy or other federal agencies.

Short-Term Energy Outlook
Chart Gallery
June 8, 2021
U.S. Energy Information Administration Independent Statistics & Analysis www.eia.gov
West Texas Intermediate (WTI) crude oil price and NYMEX confidence intervals
dollars per barrel
120
95% NYMEX
West Texas futures price
100 confidence
Intermediate (WTI) spot price
interval
80 upper bound
60
STEO forecast
40 NYMEX
futures price
20 95% NYMEX
futures price
0 confidence
2016 2017 2018 2019 2020 2021 2022 interval
Note: Confidence interval derived from options market information for the five trading days ending Jun
3, 2021. Intervals not calculated for months with sparse trading in near-the-money options contracts.
Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, June 2021,
CME Group, Bloomberg, L.P., and Refinitiv an LSEG Business
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1.50
1.50 -0.25
-0.25 -0.12
-0.12 -0.17
-0.17
1.00
1.00 -0.50
-0.50
-0.42
-0.42
0.50
0.50 -0.75
-0.75
0.00
0.00 -1.00
-1.00
2018
2018 2019
2019 2020
2020 2021 2022
2022 2019
2019 2020
2020 2021
2021 2022
2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Information Administration,
Administration, Short-Term
Short-Term Energy
Energy Outlook,
Outlook, June 2021,
June 2021, and
and Refinitiv
Refinitiv
an LSEG an LSEG Business
Business
U.S. diesel
U.S. dieseland
andcrude
crudeoiloil prices
prices Componentsofofannual
Components annual diesel
diesel
priceschanges
prices changes
dollars per
dollars pergallon
gallon dollars per
dollars pergallon
gallon
4.50
4.50 monthly retail
monthly retail diesel
diesel 1.25
1.25
annual average
annual average diesel
diesel
Brent crude
Brent crudeoil
oilprice
price forecast
forecast
4.00
4.00 monthly Brent
monthly Brent crude
crudeoil
oil 1.00
1.00
Brent annual
Brent annual average
average wholesalemargin
wholesale margin 0.52
3.50
3.50 0.75
0.75 over crude
over crude
retail margin
retail margin
3.00
3.00 0.50
0.50 over wholesale
over wholesale
2.50
2.50 0.25
0.25
2.00
2.00 forecast
forecast 0.00
0.00
1.50
1.50 -0.25
-0.25 -0.13
-0.14
1.00
1.00 -0.50
-0.50
0.50
0.50 -0.75
-0.75
-0.50
0.00
0.00 -1.00
-1.00
2018
2018 2019
2019 2020
2020 2021
2021 2022
2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June and
June 2021, 2021, and
Refinitivan
Refinitiv anLSEG
LSEGBusiness
Business
Henry Hub natural gas price and NYMEX confidence intervals

dollars per million Btu
7
6
95% NYMEX
5 futures price
Henry Hub spot price confidence interval
4 upper bound
3 STEO forecast
NYMEX
2 futures price
1 95% NYMEX
futures price
0 confidence interval
2016 2017 2018 2019 2020 2021 2022 lower bound
Note: Confidence interval derived from options market information for the five trading days ending Jun 3,
2021. Intervals not calculated for months with sparse trading in near-the-money options contracts.
Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, June 2021,
CME Group, and Refinitiv an LSEG Business
U.S. natural gas prices

dollars per thousand cubic feet
20
forecast
18
16
14
12
10
8 monthly residential price
annual average residential
6 monthly Henry Hub spot price
Henry Hub annual average
4
2
0
2017 2018 2019 2020 2021 2022
Sources: U.S. Energy Information Administration, Short-Term Energy Outlook, June 2021, and Refinitiv
an LSEG Business
World liquid
World liquidfuels
fuelsproduction
productionand consumption
and balance
consumption balance
million barrelsper
million barrels perday
day
105
105
worldproduction
world production forecast
forecast
100
100
95
95 worldconsumption
world consumption
90
90
85
85
80
80
//
75
75
0 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4
2016 2017 2018 2019 2020 2021 2022

8
8
6
6
impliedstock
stock build
build
4
4 implied
2
2
0
0
-2
-2 impliedstock
implied stockdraw
draw
-4
-4
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
Estimated unplanned liquid fuels production outages among OPEC and non-
OPEC producers
million barrels per day
6
5 non-OPEC
other
United States
4 Canada
3 OPEC
Venezuela
2 Saudi Arabia
Iran
Kuwait
1 Iraq
Nigeria
0 Libya
Jan 2019 Jan 2020 Jan 2021
Source: U.S. Energy Information Administration, Short-Term Energy Outlook, June 2021
Worldliquid
World liquidfuels
fuelsconsumption
consumption Componentsofofannual
Components annual change
change
millionbarrels
million barrelsper
perday
day million barrels
million barrelsper
perday
day
105
105 10
10
world change
world change forecast
forecast
8
8 Organizationofof
Organization
100
100
Economic
Economic 5.4
5.4
6
6 Cooperationand
Cooperation and
95
95 Development(OECD)
(OECD) 3.6
3.6
4
4 Development
non-OECD
non-OECD
90
90 2
2 0.8
0.8
85
85 monthly history
monthly history 0
0
monthly forecast
monthly forecast
80
80 annual average
annual average -2
-2
-4
-4
75
75
-6
-6
70
70
-8
-8
//
65
65
0 -8.6
-8.6
-10
-10
2019 2020 2021 2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
Annual change in world liquid fuels consumption
8
forecast
6 5.4
3.6
4 world
other non-OECD
2 0.8 Middle East
0 India
China
-2 other OECD
-4 United States
-6
-8
-8.6
-10
2019 2020 2021 2022
Worldcrude
World crudeoil
oiland
andliquid
liquid fuels
fuels production
production Componentsofofannual
change
millionbarrels
million barrelsper
perday
day millionbarrels
million barrelsper
perday
day
105
105 8
8
OPEC countries
OPEC countries forecast
forecast
non-OPEC
non-OPEC
6
6 Eurasia 5.0
5.0
Eurasia
100
100 North America
North America
4
4 Latin America
Latin America 2.6
2.6
other non-OPEC
other non-OPEC
95
95 2
2 netchange
net change
0
0
90
90 -2
-2
monthly history
monthly history
-0.1
-0.1
monthly forecast
monthly forecast -4
-4
85
85
annual average
annual average
// -6
-6
-6.4
-6.4
80
0
80 -8
-8
2019 2020 2021 2022 2019 2020 2021 2022
2
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
World liquid
World liquidfuels
fuelsproduction
production World liquid
World liquidfuels
fuelsconsumption
consumption
million barrels
million barrelsper
perday
day million barrels
million barrelsper
perday
day
120
120 120
120
forecast
forecast forecast
forecast
100
100 100
100
non-OPEC
non-OPEC non-OECD
non-OECD
80
80 80
80
60
60 60
60
40
40 40
40
Organizationofofthe
the Organizationfor
Organization for
Organization EconomicCooperation
Cooperation
20
20 PetroleumExporting
Petroleum Exporting 20
20 Economic
Countries (OPEC) and Development (OECD)
00 00
2019
2019 2020
2020 2021
2021 2022
2022 2019
2019 2020
2020 2021
2021 2022
2022
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
Organization of the Petroleum Exporting Countries (OPEC)
surplus crude oil production capacity
7 forecast
6
5
2011-2020 average
4
0
2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022
Note: Black line represents 2011-2020 average (2.4 million barrels per day).
Organization for Economic Cooperation and Development (OECD)

commercial inventories of crude oil and other liquids
days of supply
100
90
80
70
60
forecast
50
monthly range from January 2016 - December 2020
//
40
30
0
Jan 2016 Jan 2017 Jan 2018 Jan 2019 Jan 2020 Jan 2021 Jan 2022
U.S. crude
U.S. crudeoil
oilproduction
change
millionbarrels
million barrelsper
perday
day millionbarrels
million barrelsper
perday
day
14
14 3.5
3.5
forecast
forecast
3.0 Federal
3.0 FederalGulf
Gulf ofofMexico
Mexico (GOM)
(GOM)
12
12
2.5
2.5 Lower48
Lower 48excluding
excludingGOM
GOM
Alaska
Alaska
10
10 2.0
2.0 net change
net change
1.5
1.5 1.28
1.28
8
8 monthly history
monthly history
monthly forecast
monthly forecast 1.0
1.0 0.71
0.71
6
6 0.5
0.5
annual average
annual average
4
4 0.0
0.0
-0.5
-0.5 -0.24
-0.24
2
2
-1.0
-1.0
-0.93
-0.93
0
0 -1.5
-1.5
2019 2020 2021 2022 2019 2020 2021 2022
22
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. commercial crude oil inventories
million barrels
600
forecast
575
550
525
500
475
450
425
400
375
350
325
300
//
275
U.S. crude
U.S. crudeoiloiland
andliquid
liquid fuels
fuels production
change
million barrels
million barrelsperperday
day millionbarrels
million barrelsper
perday
day
25
25 3.00
3.00
ethanol
ethanol forecast
forecast
and biodiesel
and biodiesel
natural gas
natural gas
20
20 2.00
2.00 1.71
1.71
plant liquids
plant liquids
crude oil
oil 1.23
crude
netchange
net change
15
15 1.00
1.00
total monthly
total monthly production
production
forecast
forecast
10
10 0.00
0.00
annual average
annual average
-0.10
-0.10
5
5 -1.00
-1.00
-0.72
-0.72
0
0 -2.00
-2.00
2019 2020 2021 2022 2019
2019 2020
2020 2021
2021 2022
2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. liquid
U.S. liquidfuels
fuelsproduct
product supplied
supplied Componentsofofannual
change
(consumption)
(consumption)
million barrels
million barrelsper
perday
day million barrels per day
30
30 3.00
3.00
motor gasoline
motor gasoline forecast
forecast
distillate fuel
distillate fuel
25
25 2.00
2.00 jet fuel
fuel
1.49
1.49
hydrocarbon
hydrocarbon gas gas
liquids
liquids 1.00
20
20 1.00
1.00 other fuels
other fuels
0.03
0.03
15
15 0.00
0.00
monthly history
monthly history
10
10 monthly forecast
monthly forecast -1.00
-1.00
annual average
annual average
5
5 -2.00
-2.00
-2.42
-2.42
0
0 -3.00
-3.00
2019 2020 2021 2022 2019 2020 2021 2022
022
2
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. gasoline and distillate inventories
million barrels
280
total motor gasoline inventory forecast
260
240
220
200
180
160
140
120
total distillate fuel inventory
100
80
60
U.S. net imports of crude oil and liquid fuels

10
forecast
8
6 crude oil
net imports
4
2 total
0 net imports
-2 petroleum
product and
-4 other liquids
-6 net imports
Jan 2015 Jan 2016 Jan 2017 Jan 2018 Jan 2019 Jan 2020 Jan 2021 Jan 2022
Note: Petroleum product and other liquids include: gasoline, distillate fuels, hydrocarbon
gas liquids, jet fuel, residual fuel oil, unfinished oils, other hydrocarbons/oxygenates, and
other oils.
U.S. natural
U.S. naturalgas
gasplant
plant liquids
liquids production
change
millionbarrels
million barrelsper
perday
day millionbarrels
million barrelsper
perday
day
7 0.75
0.75
forecast
forecast
0.46
0.46 0.47
0.47
6 0.50
0.50
0.34
0.34
5 0.25
0.25
0.08
0.08
4 monthly production
monthly production 0.00
0.00
monthly forecast
monthly forecast
net change
net change
3 annual average
annual average -0.25
-0.25 naturalgasoline
natural gasoline
butanes
butanes
//// propane
propane
00 ethane
ethane
2 -0.50
-0.50
2019 2020 2021 2022 2019
2019 2020
2020 2021
2021 2022
022
2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. hydrocarbon
U.S. hydrocarbongas gas liquids
liquids Componentsofofannual
change
productsupplied
product supplied(consumption)
(consumption)
million barrels per day millionbarrels
million barrelsper
perday
day
5
5 0.75
0.75
net change
change forecast
forecast
net
naturalgasoline
natural gasoline
4
4 0.50
0.50 ethane
ethane
propane
propane 0.28
0.28
butanes
butanes
3
3 0.25
0.25 0.13
0.13 0.06
0.06 0.12
0.12
2
2 monthly history
monthly history 0.00
0.00
monthly forecast
monthly forecast
1
1 annual average
annual average -0.25
-0.25
0
0 -0.50
-0.50
2019 2020 2021 2022 2019 2020 2021 2022
2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. net trade of hydrocarbon gas liquids (HGL)

0.5
forecast
net imports
0.0
net exports
-0.5
net trade
propane
-1.0 ethane
natural gasoline
-1.5 butanes
-2.0
-2.5
2000 2002 2004 2006 2008 2010 2012 2014 2016 2018 2020
U.S. commercial propane inventories

million barrels
125
forecast
100
75
50
25
0
Note: Excludes propylene.

U.S. marketed
U.S. marketednatural
natural gas
gas production
change
billion cubic
billion cubicfeet
feetper
perday
day billion cubic
billion cubic feet
feetper
perday
day
105
105 15
15
U.S.
U.S. non-Gulf
non-GulfofofMexico
Mexico forecast
forecast
U.S. Gulf
U.S. Gulfof
ofMexico
Mexico
100
100 net change
net change
9.6
9.6
10
10
95
95
90
90 5
5
monthly history
monthly history
monthly forecast
monthly forecast 1.9
1.9
85
85 0.5
0.5
annual average
annual average
0
0
80
80 -1.2
-1.2
//
0
75
75 -5
-5
2019
2019 2020
2020 2021
2021 2022
2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. natural
U.S. naturalgas
gasconsumption
change
billion cubic
billion cubicfeet
feetper
perday
day billion cubic
billion cubicfeet
feetper
perday
day
120
120 5
5
forecast
forecast
110
110 4
4
3
3 2.6
2.6
100
100
90
90 2
2
80
80 1
1
70
70 0
0
60
60 -1
-1 -0.4
-0.4 0.0
0.0
50
50 -2
-2
monthly history
monthly history net change
net change
40
40 -3
-3 industrial -1.9
industrial -1.9
monthly forecast
monthly forecast
30
30 -4
-4 electricpower
electric power
annual average
annual average residentialand
and
residential
20
20 -5
-5 commercial
commercial
10
10 -6
-6 other
other
00 -7
-7
2019 2020 2021 2022 2019 2020 2021 2022
22
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. natural
U.S. naturalgas
gasproduction, consumption,
production, andand
consumption, net net
imports
imports
billion cubicfeet
billion cubic feetper
perday
day
125
125
consumption
consumption forecast
forecast
100
100
75
75
50
50 production
production
25
25
net trade
net trade(imports
(importsminus
minus exports)
exports)
0
0
-25
-25
Q3 Q4
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4
2016 2017 2018
2018 2019
2019 2020
2020 2021
2021 2022
2022
30
30
20
20 net storage
net storagebuilds
builds
10
10
0
0
-10
-10
-20
-20 net storage
net storagewithdrawals
withdrawals
-30
-30
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. annual natural gas trade
billion cubic feet per day
10 forecast
gross imports
5 as liquefied
natural gas
by pipeline
0
net trade
-5
gross exports
by pipeline
-10 as liquefied
-2.0 natural gas
-15 -5.2
-7.5
-20 -10.9 -11.5

2018 2019 2020 2021 2022
U.S.
U.S. working
workingnatural gas
natural in in
gas storage
storage
billion cubic
billion cubicfeet
feet
5,000
5,000
storagelevel
storage level forecast
forecast
4,000
4,000
3,000
3,000
2,000
2,000
1,000
1,000
monthlyrange
monthly rangefrom
from January
January 2016
2016 - December
- December 20202020
0
0
Jan
Jan 2016
2016 Jan
Jan 2017
2017 Jan
Jan 2018
2018 Jan
Jan 2019
2019 Jan
Jan 2020
2020 Jan
Jan 2021
2021 Jan
Jan 2022
2022
Percentdeviation
Percent deviationfrom
from 2016
2016 - 2020
- 2020 average
average
50%
50%
forecast
forecast
25%
25%
0%
0%
-25%
-25%
-50%
-50%
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. coal
U.S. coalproduction
change
millionshort
million shorttons
tons millionshort
million shorttons
tons
80
80 150
150
forecast
forecast
Westernregion
Western region
70
70 100
100 Appalachianregion
Appalachian region
Interiorregion
region
61
61
Interior
60
60 50
50 net change
net change
5
50
50 0
0
40
40 -50
-50
-50
-50
30
30 monthly history
monthly history -100
-100
monthly forecast
monthly forecast
20
20 -150
-150
annual average
annual average
-167
-167
10
10 -200
-200
0
0 -250
-250
2018 2019 2020 2021 2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. coal
U.S. coalconsumption
change
million short
million shorttons
tons millionshort
million shorttons
tons
80
80 125
125
coke
coke plants
plants forecast
forecast
70
70 100
100 electricpower
electric power
retail and
retail and 73
73
75
75 other industry
other industry
60
60
50
50
50
50 25
25
40
40 0
0
-25
-25 -8
-8
30
30
monthly history
monthly history -50
-50
20
20
monthly forecast
monthly forecast -75
-75
10
10 annual average
annual average
-100
-100
-102
-102 -109
-109
00 -125
-125
2018
2018 2019
2019 2020
2020 2021
2021 2022
2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. electric power coal inventories

million short tons
250
forecast
225
200
175
150
125
100
75
50
25
0
U.S. electricity
U.S. electricityconsumption
change
billion kilowatthours
billion kilowatthours billion kilowatthours
monthly history
monthly history
450
450 300
300
monthly forecast
monthly forecast forecast
forecast
250 residential
residentialsales
sales
425
425 250
industrialsales
industrial sales
annual average
annual average
400
400 200
200 commercialand
commercial and
transportationsales
transportation sales
375
375 150
150 direct use
direct use
net change
net change
350
350 100
100 77
77
57
57
325
325 50
50
300
300 0
0
275
275 -50
-50
-49
-49
250
250 -100
-100
////
225
225 -150
-150
00 -153
-153
200
200 -200
-200
2018
2018 2019
2019 2020
2020 2021
2021 2022
2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. monthly
U.S. monthlyresidential
residential electricity
electricity Annualgrowth
Annual growthininresidential
residential electricity
electricity
price
price prices
prices
cents per
cents perkilowatthour
kilowatthour percent
percent
15.0
15.0 4%
4%
forecast
forecast
14.5
14.5
3%
3% 2.7%
14.0
14.0 2.3%
2.3%
13.5
13.5 2%
2%
1.4%
1.4% 1.3%
1.3%
13.0
13.0 1.1% 1.1%
1.1%
12.5
12.5 1%
1%
12.0
12.0
history
history 0%
0%
11.5
11.5
forecast
forecast -0.1%
-0.1%
11.0
11.0 -1%
-1%
-0.8%
-0.8%
10.5
10.5
//
0
10.0
10.0 -2%
-2%
2015 2016
2015 2016 2017
2017 2018
2018 2019
2019 2020 2021
2021 2022
2022 2015 2016 2017 2018 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. electricity
U.S. electricitygeneration
generationbyby fuel,
fuel, all all sectors
sectors
billion kilowatthours percentshare
percent share
forecast
forecast forecast
forecast
4,000
4,000 50%
50%
45%
45%
40%
40%
3,000
3,000
35%
35%
naturalgas
natural gas
30%
30%
2,000
2,000 coal
coal 25%
25%
20%
20%
nuclear 15%
15%
1,000
1,000 nuclear
renewables
renewables 10%
10%
(non-hydro) 5%
(non-hydro) 5%
hydropower
hydropower
0 0%
other source 0%
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. renewable
U.S. renewableenergy
energy supply
supply Components
Componentsofofannualannualchange
change
quadrillionBritish
quadrillion Britishthermal
thermal units
units quadrillionBritish
quadrillion Britishthermal
thermal units
units
14
14 1.25
1.25
forecast
forecast forecast
forecast
12
12 1.00
1.00 0.84
0.84
0.83
0.83
net change
net change
10
10 0.75
0.75 solar
solar
0.35
0.35
wind
wind
8
8 0.50
0.50 hydropower
hydropower
0.09
0.09 liquidbiofuels
liquid biofuels
6
6 0.25
0.25 geothermal
geothermal
wood biomass
wood biomass
0.00
0.00 wastebiomass
waste biomass
4
4
2
2 -0.25
-0.25
0
0 -0.50
-0.50
2018 2019 2020 2021 2022 2019 2020 2021 2022
Note: Hydropower
Note: Hydropowerexcludes
excludes pumped
pumped storage
storage generation.
generation. Liquid
Liquid biofuels
biofuels include
include ethanol
ethanol and biodiesel.
and biodiesel. Other
Other biomass
biomass includesincludes municipal
municipal waste
waste from fromsources,
biogenic biogeniclandfill
sources,
gas,landfill gas,
and other and other
non-wood non-wood waste.
waste.
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. annual
U.S. annualCO2
CO2emissions
emissions
byby source
source Componentsofofannual
change
millionmetric
million metrictons
tons million metric
million metrictons
tons
6,000
6,000 600
600
forecast
forecast naturalgas
natural gas forecast
forecast
5,500
5,500 total energy
total energy 500
500
petroleum
petroleum
5,000
5,000 400
400 coal
coal 293
293
4,500
4,500 300
300 net change
net change
200
200 91
91
4,000
4,000
100
100
3,500
3,500
0
0
3,000
3,000
petroleum -100
-100
2,500
2,500 petroleum
-200
-200 -135
-135
2,000
2,000 natural gas -300
-300
natural gas
1,500
1,500 -400
-400
1,000
1,000 coal -500
-500
500
500 coal -600
-600
-569
-569
0
0 -700
-700
2018 2019 2020 2021 2022 2019 2020 2021 2022
Source:U.S.
Source: U.S.Energy
Energy Information
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. annual energy expenditures

share of gross domestic product
12%
10%
forecast
8%
6%
4%
2%
0%
2002 2004 2006 2008 2010 2012 2014 2016 2018 2020 2022
U.S. summer
U.S. summercooling
cooling degree
degree days
days
population-weighted
population-weighted
400
400 1,600
1,600
2019
2019 warmer
warmer
350
350 2020
2020 1,400
1,400
cooler
cooler
300
300 2021
2021
1,200
1,200
2022
2022
250
250 1,000
1,000
2011-2020 average
2011-2020 average
200
200 800
800
150
150 600
600
100
100 400
400
50
50 200
200
0
0 0
0
April May June July August
August September
September totaltotal
summer
Note: EIA
Note: EIAcalculations
calculations based
based onon National
National Oceanic
Oceanic and and Atmospheric
Atmospheric Administration
Administration (NOAA)
(NOAA) data. summer
data. Projections
Projections reflect NOAA's
reflect NOAA's 14-16
14-16 month month outlook.
outlook.
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
U.S. winter
U.S. winterheating
heatingdegree
degree days
days
population-weighted
population-weighted
1,000
1,000 4,000
4,000
2018/19
2018/19 cooler
cooler
2019/20
2019/20
2020/21
2020/21
750
750 2021/22
2021/22 warmer
warmer 3,000
3,000
previous 10-winter
previous 10-winter average
average
500
500 2,000
2,000
250
250 1,000
1,000
0
0 0
0
October
October November
November December
December January
January February
February March
March total
total winter
winter
Note: EIA
Note: EIAcalculations
calculations based
based onon National
National Oceanic
Oceanic and and Atmospheric
Atmospheric Administration
Administration (NOAA)
(NOAA)
data. data. Projections
Projections reflect
reflect NOAA's NOAA's
14-16 month14-16 month outlook.
outlook.
Source:U.S.
Source: U.S.Energy
EnergyInformation
Short-Term Energy
Energy Outlook,
Outlook, June 2021
June 2021
Table 1. U.S. Energy Markets Summary
U.S. Energy Information Administration | Short-Term Energy Outlook - June 2021
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Energy Supply
Crude Oil Production (a)

(million barrels per day) ............................. 12.75 10.81 10.81 10.90 10.70 11.04 11.17 11.38 11.55 11.67 11.88 12.05 11.31 11.08 11.79
Dry Natural Gas Production

(billion cubic feet per day) .......................... 94.79 89.68 89.83 91.15 90.53 92.26 92.63 93.26 93.13 93.48 94.31 94.80 91.35 92.18 93.93
Coal Production
(million short tons) ..................................... 149 115 136 139 139 151 160 151 153 146 155 151 539 600 605
Energy Consumption
Liquid Fuels
(million barrels per day) ............................. 19.33 16.08 18.36 18.71 18.45 19.73 19.97 20.26 20.06 20.58 20.90 20.90 18.12 19.61 20.61
Natural Gas
(billion cubic feet per day) .......................... 99.31 70.84 76.83 86.08 99.22 70.70 73.94 87.78 98.81 70.99 74.72 87.09 83.25 82.85 82.85
Coal (b)
(million short tons) ..................................... 110 96 149 123 136 123 162 129 141 120 157 126 477 550 543
Electricity
(billion kilowatt hours per day) ................... 10.14 9.64 11.87 9.89 10.52 10.04 11.88 10.07 10.72 10.23 12.01 10.16 10.39 10.63 10.78
Renewables (c)
(quadrillion Btu) .......................................... 2.92 3.00 2.83 2.91 2.95 3.35 3.08 3.16 3.29 3.56 3.26 3.31 11.65 12.54 13.41
Total Energy Consumption (d)

(quadrillion Btu) .......................................... 25.10 20.63 23.42 23.79 24.83 22.77 24.06 24.70 25.56 23.30 24.51 24.95 92.94 96.36 98.31
Energy Prices
Crude Oil West Texas Intermediate Spot

(dollars per barrel) ...................................... 45.34 27.96 40.89 42.50 58.09 64.14 64.53 60.50 58.50 56.50 56.00 56.00 39.17 61.85 56.74
Natural Gas Henry Hub Spot

(dollars per million Btu) .............................. 1.91 1.71 2.00 2.53 3.56 2.86 2.92 2.96 3.08 2.84 2.87 2.93 2.03 3.07 2.93
Coal
(dollars per million Btu) .............................. 1.93 1.91 1.93 1.92 1.91 1.90 1.88 1.85 1.87 1.87 1.85 1.82 1.92 1.88 1.85
Macroeconomic
Real Gross Domestic Product

(billion chained 2012 dollars - SAAR) ........ 19,011 17,303 18,597 18,794 19,088 19,503 19,849 20,231 20,451 20,601 20,689 20,773 18,426 19,668 20,629
Percent change from prior year ................. 0.3 -9.0 -2.8 -2.4 0.4 12.7 6.7 7.6 7.1 5.6 4.2 2.7 -3.5 6.7 4.9
GDP Implicit Price Deflator

(Index, 2012=100) ...................................... 113.4 112.9 113.8 114.4 115.6 116.5 117.0 117.5 118.0 118.6 119.2 119.8 113.6 116.6 118.9
Percent change from prior year ................. 1.7 0.6 1.1 1.3 1.9 3.2 2.8 2.7 2.1 1.8 1.8 2.0 1.2 2.7 1.9
Real Disposable Personal Income

(billion chained 2012 dollars - SAAR) ........ 15,061 16,630 15,851 15,434 17,391 16,138 15,898 15,719 15,892 16,005 16,094 16,145 15,744 16,286 16,034
Percent change from prior year ................. 1.4 12.2 6.4 3.1 15.5 -3.0 0.3 1.8 -8.6 -0.8 1.2 2.7 5.8 3.4 -1.5
Manufacturing Production Index

(Index, 2012=100) ...................................... 104.4 89.3 100.1 103.1 103.4 105.0 107.0 109.7 111.4 112.4 112.7 113.0 99.2 106.3 112.4
Percent change from prior year ................. -2.0 -15.5 -5.5 -2.6 -0.9 17.5 6.9 6.5 7.7 7.0 5.3 2.9 -6.4 7.1 5.7
Weather
U.S. Heating Degree-Days ........................ 1,874 541 70 1,418 2,098 480 72 1,511 2,091 479 73 1,509 3,902 4,161 4,153
U.S. Cooling Degree-Days ........................ 71 395 935 122 50 398 871 99 46 407 864 99 1,524 1,418 1,416
(a) Includes lease condensate.
(b) Total consumption includes Independent Power Producer (IPP) consumption.
(c) Renewable energy includes minor components of non-marketed renewable energy that is neither bought nor sold, either directly or indirectly, as inputs to marketed energy.
EIA does not estimate or project end-use consumption of non-marketed renewable energy.
(d) The conversion from physical units to Btu is calculated using a subset of conversion factors used in the calculations of gross energy consumption in EIA’s Monthly Energy Review (MER).
Consequently, the historical data may not precisely match those published in the MER or the Annual Energy Review (AER).
(e) Refers to the refiner average acquisition cost (RAC) of crude oil.
- = no data available
Notes: EIA completed modeling and analysis for this report on Thursday June 3 2021.
The approximate break between historical and forecast values is shown with historical data printed in bold; estimates and forecasts in italics.
Prices are not adjusted for inflation.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Supply Monthly , DOE/EIA-0109;
Petroleum Supply Annual , DOE/EIA-0340/2; Weekly Petroleum Status Report , DOE/EIA-0208; Petroleum Marketing Monthly , DOE/EIA-0380; Natural Gas Monthly , DOE/EIA-0130;
Electric Power Monthly , DOE/EIA-0226; Quarterly Coal Report , DOE/EIA-0121; and International Petroleum Monthly , DOE/EIA-0520.
Minor discrepancies with published historical data are due to independent rounding.
Forecasts: EIA Short-Term Integrated Forecasting System. U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.
Weather forecasts from National Oceanic and Atmospheric Administration.
Table 2. Energy Prices
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Crude Oil (dollars per barrel)
West Texas Intermediate Spot Average .............................. 45.34 27.96 40.89 42.50 58.09 64.14 64.53 60.50 58.50 56.50 56.00 56.00 39.17 61.85 56.74
Brent Spot Average ............................................................. 49.97 29.52 42.97 44.34 61.12 67.44 68.03 64.00 62.00 60.00 60.00 60.00 41.69 65.19 60.49
U.S. Imported Average ........................................................ 43.76 26.33 39.90 40.64 54.93 62.30 62.60 58.50 56.25 54.25 53.50 53.50 37.26 59.94 54.29
U.S. Refiner Average Acquisition Cost ................................ 47.48 26.88 40.79 42.09 57.19 63.17 63.55 59.50 57.25 55.25 54.50 54.50 39.75 60.99 55.32
U.S. Liquid Fuels (cents per gallon)
Refiner Prices for Resale
Gasoline .......................................................................... 153 104 137 133 180 213 207 182 174 185 186 174 133 196 180
Diesel Fuel ....................................................................... 160 97 124 133 178 201 206 196 190 186 187 187 129 196 188
Fuel Oil ............................................................................ 160 87 113 121 162 186 198 193 186 176 176 178 125 186 182
Refiner Prices to End Users
Jet Fuel ............................................................................ 165 85 116 125 163 188 197 189 187 184 184 185 131 186 185
No. 6 Residual Fuel Oil (a) ............................................... 176 93 116 119 162 155 152 143 136 134 130 130 125 153 132
Retail Prices Including Taxes
Gasoline Regular Grade (b) .............................................. 241 194 218 215 256 296 289 262 251 265 265 256 218 277 259
Gasoline All Grades (b) .................................................... 251 203 227 224 265 305 301 275 264 278 278 270 227 287 273
On-highway Diesel Fuel ................................................... 289 243 243 246 290 317 313 307 298 290 293 295 255 307 294
Heating Oil ....................................................................... 280 200 214 230 272 287 307 322 312 287 273 274 244 293 293
Natural Gas
Henry Hub Spot (dollars per thousand cubic feet) ................ 1.98 1.77 2.07 2.63 3.70 2.97 3.03 3.08 3.20 2.95 2.98 3.04 2.11 3.19 3.05
Henry Hub Spot (dollars per million Btu) ............................. 1.91 1.71 2.00 2.53 3.56 2.86 2.92 2.96 3.08 2.84 2.87 2.93 2.03 3.07 2.93
U.S. Retail Prices (dollars per thousand cubic feet)
Industrial Sector ............................................................... 3.52 2.85 2.88 3.77 5.74 3.88 4.00 4.28 4.55 3.94 3.83 4.15 3.29 4.49 4.14
Commercial Sector ........................................................... 7.13 7.63 8.49 7.53 7.56 8.29 8.91 7.91 7.68 8.09 8.47 7.54 7.48 7.94 7.79
Residential Sector ............................................................ 9.46 11.89 17.65 10.60 9.80 12.90 17.41 10.63 9.63 12.57 17.25 10.49 10.83 11.01 10.88
U.S. Electricity
Power Generation Fuel Costs (dollars per million Btu)
Coal ................................................................................. 1.93 1.91 1.93 1.92 1.91 1.90 1.88 1.85 1.87 1.87 1.85 1.82 1.92 1.88 1.85
Natural Gas ..................................................................... 2.39 2.08 2.26 2.87 7.34 3.10 3.08 3.28 3.62 3.04 3.01 3.24 2.39 4.09 3.21
Residual Fuel Oil (c) ......................................................... 12.15 6.65 8.85 8.90 11.11 12.79 12.66 12.00 11.89 12.19 11.39 11.17 9.15 12.10 11.65
Distillate Fuel Oil .............................................................. 13.27 8.39 10.37 10.54 13.66 15.57 15.94 15.33 14.93 14.59 14.53 14.61 10.73 14.87 14.70
Retail Prices (cents per kilowatthour)
Industrial Sector ............................................................... 6.38 6.63 7.08 6.53 7.15 7.03 7.19 6.59 6.93 7.02 7.20 6.59 6.66 6.99 6.94
Commercial Sector ........................................................... 10.33 10.63 10.97 10.62 11.11 10.94 11.40 10.98 11.35 11.13 11.49 11.04 10.65 11.12 11.26
Residential Sector ............................................................ 12.90 13.24 13.35 13.25 13.09 13.50 13.75 13.64 13.47 13.72 13.83 13.66 13.20 13.50 13.68
(a) Average for all sulfur contents.
(b) Average self-service cash price.
(c) Includes fuel oils No. 4, No. 5, No. 6, and topped crude.
Prices are not adjusted for inflation; prices exclude taxes unless otherwise noted.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Marketing Monthly , DOE/EIA-0380;
Weekly Petroleum Status Report , DOE/EIA-0208; Natural Gas Monthly , DOE/EIA-0130; Electric Power Monthly , DOE/EIA-0226; and Monthly Energy Review , DOE/EIA-0035.
Natural gas Henry Hub and WTI crude oil spot prices from Reuter's News Service (http://www.reuters.com).
Forecasts: EIA Short-Term Integrated Forecasting System.
Table 3a. International Petroleum and Other Liquids Production, Consumption, and Inventories
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Supply (million barrels per day) (a)
OECD ................................................ 32.95 29.43 29.97 30.69 30.20 30.89 31.53 32.00 32.20 32.48 32.76 33.21 30.76 31.16 32.67
U.S. (50 States) .............................. 20.22 17.58 18.30 18.31 17.63 18.74 18.89 19.19 19.39 19.81 20.17 20.40 18.60 18.62 19.95
Canada ........................................... 5.65 4.92 4.95 5.55 5.65 5.26 5.74 5.77 5.81 5.78 5.80 5.83 5.27 5.61 5.80
Mexico ............................................ 2.00 1.94 1.91 1.90 1.93 1.95 1.92 1.89 1.83 1.80 1.77 1.73 1.94 1.92 1.78
Other OECD ................................... 5.08 4.99 4.81 4.94 4.99 4.93 4.98 5.15 5.17 5.10 5.02 5.25 4.95 5.01 5.13
Non-OECD ........................................ 67.69 63.02 61.06 62.10 62.63 64.44 67.55 68.09 67.83 69.21 69.84 69.70 63.46 65.70 69.16
OPEC .............................................. 33.50 30.72 28.65 30.00 30.35 30.90 33.30 34.12 34.26 34.13 34.16 34.20 30.71 32.18 34.19
Crude Oil Portion ......................... 28.28 25.65 23.63 24.88 25.08 25.64 27.97 28.75 28.67 28.67 28.67 28.67 25.60 26.87 28.67
Other Liquids (b) .......................... 5.22 5.07 5.02 5.12 5.27 5.26 5.33 5.38 5.59 5.46 5.49 5.53 5.11 5.31 5.52
Eurasia ............................................ 14.73 13.18 12.72 13.13 13.39 13.68 13.73 13.88 14.06 14.65 14.80 14.94 13.44 13.67 14.62
China ............................................... 4.96 4.91 4.95 4.90 5.05 5.04 5.01 5.06 5.05 5.08 5.08 5.13 4.93 5.04 5.08
Other Non-OECD ........................... 14.50 14.21 14.75 14.06 13.84 14.83 15.51 15.02 14.46 15.36 15.79 15.44 14.38 14.81 15.27
Total World Supply ............................ 100.64 92.45 91.04 92.79 92.83 95.33 99.08 100.10 100.03 101.70 102.60 102.91 94.22 96.86 101.82
Non-OPEC Supply ............................. 67.14 61.73 62.39 62.79 62.48 64.43 65.78 65.97 65.77 67.57 68.44 68.71 63.51 64.68 67.63
Consumption (million barrels per day) (c)

OECD ................................................ 45.26 37.40 42.12 42.80 42.29 43.90 45.11 45.96 45.51 45.29 46.20 46.37 41.90 44.33 45.85
U.S. (50 States) .............................. 19.33 16.08 18.36 18.71 18.45 19.73 19.97 20.26 20.06 20.58 20.90 20.90 18.12 19.61 20.61
U.S. Territories ............................... 0.17 0.15 0.16 0.17 0.20 0.18 0.18 0.19 0.20 0.18 0.19 0.20 0.16 0.19 0.19
Canada ........................................... 2.33 1.88 2.16 2.05 2.03 2.16 2.28 2.31 2.27 2.22 2.32 2.30 2.10 2.20 2.28
Europe ............................................ 13.33 11.01 12.87 12.51 11.96 12.75 13.41 13.38 13.05 13.21 13.57 13.27 12.43 12.88 13.28
Japan .............................................. 3.69 2.89 3.03 3.50 3.67 3.00 3.12 3.45 3.64 2.98 3.06 3.37 3.27 3.31 3.26
Other OECD ................................... 6.41 5.41 5.55 5.87 5.98 6.08 6.15 6.37 6.29 6.13 6.16 6.32 5.81 6.15 6.22
Non-OECD ........................................ 50.13 47.45 51.21 52.59 52.21 52.96 53.85 54.31 54.36 55.72 55.85 55.92 50.35 53.34 55.47
Eurasia ............................................ 4.86 4.48 5.28 5.17 4.92 5.00 5.39 5.23 5.05 5.13 5.54 5.39 4.95 5.14 5.28
Europe ............................................ 0.71 0.69 0.71 0.72 0.72 0.73 0.73 0.74 0.73 0.74 0.76 0.76 0.71 0.73 0.75
China ............................................... 13.89 14.08 14.65 15.11 15.03 15.59 15.30 15.59 15.89 16.11 15.78 16.02 14.43 15.38 15.95
Other Asia ....................................... 13.16 11.64 12.60 13.61 13.83 13.52 13.61 14.17 14.53 14.77 14.34 14.74 12.75 13.78 14.60
Other Non-OECD ........................... 17.53 16.55 17.98 17.99 17.71 18.12 18.81 18.58 18.16 18.97 19.43 19.00 17.51 18.31 18.89
Total World Consumption .................. 95.40 84.85 93.33 95.39 94.50 96.86 98.96 100.27 99.86 101.01 102.05 102.29 92.26 97.67 101.31
Total Crude Oil and Other Liquids Inventory Net Withdrawals (million barrels per day)
U.S. (50 States) ................................. -0.43 -1.68 0.49 0.89 0.48 0.39 -0.14 0.47 0.06 -0.53 0.03 0.42 -0.18 0.30 0.00
Other OECD ...................................... -0.50 -1.17 0.04 0.68 0.43 0.36 0.00 -0.10 -0.07 -0.05 -0.18 -0.33 -0.23 0.17 -0.16
Other Stock Draws and Balance ....... -4.32 -4.75 1.77 1.03 0.77 0.78 0.01 -0.21 -0.16 -0.11 -0.40 -0.72 -1.55 0.34 -0.35
Total Stock Draw ............................ -5.25 -7.60 2.30 2.60 1.67 1.53 -0.12 0.17 -0.17 -0.69 -0.55 -0.62 -1.96 0.80 -0.51
End-of-period Commercial Crude Oil and Other Liquids Inventories (million barrels)
U.S. Commercial Inventory ............... 1,321 1,453 1,422 1,344 1,302 1,284 1,297 1,258 1,257 1,309 1,309 1,280 1,344 1,258 1,280
OECD Commercial Inventory ............ 2,963 3,201 3,166 3,026 2,945 2,895 2,907 2,877 2,883 2,939 2,956 2,957 3,026 2,877 2,957
(a) Supply includes production of crude oil (including lease condensates), natural gas plant liquids, biofuels, other liquids, and refinery processing gains.
(b) Includes lease condensate, natural gas plant liquids, other liquids, and refinery processing gain. Includes other unaccounted-for liquids.
(c) Consumption of petroleum by the OECD countries is synonymous with "petroleum product supplied," defined in the glossary of the EIA Petroleum Supply Monthly ,
DOE/EIA-0109. Consumption of petroleum by the non-OECD countries is "apparent consumption," which includes internal consumption, refinery fuel and loss, and bunkering.
OECD = Organization for Economic Cooperation and Development: Australia, Austria, Belgium, Canada, Chile, the Czech Republic, Denmark, Estonia, Finland,
France, Germany, Greece, Hungary, Iceland, Ireland, Israel, Italy, Japan, Latvia, Lithuania, Luxembourg, Mexico, the Netherlands, New Zealand, Norway,
Poland, Portugal, Slovakia, Slovenia, South Korea, Spain, Sweden, Switzerland, Turkey, the United Kingdom, the United States.
OPEC = Organization of the Petroleum Exporting Countries: Algeria, Angola, Congo (Brazzaville), Equatorial Guinea, Gabon, Iran, Iraq, Kuwait, Libya, Nigeria, Saudi Arabia,
the United Arab Emirates, Venezuela.
Historical data: Latest data available from Energy Information Administration international energy statistics.
Table 3b. Non-OPEC Petroleum and Other Liquids Production (million barrels per day)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
North America ....................................................... 27.87 24.44 25.16 25.76 25.21 25.95 26.56 26.85 27.03 27.39 27.74 27.96 25.81 26.15 27.53
Canada .................................................................... 5.65 4.92 4.95 5.55 5.65 5.26 5.74 5.77 5.81 5.78 5.80 5.83 5.27 5.61 5.80
Mexico ..................................................................... 2.00 1.94 1.91 1.90 1.93 1.95 1.92 1.89 1.83 1.80 1.77 1.73 1.94 1.92 1.78
United States ........................................................... 20.22 17.58 18.30 18.31 17.63 18.74 18.89 19.19 19.39 19.81 20.17 20.40 18.60 18.62 19.95
Central and South America ................................. 6.01 6.05 6.63 5.89 5.61 6.55 7.18 6.71 6.13 7.06 7.54 7.21 6.15 6.52 6.99
Argentina ................................................................. 0.69 0.60 0.64 0.62 0.63 0.69 0.70 0.69 0.71 0.76 0.75 0.73 0.64 0.68 0.74
Brazil ....................................................................... 3.44 3.89 4.29 3.52 3.23 4.12 4.66 4.20 3.56 4.51 4.90 4.46 3.79 4.06 4.36
Colombia .................................................................. 0.90 0.78 0.77 0.79 0.78 0.79 0.80 0.80 0.84 0.76 0.77 0.80 0.81 0.79 0.79
Ecuador ................................................................... 0.54 0.36 0.52 0.51 0.51 0.52 0.52 0.53 0.53 0.53 0.53 0.53 0.48 0.52 0.53
Other Central and S. America .................................. 0.45 0.42 0.41 0.45 0.47 0.44 0.49 0.49 0.49 0.50 0.59 0.69 0.43 0.47 0.57
Europe ................................................................... 4.44 4.34 4.16 4.30 4.38 4.33 4.37 4.55 4.56 4.50 4.42 4.66 4.31 4.40 4.53
Norway .................................................................... 2.05 2.00 1.96 2.02 2.11 2.08 2.12 2.23 2.24 2.19 2.21 2.34 2.01 2.13 2.25
United Kingdom ....................................................... 1.18 1.15 0.99 1.07 1.06 1.01 1.00 1.06 1.06 1.04 0.94 1.04 1.10 1.03 1.02
Eurasia ................................................................... 14.73 13.18 12.72 13.13 13.39 13.68 13.73 13.88 14.06 14.65 14.80 14.94 13.44 13.67 14.62
Azerbaijan ................................................................ 0.76 0.69 0.66 0.69 0.74 0.71 0.71 0.75 0.77 0.79 0.76 0.79 0.70 0.73 0.78
Kazakhstan .............................................................. 2.06 1.86 1.71 1.81 1.87 1.89 1.88 1.93 1.95 2.00 1.96 2.01 1.86 1.89 1.98
Russia ..................................................................... 11.54 10.25 9.97 10.26 10.43 10.73 10.77 10.82 10.96 11.49 11.70 11.75 10.50 10.69 11.48
Turkmenistan ........................................................... 0.25 0.25 0.25 0.25 0.24 0.24 0.24 0.24 0.23 0.23 0.23 0.23 0.25 0.24 0.23
Other Eurasia ........................................................... 0.12 0.12 0.12 0.12 0.11 0.12 0.12 0.14 0.15 0.16 0.16 0.16 0.12 0.12 0.16
Middle East ............................................................ 3.16 3.13 3.09 3.13 3.16 3.17 3.21 3.22 3.26 3.25 3.25 3.24 3.13 3.19 3.25
Oman ....................................................................... 1.01 0.95 0.92 0.95 0.96 0.96 1.01 1.02 1.03 1.03 1.03 1.03 0.96 0.99 1.03
Qatar ....................................................................... 1.84 1.87 1.88 1.88 1.90 1.91 1.92 1.92 1.93 1.93 1.93 1.93 1.87 1.91 1.93
Asia and Oceania ................................................. 9.44 9.16 9.21 9.18 9.34 9.31 9.31 9.33 9.34 9.33 9.30 9.31 9.25 9.32 9.32
Australia ................................................................... 0.49 0.50 0.50 0.49 0.48 0.51 0.51 0.50 0.50 0.50 0.49 0.48 0.49 0.50 0.49
China ....................................................................... 4.96 4.91 4.95 4.90 5.05 5.04 5.01 5.06 5.05 5.08 5.08 5.13 4.93 5.04 5.08
India ......................................................................... 0.96 0.90 0.92 0.92 0.92 0.92 0.92 0.91 0.92 0.91 0.90 0.90 0.92 0.92 0.91
Indonesia ................................................................. 0.91 0.89 0.87 0.88 0.89 0.88 0.87 0.86 0.87 0.86 0.85 0.83 0.89 0.87 0.85
Malaysia .................................................................. 0.71 0.60 0.63 0.64 0.65 0.64 0.64 0.64 0.64 0.63 0.62 0.61 0.65 0.64 0.63
Vietnam ................................................................... 0.25 0.24 0.23 0.23 0.23 0.22 0.22 0.22 0.22 0.21 0.21 0.21 0.23 0.22 0.21
Africa ..................................................................... 1.48 1.44 1.42 1.40 1.39 1.44 1.44 1.43 1.40 1.40 1.39 1.39 1.43 1.42 1.39
Egypt ....................................................................... 0.62 0.61 0.60 0.58 0.58 0.64 0.64 0.64 0.61 0.61 0.61 0.61 0.60 0.62 0.61
South Sudan ............................................................ 0.15 0.15 0.17 0.17 0.16 0.17 0.18 0.18 0.18 0.18 0.18 0.18 0.16 0.17 0.18
Total non-OPEC liquids ......................................... 67.14 61.73 62.39 62.79 62.48 64.43 65.78 65.97 65.77 67.57 68.44 68.71 63.51 64.68 67.63
OPEC non-crude liquids ...................................... 5.22 5.07 5.02 5.12 5.27 5.26 5.33 5.38 5.59 5.46 5.49 5.53 5.11 5.31 5.52
Non-OPEC + OPEC non-crude ............................ 72.36 66.81 67.41 67.91 67.75 69.69 71.11 71.35 71.36 73.03 73.93 74.24 68.62 69.99 73.15
Unplanned non-OPEC Production Outages ......... 0.18 0.92 0.72 0.55 0.68 - - - - - - - 0.59 - -
OPEC = Organization of the Petroleum Exporting Countries: Algeria, Angola, Congo (Brazzaville), Equatorial Guinea, Gabon, Iran, Iraq, Kuwait, Libya, Nigeria, Saudi Arabia,
the United Arab Emirates, Venezuela.
Supply includes production of crude oil (including lease condensates), natural gas plant liquids, biofuels, other liquids, and refinery processing gains.
Not all countries are shown in each region and sum of reported country volumes may not equal regional volumes.
Table 3c. OPEC Crude Oil (excluding condensates) Production (million barrels per day)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Crude Oil
Algeria ............................................................... 1.02 0.90 0.84 0.86 0.87 - - - - - - - 0.90 - -
Angola ............................................................... 1.35 1.27 1.19 1.13 1.11 - - - - - - - 1.23 - -
Congo (Brazzaville) .......................................... 0.29 0.29 0.28 0.26 0.28 - - - - - - - 0.28 - -
Equatorial Guinea ............................................. 0.13 0.12 0.11 0.11 0.11 - - - - - - - 0.11 - -
Gabon ............................................................... 0.19 0.18 0.15 0.17 0.16 - - - - - - - 0.17 - -
Iran .................................................................... 2.02 1.97 1.90 1.95 2.18 - - - - - - - 1.96 - -
Iraq .................................................................... 4.56 4.16 3.70 3.84 3.94 - - - - - - - 4.06 - -
Kuwait ............................................................... 2.77 2.48 2.25 2.30 2.33 - - - - - - - 2.45 - -
Libya ................................................................. 0.35 0.08 0.11 0.92 1.18 - - - - - - - 0.36 - -
Nigeria .............................................................. 1.72 1.55 1.44 1.44 1.31 - - - - - - - 1.54 - -
Saudi Arabia ..................................................... 9.80 9.28 8.77 9.01 8.49 - - - - - - - 9.21 - -
United Arab Emirates ....................................... 3.30 2.88 2.55 2.50 2.61 - - - - - - - 2.81 - -
Venezuela ......................................................... 0.77 0.50 0.35 0.40 0.52 - - - - - - - 0.50 - -
OPEC Total .................................................... 28.28 25.65 23.63 24.88 25.08 25.64 27.97 28.75 28.67 28.67 28.67 28.67 25.60 26.87 28.67
Other Liquids (a) ................................................ 5.22 5.07 5.02 5.12 5.27 5.26 5.33 5.38 5.59 5.46 5.49 5.53 5.11 5.31 5.52
Total OPEC Supply ............................................ 33.50 30.72 28.65 30.00 30.35 30.90 33.30 34.12 34.26 34.13 34.16 34.20 30.71 32.18 34.19
Crude Oil Production Capacity

Middle East ....................................................... 25.61 26.02 26.06 26.22 26.55 26.89 27.18 27.38 27.38 27.39 27.39 27.39 25.98 27.00 27.39
Other ................................................................. 5.82 5.60 5.48 6.33 6.73 6.63 6.47 6.14 6.05 6.05 6.05 6.05 5.81 6.49 6.05
OPEC Total .................................................... 31.43 31.63 31.54 32.56 33.28 33.51 33.65 33.52 33.44 33.43 33.44 33.45 31.79 33.49 33.44
Surplus Crude Oil Production Capacity

Middle East ....................................................... 3.15 5.27 6.90 6.62 7.00 6.82 5.10 4.68 4.68 4.69 4.69 4.69 5.49 5.89 4.69
Other ................................................................. 0.00 0.71 1.02 1.06 1.19 1.05 0.57 0.09 0.08 0.08 0.08 0.08 0.70 0.72 0.08
OPEC Total .................................................... 3.15 5.98 7.92 7.68 8.19 7.87 5.67 4.77 4.76 4.77 4.77 4.78 6.19 6.61 4.77
Unplanned OPEC Production Outages .......... 3.72 4.18 4.35 3.45 2.73 - - - - - - - 3.92 - -
(a) Includes lease condensate, natural gas plant liquids, other liquids, refinery processing gain, and other unaccounted-for liquids.
OPEC = Organization of the Petroleum Exporting Countries: Iran, Iraq, Kuwait, Saudi Arabia, and the United Arab Emirates (Middle East); Algeria, Angola, Congo (Brazzaville), Equatorial Guinea,
Gabon, Libya, Nigeria, and Venezuela (Other).
Forecasts are not published for individual OPEC countries.
Table 3d. World Petroleum and Other Liquids Consumption (million barrels per day)
2020 2021 2022
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
North America ........................................................ 23.64 19.44 22.12 22.45 22.20 23.75 24.12 24.46 24.15 24.64 25.05 25.05 21.91 23.64 24.72
Canada .................................................................... 2.33 1.88 2.16 2.05 2.03 2.16 2.28 2.31 2.27 2.22 2.32 2.30 2.10 2.20 2.28
Mexico ..................................................................... 1.97 1.48 1.59 1.68 1.71 1.85 1.86 1.88 1.81 1.83 1.82 1.83 1.68 1.83 1.83
United States ........................................................... 19.33 16.08 18.36 18.71 18.45 19.73 19.97 20.26 20.06 20.58 20.90 20.90 18.12 19.61 20.61
Central and South America ................................. 6.14 5.61 6.04 6.32 6.14 6.36 6.52 6.53 6.39 6.58 6.72 6.73 6.03 6.39 6.61
Brazil ....................................................................... 2.89 2.67 2.97 3.06 2.93 3.05 3.17 3.16 3.04 3.15 3.26 3.26 2.90 3.08 3.18
Europe ................................................................... 14.04 11.70 13.59 13.23 12.68 13.48 14.14 14.11 13.78 13.96 14.33 14.04 13.14 13.61 14.03
Eurasia ................................................................... 4.86 4.48 5.28 5.17 4.92 5.00 5.39 5.23 5.05 5.13 5.54 5.39 4.95 5.14 5.28
Russia ..................................................................... 3.65 3.33 4.04 3.92 3.71 3.82 4.14 3.97 3.80 3.92 4.25 4.10 3.74 3.91 4.02
Middle East ............................................................ 7.91 7.43 8.44 8.06 7.90 8.09 8.71 8.26 7.98 8.59 8.99 8.35 7.96 8.24 8.48
Asia and Oceania ................................................. 34.64 32.14 33.80 35.87 36.36 35.84 35.81 37.22 38.04 37.64 37.01 38.14 34.11 36.31 37.71
China ....................................................................... 13.89 14.08 14.65 15.11 15.03 15.59 15.30 15.59 15.89 16.11 15.78 16.02 14.43 15.38 15.95
Japan ....................................................................... 3.69 2.89 3.03 3.50 3.67 3.00 3.12 3.45 3.64 2.98 3.06 3.37 3.27 3.31 3.26
India ......................................................................... 4.63 3.77 4.17 4.93 5.00 4.46 4.54 4.92 5.16 5.25 4.91 5.23 4.37 4.73 5.14
Africa ..................................................................... 4.18 4.05 4.07 4.29 4.31 4.34 4.27 4.46 4.47 4.48 4.41 4.59 4.15 4.35 4.49
Total OECD Liquid Fuels Consumption ............... 45.26 37.40 42.12 42.80 42.29 43.90 45.11 45.96 45.51 45.29 46.20 46.37 41.90 44.33 45.85
Total non-OECD Liquid Fuels Consumption ........ 50.13 47.45 51.21 52.59 52.21 52.96 53.85 54.31 54.36 55.72 55.85 55.92 50.35 53.34 55.47
Total World Liquid Fuels Consumption ............... 95.40 84.85 93.33 95.39 94.50 96.86 98.96 100.27 99.86 101.01 102.05 102.29 92.26 97.67 101.31
Real Gross Domestic Product (a)

World Index, 2015 Q1 = 100 .................................... 110.3 107.6 112.4 113.5 115.7 117.1 118.7 119.6 122.4 123.1 123.8 124.3 110.9 117.8 123.4
Percent change from prior year ............................. -3.4 -6.2 -2.4 -1.8 4.9 8.9 5.6 5.4 5.8 5.1 4.3 3.9 -3.4 6.2 4.8
OECD Index, 2015 = 100 ......................................... 103.6 109.3 113.9
Percent change from prior year ............................. -4.8 5.5 4.2
Non-OECD Index, 2015 = 100 ................................. 116.0 123.6 130.0
Percent change from prior year ............................. -2.3 6.5 5.2
Nominal U.S. Dollar Index (b)

Index, 2015 Q1 = 100 .............................................. 111.7 115.9 111.5 108.3 106.8 108.0 108.0 108.6 108.9 108.8 108.6 108.4 111.9 107.8 108.7
Percent change from prior year ............................. 2.8 5.8 0.9 -1.9 -4.4 -6.8 -3.1 0.3 2.0 0.8 0.6 -0.2 1.9 -3.6 0.8
(a) GDP values for the individual countries in the indexes are converted to U.S. dollars at purchasing power parity and then summed to create values for the world, OECD, and non-OECD. Historical and
forecast data are from Oxford Economics, and quarterly values are reindexed to 2015 Q1 by EIA.
(b) Data source is the Board of Governors of the U.S. Federal Reserve System Nominal Broad Trade-Weighted Dollar Index. An increase in the index indicates an appreciation of the U.S. dollar against a
basket of currencies and a decrese in the index indicates a depreciation of the U.S. dollar against a basket of currencies. Historical and forecast data are from Oxford Economics, and quarterly values are
reindexed to 2015 Q1 by EIA.
OECD = Organization for Economic Cooperation and Development: Australia, Austria, Belgium, Canada, Chile, the Czech Republic, Denmark, Estonia, Finland,
France, Germany, Greece, Hungary, Iceland, Ireland, Israel, Italy, Japan, Latvia, Lithuania, Luxembourg, Mexico, the Netherlands, New Zealand, Norway,
Poland, Portugal, Slovakia, Slovenia, South Korea, Spain, Sweden, Switzerland, Turkey, the United Kingdom, the United States.
Table 4a. U.S. Petroleum and Other Liquids Supply, Consumption, and Inventories
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Supply (million barrels per day)
Crude Oil Supply
Domestic Production (a) .................................................. 12.75 10.81 10.81 10.90 10.70 11.04 11.17 11.38 11.55 11.67 11.88 12.05 11.31 11.08 11.79
Alaska .......................................................................... 0.48 0.41 0.44 0.46 0.46 0.41 0.40 0.44 0.43 0.39 0.39 0.43 0.45 0.42 0.41
Federal Gulf of Mexico (b) ............................................ 1.96 1.69 1.45 1.52 1.81 1.77 1.75 1.73 1.77 1.74 1.75 1.79 1.66 1.76 1.76
Lower 48 States (excl GOM) ........................................ 10.31 8.71 8.92 8.91 8.44 8.87 9.02 9.21 9.35 9.54 9.73 9.84 9.21 8.89 9.62
Crude Oil Net Imports (c) ................................................. 2.90 3.08 2.31 2.51 2.87 3.34 4.34 3.71 3.71 4.74 4.79 4.08 2.70 3.57 4.33
SPR Net Withdrawals ...................................................... 0.00 -0.23 0.15 0.04 0.00 0.19 0.00 0.05 0.05 0.05 0.03 0.11 -0.01 0.06 0.06
Commercial Inventory Net Withdrawals ........................... -0.55 -0.54 0.38 0.13 -0.18 0.39 0.20 -0.02 -0.27 0.00 0.27 -0.02 -0.14 0.10 0.00
Crude Oil Adjustment (d) ................................................. 0.67 0.03 0.38 0.32 0.42 0.40 0.23 0.16 0.22 0.22 0.23 0.16 0.35 0.30 0.21
Total Crude Oil Input to Refineries ...................................... 15.77 13.16 14.03 13.90 13.81 15.38 15.94 15.28 15.27 16.68 17.20 16.38 14.21 15.11 16.39
Other Supply
Refinery Processing Gain ................................................ 1.02 0.82 0.94 0.92 0.84 1.09 1.08 1.05 1.06 1.10 1.15 1.15 0.92 1.02 1.11
Natural Gas Plant Liquids Production .............................. 5.12 4.96 5.33 5.23 4.86 5.32 5.34 5.46 5.48 5.70 5.80 5.85 5.16 5.24 5.71
Renewables and Oxygenate Production (e) ..................... 1.11 0.80 1.03 1.07 1.03 1.08 1.10 1.08 1.08 1.11 1.12 1.12 1.01 1.07 1.11
Fuel Ethanol Production ............................................... 1.02 0.70 0.92 0.97 0.90 0.98 0.99 0.98 0.97 0.99 1.00 1.00 0.91 0.96 0.99
Petroleum Products Adjustment (f) .................................. 0.22 0.19 0.20 0.19 0.19 0.21 0.21 0.21 0.21 0.22 0.22 0.22 0.20 0.21 0.22
Product Net Imports (c) ................................................... -4.03 -2.94 -3.12 -3.32 -2.94 -3.13 -3.35 -3.27 -3.32 -3.66 -4.32 -4.16 -3.35 -3.18 -3.87
Hydrocarbon Gas Liquids ............................................. -1.99 -1.86 -1.86 -2.03 -2.02 -2.12 -2.18 -1.99 -2.04 -2.23 -2.27 -2.13 -1.94 -2.08 -2.17
Unfinished Oils ............................................................. 0.31 0.25 0.34 0.19 0.14 0.39 0.45 0.30 0.21 0.26 0.30 0.20 0.27 0.32 0.24
Other HC/Oxygenates .................................................. -0.10 -0.05 -0.04 -0.04 -0.08 -0.07 -0.06 -0.07 -0.08 -0.06 -0.06 -0.07 -0.06 -0.07 -0.07
Motor Gasoline Blend Comp. ........................................ 0.39 0.36 0.48 0.43 0.55 0.62 0.51 0.15 0.53 0.75 0.43 0.22 0.42 0.46 0.48
Finished Motor Gasoline ............................................... -0.72 -0.40 -0.58 -0.78 -0.66 -0.59 -0.60 -0.58 -0.77 -0.64 -0.76 -0.78 -0.62 -0.61 -0.74
Jet Fuel ........................................................................ -0.07 0.09 0.12 0.07 0.03 0.06 0.00 0.06 -0.04 0.01 0.10 0.16 0.05 0.04 0.06
Distillate Fuel Oil .......................................................... -1.19 -0.86 -1.15 -0.74 -0.49 -0.76 -0.85 -0.52 -0.55 -0.98 -1.28 -1.11 -0.98 -0.66 -0.98
Residual Fuel Oil .......................................................... -0.02 0.02 0.05 0.05 0.08 0.03 -0.01 0.05 -0.03 -0.07 -0.06 0.04 0.02 0.04 -0.03
Other Oils (g) ............................................................... -0.65 -0.49 -0.49 -0.48 -0.49 -0.69 -0.61 -0.66 -0.55 -0.68 -0.71 -0.70 -0.52 -0.61 -0.66
Product Inventory Net Withdrawals .................................. 0.12 -0.91 -0.04 0.71 0.66 -0.20 -0.34 0.45 0.28 -0.58 -0.28 0.34 -0.03 0.14 -0.06
Total Supply ....................................................................... 19.33 16.08 18.36 18.71 18.45 19.73 19.97 20.26 20.06 20.58 20.90 20.90 18.12 19.61 20.61
Consumption (million barrels per day)

Hydrocarbon Gas Liquids ................................................ 3.31 2.83 2.95 3.70 3.40 3.16 3.01 3.69 3.84 3.31 3.35 3.88 3.20 3.32 3.59
Unfinished Oils ................................................................ 0.14 0.11 0.01 0.03 0.05 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.07 0.01 0.00
Motor Gasoline ................................................................ 8.49 7.11 8.50 8.02 8.00 9.04 9.12 8.80 8.50 9.24 9.24 8.90 8.03 8.74 8.97
Fuel Ethanol blended into Motor Gasoline .................... 0.85 0.72 0.87 0.84 0.82 0.95 0.93 0.90 0.86 0.94 0.94 0.92 0.82 0.90 0.92
Jet Fuel ........................................................................... 1.56 0.69 0.97 1.09 1.13 1.33 1.47 1.50 1.50 1.63 1.78 1.79 1.08 1.36 1.68
Distillate Fuel Oil ............................................................. 3.97 3.51 3.70 3.92 3.97 4.07 4.04 4.23 4.28 4.22 4.15 4.25 3.78 4.08 4.22
Residual Fuel Oil ............................................................. 0.17 0.15 0.32 0.23 0.26 0.21 0.28 0.24 0.24 0.21 0.26 0.26 0.22 0.25 0.24
Other Oils (g) .................................................................. 1.68 1.68 1.91 1.71 1.63 1.91 2.05 1.79 1.72 1.96 2.12 1.83 1.75 1.85 1.91
Total Consumption ............................................................. 19.33 16.08 18.36 18.71 18.45 19.73 19.97 20.26 20.06 20.58 20.90 20.90 18.12 19.61 20.61
Total Petroleum and Other Liquids Net Imports ............. -1.13 0.14 -0.81 -0.81 -0.07 0.20 0.99 0.44 0.40 1.08 0.48 -0.09 -0.65 0.39 0.47
End-of-period Inventories (million barrels)

Commercial Inventory
Crude Oil (excluding SPR) ............................................... 482.5 531.9 497.3 485.3 501.9 466.1 447.3 449.4 473.5 473.2 447.9 449.5 485.3 449.4 449.5
Hydrocarbon Gas Liquids ................................................ 180.8 233.9 299.1 229.2 168.6 204.0 244.0 198.7 156.7 205.2 246.2 204.8 229.2 198.7 204.8
Unfinished Oils ................................................................ 100.1 91.9 81.4 78.2 93.3 89.5 89.8 83.0 93.1 90.8 89.8 83.1 78.2 83.0 83.1
Other HC/Oxygenates ..................................................... 33.6 26.2 25.2 29.9 29.1 25.5 25.3 25.6 27.7 26.4 26.1 26.4 29.9 25.6 26.4
Total Motor Gasoline ....................................................... 260.8 253.3 226.5 243.2 237.6 232.5 226.4 234.2 241.7 245.6 233.2 249.4 243.2 234.2 249.4
Finished Motor Gasoline ............................................... 22.6 23.5 22.4 25.3 20.3 23.4 22.2 24.4 24.1 23.9 23.1 26.2 25.3 24.4 26.2
Motor Gasoline Blend Comp. ........................................ 238.3 229.8 204.1 217.9 217.4 209.2 204.1 209.8 217.6 221.8 210.1 223.2 217.9 209.8 223.2
Jet Fuel ........................................................................... 39.9 41.5 40.1 38.6 39.0 41.8 43.8 40.5 39.9 40.7 43.0 39.9 38.6 40.5 39.9
Distillate Fuel Oil ............................................................. 126.7 175.4 171.7 160.4 145.5 135.3 138.5 140.9 130.2 134.7 141.5 142.4 160.4 140.9 142.4
Residual Fuel Oil ............................................................. 34.4 39.6 32.1 30.2 30.9 33.2 31.3 32.5 32.0 32.7 31.0 32.4 30.2 32.5 32.4
Other Oils (g) .................................................................. 62.0 59.2 48.6 49.3 55.8 56.3 50.7 53.0 62.0 59.8 50.5 52.0 49.3 53.0 52.0
Total Commercial Inventory ................................................ 1320.8 1452.8 1422.0 1344.3 1301.7 1284.3 1297.1 1257.7 1256.8 1309.2 1309.3 1279.8 1344.3 1257.7 1279.8
Crude Oil in SPR ................................................................ 635.0 656.0 642.2 638.1 637.8 620.1 620.1 615.8 611.5 607.3 604.6 594.9 638.1 615.8 594.9
(a) Includes lease condensate.
(b) Crude oil production from U.S. Federal leases in the Gulf of Mexico (GOM).
(c) Net imports equals gross imports minus gross exports.
(d) Crude oil adjustment balances supply and consumption and was previously referred to as "Unaccounted for Crude Oil."
(e) Renewables and oxygenate production includes pentanes plus, oxygenates (excluding fuel ethanol), and renewable fuels. Beginning in January 2021, renewable fuels includes biodiesel, renewable diesel,
renewable jet fuel, renewable heating oil, renewable naphtha and gasoline, and other renewable fuels. For December 2020 and prior, renewable fuels includes only biodiesel.
(f) Petroleum products adjustment includes hydrogen/oxygenates/renewables/other hydrocarbons, motor gasoline blend components, and finished motor gasoline.
(g) For net imports and inventories “Other Oils" includes aviation gasoline blend components, finished aviation gasoline, kerosene, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke,
asphalt and road oil, still gas, and miscellaneous products; for consumption “Other Oils” also includes renewable fuels except fuel ethanol.
SPR: Strategic Petroleum Reserve
HC: Hydrocarbons
Petroleum Supply Annual , DOE/EIA-0340/2; and Weekly Petroleum Status Report , DOE/EIA-0208.
Table 4b. U.S. Hydrocarbon Gas Liquids (HGL) and Petroleum Refinery Balances (million barrels per day, except inventories and utilization factor)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
HGL Production
Natural Gas Processing Plants
Ethane .............................................................. 1.93 1.92 2.14 2.06 1.87 2.16 2.12 2.25 2.37 2.47 2.52 2.60 2.01 2.10 2.49
Propane ............................................................ 1.72 1.61 1.68 1.70 1.62 1.69 1.70 1.71 1.67 1.72 1.73 1.74 1.68 1.68 1.72
Butanes ............................................................ 0.91 0.86 0.90 0.89 0.85 0.89 0.91 0.91 0.89 0.92 0.93 0.92 0.89 0.89 0.91
Natural Gasoline (Pentanes Plus) .................... 0.56 0.57 0.62 0.58 0.53 0.58 0.61 0.59 0.55 0.60 0.62 0.59 0.58 0.58 0.59
Refinery and Blender Net Production
Ethane/Ethylene ............................................... 0.01 0.01 0.01 0.01 0.00 0.00 0.01 0.00 0.00 0.01 0.01 0.01 0.01 0.00 0.01
Propane ............................................................ 0.29 0.24 0.27 0.27 0.25 0.29 0.31 0.31 0.30 0.31 0.32 0.31 0.26 0.29 0.31
Propylene (refinery-grade) ............................... 0.25 0.26 0.26 0.29 0.27 0.28 0.28 0.28 0.28 0.29 0.28 0.28 0.26 0.28 0.28
Butanes/Butylenes ........................................... -0.08 0.18 0.13 -0.19 -0.09 0.24 0.20 -0.19 -0.08 0.26 0.19 -0.19 0.01 0.04 0.04
Renewable Fuels and Oxygenate Plant Net Production
Natural Gasoline (Pentanes Plus) .................... -0.02 -0.01 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02 -0.02
HGL Net Imports

Ethane ................................................................. -0.30 -0.28 -0.27 -0.28 -0.35 -0.39 -0.38 -0.38 -0.43 -0.45 -0.45 -0.46 -0.28 -0.37 -0.45
Propane/Propylene .............................................. -1.12 -1.08 -1.08 -1.29 -1.11 -1.15 -1.20 -1.08 -1.08 -1.22 -1.24 -1.16 -1.14 -1.13 -1.18
Butanes/Butylenes .............................................. -0.30 -0.31 -0.36 -0.33 -0.35 -0.39 -0.40 -0.35 -0.35 -0.40 -0.40 -0.34 -0.32 -0.37 -0.37
Natural Gasoline (Pentanes Plus) ....................... -0.27 -0.19 -0.16 -0.14 -0.22 -0.19 -0.20 -0.18 -0.19 -0.17 -0.18 -0.16 -0.19 -0.20 -0.17
HGL Refinery and Blender Net Inputs

Butanes/Butylenes .............................................. 0.46 0.25 0.32 0.47 0.39 0.29 0.31 0.49 0.39 0.29 0.33 0.51 0.37 0.37 0.38
Natural Gasoline (Pentanes Plus) ....................... 0.15 0.10 0.15 0.13 0.14 0.16 0.17 0.16 0.17 0.18 0.18 0.18 0.13 0.16 0.18
HGL Consumption
Ethane/Ethylene .................................................. 1.70 1.65 1.66 1.81 1.54 1.83 1.73 1.90 2.02 2.03 2.07 2.12 1.70 1.75 2.06
Propane ............................................................... 1.09 0.59 0.58 0.99 1.09 0.61 0.57 1.07 1.13 0.54 0.55 1.02 0.81 0.83 0.81
Propylene (refinery-grade) .................................. 0.26 0.27 0.27 0.30 0.29 0.30 0.29 0.30 0.30 0.30 0.30 0.30 0.28 0.29 0.30
HGL Inventories (million barrels)

Ethane ................................................................. 52.6 49.5 62.5 74.9 65.8 65.9 63.5 65.1 57.4 56.9 56.0 59.0 59.9 65.1 57.3
Propane ............................................................... 60.3 75.3 100.7 70.4 39.3 58.7 78.9 65.9 43.1 65.5 87.7 74.4 70.4 65.9 74.4
Propylene (at refineries only) .............................. 1.4 1.5 1.5 1.5 1.1 1.5 1.8 1.8 1.7 1.9 2.1 1.9 1.5 1.8 1.9
Refinery and Blender Net Inputs

Crude OIl ............................................................. 15.77 13.16 14.03 13.90 13.81 15.38 15.94 15.28 15.27 16.68 17.20 16.38 14.21 15.11 16.39
Hydrocarbon Gas Liquids .................................... 0.61 0.35 0.47 0.60 0.53 0.45 0.48 0.65 0.56 0.47 0.51 0.69 0.51 0.53 0.56
Other Hydrocarbons/Oxygenates ....................... 1.12 0.95 1.11 1.08 1.05 1.17 1.19 1.16 1.15 1.22 1.21 1.19 1.06 1.14 1.19
Unfinished Oils .................................................... 0.05 0.23 0.44 0.20 -0.08 0.43 0.44 0.37 0.09 0.28 0.31 0.27 0.23 0.29 0.24
Motor Gasoline Blend Components .................... 0.41 0.48 0.85 0.46 0.71 0.93 0.67 0.26 0.56 0.81 0.65 0.30 0.55 0.64 0.58
Aviation Gasoline Blend Components ................ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Total Refinery and Blender Net Inputs ................... 17.97 15.17 16.90 16.23 16.01 18.36 18.71 17.72 17.63 19.46 19.89 18.83 16.57 17.71 18.96
Refinery Processing Gain .................................. 1.02 0.82 0.94 0.92 0.84 1.09 1.08 1.05 1.06 1.10 1.15 1.15 0.92 1.02 1.11
Refinery and Blender Net Production

Hydrocarbon Gas Liquids .................................... 0.47 0.69 0.67 0.36 0.44 0.82 0.79 0.40 0.50 0.86 0.80 0.41 0.55 0.62 0.64
Finished Motor Gasoline ..................................... 9.30 7.52 9.14 8.98 8.74 9.85 9.80 9.56 9.36 9.95 10.06 9.88 8.74 9.49 9.81
Jet Fuel ................................................................ 1.63 0.62 0.83 1.00 1.10 1.30 1.49 1.41 1.53 1.64 1.71 1.59 1.02 1.33 1.62
Distillate Fuel ....................................................... 4.95 4.83 4.72 4.46 4.29 4.65 4.85 4.71 4.68 5.20 5.45 5.31 4.74 4.63 5.16
Residual Fuel ...................................................... 0.23 0.18 0.19 0.15 0.19 0.21 0.27 0.21 0.26 0.29 0.30 0.24 0.19 0.22 0.27
Other Oils (a) ....................................................... 2.41 2.14 2.28 2.19 2.09 2.61 2.60 2.48 2.36 2.62 2.72 2.54 2.26 2.44 2.56
Total Refinery and Blender Net Production ............ 18.99 15.99 17.84 17.15 16.86 19.45 19.79 18.77 18.69 20.56 21.03 19.98 17.49 18.73 20.07
Refinery Distillation Inputs ................................ 16.36 13.65 14.55 14.32 14.25 15.82 16.30 15.67 15.60 16.86 17.40 16.63 14.72 15.52 16.63
Refinery Operable Distillation Capacity ........... 18.98 18.75 18.55 18.39 18.11 18.09 18.09 18.09 18.09 18.09 18.09 18.09 18.66 18.09 18.09
Refinery Distillation Utilization Factor .............. 0.86 0.73 0.78 0.78 0.79 0.87 0.90 0.87 0.86 0.93 0.96 0.92 0.79 0.86 0.92
(a) "Other Oils" includes aviation gasoline blend components, finished aviation gasoline, kerosene, petrochemical feedstocks, special naphthas, lubricants, waxes, petroleum coke, asphalt and road oil, still
gas, and miscellaneous products.
Petroleum Supply Annual , DOE/EIA-0340/2; Weekly Petroleum Status Report , DOE/EIA-0208.
Table 4c. U.S. Regional Motor Gasoline Prices and Inventories
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Prices (cents per gallon)
Refiner Wholesale Price .......................... 153 104 137 133 180 213 207 182 174 185 186 174 133 196 180
Gasoline Regular Grade Retail Prices Including Taxes
PADD 1 ................................................... 236 191 211 212 252 286 283 257 244 253 258 247 214 270 251
PADD 2 ................................................... 226 179 207 202 247 287 274 246 228 252 251 237 204 264 242
PADD 3 ................................................... 210 162 186 183 227 265 256 231 223 233 233 222 187 246 228
PADD 4 ................................................... 247 201 233 221 247 307 297 268 254 270 274 258 226 280 264
PADD 5 ................................................... 311 258 283 278 312 363 355 330 327 339 330 338 284 341 334
U.S. Average ........................................ 241 194 218 215 256 296 289 262 251 265 265 256 218 277 259
Gasoline All Grades Including Taxes 251 203 227 224 265 305 301 275 264 278 278 270 227 287 273
End-of-period Inventories (million barrels)

Total Gasoline Inventories
PADD 1 ................................................... 71.0 73.0 61.6 68.5 65.1 60.9 58.0 59.6 65.2 67.8 62.7 68.8 68.5 59.6 68.8
PADD 2 ................................................... 60.2 52.6 46.2 50.9 50.7 50.0 50.0 50.1 53.4 52.0 50.5 51.0 50.9 50.1 51.0
PADD 3 ................................................... 84.8 90.5 79.7 83.7 81.9 84.6 81.4 85.5 85.1 88.6 83.0 89.7 83.7 85.5 89.7
PADD 4 ................................................... 9.2 7.7 7.6 8.7 8.6 7.6 7.5 8.0 7.9 7.9 7.6 8.2 8.7 8.0 8.2
PADD 5 ................................................... 35.6 29.4 31.5 31.4 31.4 29.4 29.5 31.1 30.0 29.4 29.3 31.7 31.4 31.1 31.7
U.S. Total ............................................. 260.8 253.3 226.5 243.2 237.6 232.5 226.4 234.2 241.7 245.6 233.2 249.4 243.2 234.2 249.4
Finished Gasoline Inventories
U.S. Total ............................................. 22.6 23.5 22.4 25.3 20.3 23.4 22.2 24.4 24.1 23.9 23.1 26.2 25.3 24.4 26.2
Gasoline Blending Components Inventories
U.S. Total ............................................. 238.3 229.8 204.1 217.9 217.4 209.2 204.1 209.8 217.6 221.8 210.1 223.2 217.9 209.8 223.2
Regions refer to Petroleum Administration for Defense Districts (PADD).
See “Petroleum for Administration Defense District” in EIA’s Energy Glossary (http://www.eia.doe.gov/glossary/index.html) for a list of States in each region.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Petroleum Marketing Monthly , DOE/EIA-0380;
Petroleum Supply Monthly , DOE/EIA-0109; Petroleum Supply Annual , DOE/EIA-0340/2; and Weekly Petroleum Status Report , DOE/EIA-0208.
Table 5a. U.S. Natural Gas Supply, Consumption, and Inventories
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Supply (billion cubic feet per day)
Total Marketed Production ............... 102.27 96.83 97.55 98.70 97.55 99.36 99.76 100.44 100.30 100.68 101.58 102.10 98.83 99.29 101.17
Alaska ........................................... 0.96 0.88 0.88 0.98 1.02 0.78 0.72 0.88 0.92 0.78 0.72 0.87 0.92 0.85 0.82
Federal GOM (a) .......................... 2.72 2.22 1.72 1.73 2.27 2.24 2.14 2.06 2.06 1.98 1.87 1.84 2.09 2.18 1.94
Lower 48 States (excl GOM) ....... 98.58 93.74 94.95 95.99 94.27 96.33 96.89 97.50 97.32 97.92 98.98 99.39 95.81 96.26 98.41
Total Dry Gas Production ............... 94.79 89.68 89.83 91.15 90.53 92.26 92.63 93.26 93.13 93.48 94.31 94.80 91.35 92.18 93.93
LNG Gross Imports ......................... 0.24 0.12 0.09 0.09 0.15 0.18 0.18 0.20 0.32 0.18 0.18 0.20 0.13 0.18 0.22
LNG Gross Exports ......................... 7.92 5.52 3.91 8.78 9.27 9.83 8.68 9.73 9.96 8.83 8.33 9.78 6.53 9.38 9.22
Pipeline Gross Imports .................... 7.60 6.08 6.39 7.27 8.64 6.56 6.71 6.83 7.38 6.36 6.37 6.69 6.84 7.18 6.70
Pipeline Gross Exports ................... 8.15 7.17 8.09 8.18 8.30 8.42 9.30 9.49 9.32 8.66 9.38 9.38 7.90 8.88 9.18
Supplemental Gaseous Fuels ........ 0.19 0.17 0.15 0.18 0.18 0.17 0.18 0.18 0.18 0.18 0.18 0.18 0.17 0.18 0.18
Net Inventory Withdrawals .............. 12.74 -12.24 -7.68 5.36 17.19 -9.69 -7.50 6.68 17.19 -11.70 -9.26 4.49 -0.46 1.62 0.12
Total Supply ....................................... 99.49 71.12 76.78 87.09 99.12 71.24 74.22 87.92 98.90 71.01 74.08 87.19 83.61 83.07 82.74
Balancing Item (b) .............................. -0.18 -0.29 0.05 -1.01 0.11 -0.53 -0.28 -0.15 -0.09 -0.02 0.63 -0.10 -0.36 -0.21 0.11
Total Primary Supply .......................... 99.31 70.84 76.83 86.08 99.22 70.70 73.94 87.78 98.81 70.99 74.72 87.09 83.25 82.85 82.85
Consumption (billion cubic feet per day)

Residential ...................................... 22.83 8.20 3.82 16.00 25.59 7.14 3.68 16.97 24.59 7.68 3.73 16.79 12.70 13.29 13.15
Commercial ..................................... 13.93 5.82 4.36 10.31 14.81 6.67 4.73 10.87 14.83 6.24 4.65 10.79 8.60 9.25 9.11
Industrial .......................................... 24.65 20.62 21.15 23.83 24.08 22.31 21.82 24.82 25.47 22.78 22.05 24.53 22.56 23.25 23.70
Electric Power (c) ............................ 29.55 29.05 40.10 28.19 26.65 27.07 36.34 27.39 26.05 26.86 36.86 27.15 31.74 29.39 29.25
Lease and Plant Fuel ...................... 5.17 4.90 4.93 4.99 4.93 5.02 5.04 5.08 5.07 5.09 5.14 5.16 5.00 5.02 5.12
Pipeline and Distribution Use .......... 3.02 2.15 2.33 2.61 3.01 2.35 2.18 2.50 2.65 2.18 2.13 2.50 2.53 2.51 2.36
Vehicle Use ..................................... 0.16 0.10 0.13 0.13 0.14 0.15 0.15 0.15 0.16 0.16 0.16 0.16 0.13 0.15 0.16
Total Consumption ............................. 99.31 70.84 76.83 86.08 99.22 70.70 73.94 87.78 98.81 70.99 74.72 87.09 83.25 82.85 82.85
End-of-period Inventories (billion cubic feet)

Working Gas Inventory ................... 2,030 3,133 3,840 3,341 1,801 2,682 3,372 2,757 1,210 2,275 3,126 2,714 3,341 2,757 2,714
East Region (d) ............................ 385 655 890 763 313 521 778 546 71 376 647 454 763 546 454
Midwest Region (d) ...................... 472 747 1,053 918 395 621 941 749 181 482 862 732 918 749 732
South Central Region (d) ............. 857 1,221 1,313 1,155 760 1,037 1,076 975 609 904 1,000 959 1,155 975 959
Mountain Region (d) .................... 92 177 235 195 113 177 224 184 124 170 234 212 195 184 212
Pacific Region (d) ......................... 200 308 318 282 197 302 329 280 201 318 360 333 282 280 333
Alaska ........................................... 23 25 31 28 23 24 24 24 24 24 24 24 28 24 24
(a) Marketed production from U.S. Federal leases in the Gulf of Mexico.
(b) The balancing item represents the difference between the sum of the components of natural gas supply and the sum of components of natural gas demand.
(c) Natural gas used for electricity generation and (a limited amount of) useful thermal output by electric utilities and independent power producers.
(d) For a list of States in each inventory region refer to Weekly Natural Gas Storage Report, Notes and Definitions (http://ir.eia.gov/ngs/notes.html) .
LNG: liquefied natural gas.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Natural Gas Monthly , DOE/EIA-0130; and Electric Power Monthly ,
Table 5b. U.S. Regional Natural Gas Prices (dollars per thousand cubic feet)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Wholesale/Spot
Henry Hub Spot Price ......... 1.98 1.77 2.07 2.63 3.70 2.97 3.03 3.08 3.20 2.95 2.98 3.04 2.11 3.19 3.05
Residential Retail
New England ....................... 13.77 14.50 18.28 14.64 14.78 15.20 17.57 13.36 12.93 13.84 16.77 12.87 14.47 14.62 13.31
Middle Atlantic ..................... 10.77 11.85 17.85 11.77 10.41 12.54 16.94 10.96 10.06 12.41 17.07 11.14 11.76 11.21 11.19
E. N. Central ....................... 6.99 9.50 18.15 8.02 7.41 10.91 16.64 8.34 7.60 10.52 16.21 8.00 8.39 8.59 8.64
W. N. Central ...................... 6.85 9.89 17.26 8.66 7.59 10.90 17.09 9.13 7.87 10.72 16.82 8.90 8.48 8.90 9.06
S. Atlantic ........................... 12.12 15.52 24.15 14.20 12.12 17.41 22.96 12.61 11.22 16.35 22.47 12.35 14.23 13.62 13.05
E. S. Central ....................... 9.69 13.34 20.85 10.63 9.53 14.50 22.08 13.38 10.42 14.87 21.93 13.18 11.15 11.49 12.54
W. S. Central ...................... 8.52 14.22 20.83 11.67 9.32 14.10 20.58 11.69 8.78 14.20 20.13 11.29 11.40 11.64 11.24
Mountain ............................. 7.55 9.37 12.60 8.15 7.90 9.79 13.69 8.51 8.04 9.78 13.58 8.41 8.43 8.69 8.84
Pacific ................................. 13.41 14.47 14.50 13.70 14.32 14.66 15.06 13.77 13.87 14.52 15.22 14.11 13.82 14.30 14.22
U.S. Average ................... 9.46 11.89 17.65 10.60 9.80 12.90 17.41 10.63 9.63 12.57 17.25 10.49 10.83 11.01 10.88
Commercial Retail
New England ....................... 9.93 10.40 10.99 10.06 10.38 10.74 10.91 10.20 10.52 10.55 10.21 9.97 10.16 10.42 10.32
Middle Atlantic ..................... 7.91 7.00 6.78 7.53 7.87 7.69 7.06 7.48 7.84 7.62 7.12 7.57 7.50 7.62 7.63
E. N. Central ....................... 5.75 6.73 8.79 6.21 6.12 7.56 9.31 7.03 6.72 7.49 8.48 6.34 6.28 6.85 6.84
W. N. Central ...................... 5.43 6.53 8.12 6.55 6.38 7.29 8.87 7.20 7.02 7.49 8.71 6.85 6.14 6.94 7.15
S. Atlantic ........................... 8.51 9.21 9.55 8.88 8.79 9.74 9.99 8.80 8.36 9.09 9.33 8.29 8.87 9.09 8.57
E. S. Central ....................... 8.38 9.20 10.10 8.69 8.43 9.40 10.23 9.03 8.38 9.34 9.86 8.72 8.78 8.94 8.78
W. S. Central ...................... 5.99 7.18 8.13 7.46 7.01 7.49 8.57 7.91 7.05 7.49 7.91 7.17 6.92 7.55 7.28
Mountain ............................. 6.09 6.85 7.42 6.45 6.50 6.98 8.06 7.06 6.85 7.22 8.05 6.88 6.46 6.90 7.04
Pacific ................................. 9.58 9.30 9.59 9.70 10.50 10.39 10.34 9.49 9.32 9.09 9.48 9.06 9.57 10.14 9.22
U.S. Average ................... 7.13 7.63 8.49 7.53 7.56 8.29 8.91 7.91 7.68 8.09 8.47 7.54 7.48 7.94 7.79
Industrial Retail
New England ....................... 8.15 7.41 6.16 7.67 8.58 7.63 6.76 7.67 8.10 7.49 6.52 7.52 7.54 7.78 7.54
Middle Atlantic ..................... 7.43 6.76 7.00 7.61 7.70 7.24 7.32 7.50 8.05 7.74 7.55 7.88 7.28 7.50 7.89
E. N. Central ....................... 4.84 5.10 4.15 5.10 5.39 5.58 5.72 5.56 5.84 5.59 5.46 5.42 4.86 5.52 5.63
W. N. Central ...................... 3.97 3.30 3.15 4.13 5.54 4.34 4.45 4.93 5.19 4.47 4.31 4.78 3.68 4.87 4.72
S. Atlantic ........................... 4.15 3.70 3.72 4.56 5.05 4.74 4.89 5.09 5.27 4.66 4.57 4.83 4.06 4.95 4.86
E. S. Central ....................... 3.92 3.24 3.23 4.04 4.64 4.33 4.51 4.83 4.99 4.40 4.17 4.51 3.65 4.59 4.55
W. S. Central ...................... 2.19 1.92 2.19 2.89 5.75 3.06 3.32 3.30 3.35 3.14 3.17 3.21 2.31 3.73 3.22
Mountain ............................. 4.40 4.59 4.67 4.91 5.00 5.13 5.73 5.75 5.74 5.44 5.56 5.36 4.64 5.36 5.53
Pacific ................................. 7.46 6.28 6.18 7.23 8.30 7.27 7.22 7.10 7.09 6.53 6.72 6.72 6.86 7.45 6.78
U.S. Average ................... 3.52 2.85 2.88 3.77 5.74 3.88 4.00 4.28 4.55 3.94 3.83 4.15 3.29 4.49 4.14
Regions refer to U.S. Census divisions.
See "Census division" in EIA’s Energy Glossary (http://www.eia.doe.gov/glossary/index.html) for a list of States in each region.
Historical data: Latest data available from Energy Information Administration databases supporting the Natural Gas Monthly , DOE/EIA-0130.
Natural gas Henry Hub spot price from Reuter's News Service (http://www.reuters.com).
Table 6. U.S. Coal Supply, Consumption, and Inventories
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Supply (million short tons)
Production .................................................. 149.1 115.2 135.8 139.0 138.7 151.0 159.6 150.7 153.2 145.5 155.4 151.2 539.1 600.1 605.3
Appalachia ............................................... 39.7 29.3 33.9 35.5 34.8 37.3 35.6 35.7 38.9 39.7 37.3 38.4 138.3 143.5 154.4
Interior ..................................................... 25.8 19.2 23.2 22.3 22.4 25.1 28.1 27.3 28.5 27.3 28.3 27.8 90.4 102.9 111.9
Western ................................................... 83.6 66.7 78.8 81.2 81.5 88.6 95.9 87.7 85.8 78.5 89.7 85.0 310.3 353.7 339.0
Primary Inventory Withdrawals ................... 0.5 1.3 2.0 -0.9 0.3 0.2 2.2 -2.1 -1.4 -2.2 -0.9 -5.4 2.8 0.6 -9.9
Imports ....................................................... 1.3 1.1 1.3 1.3 1.1 0.9 1.2 1.2 1.0 1.0 1.3 1.3 5.1 4.5 4.6
Exports ....................................................... 20.0 14.8 15.3 19.1 20.7 18.6 18.7 22.6 28.5 19.2 19.5 25.0 69.1 80.6 92.2
Metallurgical Coal .................................... 11.7 9.0 10.2 11.3 10.3 8.9 11.5 12.4 15.9 11.1 12.6 13.6 42.1 43.1 53.2
Steam Coal ............................................. 8.3 5.8 5.1 7.8 10.4 9.7 7.2 10.2 12.5 8.1 6.8 11.5 27.0 37.5 39.0
Total Primary Supply ..................................... 130.9 102.9 123.8 120.3 119.5 133.6 144.3 127.2 124.4 125.1 136.3 122.1 477.9 524.6 507.8
Secondary Inventory Withdrawals ............... -16.6 -5.0 21.5 -3.3 20.3 -12.5 15.6 -0.6 14.3 -7.1 18.4 1.8 -3.5 22.9 27.4
Waste Coal (a) ........................................... 1.9 1.5 2.0 2.3 2.0 2.0 2.0 2.0 1.8 1.8 1.8 1.8 7.7 8.0 7.4
Total Supply .................................................. 116.2 99.4 147.3 119.3 141.8 123.1 162.0 128.6 140.5 119.8 156.5 125.7 482.1 555.5 542.6
Consumption (million short tons)

Coke Plants ................................................ 4.3 3.5 3.2 3.5 1.3 2.6 4.2 6.2 3.4 3.1 3.7 5.3 14.4 14.2 15.5
Electric Power Sector (b) ............................ 97.9 87.2 139.3 112.1 128.1 113.7 151.0 115.3 129.9 109.8 146.1 113.4 436.5 508.2 499.2
Retail and Other Industry ............................ 7.4 5.7 6.1 7.2 7.0 6.8 6.8 7.1 7.2 6.9 6.8 7.0 26.4 27.8 27.9
Residential and Commercial .................... 0.3 0.1 0.1 0.2 0.2 0.2 0.2 0.2 0.2 0.1 0.2 0.2 0.8 0.8 0.7
Other Industrial ........................................ 7.1 5.6 5.9 7.0 6.8 6.7 6.6 6.9 7.0 6.8 6.6 6.7 25.6 27.0 27.2
Total Consumption ....................................... 109.5 96.4 148.6 122.8 136.4 123.1 162.0 128.6 140.5 119.8 156.5 125.7 477.3 550.1 542.6
Discrepancy (c) 6.7 2.9 -1.3 -3.5 5.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.8 5.4 0.0
End-of-period Inventories (million short tons)

Primary Inventories (d) ............................... 30.8 29.5 27.5 28.5 28.1 27.9 25.8 27.9 29.3 31.5 32.5 37.8 28.5 27.9 37.8
Secondary Inventories ................................ 150.6 155.6 134.2 137.5 117.1 129.6 114.0 114.6 100.2 107.4 89.0 87.2 137.5 114.6 87.2
Electric Power Sector .............................. 145.2 150.4 129.1 132.7 111.8 124.2 108.4 109.2 95.1 102.1 83.6 82.0 132.7 109.2 82.0
Retail and General Industry ..................... 3.0 3.0 2.9 2.8 3.8 3.6 3.6 3.4 3.6 3.5 3.5 3.3 2.8 3.4 3.3
Coke Plants ............................................. 2.1 2.0 2.0 1.7 1.4 1.7 1.8 1.9 1.3 1.7 1.8 1.8 1.7 1.9 1.8
Commercial & Institutional …………… .... 0.2 0.2 0.2 0.3 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.3 0.2 0.2
Coal Market Indicators

Coal Miner Productivity
(Tons per hour) ........................................ 6.37 6.37 6.37 6.37 6.32 6.32 6.32 6.32 6.30 6.30 6.30 6.30 6.37 6.32 6.30
Total Raw Steel Production
(Million short tons per day) ....................... 0.268 0.174 0.197 0.224 0.246 0.256 0.270 0.304 0.289 0.251 0.251 0.260 0.216 0.269 0.263
Cost of Coal to Electric Utilities
(Dollars per million Btu) ........................... 1.93 1.91 1.93 1.92 1.91 1.90 1.88 1.85 1.87 1.87 1.85 1.82 1.92 1.88 1.85
(a) Waste coal includes waste coal and cloal slurry reprocessed into briquettes.
(b) Coal used for electricity generation and (a limited amount of) useful thermal output by electric utilities and independent power producers.
(c) The discrepancy reflects an unaccounted-for shipper and receiver reporting difference, assumed to be zero in the forecast period.
(d) Primary stocks are held at the mines and distribution points.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Quarterly Coal Report , DOE/EIA-0121; and Electric Power Monthly ,
Table 7a. U.S. Electricity Industry Overview
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Electricity Supply (billion kilowatthours)
Electricity Generation ........................ 966 933 1,148 962 989 970 1,136 970 998 986 1,148 979 4,009 4,063 4,110
Electric Power Sector (a) ................. 925 896 1,109 923 952 933 1,098 932 961 948 1,108 940 3,853 3,915 3,956
Industrial Sector (b) ......................... 38 34 36 36 34 33 34 34 34 34 37 35 143 135 140
Commercial Sector (b) .................... 3 3 4 3 3 3 4 3 3 3 4 3 13 13 14
Net Imports ...................................... 10 11 15 12 9 11 14 11 12 12 15 11 47 45 50
Total Supply ....................................... 976 944 1,163 973 998 981 1,149 980 1,010 998 1,162 990 4,056 4,108 4,160
Losses and Unaccounted for (c) ...... 53 67 71 63 51 68 57 54 45 67 57 54 254 229 225
Electricity Consumption (billion kilowatthours unless noted)

Retail Sales ........................................ 887 844 1,057 876 914 881 1,059 893 931 897 1,070 901 3,664 3,748 3,799
Residential Sector .......................... 340 334 453 334 379 342 442 340 381 347 446 344 1,462 1,503 1,518
Commercial Sector ......................... 314 293 360 309 305 307 366 317 313 314 370 319 1,276 1,294 1,316
Industrial Sector .............................. 231 216 242 231 229 231 250 235 235 235 252 236 920 945 959
Transportation Sector ..................... 2 1 2 2 2 2 2 2 2 2 2 2 7 6 6
Direct Use (d) .................................... 36 33 35 34 33 32 33 33 33 33 36 34 138 131 136
Total Consumption ........................... 923 877 1,092 910 947 913 1,093 926 964 931 1,105 935 3,802 3,879 3,935
Average residential electricity
usage per customer (kWh) ................ 2,496 2,451 3,326 2,451 2,740 2,472 3,199 2,455 2,726 2,477 3,187 2,456 10,723 10,867 10,847
End-of-period Fuel Inventories Held by Electric Power Sector

Coal (mmst) ....................................... 145.2 150.4 129.1 132.7 111.8 124.2 108.4 109.2 95.1 102.1 83.6 82.0 132.7 109.2 82.0
Residual Fuel (mmb) ......................... 8.3 8.5 8.2 8.3 8.0 8.2 8.3 8.6 8.1 8.1 8.2 8.6 8.3 8.6 8.6
Distillate Fuel (mmb) .......................... 16.5 16.5 17.0 16.8 15.9 15.9 15.8 16.1 16.0 15.9 15.9 16.2 16.8 16.1 16.2
Prices
Power Generation Fuel Costs (dollars per million Btu)
Coal ................................................ 1.93 1.91 1.93 1.92 1.91 1.90 1.88 1.85 1.87 1.87 1.85 1.82 1.92 1.88 1.85
Natural Gas .................................... 2.39 2.08 2.26 2.87 7.34 3.10 3.08 3.28 3.62 3.04 3.01 3.24 2.39 4.09 3.21
Residual Fuel Oil ............................ 12.15 6.65 8.85 8.90 11.11 12.79 12.66 12.00 11.89 12.19 11.39 11.17 9.15 12.10 11.65
Distillate Fuel Oil ............................. 13.27 8.39 10.37 10.54 13.66 15.57 15.94 15.33 14.93 14.59 14.53 14.61 10.73 14.87 14.70
Retail Prices (cents per kilowatthour)
Residential Sector .......................... 12.90 13.24 13.35 13.25 13.09 13.50 13.75 13.64 13.47 13.72 13.83 13.66 13.20 13.50 13.68
Commercial Sector ......................... 10.33 10.63 10.97 10.62 11.11 10.94 11.40 10.98 11.35 11.13 11.49 11.04 10.65 11.12 11.26
Industrial Sector .............................. 6.38 6.63 7.08 6.53 7.15 7.03 7.19 6.59 6.93 7.02 7.20 6.59 6.66 6.99 6.94
Wholesale Electricity Prices (dollars per megawatthour)
ERCOT North hub .......................... 23.41 24.03 34.12 26.41 616.34 26.15 16.02 19.59 23.78 21.99 20.40 20.66 26.99 169.52 21.71
CAISO SP15 zone .......................... 28.64 19.21 61.94 42.80 44.74 30.59 47.93 37.24 38.20 36.19 39.13 34.75 38.15 40.13 37.07
ISO-NE Internal hub ....................... 24.61 20.25 27.20 34.03 55.26 29.56 31.92 36.47 48.71 27.74 29.11 32.86 26.52 38.30 34.60
NYISO Hudson Valley zone ............ 21.82 18.13 24.38 27.05 44.74 28.98 33.28 30.67 35.72 28.10 30.79 28.24 22.85 34.42 30.72
PJM Western hub ........................... 22.47 20.79 28.24 26.44 35.09 32.07 33.84 31.07 32.76 31.01 33.49 30.52 24.49 33.02 31.94
Midcontinent ISO Illinois hub .......... 24.43 23.00 29.35 24.94 44.97 31.09 33.11 30.74 31.33 31.24 33.39 30.72 25.43 34.98 31.67
SPP ISO South hub ........................ 20.06 19.54 26.27 24.34 250.31 26.35 31.31 26.52 26.61 26.65 30.97 26.78 22.55 83.62 27.75
SERC index, Into Southern ............ 23.58 18.23 23.47 25.21 41.10 29.30 30.61 29.44 29.77 29.24 30.84 28.48 22.62 32.61 29.58
FRCC index, Florida Reliability ....... 26.24 18.53 23.75 25.39 27.73 28.92 29.67 29.14 29.72 27.93 28.13 27.99 23.48 28.86 28.44
Northwest index, Mid-Columbia ..... 22.77 14.49 33.56 31.00 34.56 36.30 41.54 34.41 37.45 34.03 36.71 33.79 25.46 36.70 35.50
Southwest index, Palo Verde ......... 22.07 19.60 80.81 36.10 41.72 29.13 39.33 29.91 29.84 29.74 31.40 28.34 39.64 35.02 29.83
kWh = kilowatthours. Btu = British thermal units.
(a) Generation supplied by power plants with capacity of at least 1 megawatt operated by electric utilities and independent power producers.
(b) Generation supplied by power plants with capacity of at least 1 megawatt operated by businesses in the commercial and industrial sectors, primarily for onsite use.
(c) Includes transmission and distribution losses, data collection time-frame differences, and estimation error.
(d) Direct Use represents commercial and industrial facility use of onsite net electricity generation; and electrical sales or transfers to adjacent or colocated facilities
for which revenue information is not available. See Table 7.6 of the EIA Monthly Energy Review .
Historical data sources:
(1) Electricity supply, consumption, fuel costs, and retail electricity prices: Latest data available from U.S. Energy Information Administration databases
supporting the following reports: Electric Power Monthly, DOE/EIA-0226; and Electric Power Annual, DOE/EIA-0348
(2) Wholesale electricity prices (except for PJM RTO price): S&P Global Market Intelligence, SNL Energy Data
(3) PJM ISO Western hubHub wholesale
wholesale electricity
electricity prices:
prices: PJM
PJM Data
Data Miner
Miner website.
website
Table 7b. U.S. Regional Electricity Retail Sales (billion kilowatthours)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Residential Sector
New England ............... 11.7 10.9 14.6 11.0 12.9 11.2 13.8 11.1 13.3 11.0 13.4 11.1 48.2 49.0 48.9
Middle Atlantic .............. 32.2 30.6 43.5 30.9 36.1 30.6 40.4 31.4 36.6 30.6 40.0 31.4 137.1 138.5 138.7
E. N. Central ................ 46.4 43.7 56.5 43.4 50.2 44.1 53.8 44.6 51.4 44.4 54.2 44.7 190.0 192.7 194.7
W. N. Central ............... 27.6 23.7 30.0 24.5 29.9 24.6 29.6 25.7 33.1 26.4 31.7 27.1 105.8 109.9 118.4
S. Atlantic ..................... 84.3 86.3 114.7 85.3 95.2 90.6 113.0 85.7 95.0 89.9 112.9 86.6 370.6 384.6 384.4
E. S. Central ................. 29.0 26.0 37.2 26.6 33.8 26.9 37.5 27.3 33.6 27.2 38.0 27.6 118.8 125.5 126.3
W. S. Central ............... 48.8 52.9 76.4 48.5 56.8 53.4 77.2 50.5 54.1 55.7 78.5 51.5 226.5 237.8 239.8
Mountain ...................... 22.5 25.7 36.2 24.0 23.7 26.0 34.2 24.0 23.7 26.2 34.3 24.4 108.4 108.0 108.7
Pacific contiguous ........ 36.7 33.2 43.0 38.6 39.0 33.4 41.6 37.7 39.4 34.0 41.7 37.9 151.5 151.7 152.9
AK and HI ..................... 1.3 1.1 1.2 1.3 1.3 1.1 1.2 1.3 1.3 1.1 1.2 1.3 4.9 4.9 4.9
Total .......................... 340.3 334.1 453.4 334.1 378.9 341.8 442.3 339.5 381.5 346.6 446.0 343.7 1,462.0 1,502.5 1,517.8
Commercial Sector
New England ............... 12.3 10.6 13.2 11.4 11.7 10.8 13.0 11.6 11.9 10.8 12.9 11.5 47.5 47.1 47.1
Middle Atlantic .............. 35.9 31.0 38.9 33.2 34.6 33.7 39.4 34.8 36.2 34.8 39.9 35.0 138.9 142.5 145.9
E. N. Central ................ 43.1 38.3 47.3 41.0 41.7 40.9 48.0 42.6 43.2 42.0 48.7 42.9 169.7 173.3 176.9
W. N. Central ............... 24.7 21.6 26.3 23.4 24.0 21.5 26.5 23.8 24.8 22.3 27.3 24.5 96.0 95.9 98.8
S. Atlantic ..................... 72.0 70.0 85.7 72.4 70.8 74.9 87.8 74.3 73.3 76.7 88.8 74.9 300.2 307.7 313.8
E. S. Central ................. 20.7 19.4 25.3 20.4 20.9 20.0 25.7 20.8 21.2 20.4 26.0 21.0 85.8 87.5 88.6
W. S. Central ............... 44.3 44.6 55.0 45.4 42.4 46.0 56.8 47.3 43.0 47.5 57.5 48.0 189.4 192.6 196.1
Mountain ...................... 22.4 22.1 27.4 22.8 21.9 23.6 27.5 23.3 22.6 24.2 28.0 23.8 94.7 96.4 98.6
AK and HI ..................... 1.4 1.2 1.3 1.3 1.3 1.3 1.4 1.4 1.4 1.4 1.5 1.5 5.2 5.4 5.7
Total .......................... 313.7 292.7 360.3 308.9 304.6 307.1 365.5 316.9 312.8 314.5 369.6 319.4 1,275.7 1,294.2 1,316.4
Industrial Sector
New England ............... 3.7 3.5 3.9 3.7 3.8 3.6 4.0 3.7 3.7 3.6 3.9 3.6 14.8 15.0 14.8
Middle Atlantic .............. 18.0 16.2 18.6 17.6 17.6 17.0 19.0 17.8 18.1 17.3 19.2 17.9 70.4 71.5 72.5
E. N. Central ................ 44.0 37.7 44.5 42.5 44.8 41.3 46.6 43.3 46.3 42.0 46.8 43.2 168.7 176.0 178.3
W. N. Central ............... 21.7 20.3 23.2 22.1 23.0 22.8 24.4 22.8 24.1 23.5 24.9 23.1 87.3 93.0 95.5
S. Atlantic ..................... 32.8 31.0 34.2 33.6 33.4 33.4 35.3 34.0 34.0 33.6 35.3 33.7 131.7 136.1 136.7
E. S. Central ................. 23.3 21.4 23.4 22.9 23.8 23.3 24.2 23.3 24.5 23.7 24.4 23.2 91.1 94.6 95.7
W. S. Central ............... 46.6 44.9 47.9 48.7 44.1 46.5 49.5 50.0 45.9 48.0 50.8 51.0 188.1 190.1 195.6
Mountain ...................... 20.1 20.3 22.6 19.9 19.2 21.2 23.3 20.3 19.7 21.7 23.7 20.6 82.9 83.9 85.6
AK and HI ..................... 1.2 1.0 1.2 1.2 1.1 1.1 1.2 1.2 1.1 1.1 1.2 1.2 4.5 4.5 4.5
Total .......................... 230.7 216.0 241.6 231.2 228.8 230.8 250.0 235.3 235.5 234.7 252.3 236.2 919.5 944.9 958.7
Total All Sectors (a)
New England ............... 27.8 25.1 31.9 26.3 28.5 25.6 30.8 26.5 29.1 25.5 30.3 26.4 111.0 111.5 111.2
Middle Atlantic .............. 86.9 78.5 101.8 82.5 89.2 82.1 99.6 84.8 91.7 83.4 99.9 85.1 349.7 355.7 360.1
E. N. Central ................ 133.7 119.7 148.4 127.0 136.9 126.4 148.5 130.6 141.0 128.6 149.9 131.0 528.8 542.4 550.5
W. N. Central ............... 74.0 65.7 79.5 70.0 77.0 68.9 80.6 72.3 82.0 72.2 84.0 74.7 289.2 298.8 312.8
S. Atlantic ..................... 189.5 187.6 235.0 191.6 199.7 199.1 236.5 194.3 202.6 200.5 237.2 195.5 803.7 829.6 835.9
E. S. Central ................. 73.0 66.8 85.9 69.9 78.5 70.2 87.4 71.4 79.3 71.2 88.4 71.7 295.7 307.6 310.6
W. S. Central ............... 139.8 142.4 179.4 142.7 143.3 146.0 183.5 147.9 143.1 151.3 186.8 150.5 604.2 620.7 631.7
Mountain ...................... 65.0 68.2 86.3 66.7 64.8 70.9 85.1 67.7 66.0 72.1 86.1 68.7 286.2 288.5 293.0
AK and HI ..................... 3.8 3.4 3.6 3.8 3.6 3.5 3.8 3.9 3.7 3.6 3.8 4.0 14.6 14.8 15.2
Total .......................... 886.6 844.3 1,056.9 875.9 914.0 881.3 1,059.4 893.2 931.5 897.3 1,069.5 900.9 3,663.7 3,748.0 3,799.2
(a) Total retail sales to all sectors includes residential, commercial, industrial, and transportation sector sales.
Retail Sales represents total retail electricity sales by electric utilities and power marketers.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric
Table 7c. U.S. Regional Retail Electricity Prices (Cents per Kilowatthour)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Residential Sector
New England .............. 21.76 21.32 20.95 20.80 21.38 21.74 21.97 22.29 23.21 23.61 23.65 23.62 21.20 21.83 23.51
Middle Atlantic ............. 15.47 15.96 16.18 15.98 15.62 16.32 16.87 16.67 16.07 16.53 16.96 16.67 15.92 16.38 16.57
E. N. Central ............... 13.14 13.75 13.33 13.75 13.38 14.15 13.76 14.08 13.72 14.45 13.97 14.27 13.48 13.82 14.08
W. N. Central .............. 10.98 12.59 12.88 11.46 10.88 12.99 13.61 11.66 10.52 12.57 13.06 11.40 11.99 12.27 11.86
S. Atlantic .................... 11.79 11.80 12.05 11.83 11.66 11.81 12.30 12.21 12.17 12.25 12.60 12.27 11.88 12.01 12.34
E. S. Central ............... 11.24 11.56 11.28 11.41 11.18 11.82 11.65 11.76 11.52 12.01 11.69 11.81 11.36 11.58 11.74
W. S. Central .............. 11.04 11.42 11.29 11.37 11.85 11.69 11.86 11.90 12.10 11.21 11.33 11.53 11.29 11.83 11.52
Mountain ..................... 11.42 12.08 12.19 11.64 11.53 12.21 12.41 11.86 11.77 12.41 12.52 11.93 11.88 12.05 12.20
Pacific ......................... 15.69 16.18 17.77 16.79 16.76 16.90 18.09 16.90 17.14 17.74 18.70 17.19 16.67 17.19 17.71
U.S. Average ........... 12.90 13.24 13.35 13.25 13.09 13.50 13.75 13.64 13.47 13.72 13.83 13.66 13.20 13.50 13.68
Commercial Sector
New England .............. 16.24 15.67 15.98 15.67 16.28 16.04 16.68 16.48 17.14 16.78 17.25 16.86 15.90 16.38 17.02
Middle Atlantic ............. 11.69 12.53 13.21 12.41 12.48 13.15 13.78 12.95 12.78 13.29 13.69 12.79 12.47 13.11 13.15
E. N. Central ............... 9.95 10.37 10.19 10.29 10.40 10.69 10.56 10.67 10.63 10.81 10.62 10.72 10.19 10.58 10.69
W. N. Central .............. 9.07 10.12 10.33 9.12 9.10 10.70 11.16 9.50 8.84 10.16 10.55 9.18 9.66 10.13 9.69
S. Atlantic .................... 9.23 9.02 9.09 9.20 9.29 9.03 9.34 9.59 9.62 9.17 9.34 9.53 9.13 9.31 9.41
E. S. Central ............... 10.75 10.83 10.60 10.67 10.96 11.16 11.00 11.06 11.21 11.28 11.09 11.16 10.70 11.04 11.18
W. S. Central .............. 7.84 7.87 7.89 7.98 11.28 8.21 8.32 8.03 11.34 8.66 8.78 8.35 7.90 8.87 9.20
Mountain ..................... 9.00 9.82 10.09 9.31 9.11 9.95 10.30 9.40 9.13 9.93 10.24 9.38 9.58 9.73 9.70
Pacific ......................... 13.50 14.79 17.20 15.05 14.53 15.43 17.97 15.58 15.06 16.06 18.54 16.09 15.18 15.94 16.49
U.S. Average ........... 10.33 10.63 10.97 10.62 11.11 10.94 11.40 10.98 11.35 11.13 11.49 11.04 10.65 11.12 11.26
Industrial Sector
New England .............. 12.29 12.22 12.41 12.12 13.49 13.10 12.97 12.53 13.86 13.34 13.13 12.65 12.26 13.02 13.25
Middle Atlantic ............. 6.36 6.35 6.41 6.28 6.50 6.48 6.38 6.23 6.31 6.32 6.22 6.06 6.35 6.40 6.23
E. N. Central ............... 6.51 6.78 6.75 6.62 6.92 7.09 6.88 6.76 6.91 7.14 6.93 6.80 6.66 6.91 6.94
W. N. Central .............. 6.94 7.32 7.89 6.62 6.97 7.38 8.02 6.76 6.92 7.49 8.15 6.88 7.20 7.30 7.37
S. Atlantic .................... 5.98 6.09 6.50 6.09 6.24 6.36 6.64 6.16 6.25 6.35 6.61 6.13 6.17 6.35 6.34
E. S. Central ............... 5.45 5.51 5.70 5.52 5.75 5.72 5.80 5.56 5.68 5.71 5.78 5.54 5.54 5.71 5.68
W. S. Central .............. 5.05 4.98 5.21 5.03 7.61 5.75 5.23 4.95 6.53 5.57 5.17 4.86 5.07 5.83 5.51
Mountain ..................... 5.73 6.15 6.91 5.94 6.24 6.61 7.02 6.00 6.27 6.67 7.02 6.03 6.21 6.49 6.52
Pacific ......................... 8.97 10.33 12.38 10.95 9.64 10.87 12.66 11.25 9.90 11.23 12.98 11.59 10.71 11.18 11.50
U.S. Average ........... 6.38 6.63 7.08 6.53 7.15 7.03 7.19 6.59 6.93 7.02 7.20 6.59 6.66 6.99 6.94
All Sectors (a)
New England .............. 18.02 17.61 17.79 17.27 18.19 18.08 18.54 18.33 19.47 19.23 19.53 19.10 17.68 18.29 19.34
Middle Atlantic ............. 11.98 12.58 13.23 12.42 12.56 12.94 13.62 12.92 12.82 13.03 13.57 12.81 12.58 13.03 13.07
E. N. Central ............... 9.92 10.47 10.36 10.24 10.35 10.72 10.56 10.53 10.53 10.86 10.68 10.63 10.24 10.54 10.67
W. N. Central .............. 9.15 10.15 10.58 9.15 9.16 10.42 11.11 9.41 8.96 10.17 10.78 9.27 9.77 10.04 9.80
S. Atlantic .................... 9.80 9.82 10.16 9.82 9.91 9.85 10.35 10.15 10.24 10.08 10.48 10.16 9.91 10.08 10.25
E. S. Central ............... 9.25 9.41 9.56 9.26 9.48 9.61 9.84 9.53 9.63 9.70 9.89 9.59 9.38 9.62 9.71
W. S. Central .............. 8.03 8.28 8.63 8.12 10.37 8.70 8.97 8.31 10.08 8.62 8.87 8.26 8.29 9.07 8.94
Mountain ..................... 8.83 9.58 10.14 9.14 9.15 9.78 10.25 9.26 9.23 9.85 10.26 9.28 9.48 9.65 9.70
Pacific ......................... 13.41 14.30 16.41 14.92 14.50 14.91 16.85 15.22 14.92 15.58 17.38 15.62 14.82 15.42 15.92
U.S. Average ........... 10.29 10.63 11.11 10.54 10.94 10.91 11.39 10.83 11.10 11.05 11.45 10.87 10.66 11.03 11.13
(a) Volume-weighted average of retail prices to residential, commercial, industrial, and transportation sectors.
Historical data: Latest data available from Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric
Table 7d part 1. U.S. Regional Electricity Generation, Electric Power Sector (billion kilowatthours), continues on Table 7d part 2
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
United States
Natural Gas ................................... 354.7 342.6 474.2 340.7 318.2 319.4 430.2 331.7 311.8 318.0 437.2 329.9 1,512.2 1,399.6 1,396.9
Coal .............................................. 170.3 151.2 248.2 198.6 230.3 200.6 269.8 204.8 236.3 192.1 260.5 200.8 768.2 905.4 889.7
Nuclear ......................................... 204.1 190.7 204.1 191.0 198.5 187.7 204.6 186.4 188.8 185.2 197.2 185.6 789.9 777.2 756.8
Renewable Energy Sources: ......... 190.1 206.5 176.9 187.0 198.0 221.5 189.4 203.7 217.5 248.2 208.6 217.1 760.6 812.6 891.3
Conventional Hydropower 75.0 81.3 70.6 63.0 69.3 71.6 61.2 57.0 67.9 79.8 65.0 58.8 289.9 259.1 271.4
Wind .......................................... 87.4 87.1 67.5 94.7 96.3 103.4 80.5 110.3 110.4 112.1 86.9 116.5 336.7 390.5 426.0
Solar (a) .................................... 16.7 27.3 27.6 18.5 21.4 34.6 35.5 24.0 28.3 44.7 44.7 29.6 90.1 115.6 147.3
Biomass ..................................... 7.1 6.7 7.0 6.7 7.0 7.7 7.9 8.2 7.0 7.5 7.7 7.8 27.5 30.8 30.0
Geothermal ................................ 3.9 4.2 4.2 4.2 3.9 4.3 4.2 4.3 3.9 4.0 4.3 4.4 16.5 16.6 16.6
Pumped Storage Hydropower ....... -1.0 -1.2 -2.0 -1.2 -1.1 -1.4 -2.4 -1.2 -1.0 -1.3 -2.3 -1.1 -5.3 -6.0 -5.8
Petroleum (b) ............................... 4.0 3.9 4.5 4.0 5.2 3.4 4.0 4.2 4.7 3.6 4.2 4.9 16.5 16.8 17.3
Other Gases ................................. 1.0 0.4 0.8 0.9 0.7 0.4 0.7 0.9 0.7 0.5 0.7 0.9 3.1 2.7 2.8
Other Nonrenewable Fuels (c) ...... 1.9 1.8 1.9 1.9 1.9 1.8 1.7 1.8 1.8 1.8 1.7 1.9 7.5 7.1 7.1
Total Generation ........................... 925.2 896.1 1,108.5 922.9 951.8 933.5 1,098.0 932.3 960.6 948.0 1,107.7 939.8 3,852.8 3,915.5 3,956.1
New England (ISO-NE)
Natural Gas ................................... 10.8 10.0 16.1 10.8 12.1 10.3 17.2 12.2 9.4 11.6 17.6 11.4 47.7 51.7 50.0
Coal .............................................. 0.1 0.0 0.0 0.1 0.5 0.0 0.0 0.1 0.4 0.0 0.0 0.1 0.2 0.6 0.5
Nuclear ......................................... 7.3 4.9 7.3 6.1 7.1 7.3 7.2 5.6 7.0 6.2 7.2 7.2 25.6 27.2 27.7
Conventional hydropower .............. 2.2 2.1 1.8 1.7 1.9 2.2 1.3 1.8 2.0 2.3 1.3 1.8 7.8 7.2 7.4
Nonhydro renewables (d) ............. 2.6 2.7 2.4 2.6 2.8 3.1 2.7 3.2 3.3 3.3 2.8 3.3 10.3 11.7 12.6
Other energy sources (e) ............. 0.3 0.3 0.4 0.4 0.4 0.4 0.2 0.4 0.4 0.3 0.3 0.4 1.4 1.4 1.4
Total generation ............................ 23.2 20.1 28.0 21.7 24.7 23.3 28.6 23.2 22.5 23.7 29.2 24.2 92.9 99.8 99.6
Net energy for load (f) .................. 27.9 25.2 32.3 27.6 29.3 26.8 31.9 28.2 29.9 27.0 31.8 28.3 113.0 116.2 117.0
New York (NYISO)
Natural Gas ................................... 12.4 11.4 20.6 12.8 12.8 13.1 20.3 15.9 14.9 14.9 21.1 16.2 57.1 62.1 67.2
Coal .............................................. 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.0 0.0
Nuclear ......................................... 10.7 9.2 9.0 9.6 9.3 7.8 7.1 6.8 6.5 7.0 6.7 7.0 38.5 31.0 27.3
Mid-Atlantic (PJM)
Natural Gas ................................... 78.4 69.9 97.6 69.9 72.5 72.7 86.2 73.2 79.0 79.3 95.7 78.4 315.8 304.6 332.5
Coal .............................................. 33.7 29.7 46.8 38.1 50.5 41.4 52.6 40.4 56.2 33.8 49.1 37.0 148.3 184.8 176.1
Nuclear ......................................... 68.9 67.1 70.9 68.9 68.4 64.8 72.4 62.4 59.0 59.2 62.9 57.7 275.7 268.0 238.9
Southeast (SERC)
Natural Gas ................................... 61.9 59.1 74.7 58.5 57.6 55.0 69.9 58.1 53.7 55.8 70.6 55.4 254.2 240.6 235.5
Coal .............................................. 23.8 22.1 44.4 28.0 36.3 33.1 46.6 32.0 39.4 35.8 48.4 34.9 118.3 148.0 158.5
Nuclear ......................................... 53.0 50.5 54.1 52.5 53.8 52.5 55.4 52.0 54.1 55.2 58.4 56.3 210.1 213.7 224.0
Other energy sources (e) ............. -0.1 -0.3 -0.6 -0.2 0.0 -0.4 -0.6 -0.2 0.0 -0.3 -0.7 -0.2 -1.1 -1.2 -1.1
Florida (FRCC)
Natural Gas ................................... 40.0 45.7 52.8 41.0 34.5 41.2 45.6 35.6 32.1 41.3 46.0 36.6 179.5 156.9 155.9
Coal .............................................. 2.1 3.5 5.7 4.6 4.7 5.5 6.2 4.5 4.9 5.4 5.8 4.0 15.9 20.8 20.1
Nuclear ......................................... 7.3 7.6 7.6 7.0 7.8 7.2 7.9 6.9 7.9 7.3 8.1 7.1 29.4 29.8 30.4
(a) Solar generation from large-scale power plants with more than 1 megawatt of capacity. Excludes generation from small-scale solar photovoltaic systems.
(b) Residual fuel oil, distillate fuel oil, petroleum coke, and other petroleum liquids.
(c) Batteries, chemicals, hydrogen, pitch, purchased steam, sulfur, nonrenewable waste, and miscellaneous technologies.
(d) Wind, large-scale solar, biomass, and geothermal
(e) Pumped storage hydroelectric, petroleum, other gases, batteries, and other nonrenewable fuels. See notes (b) and (c).
(f) Regional generation from generating units operated by electric power sector, plus energy receipts from minus energy deliveries to U.S. balancing authorities outside region.
Data reflect generation supplied by power plants with a combined capacity of at least 1 megawatt operated by electric utilities and independent power producers.
Historical data: Latest data available from U.S. Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric Power
Annual , DOE/EIA-0348.
Table 7d part 2. U.S. Regional Electricity Generation, Electric Power Sector (billion kilowatthours), continued from Table 7d part 1
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Midwest (MISO)
Natural Gas ................................... 43.9 43.2 53.4 37.7 34.5 35.0 46.8 36.1 37.0 38.0 51.6 38.2 178.3 152.4 164.7
Coal .............................................. 51.0 41.1 68.5 57.8 69.7 56.7 76.2 61.1 70.8 55.9 72.2 58.5 218.4 263.8 257.4
Nuclear ......................................... 26.6 22.9 24.4 21.2 23.6 22.1 24.1 24.1 23.8 22.2 23.8 23.0 95.1 93.9 92.8
Central (Southwest Power Pool)
Natural Gas ................................... 17.5 16.3 24.2 13.7 12.4 12.6 20.2 12.6 14.3 12.6 21.5 12.8 71.6 57.9 61.2
Coal .............................................. 17.0 15.7 26.7 19.8 21.8 16.4 26.5 17.9 21.5 16.5 26.9 20.0 79.2 82.7 85.0
Nuclear ......................................... 4.4 4.4 4.2 3.8 4.1 3.0 4.4 4.4 4.3 4.4 4.1 2.5 16.8 16.0 15.3
Texas (ERCOT)
Natural Gas ................................... 37.2 42.1 59.3 36.0 33.0 36.2 51.4 29.7 23.5 28.4 43.8 24.1 174.6 150.3 119.9
Coal .............................................. 13.1 15.8 20.3 17.9 16.3 18.0 22.9 17.7 15.1 17.7 22.8 17.0 67.2 74.9 72.7
Nuclear ......................................... 10.4 9.7 11.0 10.3 10.5 10.4 10.3 9.5 10.7 10.0 10.6 10.8 41.4 40.6 42.1
Northwest
Natural Gas ................................... 23.7 17.1 27.3 21.6 20.9 19.1 30.2 24.0 21.2 15.7 30.6 24.3 89.6 94.1 91.8
Coal .............................................. 22.3 16.1 24.5 23.2 22.5 20.8 27.2 21.2 20.8 17.4 24.9 19.3 86.1 91.6 82.4
Nuclear ......................................... 2.4 2.0 2.4 2.5 2.5 1.3 2.4 2.4 2.4 2.4 2.4 2.4 9.4 8.6 9.7
Southwest
Natural Gas ................................... 11.8 14.7 20.4 14.8 11.0 11.9 17.4 12.4 9.5 8.1 14.3 10.5 61.7 52.7 42.4
Coal .............................................. 5.3 5.3 8.8 6.6 5.9 6.4 9.0 8.0 5.6 7.3 7.9 7.8 25.9 29.3 28.6
Nuclear ......................................... 8.3 7.6 8.7 7.0 8.5 7.2 8.6 7.7 8.4 7.5 8.6 7.5 31.6 31.9 32.1
California
Natural Gas ................................... 16.7 12.6 27.0 23.6 16.6 11.8 24.3 21.3 16.4 11.6 23.8 21.1 79.9 74.0 72.8
Coal .............................................. 1.4 1.2 2.1 2.0 1.8 1.8 2.2 1.5 1.1 1.7 2.1 1.8 6.7 7.2 6.7
Nuclear ......................................... 4.8 4.9 4.5 2.1 2.9 4.2 4.7 4.7 4.6 3.8 4.4 4.0 16.3 16.4 16.7
(a) Large-scale solar generation from power plants with more than 1 megawatt of capacity. Excludes generation from small-scale solar photovoltaic systems.
(b) Residual fuel oil, distillate fuel oil, petroleum coke, and other petroleum liquids.
(c) Batteries, chemicals, hydrogen, pitch, purchased steam, sulfur, nonrenewable waste, and miscellaneous technologies.
(d) Wind, large-scale solar, biomass, and geothermal
(e) Pumped storage hydroelectric, petroleum, other gases, batteries, and other nonrenewable fuels. See notes (b) and (c).
(f) Regional generation from generating units operated by electric power sector, plus energy receipts from minus energy deliveries to U.S. balancing authorities outside region.
Data reflect generation supplied by power plants with a combined capacity of at least 1 megawatt operated by electric utilities and independent power producers.
Historical data: Latest data available from U.S. Energy Information Administration databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226; and Electric Power
Annual , DOE/EIA-0348.
Table 8a. U.S. Renewable Energy Consumption (Quadrillion Btu)
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Electric Power Sector
Geothermal .......................................... 0.035 0.037 0.037 0.038 0.035 0.038 0.038 0.038 0.035 0.036 0.038 0.039 0.147 0.148 0.148
Hydroelectric Power (a) ........................ 0.668 0.724 0.629 0.561 0.622 0.694 0.599 0.559 0.691 0.694 0.597 0.556 2.581 2.474 2.538
Solar (b) ................................................ 0.152 0.248 0.252 0.168 0.195 0.315 0.324 0.218 0.257 0.407 0.407 0.269 0.820 1.052 1.341
Waste Biomass (c) ................................ 0.063 0.058 0.059 0.059 0.059 0.066 0.063 0.061 0.056 0.065 0.063 0.061 0.238 0.249 0.245
Wood Biomass ..................................... 0.049 0.043 0.048 0.046 0.050 0.052 0.059 0.066 0.052 0.051 0.055 0.061 0.185 0.227 0.219
Wind ..................................................... 0.796 0.793 0.615 0.862 0.877 0.941 0.733 1.004 1.005 1.020 0.791 1.061 3.065 3.555 3.878
Subtotal ............................................. 1.761 1.904 1.639 1.733 1.837 2.106 1.815 1.947 2.097 2.273 1.952 2.046 7.037 7.705 8.368
Industrial Sector
Biofuel Losses and Co-products (d) ...... 0.197 0.135 0.179 0.188 0.170 0.188 0.192 0.189 0.184 0.190 0.193 0.194 0.698 0.739 0.761
Geothermal .......................................... 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.001 0.004 0.004 0.004
Solar (b) ............................................... 0.007 0.010 0.010 0.007 0.007 0.011 0.011 0.008 0.008 0.012 0.012 0.009 0.033 0.037 0.041
Waste Biomass (c) ................................ 0.041 0.039 0.036 0.041 0.041 0.039 0.038 0.040 0.040 0.039 0.038 0.040 0.156 0.158 0.157
Wood Biomass ..................................... 0.349 0.340 0.336 0.352 0.338 0.339 0.352 0.355 0.346 0.343 0.355 0.358 1.376 1.385 1.402
Subtotal ............................................. 0.594 0.520 0.558 0.588 0.556 0.574 0.590 0.592 0.577 0.581 0.594 0.599 2.261 2.312 2.351
Commercial Sector
Geothermal .......................................... 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.006 0.024 0.024 0.024
Solar (b) ............................................... 0.025 0.037 0.037 0.025 0.029 0.043 0.043 0.030 0.035 0.050 0.051 0.035 0.123 0.146 0.171
Waste Biomass (c) ................................ 0.010 0.008 0.009 0.009 0.009 0.009 0.009 0.009 0.009 0.009 0.009 0.009 0.036 0.036 0.036
Wood Biomass ..................................... 0.021 0.021 0.021 0.021 0.020 0.020 0.021 0.021 0.020 0.020 0.021 0.021 0.083 0.082 0.082
Subtotal ............................................. 0.068 0.077 0.078 0.067 0.070 0.084 0.086 0.072 0.076 0.092 0.093 0.077 0.290 0.313 0.338
Residential Sector
Geothermal .......................................... 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.010 0.040 0.040 0.040
Solar (e) ................................................. 0.058 0.086 0.086 0.061 0.067 0.102 0.102 0.071 0.076 0.115 0.115 0.079 0.291 0.341 0.385
Wood Biomass ..................................... 0.114 0.114 0.115 0.115 0.112 0.114 0.115 0.115 0.112 0.114 0.115 0.115 0.458 0.456 0.456
Subtotal ............................................. 0.181 0.210 0.211 0.186 0.188 0.225 0.227 0.196 0.198 0.239 0.240 0.204 0.788 0.837 0.881
Transportation Sector
Biomass-based Diesel (f) ...................... 0.061 0.064 0.073 0.076 0.057 0.074 0.073 0.079 0.085 0.087 0.092 0.095 0.275 0.284 0.359
Ethanol (f) .............................................. 0.257 0.220 0.267 0.258 0.244 0.288 0.286 0.276 0.259 0.286 0.287 0.283 1.002 1.093 1.116
Subtotal ............................................. 0.318 0.284 0.340 0.334 0.301 0.362 0.359 0.355 0.343 0.373 0.379 0.378 1.277 1.377 1.474
All Sectors Total
Biomass-based Diesel (f) ...................... 0.061 0.064 0.073 0.076 0.057 0.074 0.073 0.079 0.085 0.087 0.092 0.095 0.275 0.284 0.359
Biofuel Losses and Co-products (d) ...... 0.197 0.135 0.179 0.188 0.170 0.188 0.192 0.189 0.184 0.190 0.193 0.194 0.698 0.739 0.761
Ethanol (f) .............................................. 0.267 0.228 0.278 0.268 0.254 0.299 0.297 0.286 0.269 0.297 0.298 0.294 1.041 1.135 1.159
Geothermal .......................................... 0.052 0.054 0.054 0.055 0.051 0.055 0.054 0.055 0.052 0.053 0.055 0.056 0.214 0.215 0.215
Solar (b)(e) ........................................... 0.238 0.374 0.377 0.257 0.295 0.471 0.480 0.327 0.377 0.584 0.585 0.392 1.246 1.573 1.938
Waste Biomass (c) ................................ 0.113 0.105 0.104 0.108 0.108 0.113 0.110 0.111 0.104 0.113 0.110 0.110 0.430 0.442 0.437
Wood Biomass ..................................... 0.532 0.517 0.519 0.533 0.520 0.526 0.547 0.557 0.530 0.528 0.547 0.554 2.101 2.150 2.158
Wind ..................................................... 0.796 0.793 0.615 0.862 0.877 0.941 0.733 1.004 1.005 1.020 0.791 1.061 3.065 3.555 3.878
Total Consumption ................................. 2.923 2.995 2.826 2.907 2.952 3.352 3.078 3.162 3.291 3.558 3.259 3.305 11.652 12.544 13.413
(a) Conventional hydroelectric power only. Hydroelectricity generated by pumped storage is not included in renewable energy.
(b) Solar consumption in the electric power, commercial, and industrial sectors includes energy produced from large scale (>1 MW) solar thermal and photovoltaic generators and small-scale (<1 MW) distribu
(c) Municipal solid waste from biogenic sources, landfill gas, sludge waste, agricultural byproducts, and other biomass.
(d) Losses and co-products from the production of fuel ethanol and biomass-based diesel
(e) Solar consumption in the residential sector includes energy from small-scale (<1 MW) solar photovoltaic systems. Also includes solar heating consumption in all sectors.
(f) Fuel ethanol and biomass-based diesel consumption in the transportation sector includes production, stock change, and imports less exports. Some biomass-based diesel may be consumed in
-the residential
= no sector in heating oil.
data available
Historical data: Latest data available from EIA databases supporting the following reports: Electric Power Monthly , DOE/EIA-0226 and Renewable Energy Annual , DOE/EIA-0603; Petroleum
Table 8b. U.S. Renewable Electricity Generation and Capacity
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Renewable Energy Electric Generating Capacity (megawatts, end of period)
Electric Power Sector (a)
Biomass .............................................. 6,605 6,603 6,553 6,552 6,542 6,398 6,397 6,441 6,444 6,447 6,447 6,447 6,552 6,441 6,447
Waste .............................................. 3,932 3,930 3,856 3,855 3,845 3,843 3,842 3,886 3,889 3,892 3,892 3,892 3,855 3,886 3,892
Wood ............................................... 2,673 2,673 2,697 2,697 2,697 2,554 2,554 2,554 2,554 2,554 2,554 2,554 2,697 2,554 2,554
Conventional Hydroelectric ................ 79,520 79,514 79,660 79,663 79,664 79,733 79,736 79,781 79,795 79,809 79,850 79,854 79,663 79,781 79,854
Geothermal ......................................... 2,502 2,520 2,520 2,520 2,520 2,520 2,520 2,562 2,562 2,562 2,562 2,562 2,520 2,562 2,562
Large-Scale Solar (b) ......................... 39,126 41,216 43,013 47,575 50,238 53,489 56,678 63,077 65,091 70,573 72,388 79,669 47,575 63,077 79,669
Wind ................................................... 106,205 107,768 109,295 118,262 121,148 126,519 128,415 134,261 134,971 136,842 137,422 139,583 118,262 134,261 139,583
Other Sectors (c)
Biomass .............................................. 6,395 6,395 6,391 6,405 6,383 6,392 6,372 6,372 6,372 6,372 6,364 6,364 6,405 6,372 6,364
Waste .............................................. 781 781 777 791 788 792 792 792 792 792 792 792 791 792 792
Wood ............................................... 5,615 5,615 5,615 5,615 5,595 5,600 5,580 5,580 5,580 5,580 5,572 5,572 5,615 5,580 5,572
Conventional Hydroelectric ................ 289 289 289 289 289 289 287 287 287 287 287 287 289 287 287
Large-Scale Solar (b) ......................... 441 468 473 480 482 498 511 545 548 548 548 548 480 545 548
Small-Scale Solar (d) ......................... 24,355 25,255 26,264 27,724 28,888 29,950 31,073 32,198 33,375 34,504 35,640 36,751 27,724 32,198 36,751
Residential Sector ........................... 15,071 15,689 16,373 17,238 18,076 18,731 19,412 20,076 20,776 21,446 22,148 22,811 17,238 20,076 22,811
Commercial Sector .......................... 7,425 7,642 7,910 8,430 8,725 9,071 9,450 9,847 10,260 10,654 11,027 11,412 8,430 9,847 11,412
Industrial Sector ............................... 1,859 1,924 1,981 2,056 2,088 2,148 2,211 2,275 2,340 2,403 2,465 2,528 2,056 2,275 2,528
Wind ................................................... 113 339 348 348 348 348 348 598 598 598 598 598 348 598 598
Renewable Electricity Generation (billion kilowatthours)

Electric Power Sector (a)
Biomass .............................................. 7.1 6.7 7.0 6.7 7.0 7.7 7.9 8.2 7.0 7.5 7.7 7.8 27.5 30.8 30.0
Waste .............................................. 4.1 4.0 4.0 3.9 4.0 4.4 4.3 4.1 3.8 4.4 4.2 4.1 16.1 16.8 16.5
Wood ............................................... 3.0 2.7 3.0 2.7 3.1 3.2 3.6 4.1 3.2 3.1 3.4 3.7 11.4 14.1 13.5
Conventional Hydroelectric ................ 75.0 81.3 70.6 63.0 69.3 71.6 61.2 57.0 67.9 79.8 65.0 58.8 289.9 259.1 271.4
Geothermal ....................................... 3.9 4.2 4.2 4.2 3.9 4.3 4.2 4.3 3.9 4.0 4.3 4.4 16.5 16.6 16.6
Large-Scale Solar (b) ......................... 16.7 27.3 27.6 18.5 21.4 34.6 35.5 24.0 28.3 44.7 44.7 29.6 90.1 115.6 147.3
Wind .................................................. 87.4 87.1 67.5 94.7 96.3 103.4 80.5 110.3 110.4 112.1 86.9 116.5 336.7 390.5 426.0
Other Sectors (c)
Biomass .............................................. 7.4 7.1 7.0 7.1 7.0 7.1 7.0 7.1 7.0 7.1 7.0 7.1 28.6 28.2 28.2
Waste .............................................. 0.7 0.7 0.7 0.7 0.7 0.7 0.7 0.7 0.7 0.7 0.7 0.7 2.7 2.7 2.7
Wood ............................................... 6.7 6.4 6.4 6.4 6.3 6.4 6.4 6.4 6.3 6.4 6.4 6.4 25.8 25.4 25.4
Conventional Hydroelectric ................ 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 0.3 1.2 1.2 1.2
Large-Scale Solar (b) ......................... 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.2 0.8 0.9 0.9
Small-Scale Solar (d) ......................... 8.4 12.4 12.3 8.7 9.8 14.7 14.8 10.2 11.4 17.0 17.1 11.7 41.7 49.5 57.3
Residential Sector .......................... 5.0 7.5 7.5 5.4 5.9 9.0 9.1 6.3 6.9 10.4 10.5 7.2 25.4 30.3 35.0
Commercial Sector ......................... 2.7 3.8 3.8 2.6 3.1 4.5 4.6 3.2 3.6 5.3 5.3 3.7 12.9 15.3 17.9
Industrial Sector .............................. 0.7 1.0 1.0 0.7 0.8 1.1 1.2 0.8 0.9 1.3 1.3 0.9 3.5 3.9 4.4
Wind .................................................. 0.1 0.1 0.2 0.4 0.3 0.2 0.2 0.3 0.4 0.4 0.4 0.4 0.8 1.0 1.5
(a) Power plants larger than or equal to one megawatt in size that are operated by electric utilities or independent power producers.
(b) Solar thermal and photovoltaic generating units at power plants larger than or equal to 1 megawatt.
(c) Businesses or individual households not primarily engaged in electric power production for sale to the public, whose generating capacity is at least one megawatt (except for small-scale solar
photovoltaic data, which consists of systems smaller than 1 megawatt).
(d) Solar photovoltaic systems smaller than one megawatt.
Historical data: Latest data available from EIA databases supporting the Electric Power Monthly, DOE/EIA-0226.
Table 9a. U.S. Macroeconomic Indicators and CO2 Emissions
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Macroeconomic
Real Gross Domestic Product
(billion chained 2012 dollars - SAAR) ............ 19,011 17,303 18,597 18,794 19,088 19,503 19,849 20,231 20,451 20,601 20,689 20,773 18,426 19,668 20,629
Real Personal Consumption Expend.
Real Private Fixed Investment
Business Inventory Change
(billion chained 2012 dollars - SAAR) ............ -52 -298 -1 60 -90 -18 83 228 254 248 219 180 -73 51 225
Real Government Expenditures
Real Exports of Goods & Services
Real Imports of Goods & Services
Real Disposable Personal Income
Non-Farm Employment
(millions) ....................................................... 151.9 133.7 140.9 142.6 143.4 145.3 148.4 150.2 151.2 152.0 152.6 153.2 142.3 146.8 152.2
Civilian Unemployment Rate
(percent) ...................................................... 3.8 13.1 8.8 6.8 6.2 5.8 4.9 4.2 4.0 3.7 3.6 3.5 8.1 5.2 3.7
Housing Starts
(millions - SAAR) ........................................... 1.49 1.09 1.44 1.58 1.60 1.59 1.56 1.54 1.50 1.46 1.43 1.39 1.40 1.57 1.44
Industrial Production Indices (Index, 2012=100)

Total Industrial Production ............................... 107.7 93.7 102.5 104.9 105.2 106.7 108.5 111.3 113.1 114.3 114.9 115.3 102.2 107.9 114.4
Manufacturing .............................................. 104.4 89.3 100.1 103.1 103.4 105.0 107.0 109.7 111.4 112.4 112.7 113.0 99.2 106.3 112.4
Food ........................................................ 116.5 107.9 113.6 116.0 117.6 119.1 119.3 119.4 119.6 119.8 120.1 120.5 113.5 118.9 120.0
Paper ....................................................... 94.7 87.2 87.0 91.8 91.0 92.3 93.2 94.0 94.5 95.0 95.0 95.1 90.2 92.7 94.9
Petroleum and Coal Products .................... 105.0 82.7 89.9 93.1 96.5 99.4 100.1 101.0 101.7 102.2 102.3 102.2 92.6 99.3 102.1
Chemicals ................................................. 99.8 93.7 96.4 99.8 95.7 101.5 106.6 108.7 109.2 109.5 109.6 110.0 97.4 103.1 109.6
Nonmetallic Mineral Products ................... 122.2 106.3 113.7 117.8 117.2 118.8 120.3 120.7 120.9 120.9 120.9 121.2 115.0 119.3 121.0
Primary Metals .......................................... 94.4 69.6 79.3 87.7 89.3 91.6 92.6 94.1 94.5 95.0 94.3 93.9 82.8 91.9 94.4
Coal-weighted Manufacturing (a) .................. 106.5 94.1 100.9 105.3 102.3 105.0 106.6 108.2 109.2 109.8 109.9 110.3 101.7 105.5 109.8
Distillate-weighted Manufacturing (a) ............ 98.8 85.6 92.5 95.8 96.9 98.7 99.8 100.8 101.2 101.4 101.3 101.2 93.2 99.1 101.2
Electricity-weighted Manufacturing (a) .......... 105.1 89.4 98.4 103.0 101.4 104.3 105.9 107.4 108.3 109.1 109.1 109.2 99.0 104.8 108.9
Natural Gas-weighted Manufacturing (a) ....... 107.8 94.0 100.3 105.4 101.4 105.5 107.3 108.8 109.7 110.5 110.5 110.8 101.9 105.8 110.3
Price Indexes
Consumer Price Index (all urban consumers)
(index, 1982-1984=1.00) ............................... 2.59 2.56 2.59 2.61 2.63 2.66 2.66 2.67 2.68 2.69 2.70 2.72 2.59 2.66 2.70
Producer Price Index: All Commodities
(index, 1982=1.00) ........................................ 1.97 1.88 1.94 1.99 2.10 2.12 2.12 2.11 2.12 2.13 2.13 2.13 1.94 2.11 2.13
Producer Price Index: Petroleum
(index, 1982=1.00) ........................................ 1.71 1.05 1.47 1.50 1.89 2.11 2.10 1.94 1.86 1.89 1.89 1.84 1.43 2.01 1.87
GDP Implicit Price Deflator
(index, 2012=100) ......................................... 113.4 112.9 113.8 114.4 115.6 116.5 117.0 117.5 118.0 118.6 119.2 119.8 113.6 116.6 118.9
Miscellaneous
Vehicle Miles Traveled (b)
(million miles/day) .......................................... 7,762 6,880 8,262 8,009 7,683 9,000 8,990 8,831 8,233 9,286 9,249 9,030 7,730 8,630 8,952
Air Travel Capacity
(Available ton-miles/day, thousands) ............. 630 363 478 537 523 567 605 650 649 708 725 697 502 587 695
Aircraft Utilization
(Revenue ton-miles/day, thousands) .............. 328 152 208 238 230 285 347 381 405 452 460 437 231 311 439
Airline Ticket Price Index
(index, 1982-1984=100) ................................ 250.8 203.7 200.6 215.1 198.4 220.1 201.1 209.2 208.4 226.7 227.7 244.6 217.5 207.2 226.8
Raw Steel Production
(million short tons per day) ............................. 0.268 0.174 0.197 0.224 0.246 0.256 0.270 0.304 0.289 0.251 0.251 0.260 0.216 0.269 0.263
Carbon Dioxide (CO2) Emissions (million metric tons)

Petroleum ........................................................ 553 442 518 522 515 553 568 572 558 577 589 588 2,035 2,207 2,312
Natural Gas ..................................................... 490 349 383 429 485 349 368 438 483 350 372 434 1,651 1,640 1,640
Coal ................................................................ 201 177 271 224 247 224 296 238 255 219 286 232 873 1,006 993
Total Energy (c) ............................................... 1,247 971 1,174 1,178 1,250 1,128 1,235 1,251 1,299 1,149 1,250 1,257 4,571 4,864 4,955
(a) Fuel share weights of individual sector indices based on EIA Manufacturing Energy Consumption Survey .
(b) Total highway travel includes gasoline and diesel fuel vehicles.
(c) Includes electric power sector use of geothermal energy and non-biomass waste.
SAAR = Seasonally-adjusted annual rate
Historical data: Latest data available from U.S. Department of Commerce, Bureau of Economic Analysis; Federal Reserve System, Statistical release G17; Federal Highway Administration; and Federal
Forecasts: EIA Short-Term Integrated Forecasting System. U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.
Table 9b. U.S. Regional Macroeconomic Data
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Real Gross State Product (Billion $2009)
New England ................ 993 901 969 981 998 1,019 1,036 1,055 1,064 1,072 1,076 1,079 961 1,027 1,073
Middle Atlantic .............. 2,774 2,486 2,669 2,695 2,737 2,805 2,856 2,914 2,947 2,971 2,987 2,997 2,656 2,828 2,976
E. N. Central ................ 2,502 2,266 2,458 2,480 2,521 2,575 2,616 2,663 2,686 2,702 2,710 2,716 2,427 2,594 2,703
W. N. Central ............... 1,188 1,084 1,168 1,184 1,202 1,225 1,243 1,264 1,276 1,283 1,288 1,291 1,156 1,233 1,284
S. Atlantic ..................... 3,388 3,114 3,337 3,369 3,417 3,486 3,544 3,609 3,646 3,672 3,686 3,701 3,302 3,514 3,677
E. S. Central ................ 828 742 809 820 832 848 861 875 883 888 891 895 800 854 889
W. S. Central ............... 2,317 2,125 2,267 2,303 2,338 2,389 2,433 2,484 2,516 2,536 2,551 2,565 2,253 2,411 2,542
Mountain ...................... 1,283 1,177 1,265 1,280 1,303 1,331 1,356 1,381 1,398 1,408 1,413 1,420 1,251 1,343 1,410
Pacific .......................... 3,769 3,436 3,684 3,714 3,770 3,857 3,937 4,021 4,070 4,103 4,121 4,142 3,651 3,896 4,109
Industrial Output, Manufacturing (Index, Year 2012=100)
New England ................ 97.1 82.9 92.3 95.4 95.5 97.0 98.8 101.3 102.7 103.6 103.7 103.9 91.9 98.1 103.5
Middle Atlantic .............. 96.2 79.7 90.8 93.6 93.6 95.3 97.4 100.1 101.6 102.7 103.0 103.3 90.1 96.6 102.7
E. N. Central ................ 104.7 84.9 99.8 102.7 103.0 104.5 106.4 109.4 111.2 112.2 112.6 112.9 98.0 105.8 112.2
W. N. Central ............... 103.8 90.4 100.0 102.7 103.5 105.1 106.9 109.5 110.9 111.6 112.0 112.2 99.2 106.2 111.7
S. Atlantic ..................... 109.1 94.3 105.1 108.7 108.7 110.3 112.5 115.4 117.0 118.0 118.2 118.3 104.3 111.7 117.9
E. S. Central ................ 108.6 89.1 104.8 108.5 109.3 110.9 112.7 115.1 116.3 117.0 117.2 117.4 102.7 112.0 117.0
W. S. Central ............... 100.1 88.2 95.3 97.7 98.2 99.8 102.0 104.8 106.6 107.8 108.3 108.6 95.3 101.2 107.8
Mountain ...................... 115.6 102.9 113.6 117.0 117.8 119.4 121.5 124.5 126.3 127.2 127.5 127.6 112.3 120.8 127.2
Pacific .......................... 102.9 89.1 97.5 99.5 99.3 100.5 102.7 105.5 107.5 109.0 109.5 110.0 97.2 102.0 109.0
Real Personal Income (Billion $2009)
New England ................ 891 980 932 905 1,010 947 935 926 937 944 949 952 927 955 945
Middle Atlantic .............. 2,313 2,517 2,429 2,325 2,592 2,435 2,402 2,380 2,408 2,426 2,440 2,446 2,396 2,452 2,430
E. N. Central ................ 2,455 2,698 2,578 2,515 2,814 2,625 2,592 2,563 2,587 2,605 2,619 2,625 2,562 2,649 2,609
W. N. Central ............... 1,159 1,259 1,180 1,185 1,298 1,228 1,215 1,205 1,215 1,223 1,229 1,233 1,196 1,236 1,225
S. Atlantic ..................... 3,265 3,506 3,411 3,347 3,731 3,499 3,463 3,433 3,469 3,494 3,515 3,530 3,382 3,532 3,502
E. S. Central ................ 910 990 937 928 1,051 976 963 950 960 965 970 972 941 985 967
W. S. Central ............... 2,037 2,201 2,099 2,066 2,304 2,172 2,145 2,128 2,157 2,176 2,191 2,201 2,101 2,187 2,181
Mountain ...................... 1,211 1,316 1,257 1,239 1,377 1,295 1,282 1,272 1,286 1,296 1,303 1,310 1,256 1,306 1,299
Pacific .......................... 2,832 3,039 2,977 2,910 3,212 3,014 2,985 2,970 3,005 3,030 3,049 3,062 2,939 3,045 3,036
Households (Thousands)
New England ................ 5,897 5,858 5,961 5,952 5,952 5,960 5,976 5,990 5,998 6,007 6,018 6,029 5,952 5,990 6,029
Middle Atlantic .............. 16,163 16,049 16,333 16,310 16,312 16,329 16,366 16,405 16,429 16,453 16,476 16,502 16,310 16,405 16,502
E. N. Central ................ 18,866 18,752 19,098 19,077 19,085 19,116 19,170 19,228 19,265 19,290 19,314 19,343 19,077 19,228 19,343
W. N. Central ............... 8,647 8,603 8,768 8,773 8,785 8,804 8,833 8,863 8,883 8,905 8,926 8,943 8,773 8,863 8,943
S. Atlantic ..................... 25,672 25,565 26,084 26,122 26,186 26,271 26,388 26,510 26,601 26,696 26,784 26,869 26,122 26,510 26,869
E. S. Central ................ 7,660 7,622 7,769 7,775 7,786 7,804 7,831 7,859 7,878 7,898 7,917 7,934 7,775 7,859 7,934
W. S. Central ............... 14,889 14,831 15,138 15,168 15,209 15,262 15,334 15,407 15,465 15,522 15,579 15,632 15,168 15,407 15,632
Mountain ...................... 9,465 9,439 9,644 9,673 9,711 9,756 9,813 9,872 9,919 9,962 10,004 10,043 9,673 9,872 10,043
Pacific .......................... 18,782 18,678 19,034 19,039 19,057 19,089 19,145 19,204 19,247 19,287 19,331 19,370 19,039 19,204 19,370
Total Non-farm Employment (Millions)
New England ................ 7.6 6.4 6.9 7.0 7.0 7.1 7.3 7.4 7.4 7.5 7.5 7.5 6.9 7.2 7.5
Middle Atlantic .............. 20.1 16.8 18.0 18.3 18.4 18.7 19.2 19.4 19.6 19.8 19.9 20.0 18.3 18.9 19.8
E. N. Central ................ 22.3 19.4 20.8 21.0 21.1 21.4 21.8 22.0 22.1 22.2 22.3 22.4 20.9 21.6 22.3
W. N. Central ............... 10.8 9.8 10.2 10.3 10.4 10.5 10.7 10.8 10.8 10.8 10.9 10.9 10.3 10.6 10.9
S. Atlantic ..................... 29.3 26.3 27.6 27.9 28.1 28.4 29.0 29.4 29.5 29.7 29.8 29.9 27.8 28.7 29.7
E. S. Central ................ 8.3 7.5 7.9 8.1 8.1 8.2 8.3 8.4 8.4 8.4 8.4 8.4 8.0 8.2 8.4
W. S. Central ............... 17.9 16.3 16.8 17.1 17.2 17.4 17.8 18.0 18.1 18.2 18.3 18.3 17.0 17.6 18.2
Mountain ...................... 11.2 10.1 10.6 10.7 10.8 10.9 11.2 11.3 11.4 11.4 11.5 11.5 10.6 11.0 11.4
Pacific .......................... 24.0 21.0 21.8 22.0 22.1 22.5 23.0 23.4 23.6 23.8 23.9 24.0 22.2 22.7 23.8
Historical data: Latest data available from U.S. Department of Commerce, Bureau of Economic Analysis; Federal Reserve System, Statistical release G17.
Forecasts: U.S. macroeconomic forecasts are based on the IHS Markit model of the U.S. Economy.
Table 9c. U.S. Regional Weather Data
2020 2021 2022 Year
Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 Q1 Q2 Q3 Q4 2020 2021 2022
Heating Degree Days
New England ................ 2,743 975 115 2,002 3,014 803 127 2,139 3,101 844 131 2,139 5,834 6,084 6,215
Middle Atlantic .............. 2,471 838 85 1,832 2,820 658 77 1,954 2,869 672 79 1,954 5,226 5,509 5,573
E. N. Central ................. 2,786 846 126 2,099 3,088 736 119 2,230 3,149 725 119 2,230 5,856 6,173 6,223
W. N. Central ................ 3,035 799 167 2,311 3,224 756 152 2,435 3,248 706 155 2,435 6,312 6,566 6,543
South Atlantic ............... 1,106 252 17 874 1,337 218 11 934 1,366 186 11 933 2,249 2,501 2,496
E. S. Central ................. 1,485 338 20 1,230 1,794 320 18 1,276 1,804 246 18 1,276 3,072 3,408 3,344
W. S. Central ................ 970 102 8 738 1,297 126 4 776 1,149 83 4 775 1,818 2,204 2,011
Mountain ....................... 2,205 670 125 1,765 2,289 665 141 1,831 2,208 694 147 1,830 4,766 4,926 4,879
Pacific ........................... 1,539 526 64 1,088 1,562 487 93 1,224 1,519 583 94 1,225 3,217 3,366 3,420
U.S. Average ............ 1,874 541 70 1,418 2,098 480 72 1,511 2,091 479 73 1,509 3,902 4,161 4,153
Heating Degree Days, Prior 10-year Average
New England ................ 3,152 823 105 2,128 3,134 856 107 2,100 3,101 855 112 2,126 6,207 6,197 6,194
Middle Atlantic .............. 2,948 644 69 1,944 2,913 678 71 1,911 2,887 684 73 1,931 5,606 5,573 5,576
E. N. Central ................. 3,197 698 102 2,197 3,156 731 105 2,170 3,133 730 102 2,196 6,194 6,161 6,161
W. N. Central ................ 3,287 702 132 2,379 3,247 728 133 2,367 3,218 729 131 2,396 6,500 6,475 6,475
South Atlantic ............... 1,459 169 10 952 1,393 180 11 914 1,377 187 11 917 2,589 2,498 2,492
E. S. Central ................. 1,850 214 15 1,277 1,772 232 16 1,249 1,764 244 15 1,252 3,356 3,269 3,275
W. S. Central ................ 1,199 83 3 794 1,140 86 3 786 1,145 94 3 782 2,078 2,015 2,024
Mountain ....................... 2,192 718 135 1,844 2,181 701 134 1,842 2,172 682 134 1,829 4,889 4,857 4,818
Pacific ........................... 1,456 580 85 1,162 1,462 553 81 1,148 1,455 523 80 1,139 3,284 3,243 3,198
U.S. Average ............ 2,149 472 64 1,509 2,108 482 65 1,484 2,090 478 64 1,490 4,194 4,138 4,123
Cooling Degree Days
New England ................ 0 100 539 0 0 115 435 2 0 88 406 2 639 552 495
Middle Atlantic .............. 0 157 682 4 0 180 559 5 0 161 541 5 843 744 707
E. N. Central ................. 2 218 607 2 2 220 541 8 0 220 544 8 828 770 772
W. N. Central ................ 6 294 662 3 8 255 680 11 3 263 671 11 966 954 948
South Atlantic ............... 196 619 1,232 302 154 669 1,186 246 132 667 1,172 246 2,349 2,255 2,217
E. S. Central ................. 72 420 1,057 79 40 481 1,060 72 29 521 1,065 72 1,628 1,653 1,687
W. S. Central ................ 174 839 1,502 210 91 792 1,528 214 91 870 1,521 214 2,725 2,625 2,696
Mountain ....................... 11 466 1,088 120 11 443 946 79 19 428 932 79 1,684 1,478 1,457
Pacific ........................... 24 196 716 125 23 160 587 59 27 169 587 59 1,062 830 842
U.S. Average ............ 71 395 935 122 50 398 871 99 46 407 864 99 1,524 1,418 1,416
Cooling Degree Days, Prior 10-year Average
New England ................ 0 83 471 1 0 80 473 1 0 84 469 1 554 555 555
Middle Atlantic .............. 0 170 609 6 0 163 610 6 0 162 601 7 785 779 770
E. N. Central ................. 3 240 579 8 3 234 572 7 3 234 562 7 829 816 807
W. N. Central ................ 7 296 696 11 7 294 686 10 7 293 675 10 1,010 998 986
South Atlantic ............... 127 696 1,202 247 143 680 1,195 261 147 674 1,191 266 2,272 2,279 2,278
E. S. Central ................. 36 557 1,082 72 42 532 1,064 74 43 522 1,061 78 1,747 1,712 1,705
W. S. Central ................ 100 892 1,576 207 114 880 1,567 210 113 855 1,541 213 2,774 2,771 2,723
Mountain ....................... 24 432 939 81 24 444 954 86 24 453 949 86 1,476 1,509 1,512
Pacific ........................... 31 185 624 78 31 193 647 85 31 198 652 85 917 956 966
U.S. Average ............ 47 420 892 100 52 415 894 105 53 413 888 106 1,459 1,466 1,460
Regional degree days for each period are calculated by EIA as contemporaneous period population-weighted averages of state degree day data published by the National
Oceanic
See and in
Change Atmospheric
Regional and Administration (NOAA).
U.S. Degree-Day Calculations (http://www.eia.gov/forecasts/steo/special/pdf/2012_sp_04.pdf) for more information.
Regions refer to U.S. Census divisions. See "Census division" in EIA’s Energy Glossary (http://www.eia.gov/tools/glossary/) for a list of states in each region.
Historical data: Latest data available from U.S. Department of Commerce, National Oceanic and Atmospheric Association (NOAA).
Forecasts: Based on forecasts by the NOAA Climate Prediction Center (http://www.cpc.ncep.noaa.gov/pacdir/DDdir/NHOME3.shtml).
Appendix to the June 2021 Short-Term Energy Outlook
This appendix is prepared in fulfillment of section 1245(d)(4)(A) of the National Defense Authorization Act (NDAA) for Fiscal
Year 2012, as amended. The law requires the U.S. Energy Information Administration (EIA), the statistical and analytical
agency within the U.S. Department of Energy, to submit to Congress a report on the availability and price of petroleum and
petroleum products produced in countries other than Iran in the two-month period preceding the submission of the
report. By law, EIA’s data, analyses, and forecasts are independent of approval by any other officer or employee of the U.S.
Government. The data in this appendix, therefore, should not be construed as representing those of the U.S. Department
of Energy or other federal agencies.
EIA consulted with the U.S. Department of the Treasury, the U.S. Department of State, and the intelligence community in
the process of developing the NDAA report, which was previously published as a stand-alone report. Detailed background
and contextual information not repeated here can be found in early editions of the NDAA report.
This appendix is published in the Short-Term Energy Outlook in even numbered months.
Table a1. Summary of Estimated Petroleum and Other Liquids Quantities

Apr 2021 - May Apr 2020 - May 2018 - 2020
Apr 2021 May 2021 2021 Average 2020 Average Average
Global Petroleum and Other Liquids (million barrels per day)

Global Petroleum and Other Liquids Production (a) 94.0 95.0 94.5 94.3 98.6
Global Petroleum and Other Liquids Consumption (b) 96.2 96.2 96.2 82.4 97.7
Biofuels Production (c) 2.6 2.9 2.7 2.4 2.6
Biofuels Consumption (c) 2.5 2.6 2.6 2.4 2.6
Iran Liquid Fuels Production 3.5 3.5 3.5 3.0 3.6
Iran Liquid Fuels Consumption 1.5 1.6 1.5 1.4 1.8
Petroleum and Petroleum Products Produced and Consumed in Countries Other Than Iran (million barrels per day)
Production (d) 87.9 88.6 88.3 88.9 92.3

Consumption (d) 92.2 92.1 92.1 78.6 93.4
Production minus Consumption -4.4 -3.4 -3.9 10.3 -1.1
World Inventory Net Withdrawals Including Iran 2.3 1.2 1.7 -12.0 -0.8
Estimated OECD Inventory Level (e) (million barrels) 2910 2903 2906 3156 2942
Surplus Production Capacity (million barrels per day)
OPEC Surplus Crude Oil Production Capacity (f)

8.5 8.1 8.3 4.4 3.4
Note: The term “petroleum and other liquids” encompasses crude oil, lease condensate, natural gas liquids, biofuels, coal-to-liquids, gas-to-
liquids, and refinery processing gains, which are important to consider in concert due to the inter-related supply, demand, and price dynamics
of petroleum, petroleum products, and related fuels.
(a) Production includes crude oil (including lease condensates), natural gas liquids, other liquids, and refinery processing gains.
(b) Consumption of petroleum by the OECD countries is synonymous with “products supplied," defined in the glossary of the EIA Petroleum Supply Monthly,
DOE/EIA-0109. Consumption of petroleum by the non-OECD countries is "apparent consumption," which includes internal consumption, refinery fuel, and loss, and
bunkering.
(c) Biofuels production and consumption are based on EIA estimates as published in the International Energy Statistics. Biofuels production in the third quarter
tends to be at its highest level in the year as ethanol production in Brazil reaches its seasonal peak and is typically lowest in the first quarter as seasonal production
falls in the South/South-Central region of Brazil.
(d) Global production of petroleum and petroleum products outside of Iran is derived by subtracting biofuels production and Iran liquid fuels production from global
liquid fuels production. The same method is used to calculate global consumption outside of Iran.
(e) Estimated inventory level is for OECD countries only.
(f) EIA defines surplus oil production capacity as potential oil production that could be brought online within 30 days and sustained for at least 90 days, consistent
with sound business practices. This does not include oil production increases that could not be sustained without degrading the future production capacity of a
field.
Source: U.S. Energy Information Administration.
Table a2. Crude Oil and Petroleum Product Price Data

Apr 2021 - May Apr 2020 - May 2018 - 2020
Apr 2021 May 2021 2021 Average 2020 Average Average
Item
Brent Front Month Futures Price ($ per barrel) 65.33 68.31 66.78 22.47 59.69
WTI Front Month Futures Price ($ per barrel) 61.69 65.16 63.38 23.74 53.76
Dubai Front Month Futures Price ($ per barrel) 63.28 66.44 64.82 30.09 59.01
Brent 1st - 13th Month Futures Spread ($ per barrel) 4.20 4.19 4.20 3.71 1.01
WTI 1st - 13th Month Futures Spread ($ per barrel) 4.00 4.63 4.31 3.75 0.57
RBOB Front Month Futures Price ($ per gallon) 2.01 2.13 2.07 0.79 1.61
Heating Oil Front Month Futures Price ($ per gallon) 1.86 2.02 1.94 1.02 1.76
RBOB - Brent Futures Crack Spread ($ per gallon) 0.45 0.50 0.48 0.25 0.19
Heating Oil - Brent Futures Crack Spread ($ per 0.30 0.39 0.35 0.49 0.34
gallon)
(a) Brent refers to Brent crude oil traded on the Intercontinental Exchange (ICE).
(b) WTI refers to West Texas Intermediate crude oil traded on the New York Mercantile Exchange (NYMEX), owned by Chicago Mercantile Exchange (CME) Group.
(c) RBOB refers to reformulated blendstock for oxygenate blending traded on the NYMEX.
Source: U.S. Energy Information Administration, based on Chicago Mercantile Exchange (CME), Intercontinental Exchange (ICE), and Dubai Mercantile Exchange
(DME).

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June 2021

Short-Term Energy Outlook

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 1

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 2

• Following a significant weather-related decline in U.S. natural gas production in

Electricity, coal, renewables, and emissions

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 3

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 4

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 5

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 6

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 7

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 8

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 9

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 10

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 11

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 12

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 13

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 14

U.S. Energy Information Administration | Short-Term Energy Outlook June 2021 15

U.S. Energy Information Administration Independent Statistics & Analysis www.eia.gov

Henry Hub natural gas price and NYMEX confidence intervals

U.S. natural gas prices

2016 2017 2018 2019 2020 2021 2022

Organization for Economic Cooperation and Development (OECD)

U.S. net imports of crude oil and liquid fuels

U.S. net trade of hydrocarbon gas liquids (HGL)

U.S. commercial propane inventories

Note: Excludes propylene.

-20 -10.9 -11.5

U.S. electric power coal inventories

U.S. annual energy expenditures

Crude Oil Production (a)

Dry Natural Gas Production

Total Energy Consumption (d)

Crude Oil West Texas Intermediate Spot

Natural Gas Henry Hub Spot

Real Gross Domestic Product

GDP Implicit Price Deflator

Real Disposable Personal Income

Manufacturing Production Index

Consumption (million barrels per day) (c)

Crude Oil Production Capacity

Surplus Crude Oil Production Capacity

Real Gross Domestic Product (a)

Nominal U.S. Dollar Index (b)

Consumption (million barrels per day)

End-of-period Inventories (million barrels)

HGL Net Imports

HGL Refinery and Blender Net Inputs

HGL Inventories (million barrels)

Refinery and Blender Net Inputs

Refinery and Blender Net Production

End-of-period Inventories (million barrels)

Consumption (billion cubic feet per day)

End-of-period Inventories (billion cubic feet)

Consumption (million short tons)

End-of-period Inventories (million short tons)

Coal Market Indicators

Electricity Consumption (billion kilowatthours unless noted)