Introduction
The role of natural gas in the U.S. economy has been a major part of the energy policy debate in the 114th Congress. Both the House and the Senate have held multiple hearings related to natural gas. Numerous bills have been introduced in both houses. This report highlights key aspects of global natural gas markets, including supply and demand, and major U.S. developments.1 Select statutes of U.S. law related to natural gas can be found in Appendix G.
Some consider natural gas a potential bridge fuel to a lower-carbon economy, because it is cleaner burning than coal and oil. Natural gas combustion emits about one-half less carbon dioxide than coal and one-quarter less than oil when consumed in a typical electric power plant, offset somewhat by fugitive emissions.2 Fugitive emissions, which can be intentional (i.e., vented) or unintentional (i.e., leaked), are natural gas that is released to the atmosphere during industry operations.3 Natural gas combustion also emits less particulate matter, sulfur dioxide, and nitrogen oxides than coal or oil.
In recent years, the United States has become the home to the shale gas revolution,4 as improved methods to extract natural gas from certain shale formations have significantly increased the resource profile of the United States. This has spurred other countries to try to develop shale gas, but progress is slow outside of North America.
If the United States continues to and other countries can bring large new volumes of natural gas to market at a competitive price, then natural gas could play a larger role in the world's economy. In 2016, the United States started exporting liquefied natural gas (LNG) from the lower 48 states. Several key factors will determine whether significant new quantities of natural gas come to market, particularly unconventional natural gas resources.5 These factors include price, technical capability, environmental concerns, and political considerations. Many countries, both producing and consuming, are watching how the development of U.S. unconventional natural gas resources evolves.
Key Points
- Natural gas is likely to play a greater role in the world energy mix given its growing resource base6 and its relatively low carbon emissions compared to other fossil fuels.
- The world used 122,442 billion cubic feet (bcf) of natural gas in 2015, of which the United States consumed over 27,463 bcf,7 or about 23% (the most of any country).
- World natural gas consumption grew by 1.7% in 2015, which was below the 10-year average of 2.3%; U.S. consumption grew by 3%.8
- U.S. unconventional natural gas reserves9 and production, particularly shale gas, have grown rapidly in recent years. According to the latest data, shale gas made up 51% of proved U.S. natural gas reserves10 and accounts for 56% of dry natural gas production.11
- The new shale gas resources have changed the U.S. natural gas position from a net importer to a potential net exporter.
- Global trade in natural gas is increasing and new players are entering on both the supply side and the import side, making the global gas market more integrated.
Natural Gas Consumption
Key Global Consumers
In 2015, the world consumed about 122,442 bcf of natural gas12—23.8% of total global primary energy consumption, placing it third behind oil and coal. The United States was the world's largest consumer of natural gas, accounting for 27,463 bcf, or 22.8%, of global consumption (see Figure 1).13
Russia is the second-largest consumer of natural gas, using 13,820 bcf in 2015.14 Natural gas accounted for 53% of Russia's total primary energy consumption, ranking it above oil and coal.15 However, natural gas consumption has declined overall in Russia, decreasing 8% between 2011 and 2015,16 due to a weak economic environment.17
Global consumption of natural gas grew at 1.7%, which was below the 10-year average of 2.3%. The United States was one of three countries with the largest consumption growth, at 3%, while also contributing the largest growth in absolute terms and accounting for almost 40% of the total growth. Iran and China also experienced increased natural gas consumption, at 6.2% and 4.7%, respectively.
China is the most populated country in the world and has a growing economy, resulting in the country being one of the largest global energy consumers. China accounts for almost half of the world's total coal consumption, and while the use of natural gas has increased over the past 10 years it remains a small percentage of China's energy consumption, at about 5%.18 China continues to seek increased energy security by expanding natural gas imports through pipelines and as LNG.
Iran holds the world's second-largest natural gas reserves; however, its energy sector has stagnated in the past few years due to international sanctions and a lack of foreign investment and financing. Iran has a thriving domestic energy demand that has increased 50% since 2004.19 The majority of Iran's natural gas production is consumed domestically, with natural gas comprising 60% of its total primary energy consumption in 2014. The lifting of international sanctions began in early 2016 following the implementation of the Joint Comprehensive Plan of Action. Major discussion points for policymakers in light of the lifting of sanctions may be Iran's capacity for natural gas production and its role in the global energy market.
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Source: BP Statistical Review of World Energy 2016, p. 23. Note: Units = billion cubic feet (bcf). |
U.S. Consumption
In 2015, the United States consumed 27,463 bcf of natural gas, making up nearly 23% of total global consumption. The United States is the largest consumer overall of natural gas, and the second-largest consumer overall of energy in the world.
Electric power generation made up 35% of U.S. natural gas consumption in 2015; industrial use accounted for 27%, residential use for 17%, and commercial use for 12%.20 There is a noted rise in the use of natural gas for electric power generation, which can be attributed to low natural gas prices due to the abundance of domestic gas resources, and to policies that promote the use of fuels with lower emissions. Demand for natural gas for power generation has more than doubled since 200021 and is expected to grow by 40% by 2040.22
The U.S. industrial sector increased its consumption of natural gas by 10% between 2010 and 2015.23 As the United States continues to expand its growing resource base, the industrial sector will see a wider array of fuel and feedstock choices, and manufacturing industries such as bulk or primary metals could also experience further growth.24
Natural Gas Supply and Trade
Natural Gas Reserves Growing
Global proved natural gas reserves—natural gas that has been discovered and can be expected to be technically and economically produced—amounted to 6,599,400 bcf (or 6,599 trillion cubic feet (tcf)) in 2015, which correlates to a 53-year supply at current production levels (see Figure 2).25 New reserves are developed every year as existing reserves are consumed. Global natural gas reserves have grown about 19% since 2005, demonstrating the success of exploration and improved recovery techniques.26 Of the top 10 reserve holding companies all are majority owned by their respective governments (see Appendix F).
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Source: BP Statistical Review of World Energy 2016, p. 20. Note: Units = billion cubic feet (bcf). |
Globally, over half of the world's proven natural gas reserves are controlled by the top 10 government-owned companies, with all but one being 100% state-owned. Russia's Gazprom is majority-owned by the state and acts as an arm of the government. Iran's National Iranian Oil Company is the single largest reserve holder of natural gas.
In 2015, U.S. natural gas reserves were 368,700 bcf, about 5.6% of total world reserves.27 The development of shale gas has been a huge driver behind the increase in U.S. natural gas resources (see Figure 3); in 2014, shale made up 51% of proven natural gas reserves.28
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Source: BP Statistical Review of World Energy 2016. Note: Units = billion cubic feet (bcf) |
Production
Global natural gas production in 2015 grew by 2.2%, which was below the 10-year average of 2.4%. Growth was below average in all regions except North America, Africa, and Asia Pacific. U.S. natural gas production accounted for 22% of total global production in 2015.
Between 2005 and 2015, total natural gas production in the United States increased 50%.29 In 2015, the United States produced 27,086 bcf of natural gas, an increase from 25,716 bcf in 2014. The United States had the world's largest production increase, 5.4% (see Figure 4).30 The increase in natural gas production can be attributed to the development of unconventional resources, specifically in the Marcellus and Utica shale formations, which have accounted for 85% of the increase in natural gas production since 2012.31
Overall, U.S. natural gas production is continually rising despite low prices. Between 2005 and 2015, production increased over 65%.32
By 2040, shale gas production is projected to increase 73% to 19.6 tcf, leading to a 45% overall increase in total U.S. natural gas production, from 24.4 tcf to 35.5 tcf.33
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Source: BP Statistical Review of World Energy 2015, p. 22. Note: Units = billion cubic feet (bcf). |
Liquefied Natural Gas
Liquefied natural gas (LNG) is natural gas that has been cooled to a liquid state, making it 600 times smaller in volume.34 In its liquid form, natural gas can be shipped to global markets on tankers and received at LNG import terminals. LNG is becoming more prevalent in the global gas trade as new gas supplies are introduced to the market, further integrating regional gas markets.35
In 2015, LNG trade increased 1.8%, and the share of LNG in the global gas trade was 33%. In response to the increase in LNG trade, many countries are looking to expand their LNG export capacity. In 2016, Australia (in January) and the United States (in February) from the lower 48 launched their first shipments of LNG.
In the past decade, the United States prepared to increase imports of LNG based on forecasts of growing consumption, and began constructing LNG import terminals. However, the rise in prices gave the industry incentives to bring more domestic gas to market, reducing the need to use import terminals. Due to the abundance of domestic natural gas, there has been a push for modification and expansion of existing LNG terminals in order to expand U.S. export capacity, which requires authorization from the Department of Energy and the Federal Energy Regulatory Commission (FERC).36
U.S. Development and Growth
The U.S. natural gas market is in a period of transition. Technologies such as hydraulic fracturing and horizontal drilling have expanded the domestic natural gas supply, making possible the development of unconventional natural gas resources found in shale, coal seams, and tight lower-permeability rock formations.37 Improved efficiency has lowered production costs, making shale gas economically competitive at almost any price.
Production has shifted away from the Gulf of Mexico to regions where sources of conventional natural gas are not traditionally found. (See Figure 5.) For instance, the Marcellus and Utica Basins are expansive shale resources located in the East and Northeast (West Virginia, Pennsylvania, New York, and Ohio). The location of these basins impacts the transportation of natural gas, as there is a reduced need for natural gas from the Rockies or Gulf Coast. The decrease in demand for gas from these areas and an increase in production from shale plays such as Marcellus have reduced prices and the number of imports needed from Canada and elsewhere.38 Increased production in the future is expected from the Marcellus, Eagle Ford, Anadarko, Utica, and Haynesville Basins.39
Because of the development in supply, the United States has gone from being a net importer of natural gas to being a projected net exporter by 2017.40 The first LNG shipments from the lower-48 occurred in February 2016 from the Sabine Pass LNG Terminal in Louisiana to Brazil, India, and the United Arab Emirates. On June 26, 2016, the Panama Canal reopened for commercial business, after undergoing construction for an additional ship traffic lane. The newly expanded canal eliminates about 10 days in transit time from the U.S. Gulf of Mexico to Asian markets, thus offering a potential shipping route for U.S. LNG. However, only 10% of LNG carriers are small enough to fit the canal; no LNG transits have been scheduled through the canal.41
The development in supply has placed the United States in a strategic position that may prove advantageous in the global natural gas market. However, this also raises questions for policymakers regarding the effects of the export of U.S. natural gas on domestic gas prices and the overall economy. Furthermore, questions remain about the size of U.S. shale gas resources; the price level required to sustain development; and whether there are technical, environmental, or political factors that might limit development.
The use and disposition of water in the industry process of hydraulic fracturing42 is one of the main issues facing companies and regulators. As U.S. natural gas production continues to grow, this practice has raised concerns over the quality and quantity of drinking water in areas situated near hydraulic fracturing, the competition for other water users, and the disposal of wastewater. In 2010, the Environmental Protection Agency (EPA) announced that it would undertake a study to assess any impact hydraulic fracturing might have on drinking water.43 A final report has not been released.44
There is concern over deep-well injection and human-caused earthquakes. The wastewater produced from horizontal drilling and hydraulic fracturing is typically disposed through deep-well injection, in which the wastewater is injected into deep geologic strata. The concern is that deep-well injection may be linked to human-induced earthquakes, as the number of earthquakes of magnitude 3.0 or greater has increased.45
Emissions from the natural gas sector and the impact on human health is also a concern; specifically, methane emissions. As the primary component of natural gas, methane is a precursor to smog and a potent greenhouse gas.46 While state and local authorities regulate natural gas systems, in 2012 the EPA established national minimum air standards, or New Source Performance Standards (NSPS), to reduce methane and volatile organic compound (VOC) emissions in the natural gas sector. In May 2016, the EPA updated the 2012 NSPS to include additional equipment in the gas production chain.47 The NSPS include natural gas well sites, natural gas processing plants, and natural gas compressor stations.48 Federal standards for methane emissions do not cover all sources of methane, such as offshore sources or coalbed methane production facilities. As the production of natural gas continues to expand in the United States, the issue of methane as an air pollutant may be a significant one for policymakers.
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Source: Created by CRS using data from Platt's 2016 and Esri 2014. Note: Hawaii is not included, as it does not produce natural gas or possess proved natural gas reserves. |
Global Gas Market Becoming More Integrated
Although most natural gas is consumed in the country where it is produced, global and regional markets are becoming more integrated (see Figure 6). About 30% of natural gas is traded internationally, mostly within regional markets, and the amount of natural gas traded is increasing. Natural gas is transported primarily in two ways: by pipeline, and as a liquid in tankers. Pipelines transport gas between two fixed points, while LNG provides flexibility in the final destination. Global LNG trade increased by 1.8% in 2015, and LNG's share of the global gas trade was 33%.49
Traditionally, natural gas is sold under long-term contracts indexed to oil prices, except in the United States and a few other places where natural gas prices are market-based.50 U.S. LNG exports have placed pressure on other countries to delink their gas exports from oil-indexed prices. Almost all natural gas that is traded internationally is under long-term contracts, usually 20 years in length, whether it is by pipeline or as LNG. This is primarily because natural gas transportation is expensive and long-term contracts are needed to finance construction of the transport facilities. Sometimes LNG consumers do not require the entire amount of natural gas in their contracts. LNG producers can sell the excess to other consumers on a one-time or short-term basis (e.g., sell it on "spot"). The spot market for natural gas is growing.
Russia is the world's largest natural gas exporter, primarily through its massive pipeline network to Europe. Russia opened its first LNG export terminal in 2009, primarily targeting the Asian market, to give it flexibility in its exports. Qatar is the leading exporter of LNG, accounting for 31% of the world LNG trade in 2015, the majority of which goes to Asia and Europe. Europe is the largest importing region of natural gas, receiving most of its imports by pipeline from Russia, Norway, and Algeria; however, recent developments regarding Russia and the Ukraine have pushed the European Union to consider more secure sources of natural gas.51 Asia, the most import-dependent region, relies mostly on LNG; however, China has become more reliant on imported gas via pipeline, from Kazakhstan, Myanmar, and Turkmenistan. China has been Turkmenistan's primary importer of natural gas, with more than 70% of Turkmenistan's exports going to China in 2015.
Currently, the United States and Canada have an extensively integrated pipeline system. Canada and Mexico are the only recipients of U.S. natural gas by pipeline. Exports are expected to increase to Mexico, from 1 tcf in 2015 to almost 1.5 tcf in 2040.52 Meanwhile, exports to Canada are projected to slightly rise from 0.7 tcf to 0.75 tcf, over the same time period.
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Source: BP Statistical Review of World Energy, 2016, p. 28. |
U.S. LNG Exports
U.S. LNG prices are market-based, resulting in a price differential that may create an economic incentive for the United States to export domestically produced natural gas. In February 2016, the first cargo of U.S. LNG was shipped from the Sabine Pass Liquefaction export terminal in Louisiana to Brazil.
The export of U.S. LNG has been the center of debate for policymakers, with questions focusing on how U.S. natural gas may affect the global market and geopolitics, as well as domestic prices.
As of April 2016, there is one LNG export terminal in operation and several LNG export terminal projects under construction in the lower-48 states:
- Additional LNG "trains" at Sabine Pass Liquefaction in Sabine, LA;
- Dominion-Cove Point LNG in Cove Point, MD;
- Cameron LNG in Hackberry, LA;
- Freeport LNG Expansion/FLNG Liquefaction in Freeport, TX; and
- Cheniere Marketing-Corpus Christi LNG in Corpus Christi, TX.53
The Kenai LNG terminal, which began operations in 1969 in Alaska, continues to operate, primarily supplying LNG to Japan.
Also, in February 2016, the United States began shipping quantities of LNG to Barbados from Miami, FL. The LNG was shipped to Barbados in cryogenic containers instead of a specialized tanker ship. Cryogenic containers are comparable to shipping containers and can be transported over land and loaded onto ships. The natural gas from these shipments has been sold at a higher price than the Sabine Pass exports, ranging from $10 per MBtus to almost $16 per MBtus. In 2014, a relatively small amount of LNG was shipped to Honolulu, HI, using this method, the first time to the state.
Alaska has great potential to become a major source of natural gas. The United States Geological Survey (USGS) estimates that conventional natural gas resources on Alaska's North Slope may potentially exceed 200,000 bcf,54 more than eight times the total amount of current U.S. gas consumption. However, the majority of gas produced in Alaska is used for reinjection to boost oil production and is not brought to market. Alaskan officials have pushed for a pipeline to be constructed in order to sell natural gas internationally as LNG, but as of 2016 this is considered commercially challenging.
Future Developments and Trends, Global and Domestic
In February 2016, the Trans-Pacific Partnership (TPP) free trade agreement (FTA) was signed between the United States and Singapore, Brunei, New Zealand, Chile, Australia, Peru, Vietnam, Malaysia, Mexico, Canada, and Japan.55 The TPP may have an impact on the U.S. natural gas trade, as permits for natural gas exports to countries with which the United States has an FTA receive expedited approval under the Natural Gas Act. Thus membership in the TPP would, in effect, grant free trade status to key consumers of LNG. A trade agreement called the Transatlantic Trade and Investment Partnership (TTIP) has been proposed between the United States and the EU, with the aim of promoting trade and economic growth. The areas the TTIP addresses include market access, regulation, and rules and principles for cooperation, and it would, in effect, also give free trade status to signatories regarding natural gas. Neither TPP nor TTIP has been ratified.
In December 2015, the United Nations Climate Change Conference, or COP-21, was held in Paris; the objective of the conference was to address climate change and come to a universal agreement on steps needed to mitigate it. The conference resulted in the Paris Agreement, which establishes governing measures regarding emissions mitigations, adaptation, and finance. The United States signed the agreement on April 22, 2016.
It is noteworthy that U.S. infrastructure expansion, maintenance, and construction may not be able to keep up with its growing supplies; 50% of gas transmission and gathering pipelines were built in the 1950s and 1960s. It is estimated that investment in natural gas interstate pipelines may range from $2.6 billion to $3.5 billion annually between 2015 and 2030.56 This amount of investment may prove difficult to raise given other infrastructure demands.
Other issues that may affect both the domestic and international markets will be oil prices; new infrastructure; technological development; increased interdependence between the gas and electric sectors; and climate and environmental policy.57
Gas Exporting Countries Forum Still Ineffective
The Gas Exporting Countries Forum (GECF), also referred to as gas OPEC (Organization of the Petroleum Exporting Countries), is a nascent cartel organization based in Qatar comprising 11 natural gas producing countries (Table 1). The GECF was formed in 2001, signing an organizing charter in 2008. Together, the countries account for 62% of global natural gas reserves, 57% of the LNG trade, and 39% of the pipeline gas trade. Given the U.S. resource base of natural gas, it is highly unlikely that the GECF could significantly affect U.S. natural gas consumption within the next five years or, most likely, longer. Canada, by far the largest source of imported natural gas to the United States, is not a member of the GECF. Europe is probably most vulnerable to possible cartel control, as more than half its imports come from cartel members, particularly Russia and Algeria. Nevertheless, the current structure of natural gas markets (i.e., long-term contracts and pipelines connecting individual sellers to specific buyers) is not conducive to supply or price manipulation, and significant changes would need to be made to how natural gas is brought to market and sold before the GECF could have influence.
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Reserves |
Production |
LNG Exports |
Pipeline Exports |
Total Exports |
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Algeria* |
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Bolivia |
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Egypt♯ |
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Equatorial Guinea♯ |
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Iran* |
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Libya* |
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Nigeria*♯ |
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Qatar* |
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Russia |
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Trinidad & Tobago |
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UAE*♯ |
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Venezuela* |
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TOTAL GECF |
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% of World |
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Sources: BP Statistical Review of World Energy 2016 and Cedigaz statistical databases.
Notes: * denotes a member of OPEC, ♯ denotes some data from 2014.
Production Widespread
Overall, global natural gas production in 2015 grew by 2.2%, which was below the 10-year average of 2.4%. The United States surpassed Russia as the world's largest natural gas producer in 2009. The success of the United States to date and the potential for further shale gas development has initiated an evaluation by most countries of their potential natural gas resources. However, outside of Canada, whose shale gas industry is developing alongside that of the United States, it is unlikely that significant commercial production will be achieved before the end of the decade in another country. Most countries looking at shale gas currently do not have the data, technology, or equipment required to evaluate their shale gas resources, let alone successfully exploit them.
Natural Gas Prices Remain Low
The price of natural gas in the United States, Canada, and the United Kingdom is set by the market, with centers or hubs providing buyers and sellers with competitive price data (see Figure 7). The most well-known hub in the United States is the Henry Hub in Erath, LA, where multiple interstate and intrastate natural gas pipelines interconnect. There are various prices for natural gas in the United States depending on the category of consumer. Residential consumers pay the highest price, followed by various commercial users.58
By 2040, the Henry Hub natural gas spot price is projected by EIA to rise to $7.85 per million British thermal units (MBtu) due to increased domestic and international demand. This would require an increase in the number of well completions in order to meet higher production levels.59 EIA's projection is based on existing information and does not account for significant changes in the market, such as new technologies, regulations, or discoveries.
Outside the United States, Canada, and the United Kingdom, almost all wholesale natural gas is sold under long-term contracts. The price of natural gas within these contracts is commonly determined by a formula that links the natural gas price to the price of crude oil or some oil-based product. Although in many markets natural gas no longer competes as a substitute against oil-based products, this vestige of the contracts has remained. Over the last several years, the disparity between contract prices and spot prices has raised pressure on gas producers to do away with this concept. However, the recent fall in world oil prices may suspend this debate. Nevertheless, some producers have started incorporating a spot price for natural gas into their pricing formulas. The price differences reflect the regional nature of the natural gas industry and the disparity between contract and spot prices. Asia, in particular, has been willing to pay high prices to secure its natural gas supplies.
Two other contract concepts are worth highlighting: take-or-pay clauses and destination clauses. With a take-or-pay clause, a buyer of natural gas must pay the seller regardless of whether it actually receives the natural gas. Typically, in contracts, buyers must purchase at least 80% of the total volume of natural gas contracted. For example, if a contract is for 100 bcf, but the buyer only needs 80 bcf, then that is all it pays for; but if the buyer only needs 50 bcf, it still must pay for an additional 30 bcf even if it cannot use it. A destination clause allows a cargo to be redirected to a different destination and buyer. Such a clause was not common until recent years and contributes to a more efficient market.
Looking Forward
Is it time for natural gas to take center stage as the world's primary energy source? That is the main question confronting the natural gas industry over the next decade. The International Energy Agency (IEA) states that natural gas is one of the fastest growing fossil fuels, with an increase in demand of approximately 60% in 2040 over 2013;60 natural gas is a major alternative for a world that looks to gradually decarbonize its energy system. Most of the new demand for natural gas is projected to come from non-OECD countries, primarily China and those in the Middle East. Nonetheless, the global landscape for energy is shifting; as North America continues to produce unconventional gas, the rest of the world's exploration of unconventional resources is occurring more gradually.
China is typically a driver in global energy trends. Recently, China has decided to change its economic model, shifting away from an industry-heavy economy to a services-focused one. This change will require 85% less energy to generate future Chinese growth;61 consequently, predictions are uncertain regarding China's future in energy consumption. India, on the other hand, is projected to be a growing contributor to global energy demand, accounting for 25% of the rise in global energy use to 2040.62 However, meeting India's energy demand may prove to be a huge financial commitment—nearly $2.8 trillion. Natural gas comprises about 6% of India's primary energy supply, and is projected to make up less than 10% of India's energy mix in 2040.63
Sectorally, the U.S. electric power industry leads the growth in natural gas demand due to several factors, including relatively low prices, lower capital costs, excess natural gas generation capacity, and competitive financing of projects. Government policies, particularly in regard to carbon dioxide emissions, will be a key factor in determining the rate of growth of natural gas usage. Globally, natural gas is projected to account for 28% of total world electricity generation in 2040,64 with non-OECD countries representing 61% of this.
Natural gas production would likely need to increase to meet the rise in demand and keep prices from dramatically rising. Production and growth is projected in every region except Europe. Unconventional gas resources65—coal bed methane, shale gas, and tight gas—account for about 60% of growth in the global gas supply. However, outside of North America unconventional resource development is slower and uneven. China does have policies that encourage production, but limited water availability, geology, and population density in resource-rich areas may hinder any attempts to fully realize its capacity.
Appendix A. Global Natural Gas Consumption (2015)
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Rank |
Country |
Consumption (bcf) |
Share of World |
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1 |
United States |
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2 |
Russia |
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3 |
China |
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4 |
Iran |
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5 |
Japan |
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6 |
Saudi Arabia |
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7 |
Canada |
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8 |
Mexico |
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9 |
Germany |
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10 |
UAE |
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11 |
United Kingdom |
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12 |
Italy |
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13 |
Thailand |
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14 |
India |
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15 |
Uzbekistan |
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16 |
Egypt |
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17 |
Argentina |
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18 |
Qatar |
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19 |
South Korea |
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20 |
Turkey |
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Rest of World |
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Global Total |
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Source: BP Statistical Review of World Energy 2016, p. 23.
Note: Units = billion cubic feet (bcf).
Appendix B. Global Natural Gas Reserves (2015)
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Rank |
Country |
Reserves (bcf) |
Share of World |
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1 |
Iran |
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2 |
Russia |
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3 |
Qatar |
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4 |
Turkmenistan |
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5 |
United States |
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6 |
Saudi Arabia |
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7 |
UAE |
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8 |
Venezuela |
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9 |
Nigeria |
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10 11 12 |
Algeria China Iraq |
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13 |
Australia |
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14 |
Indonesia |
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15 |
Canada |
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16 |
Norway |
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17 |
Egypt |
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18 |
Kuwait |
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19 |
Libya |
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20 |
India |
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Rest of World |
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Global Total |
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Source: BP Statistical Review of World Energy 2061, p. 20.
Notes: Italics indicate GECF member. Units = billion cubic feet (bcf).
Appendix C. Global Natural Gas Production (2015)
|
Rank |
Country |
Production (bcf) |
Share of World |
|
1 |
United States |
27,086 |
22% |
|
2 |
Russia |
20,238 |
16% |
|
3 |
Iran |
6,794 |
5% |
|
4 |
Qatar |
6,405 |
5% |
|
5 |
Canada |
5,773 |
5% |
|
6 |
China |
4,870 |
4% |
|
7 |
Norway |
4,135 |
3% |
|
8 |
Saudi Arabia |
3,757 |
3% |
|
9 |
Algeria |
2,930 |
2% |
|
10 |
Indonesia |
2,649 |
2% |
|
11 |
Turkmenistan |
2,556 |
2% |
|
12 |
Malaysia |
2,408 |
2% |
|
13 |
Australia |
2,367 |
2% |
|
14 |
Uzbekistan |
2,039 |
2% |
|
15 |
UAE |
1,968 |
2% |
|
16 |
Mexico |
1,878 |
1% |
|
17 |
Nigeria |
1,767 |
1% |
|
18 |
Egypt |
1,609 |
1% |
|
19 |
Netherlands |
1,519 |
1% |
|
20 |
Pakistan |
1,480 |
1% |
|
Rest of World |
20,677 |
18% |
|
|
Global Total |
124,913 |
100% |
Source: BP Statistical Review of World Energy 2016, p. 22.
Notes: Italics indicate GECF member. Units = billion cubic feet (bcf). Totals may not add due to rounding.
Appendix D. U.S. Natural Gas Imports and Exports
|
Rank |
Country |
2010-2015 Average |
2015 Imports |
Share of U.S. Imports |
2015 Imports as a Share of U.S. Consumption |
||||||
|
1 |
Canada |
|
|
|
|
||||||
|
2 |
Trinidad & Tobago |
|
|
|
|
||||||
|
3 |
Norway |
|
|
|
|
||||||
|
4 |
Yemen |
|
|
|
|
||||||
|
5 |
Mexico |
|
|
|
|
||||||
|
6 |
Egypt |
|
|
|
|
||||||
|
7 |
Nigeria |
|
|
|
|
||||||
|
8 |
Peru |
|
|
|
|
||||||
|
9 |
Qatar |
|
|
|
|
||||||
|
TOTAL |
|
|
|
|
Source: EIA's U.S. Natural Gas Imports by Country, https://www.eia.gov/dnav/ng/ng_move_impc_s1_m.htm.
Notes: Italics indicate GECF member. The United States had imported LNG from Australia, Brunei, Indonesia, and UAE prior to the time period examined in this table. Totals may not add due to rounding.
|
Rank |
Country |
2010-2015 Average |
2015 Exports |
2015 Share of U.S. Exports |
2015 Exports as a Share of U.S. Production |
||||||
|
1 |
Mexico |
|
|
|
|
||||||
|
2 |
Canada |
|
|
|
|
||||||
|
3 |
Japan |
|
|
|
|
||||||
|
4 |
Taiwan |
|
|
|
|
||||||
|
Other |
|
|
|
|
|||||||
|
TOTAL |
1,522 |
1,784 |
100% |
7% |
Source: EIA's U.S. Natural Gas Exports by Country, https://www.eia.gov/dnav/ng/ng_move_expc_s1_a.htm.
Notes: The United States has exported natural gas as LNG to both Canada and Mexico in addition to its more traditional pipeline exports. The LNG exports are incorporated into the figures above, but are negligible. 2016 U.S. LNG exports not included. Totals may not add due to rounding.
Appendix E. Global Natural Gas Exporters (2015)
|
Rank |
Country |
Pipeline |
LNG |
Total |
Share of World |
||||
|
1 |
Russian Federation |
|
|
|
|
||||
|
2 |
Qatar |
|
|
|
|
||||
|
3 |
Norway |
|
|
|
|
||||
|
4 |
Canada |
|
|
|
|
||||
|
5 |
United States |
|
|
|
|
||||
|
6 |
Algeria |
|
|
|
|
||||
|
7 |
Netherlands |
|
|
|
|
||||
|
8 |
Australia |
|
|
|
|
||||
|
9 |
Turkmenistan |
|
|
|
|
||||
|
10 |
Malaysia |
|
|
|
|
||||
|
Rest of World |
|
|
|
|
|||||
|
Global Total |
|
|
|
|
Source: BP Statistical Review of World Energy 2016, p. 29.
Notes: Italics indicate GECF member. Units = billion cubic feet (bcf). Totals may not add due to rounding.
Appendix F. Major Global Gas Companies (2014)
|
Rank |
Company |
Country |
Output (MMcf/d) |
|
1 |
Gazprom |
Russia |
45,130 |
|
2 |
NIOC |
Iran |
16,699 |
|
3 |
Qatar Petroleum |
Qatar |
11,670 |
|
4 |
Exxon Mobil |
United States |
11,145 |
|
5 |
CNPC |
China |
11,017 |
|
6 |
Saudi Aramco |
Saudi Arabia |
10,473 |
|
7 |
Royal Dutch Shell |
Netherlands/UK |
9,259 |
|
8 |
Sonatrach |
Algeria |
7,649 |
|
9 |
BP |
UK |
7,100 |
|
10 |
Petronas |
Malaysia |
6,310 |
Source: "Top 50 and Rankings in Six Operational Criteria," Petroleum Intelligence Weekly 54, no. 46 (November 16, 2015): Special Supplement, pp. 2-3. Italics = majority state owned.
|
Rank |
Company |
Country |
Reserves (bcf) |
|
|
1 |
NIOC |
|
1,201,405 |
|
|
2 |
Gazprom |
|
667,268 |
|
|
3 |
Qatar Petroleum |
|
632,726 |
|
|
4 |
Saudi Aramco |
|
288,400 |
|
|
5 |
PDV |
|
198,368 |
|
|
6 |
Sonatrach |
|
159,100 |
|
|
7 |
INOC |
|
126,700 |
|
|
8 |
Adnoc |
|
121,260 |
|
|
9 |
CNPC |
|
109,498 |
|
|
10 |
NNPC |
|
106,262 |
Source: "Top 50 and Rankings in Six Operational Criteria," Petroleum Intelligence Weekly 54, no. 46 (November 16, 2015): Special Supplement, pp. 2-3. Italics = majority state owned.
Appendix G. Select U.S. Statutes Related to Natural Gas
|
Act |
U.S. Code Citation |
Purpose |
|
Natural Gas Act |
15 U.S.C. §717b et seq. |
Governs siting of interstate natural gas pipelines and interstate transmission of natural gas. Also gives authority to DOE for imports and exports of liquefied natural gas. |
|
Natural Gas Wellhead Decontrol Act of 1989 |
15 U.S.C. §3301 et seq. |
Removed remaining price ceilings on natural gas sales. |
|
Mineral Leasing Act of 1920 |
30 U.S.C. §181 et seq. |
Governs leasing activity on federal lands, including leases for purposes of oil and natural gas exploration and production. |
|
Outer Continental Shelf Lands Act |
43 U.S.C. §1331 et seq. |
Governs activities on Outer Continental Shelf, including leasing for purposes of oil and natural gas exploration and production. |
|
Natural Gas Pipeline Safety Act of 1968 |
49 U.S.C. §60101 et seq. |
Authorizes DOT to regulate pipeline transportation of natural gas and other gases as well as the transportation and storage of LNG. |
|
Natural Gas Policy Act of 1978 |
15 U.S.C. §3301 et seq. |
Gave FERC authority over intrastate and interstate natural gas production. The act also set price ceilings for natural gas. |
|
Homeland Security Act of 2002 |
6 U.S.C. §101 et seq. |
Incorporated the Transportation Security Administration (TSA), which has jurisdiction for natural gas pipeline security, into the Department of Homeland Security. |
|
The Clean Air Act of 1970 |
42 U.S.C. §7401 et seq. |
Comprehensive federal law that regulates air emissions from stationary and mobile sources. Authorizes the EPA to establish National Ambient Air Quality Standards (NAAQS) to protect public health and welfare, and to regulate emissions of hazardous air pollutants. |
|
PIPES Act of 2016 (Protecting our Infrastructure of Pipelines and Enhancing Safety Act of 2016) |
49 U.S.C. §60101 et seq. |
Reauthorizes the Pipeline and Hazardous Materials Safety Administration's (PHMSA's) oil and gas pipeline programs through 2019. Gives Secretary of Transportation the power to quickly issue emergency orders for the pipeline industry. Requires the PMHSA to develop national regulations for the construction and operation of underground natural gas storage facilities, and ensures that the PMHSA completes directives set in previous pipeline safety bill in 2011. |
Source: Compiled by the Congressional Research Service (CRS).
Notes: The above list is not exhaustive, but highlights important statutes that relate to natural gas. Certain sections of the acts referenced may be codified in other parts of the U.S. Code.