Natural gas is one of the most abundant energy sources in the world. Like oil, it is created by the decomposition of organic matter. The lightest of all hydrocarbons, natural gas is commonly found in underground formations either by itself; associated with or lying atop oil deposits; or dissolved in crude oil.

Texas is the nation’s largest producer and consumer of natural gas, providing one-fourth of U.S. supplies and consuming one-sixth, primarily in the industrial and electricity generation sectors.

Once burned as an oilfield waste product, natural gas now supplies the U.S. with 22.5 percent of its energy, as measured by British thermal units (Btu). Texas is the nation’s largest producer and consumer of natural gas, providing one-fourth of U.S. supplies and consuming one-sixth, primarily in the industrial and electricity generation sectors.

Natural gas imports via pipeline from Canada and Mexico, as well as liquefied natural gas (LNG) imports from overseas, now provide 19 percent of total U.S. supplies.3Texas is the entry point for up to two-thirds of Mexican gas imported by pipeline, with a capacity of 2,485 million cubic feet (MMcf) daily.

Natural gas, along with crude oil, is a major economic boon to Texas. Combined, these two energy sources accounted for 14.9 percent or $159.3 billion of the 2006 Texas gross state product (GSP).


The practical use of natural gas dates back to the Chinese of 2,500 years ago, who used bamboo pipes to collect it from natural seeps and convey it to gas-fired evaporators, where it was used to boil ocean water for the salt. French explorers in the early 17th century found Native Americans around the Great Lakes burning gas from natural seeps for cooking. As inexpensive cast-iron pipe became available in the 19th century, natural gas derived from coal became a relatively common fuel for street lighting in some U.S. cities.5

As the technology to create seamless steel pipe and related equipment advanced, the size and length of pipelines increased, as did the volumes of gas that could be transported easily and safely over many miles. The first natural gas pipeline longer than 200 miles was built in 1925, from Louisiana to Texas.

Natural gas is a proven, reliable and clean fuel that has provided Texas not only with abundant and relatively inexpensive energy supplies for more than a half-century, but also has provided the Texas economy with a reliable income.

The first long-line interstate pipelines were built in the 1930s to ship crude oil, not natural gas, from Texas and Oklahoma to the Midwest. Because natural gas is created from the same materials by the same processes as oil, natural gas often is encountered in oil drilling. Before the mid-1940s, it was an unwanted byproduct and was simply flared (burned off) in the field. As concerns about field conservation grew, Texas banned flaring after World War II, so producers had to find markets for gas.

During World War II, the War Production Board approved other long-line crude oil pipelines from Texas to the East Coast, to avoid the threat to oil tankers from Nazi submarines. After the war, the government allowed these pipelines to carry natural gas instead of crude oil, which they do to this day. U.S. demand for natural gas rose rapidly thereafter. Residential demand grew 50-fold between 1906 and 1970.

Today, natural gas has become extremely important as a concentrated, clean fuel for home heating and cooking and electrical power generation, and is sought after almost as much as oil.


Natural gas is in fact a generic name for several gases. The natural gas that is piped into our homes, business and electricity generation plants is primarily methane, an odorless, colorless, lighter-than-air gas. When produced from an underground formation, natural gas commonly contains other compounds, including slightly heavier hydrocarbon gases such as propane and butane, water and sulphurous compounds, and is known as “wet gas”

Typical Composition of Natural Gas
Chemical Component Chemical Composition Proportion of Natural Gas
Methane CH4 70-90%
Ethane C2H6 0-20%*
Propane C3H8 0-20%*
Butane C4H10 0-20%*
Carbon Dioxide CO2 0-8%
Oxygen O2 0-0.2%
Nitrogen N2 0-5%
Hydrogen sulphide H2S 0-5%
Rare gases** Ar, He, Ne, Xe trace

*Ethane, Propane and Butane together account for 0-20% of natural gas.

**Argon, helium, neon, xenon.

Source: Natural Gas Supply Association.

“Casinghead gas” is the gas that appears with crude oil, often dissolved in it; “gas well gas” comes from gas-only formations; and “coal seam” or “coal bed” gas is found in coal formations. Natural gas is also a byproduct of refined crude oil. In addition, many fossil fuels and other carbon-containing materials, such as coal and coke, can be gasified to produce natural gas.

According to the U.S. Department of Energy’s Energy Information Administration (EIA), natural gas provided 33.9 percent of all Btuderived from domestically produced fossil fuels in 2006; 26.8 percent of the Btu from all fuels domestically produced, including nuclear and biofuels; and 22.5 percent of Btu derived from the total U.S. energy supply.

Natural gas is a versatile fuel and very simple to use, as it can be burned or used either as feedstock for other products or to power fuel cells. It is the fuel of choice for most Texas electric utilities, which use it to boil water to produce steam, turn turbines and generate electricity. EIA reports that one cubic foot of natural gas at normal pipeline pressure and temperature produces about 1,031Btu, roughly the same Btu content as 1.3 ounces of high-grade coal.

Natural Gas in Texas

Natural gas is a proven, reliable and clean fuel that has provided Texas not only with abundant and relatively inexpensive energy supplies for more than a half-century, but also has provided the Texas economy with a reliable income. In a world where other energy supplies have uncertain futures, natural gas remains a popular, dependable and, most importantly, domestically produced fuel.


Economic Impact

As noted in earlier chapters, the federal and state governments combine oil and natural gas data for various statistics because of the high degree of overlap between the two. In 2006, more than 312,000 Texans, or 3.1 percent of the state work force, were employed in the oil and natural gas industry, which accounted for more than $159 billion or 14.9 percent of Texas’ gross state product (GSP). Oil and gas industry wages totaled $30.6 billion in that year, or about 6.9 percent of all wages in Texas. Per employee, the industry contributed $511,000 to the GSP. This compares very favorably with the 2003 GSP per employee of $319,000.13

Historically, the oil and natural gas industry have accounted for approximately 10 percent to 25 percent of the state’s GSP. (The price indicated in the exhibit is based on the taxable value of gas from in-state production, in dollars adjusted for inflation.) However, compared to the relatively close relationship between the real price of oil and the industry’s contribution to the state’s GSP, the real price of natural gas is slightly less volatile and does not appear to track GSP closely.


According to the Electric Reliability Council of Texas (ERCOT), which operates the largest of Texas’ four electric grids, natural gas could provide about 72 percent of its total electric generation capacity if used at maximum output every hour of every day. But because cheaper fuel alternatives often are used when available, and plants are often down for maintenance and repair, Texas electric generators used natural gas to produce 46.6 percent of the electricity on the ERCOT grid in 2006 – still making it the most common fuel for electricity generation in the state.

The industrial and electric power sectors dominate consumer natural gas demand in Texas, accounting for 90 percent of the state’s use.

The price of natural gas sold to electric power consumers in November 2007 was $6.58 per Mcf, about 42 percent below the post-Katrina and Rita high price of $11.30 in October 2005.

According to 2006 EIA statewide data, natural gas is used as the primary energy source in 48 operating Texas utility plants with a total of 144 generators. The “nameplate” (maximum) capacity of these generators is 17,350 megawatts (MW). Seven other Texas plants, with a total 10 generators and 3,787 MW of nameplate capacity, use natural gas as a backup fuel.

Thirty of these plants are in ERCOT; three are in the Southeastern Reliability Council (SERC) grid (in southeastern Texas); 13 are in the Southwest Power Pool (SPP) grid (covering the western and northern Panhandle and the Texarkana area); and two are in the Western Electric Coordinating Council (WECC) electricity grid (in far West Texas)

Natural Gas-Powered Generation in Texas, 2006, By Grid
Grid Total Plants Total Generation Units Utility-Owned Plants Utility-Owned Generation Units Natural Gas-Driven, Utility-Owned Generation Plants Natural Gas-driven, Utility-Owned Generation Units
ERCOT 217 698 59 164 30 92
SERC 18 65 3 9 3 9
SPP 36 78 19 49 13 36
WECC 6 18 3 8 2 7
State Total 277 859 84 230 48 144

Sources: U.S. Energy Information Administration and Texas Comptroller of Public Accounts.

Private industrial plants also use natural gas to generate electricity for their own consumption. Some of these plants are owned by a wide variety of manufacturers and processors, such as Alcoa World Alumina, LLC, E. I. DuPont De Nemours & Co. and ExxonMobil.17


Texas Dry Natural Gas Consumption by End Use, 2006 (Millions of Cubic Feet [MMcf])
End Use 2006 Total Percent of Total
Residential 166,225 5.4%
Commercial 149,221 4.9%
Industrial 1,288,510 42.0%
Vehicle Fuel 1,972 <0.1%
Electric Power 1,463,658 47.7%
Total 3,069,646

Sources: U.S. Energy Information Administration and Texas Comptroller of Public Accounts.

To reduce vehicle air emissions, the Texas Department of Transportation (TxDOT) uses natural gas and propane (a liquefied petroleum gas, or LPG) as fuel to power about 4,500 fleet vehicles and buses, which reduced its fiscal 2005 gasoline consumption by five million gallons, or 0.4 percent of the state’s gasoline consumption that year. In that year, all natural gas vehicles in Texas consumed 1,811 MMcf, less than one-tenth of 1 percent of the natural gas consumed in the state. Since TxDOT’s program began in 1993, it has replaced a total of 52 million gallons of gasoline with 52 million gallons of cleaner-burning alternative fuels.

In addition to its merit as a fuel, natural gas is essential to the recovery of other hydrocarbons in underground formations. As a well is drilled into an oil accumulation pressurized by the weight of overlaying rock, the lighter gas expands in response to the release of pressure, forcing the oil downward in the formation and up the producing wells to the surface. For this reason, recovering all the natural gas in an oil field is not always a wise or economical idea. Other substances – water and injected non-hydrocarbon gas – can be used to artificially pressurize a formation, but often at substantial cost.


EIA data indicate that the U.S. consumed 21.7 trillion cubic feet of natural gas in 2006. Of that amount, 92.1 percent went to U.S. consumers; natural gas processors and pipelines used the remainder. Processors use natural gas to fuel the facilities that separate liquids from natural gas, while pipelines use natural gas to run the compressor engines that pressurize the gas, allowing it to travel hundreds of miles through the pipeline.

Of the consumer share, residential users accounted for 21.9 percent of gas supplies; commercial users consumed 14.2 percent; industrial users consumed 32.6 percent; and electric power generators used the remaining 31.2 percent.21

In 2006, Texas consumed more natural gas than any other state, or about 16 percent of total U.S. consumption. The industrial and electric power sectors dominate consumer natural gas demand in Texas, accounting for 90 percent of the state’s use.

The Barnett Shale is one of the most active natural gas production zones in the state and the nation.


Natural gas is extracted through subsurface drilling. Natural gas does not require refining in the sense crude oil does, but it does require cleaning, due to the presence of other gases and liquids. These are removed at a gas processing plant where, as a safety measure, an odorant called mercaptan is added to the naturally odorless methane, giving it a distinctive rotten egg smell.

Four states – Texas, Louisiana, New Mexico and Oklahoma – and the Gulf of Mexico accounted for more than three-quarters of all natural gas produced in the U.S. until the late-1990s. In 2005, these four states plus Gulf production represented 68.4 percent of all U.S. production.23Texas natural gas production reached its peak in 1972, at more than 9.6 trillion cubic feet or more than 40 percent of all U.S. production.24 In 2006, Texas produced more than 5.1 trillion cubic feet or 27.8 percent of all natural gas produced in the U.S., still more than any other state.

Production in western states (California, Colorado, Montana, Nevada, Utah and Wyoming) has helped to make up for declining production from Texas, Louisiana, New Mexico and Oklahoma, while Alaskan production has remained steady.


In the 1980s, horizontal or “slant-hole” drilling came into widespread use in the prolific Austin Chalk (Giddings) gas fields east of Austin. This technique allows producers to drill vertically and then horizontally, to access multiple permeable zones associated with vertical geologic faults. In 1993, the chairman of Oryx Energy Co., at the time a major producer in the Austin Chalk, noted that the costs of drilling horizontal wells were about 50 percent higher than that for vertical wells, but the daily production was three to five times higher. Gas production in the Austin Chalk formation was very high for several years, but has fallen slightly since.


Today, horizontal drilling also is used in the Barnett Shale trend, extending south and west from Fort Worth over parts of 19 counties. The Barnett Shale is one of the most active natural gas production zones in the state and the nation. It contains more than 26 trillion cubic feet of natural gas locked up in a “tight” shale formation. (A tight formation is one in which hydrocarbons are trapped in rock of particularly low permeability and low porosity.) Producers use large volumes of fresh water injected down hole to fracture or “frac” the shale and release the gas.


“Unconventional Gas”

The success of the Barnett Shale production zone has spurred efforts to produce gas in many other areas and geological formations that were previously considered unrecoverable or uneconomic. These “unconventional gas” sources include tight gas sands, shales and coalbeds. Producers have known about these unconventional resources for decades, but relatively low gas prices prevented their exploitation until recently. Unconventional gas production requires permeability enhancement of the reservoir rock, which is accomplished by “frac” techniques. Because of this requirement, each well may be more difficult and more expensive than regular drilling for conventional sources of gas. Only when natural gas prices are high does producing from unconventional sources become economically feasible.

Some 215,000 miles of interstate pipelines deliver natural gas to every corner of the U.S., along with 87,000 miles of intrastate pipelines.

Unconventional gas resources tend to cover large contiguous areas, however, creating economies of scale for operators who specialize in such drilling. Now that gas prices consistently are above $5-6 per Mcf, activity and production has increased dramatically. About 31 percent of current U.S. gas production comes from these unconventional resources. Many of the major unconventional gas fields in Texas (such as East Newark Barnett, Oak Hill Cotton Valley, Carthage Cotton Valley, Sawyer Canyon and Ozona Canyon) have significantly increased production in the past decade. Continued growth in unconventional gas production is expected in Texas and the U.S.30

Gathering and Distribution

The first and smallest component of the pipeline system is a gathering line, generally less than eight inches in diameter, usually located in rural areas and operating under low pressure. Many states, including Texas, do not regulate these lines. Before the gas travels from the area of production, it is processed to remove liquids and non-hydrocarbon gases to become pipeline quality. It then is placed in ever-larger pipelines known as transmission lines, which can be up to 48 inches or more in diameter. These pipelines operate at higher pressures and if they cross state boundaries, become regulated by the Federal Energy Regulatory Commission (FERC).

As the gas nears its final points of sale, the pipeline diameters become smaller again, and are known as distribution lines. In energy parlance, interstate pipelines end at the “city gate,” meaning at the pipeline terminus such as a utility or industrial facility, and the gas is sent to the end-user’s “burner tip” through the utility’s distribution lines.31

Interstate Pipeline Construction

Constructing a new interstate pipeline or expanding an existing one is a lengthy and complex undertaking – and an expensive one, too. Although construction costs per mile are extremely variable and site-specific, the Interstate Natural Gas Association of America estimates that new pipeline construction costs are approaching $3 million per mile and trending upward.32

Most of Texas’ interstate pipelines follow the Gulf Coast to the Mississippi River, then diverge northward to serve the Midwest and northeastward to serve the East Coast. West Texas oil and gas fields generally deliver to the West Coast.

Some 215,000 miles of interstate pipelines deliver natural gas to every corner of the U.S., along with 87,000 miles of intrastate pipelines. Texas leads all states in its number of pipeline miles.


Thirty-one states derive more than 80 percent of their natural gas from interstate pipelines.

The U.S. also imports significant quantities of natural gas – more than 4.2 trillion cubic feet (Tcf) in 2006. Canadian pipeline imports represented more than 85 percent of 2006 U.S. imports.


Storage and Disposal

Large, commercial volumes of natural gas are usually stored in underground rock formations with an impermeable cap, such as caverns in salt domes or depleted oil and gas reservoirs, or in large aboveground tank facilities. In 2007, Texas had 35 natural gas storage sites–20 in depleted reservoirs around the state and 15 in underground salt caverns along its coast. In all, Texas’ natural gas storage capacity was 683.5 billion cubic feet in August 2007, placing the state fourth in the nation behind Michigan, Illinois and Pennsylvania.


Texas’s natural gas storage facilities allow the state to store its natural gas production during the summer months, when national demand typically is lower, and then ramp up delivery quickly during the winter months, when markets across the country require natural gas for home heating.

Due to the growing use of natural gas for electricity generation, however, Texas has occasionally withdrawn natural gas from storage during the summer to help meet the state’s peak electricity demands due to high air conditioning use. Although the volume fluctuates constantly, from September 2006 to August 2007 Texas underground facilities averaged 575.8 Bcf of natural gas in storage, or about 8 percent of the U.S. total.


Natural gas is widely available in Texas and the U.S. as a whole, due to many on- and offshore gas fields and an extensive drilling and pipeline infrastructure.

Texas is the nation’s leading producer of natural gas, and in 2006 produced 5.1 trillion cubic feet, nearly half again as much as the state consumed (3.4 trillion cubic feet) and 27.8 percent of total U.S. marketed production. Today, the Barnett Shale (Newark East) field in Northeast Texas is the second-largest natural gas field in the continental U.S., as ranked by 2005 gas production. Two other Texas fields are in the top ten – the Hugoton field stretching across the Panhandle into Oklahoma and Kansas is third, and the Carthage field in East Texas is seventh. The Giddings field in the Austin Chalk play is eighteenth.

Reserve estimates have been increasing in recent years, due primarily to the discovery of large reserves of natural gas in the Gulf of Mexico.

At the end of 2006, U.S. dry natural gas reserves totaled 211.1 trillion cubic feet. Federal reserves in the Gulf of Mexico were 14.5 Tcf; Texas state offshore reserves were 0.3 Tcf. Texas as a whole had 61.8 Tcf in dry natural gas reserves, a 42.1 percent increase since 2000. Texas reserves represented 29.2 percent of the total U.S. reserves. To put this into perspective, total U.S. natural gas consumption in 2006 was 21.7 Tcf, down from a high of 23 Tcfin 2002.

Reserve estimates have been increasing in recent years, due primarily to the discovery of large reserves of natural gas in the Gulf of Mexico. The most promising of these reserves, however, are located in areas of deep water – greater than 5,000 feet, or almost one mile – and are increasingly expensive to find and produce.

Also, much of the U.S.’s offshore lands are off-limits to oil and gas exploration and production due to both congressional and presidential decree resulting from local environmental concerns. The American Petroleum Institute estimates that these lands could produce 656 Tcf of natural gas – more than three times existing reserves.

Unconventional gas sources, though expensive to produce, are becoming more attractive and are an increasingly large percentage of total gas supply as gas prices remain near historical highs. These prices, though, tend to depress consumption and therefore price.

Costs and Benefits

Natural gas is inextricably linked with crude oil in the ground and in the marketplace, even though oil is traded in a global market and natural gas is traded more often in a continental market such as that in North America. Because gas is often co-produced with oil, its price is related to the price of oil, whether that price is set on the floor of the New York Mercantile Exchange or in a boardroom of the Organization of Petroleum Exporting Countries (OPEC), and it is subject to the same political and economic pressures facing crude oil, although on a somewhat lesser scale.

Natural gas prices have been highly volatile over the last few years, due in large part to production disruptions and outages caused by hurricanes Katrina and Rita in the Gulf of Mexico. In addition, prior to these storms, cold winters on the eastern and western coasts significantly depleted the amount of natural gas held in storage, further tightening the market.

The average production cost of natural gas is computed at each individual well and is based on its type, depth, type of recovery methods used and other factors. U.S. natural gas wellhead prices were $5.80 per thousand cubic feet (Mcf) in early 2005; by October, the price had nearly doubled, to $10.33 per Mcf. During 2006, prices declined from a high of $8.02 in January to $5.09 in October. In 2007, prices began at $5.92 per Mcf in January; rose slightly in anticipation of the summer cooling season to $6.98 per Mcf in May; and fell back to $5.90 in August. By November, prices rose again to $6.37 and in January 2008, were $6.99.

Environmental Impact

Natural gas is a relatively clean fuel, leaving no ash residue and producing lower emissions of nitrous oxides (NOX), sulfur oxides (SOX) and carbon dioxide (CO2) than coal. In Texas in 2006, natural gas-burning electric, commercial and industrial plants emitted 42.1 percent of the state’s total NOX gases, 0.1 percent of its SOX gases and 40.4 percent of the state’s CO2 emissions.

Texas Electric Utility, Commercial and Industrial Air Emissions, 2006 (in Metric Tons)
Emissions CO2
(Metric Tons)
(Metric Tons)
(Metric Tons)
Total U.S. Emissions 2,459,800,018 9,523,561 3,799,447
Total Texas Emissions 257,552,164 558,350 260,057
Texas Emissions as a Percent of U.S. 10.5% 5.9% 6.8%
Emissions from Coal in Texas 150,589,481 523,073 119,910
Percent of state emissions from coal 58.5% 93.7% 46.1%
Percent of U.S. emissions from coal in Texas 6.1% 5.5% 3.2%
Emissions from Natural Gas in Texas 104,093,526 638 109,443
Percent of state emissions from natural gas 40.4% 0.1% 42.1%
Percent of U.S. emissions from natural gas in Texas 4.2% 0.0% 2.9%
Emissions from Petroleum in Texas 2,869,153 28,819 7,530
Percent of state emissions from petroleum 1.1% 5.2% 2.9%
Percent of U.S. emissions from petroleum in Texas 0.1% 0.3% 0.2%

Source: U.S. Energy Information Administration and Comptroller of Public Accounts.

While natural gas is a significantly cleaner-burning fuel than coal, molecule for molecule in its unburned state it is also the most potent greenhouse gas (GHG), due to its high capacity for trapping heat radiating outward from the Earth.

Other Risks

In a controlled state, natural gas is very safe. If released to the atmosphere, however, it is highly combustible until it dissipates. Because of its combustibility, the greatest physical risk involved with natural gas is a sudden, uncontrolled release, either from a well, storage facility or pipeline. The most common source of these releases is an unintended piercing of a natural gas line, often by a backhoe or other construction excavation equipment.

For this reason, both the federal and Texas governments have “one-call” systems to allow anyone digging near a pipeline to make one call to a central clearinghouse, which then sends information on the proposed dig to all local utilities. These utilities can send out crews to locate and mark underground facilities.

In addition, natural gas power plants use some water. Depending on the plant type, electricity generation from natural gas requires withdrawals of between zero and 5,863 gallons per million Btu of heat energy produced. This is the amount of water extracted from a water source; most of the water withdrawn is returned to that source.

Water consumption refers to the portion of those withdrawals that is actually used and no longer available. Electric generation using natural gas consumes between two and 56 gallons of water for each million Btu of heat energy produced.

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