Barnett Shale Natural Gas

Barnett Shale Natural Gas

Our Company and its' Joint Venture Partners are Making Acquisitions in the Following Areas:

  • Barnett Shale Natural Gas
  • Devonian Black Shale
  • Enhanced Oil Recovery
  • Gas Compression
  • Gas Gathering
  • Gas Processing
  • Marcellus Black Shield
  • Natural Gas Plays
  • Oil and Gas Plays
  • Oil and Natural Gas Development
  • Oil and Natural Gas Investments
  • Oil and Natural Gas Leases
  • Oil and Natural Gas Properties
  • Oil and Natural Gas Production
  • Oil and Natural Gas Resources
  • Stranded Gas
  • Stranded Oil
  • Stranded Oil and Gas

Our company and our investor-partners are presently to make investments and acquisitions in the above-referenced areas.

Properties must be located in the continental U.S. or Canada.

The investment capital our investor-partners have is liquid (cash) and the amounts are significant. Their investment capital comes from previous success in their Oil and Natural Gas Investments – they know and understand oil and natural gas investments and this industry and are seeking to make investments in the above-referenced areas. As such, they bring "smart money" to our new oil and natural gas investments and energy-related opportunities.

More about us and our interests and Oil and Natural Gas Properties/Leases:

We are an independent energy company engaged in the business of oil and natural gas exploration and production.

This will be accomplished primarily through a new drilling program as well as the acquisition of producing oil and natural gas leases and our ownership of perpetual mineral interests. Other companies operate almost all of the oil and natural gas wells from which we receive revenues. We have no control over the "outside" conditions and forces that determine our royalties or working interest revenues.

 

Our business model and operational strategy is focused on targeting opportunities that are of lower risk – such as the Barnett Shale Play – which provides our investor-partners with the potential for stable cash flow and long asset life while keeping our operating costs low. The Company has no short-term or long-

1.2 MW Turbine Genset Excellent Solution for Stranded Gas Applications Also Available in Cogeneration Models with Heat Recovery/ Steam Generation for Enhanced Oil Recovery and Trigeneration Models for Commercial Applications.

One of our solutions for oil and gas companies with Stranded Gas is to use the Stranded Gas as fuel that generates clean electricity with one of our gas turbine generators. For as little as $785/kW (plus shipping costs and any related set-up costs) you could be generating revenues with one of our gas turbine generators!

Did you know that approximately 40% of the world's available natural gas reserves are classified as "stranded gas?"

Stranded gas refers to natural gas that has been discovered but has not, or will not be developed due to their location or the economics of getting the natural gas delivered to the marketplace.

Natural gas pipelines have transported natural gas safely, reliably, and economically to the marketplace whenever large reservoirs of natural gas are found in locations where there were existing pipelines. Even for new natural gas fields, where there are large reservoirs and supplies of natural gas, pipelines were laid to transport the natural gas to markets. However, natural gas supplies from easy to find, and easy to produce fields have been on the decline. This leaves the "stranded gas" from the fields that have not been developed due to the economics, location, or the supply was not large enough. "Stranded gas" wells and reservoirs are becoming increasingly attractive opportunities as we can make the stranded gas a new profit center for your company.

We can help your company turn unproductive, zero revenue stranded gas assets into economic cash flows and a new source or revenues. Stranded gas wells with a nearby electric transmission line with a minimum production of approximately 70,000 cubic feet of natural gas per day – can become a new profit center with our assistance!

We can take wells that have been plugged in years ago, and make them productive by taking the stranded gas and placing one or more of our power plants at or near the site, and convert the stranded gas into electricity, and then selling it to the power grid – thereby creating a new profit center from shut-in wells. Shut-in natural gas wells can be made productive, with new revenues from generating cogeneration power for connection to the grid. It's much easier to transport electrons long distances, than it is to transport natural gas long distances.

Alternatively, depending on the location, we may be able to place our LNG equipment near stranded gas wells and convert the natural gas to Liquefied Natural Gas, and then transport the LNG to a nearby market.

Our company provides turn-key project solutions that include all or part of the following:

  • Engineering and Economic Feasibility Studies
  • Project Design, Engineering & Permitting
  • Project Construction
  • Project Capital and Investment Funding
  • Financing Options (including long-term capital leasing and attractive programs for municipal/governmental entities
  • Shared/Guaranteed Savings program with no capital requirements (qualified clients)
  • Project Commissioning
  • Operations & Maintenance

Liquefied Natural Gas

Liquefied natural gas or LNG is natural gas that has been processed to remove impurities and heavy hydrocarbons and then condensed into a liquid at atmospheric pressure by cooling it to approximately -163 degrees Celsius. LNG is transported by specially designed vessels and stored in specially designed tanks. LNG is about 1/600th the volume of natural gas at standard temperature and pressure (STP), making it much more cost-efficient to transport over long distances where pipelines do not exist. Where moving natural gas by pipelines is not possible or economical, it can be transported by LNG vessels, where the most common tank types are membrane (prismatic) or Moss Rosenberg (spheres).

Basic Facts on LNG

LNG offers an energy density comparable to petrol and diesel fuels and produces less pollution, but its relatively high cost of production and the need to store it in expensive cryogenic tanks have prevented its widespread use in commercial applications.

Conditions required to condense natural gas depend on its precise composition, the market that it will be sold to and the process being used, but typically involve temperatures between -120 and -170 degrees Celsius (pure methane liquefies at -161.6 C) and pressures of between 101 and 6000 kPa (14.7 and 870 lbf/in²). High pressure natural gas that is condensed is then reduced in pressure for storage and shipping.

The density of LNG is roughly 0.41 to 0.5 kg/L, depending on temperature, pressure and composition. In comparison water has a density of 1.0 kg/L.

LNG does not have a specific heat value as it is made from natural gas, which is a mixture of different gases. The heat value depends on the source of gas that is used and the process that is used to liquefy the gas. The higher heating value of LNG is estimated to be 24MJ/L at -164 degrees Celsius. This corresponds to a lower heating value of 21MJ/L.

The natural gas fed into the LNG plant will be treated to remove water, hydrogen sulfide, carbon dioxide and other components that will freeze (e.g., benzene) under the low temperatures needed for storage or be destructive to the liquefaction facility. Purified LNG typically contains more than 90% methane. It also contains small amounts of ethane, propane, butane and some heavier alkanes. The purification process can be designed to give almost 100% methane.

The most important infrastructure needed for LNG production and transportation is an LNG plant consisting of one or more LNG trains, each of which is an independent unit for gas liquefaction. The largest LNG train is the SEGAS Plant in Egypt with a capacity of 5mtpaExxon Mobil operating Qatargas stage 2, of which one train has a production ability of 5 million ton per annum (mtpa). Other facilities needed are load-out terminals for loading the LNG onto vehicles, LNG vessels for transportation, and a receiving terminal at the destination for discharge and regasification, where the LNG is reheated and turned into gas. Regasification terminals are usually connected to a storage and pipeline distribution network to distribute natural gas to local distribution companies (LDCs) or Independent Power Plants (IPPs).

In 1964 the UK and France were the LNG buyers under the world’s first LNG trade from Algeria, witnessing a new era of energy. As most LNG plants are located in "stranded" areas not served by pipelines, the costs of LNG treatment and transportation were so huge that development has been slow during the past half century. The construction of an LNG plant costs USD 1-3 billion, a receiving terminal costs USD 0.5-1 billion, and LNG vessels cost USD 0.2-0.3 billion. Compared with the crude oil, the natural gas market is small but mature. The commercial development of LNG is a style called value chain, which means LNG suppliers first confirm the downstream buyers and then sign 20-25 year contracts with strict terms and structures for gas pricing. Only when the customers were confirmed and the development of a greenfield project deemed economically feasible could the sponsors of an LNG project invest in their development and operation. Thus, the LNG business has been regarded as a game of the rich, where only players with strong financial and political resources could get involved. Major international oil companies (IOCs) such as BP, ExxonMobil, Royal Dutch Shell; and national oil companies (NOCs) such as Pertamina, Petronas were active players. Japan, South Korea and Taiwan imported large sums of LNG due to their shortage of energy. In 2002 Japan imported 54 million tons of LNG, representing 48% of the LNG trade around the world that year. Also in 2002, South Korea imported 17.7 million tons and Taiwan 5.33 million tons. These three major buyers purchase approximately 70% of the world's LNG demand.

In recent years, as more players take part in investment, both in downstream and upstream, and new technologies are adopted, the prices for construction of LNG plants, receiving terminals and vessels have fallen, making LNG a more competitive means of energy distribution. The standard price for a 125,000-cubic-meter LNG vessel built in European and Japanese shipyards used to be USD 250 million. When Korean and Chinese shipyards entered the race, increased competition reduced profit margins and improved efficiency, reducing costs 60%. The per-ton construction cost of a LNG liquefaction plant fell steadily from the 1970s through the1990s, with the cost reduced to approximately 35%.

Due to energy shortage concerns, many new LNG terminals are being contemplated in the United States. Concerns over the safety of such facilities has created extensive controversy in the regions where plans have been created to build such facilities. One such location is in the Long Island Sound between Connecticut and Long Island. Broadwater Energy, an effort between Trans Canada and Shell (A British-Dutch Corporation) wishes to build a LNG terminal in the sound on the New York side. Local politicans including the Suffolk County Executive have raised questions about the terminal. New York Senators Chuck Schumer and Hillary Clinton have both announced their opposition to the project.

Trade in LNG

LNG is shipped around the world in specially constructed seagoing vessels. The trade of LNG is completed by signing a sale and purchase agreement (SPA) between a supplier and receiving terminal, and by signing a gas sale agreement (GSA) between a receiving terminal and end-users. Most of the contract terms used to be DEX or Ex Ship, which meant the seller was responsible for the transportation. But with low shipbuilding costs, and the buyer preferring to ensure reliable and stable supply, there are more and more contract terms of FOB, under which the buyer is responsible for the transportation, which is realized by the buyer owning the vessel or signing a long-term charter agreement with independent carriers.

The agreements for LNG trade used to be long-term portfolios that were relatively inflexible both in price and volume. If the annual contract quantity is confirmed, the buyer is obliged to take and pay for the product, or pay for it even if not taken, which is called the obligation of take or pay (TOP).

In contrast to LNG imported to North America, where the price is pegged to Henry Hub, most of the LNG imported to Asia is pegged to crude oil prices by a formula consisting of indexation called the Japan Crude Cocktail (JCC).

The pricing structure that has been widely used in Asian LNG SPAs is as follows: PLNG = A+B×Pcrude oil, where A refers to a term that represents various non-oil factors, but usually a constant determined by negotiation at a level that can prevent LNG prices from falling below a certain level. It thus varies regardless of oil price fluctuation. Typical figures of ex-ship contracts range from USD 0.7 to 0.9. B is a degree of indexation to oil prices; typical figures are 0.1485 or 0.1558, and Pcrude oil usually denominated in JCC. PLNG and Pcrude oil stand for price of oil in USD per million British thermal unit (MMBTU (in the fuel industry, M stands for 1000 and MM for 1 000 000)). With the demand of LNG moving up and down, the price of LNG moves in a "S" curve. With new demand from China, India and US increasing dramatically, and crude oil price skyrocketing, the LNG price is on the rise too.

In the mid 1990s LNG was a buyer's market. At the request of buyers, the SPAs began to adopt some flexibility on volume and price. The buyers had more upward and downward flexibilities in TOP, and short-term SPAs less than 15 years came into effect. At the same time, alternative destinations for cargo and arbitrage were also allowed. By the turn of the 21st century, the market was again in favor of sellers. Sellers now propose rigid SPAs and would like an association similar to OPEC to be established to protect their interests. It is certain that the competition between sellers and buyers will go on.

Receiving terminals exist in several countries (see the list of importing countries in table below; China is expected to move onto the list by 2006), allowing gas imports from other areas (see list of exporting countries in table below).

The United States Department of Energy's Energy Information Administration provides estimates of LNG trade in 2002 as follows:

Country

Export volume

Country

Import volume

(109 ft³)

(106 t)

(109 ft³)

(106 t)

Indonesia

1,100  

23.0  

Japan

9,200  

188.3  

Algeria

935  

19.6  

South Korea

2,000  

40.7  

Malaysia

741  

15.6  

France

511  

10.7  

Qatar

726  

14.9  

Taiwan

363  

7.5  

Nigeria

394  

8.2  

United Kingdom

356  

7.3  

Australia

367  

7.7  

United States

229  

4.8  

Oman

356  

7.3  

Turkey

224  

4.6  

Brunei Darussalam

351  

7.2  

Portugal

146  

3.3  

United Arab Emirates

278  

5.7  

Spain

131  

2.7  

Russia

234  

4.8  

Italy

130  

2.6  

Trinidad and Tobago

189  

4.0  

Belgium

124  

2.7  

United States

68  

1.4  

India

122  

2.5  

 

LNG safety and accidents

In its liquid state, LNG is not explosive. For an explosion to occur with LNG, it must first vaporize and then mix with air in the proper proportions (the explosive range is 5% to 15%), and then be ignited afterwards. Serious accidents involving LNG to date are listed below:

  • 1944, 20 October. The East Ohio Natural Gas Company experienced a failure of an LNG tank in Cleveland, Ohio. 128 people perished in the explosion and fire. The tank did not have a dike retaining wall, and it was made during World War II, when metal rationing was very strict. The steel of the tank was made with an extremely low amount of nickel, which made the tank brittle when exposed to the extreme cold of LNG, and the tank ruptured, spilling LNG into the city sewer system.
  • 1973, February,Staten Island, New York. While repairing the interior of an empty storage tank, a fire started. The pressure increased inside the tank so fast the concrete dome on the tank lifted and then collapsed falling inside the tank and killing the 37 construction workers below.
  • 1979, Lusby, Maryland, at the Cove Point LNG facility a pump seal failed, releasing gas vapors, which entered and settled in an electrical conduit. A worker switched off a circuit breaker, igniting the gas vapors, killing a worker and causing heavy damage to the building. National fire codes were changed as a result of the accident.
  • 2004, 19 January, Skikda, Algeria. Explosion at Sonatrach LNG liquefaction facility. 27 killed, 80 injured, three LNG trains destroyed, 2004 production was down 76% for the year. A cold hydrocarbon leak occurred introducing the high-pressure steam boiler with gases via a combustion air fan. The explosion inside the boiler fire box precipitated a larger explosion of vapors outside the box.

Seaborne LNG transport tankers (including their loading terminals) have not had a major accident in over 33,000 voyages since maritime inception in 1959. There have, however, been several significant incidents with LNG ships, but with no spills. In addition to accidents, terrorism experts are concerned that intentional sabotage could lead to unprecedented releases, resulting in massive fires and other damaging effects. The latter may include detonations (producing large blast waves) and deflagration-to-detonation transition phenomena. As the Department of Energy notes in its December 2004 report (Sandia National Labs, SAND2004-6258), the available testing data on LNG spills are based on releases of very small size in comparison to releases expected from intentional attacks. Despite intense local opposition, the Federal Energy Regulatory Commission has approved a site permit for an LNG terminal in Fall River, Massachusetts in a densely populated harbor area.

LNG storage

LNG tanks are always of double-wall construction with extremely efficient insulation between the walls. Large tanks are low aspect ratio (height to width) and cylindrical in design with a domed roof. Storage pressures in these tanks are very low, less than 5 psig. Smaller quantities, 70,000 gallons and less are stored in horizontal or vertical, vacuum-jacketed, pressure vessels. These tanks may be at pressures anywhere from less than 5 psig to over 250 psig.

LNG must be maintained cold (at least below -117°F) to remain a liquid, independent of pressure.

LNG refrigeration

The insulation, as efficient as it is, will not keep the temperature of LNG cold by itself. LNG is stored as a "boiling cryogen," that is, it is a very cold liquid at its boiling point for the pressure it is being stored. Stored LNG is analogous to boiling water, only 470° colder. The temperature of boiling water (212°F) does not change, even with increased heat, as it is cooled by evaporation (steam generation). In much the same way, LNG will stay at near constant temperature if kept at constant pressure. This phenomenon is called "autorefrigeration". As long as the steam (LNG vapor boil off) is allowed to leave the tea kettle (tank), the temperature will remain constant. If the vapor is not drawn off, then the pressure and temperature inside the vessel will rise. However, even at 100 psig, the LNG temperature will still be only about -200°F.

Liquefied Natural Gas (LNG)

When natural gas is cooled to a temperature of approximately -260°F at atmospheric pressure it condenses to a liquid called liquefied natural gas (LNG). One volume of this liquid takes up about 1/600th the volume of natural gas at a stove burner tip. LNG weighs less than one-half that of water, actually about 45% as much. LNG is odorless, colorless, non-corrosive, and non-toxic. When vaporized it burns only in concentrations of 5% to 15% when mixed with air. Neither LNG, nor its vapor, can explode in an unconfined environment. Natural gas is composed primarily of methane (typically, at least 90%), but may also contain ethane, propane and heavier hydrocarbons. Small quantities of nitrogen, oxygen, carbon dioxide, sulfur compounds, and water may also be found in "pipeline" natural gas. The liquefaction process removes the oxygen, carbon dioxide, sulfur compounds, and water. The process can also be designed to purify the LNG to almost 100% methane.

Compressed natural gas (CNG)

Compressed natural gas (CNG) is natural gas pressurized and stored in welding bottle-like tanks at pressures up to 3,600 psig. Typically, it is same composition of the local "pipeline" gas, with some of the water removed. CNG and LNG are both delivered to the engines as low pressure vapor (ounces to 300 psig). CNG is often misrepresented as the only form natural gas can be used as vehicle fuel. LNG can be used to make CNG. This process requires much less capital intensive equipment and about 15% of the operating and maintenance costs.

Liquid Petroleum Gas (LPG)

Liquid petroleum gas (LPG, and sometimes called propane) is often confused with LNG and vice versa. They are not the same and the differences are significant. LPG is composed primarily of propane (upwards to 95%) and smaller quantities of butane. LPG can be stored as a liquid in tanks by applying pressure alone. LPG is the "bottled gas" often found under BBQ grills. LPG has been used as fuel in light duty vehicles for many years. Many petrol stations in Europe have LPG pumps as well.

Photo of a natural gas fuel pump.

Compressed Natural Gas

Compressed natural gas is widely available throughout the U.S. from domestically produced natural gas wells and natural gas pipelines and local distribution companies. Natural gas is available to end-users through the utility infrastructure. It is also clean burning and produces significantly fewer harmful emissions than reformulated gasoline or diesel when used in natural gas vehicles. In addition, commercially available medium- and heavy-duty natural gas engines have demonstrated over 90% reductions of carbon monoxide (CO) and particulate matter and more than 50% reduction in nitrogen oxides (NOx) relative to commercial diesel engines. Natural gas can either be stored onboard a vehicle as compressed natural gas (CNG) at 3,000 or 3,600 psi or as liquefied natural gas (LNG) at typically 20-150 psi. Natural gas can also be blended with hydrogen.

Compressed Natural Gas and Compressed Natural Gas Vehicles

What Types of Vehicles Run on Compressed Natural Gas?

According to the Natural Gas Vehicle Coalition (NGVC), as of 2005 there are 130,000 light- and heavy-duty compressed natural gas (CNG) and liquefied natural gas (LNG) vehicles in the United States and 5 million worldwide.

Dedicated natural gas vehicles (NGVs) are designed to run only on natural gas; bi-fuel NGVs have two separate fueling systems that enable the vehicle to use either natural gas or a conventional fuel (gasoline or diesel). In general, dedicated NGVs demonstrate better performance and have lower emissions than bi-fuel vehicles because their engines are optimized to run on natural gas. In addition, the vehicle does not have to carry two types of fuel, thereby increasing cargo capacity and reducing weight.

There are a few light-duty NGVs still available, but if you want a specific type of vehicle, you may want to consider retrofitting a vehicle to an NGV by using an aftermarket conversion system. Heavy-duty NGVs are also available as trucks, buses, and shuttles. Approximately one of every five new transit buses in the United States is powered by natural gas.

As a new twist, tests are being conducted using natural gas vehicles that are fueled with a blend of compressed natural gas and hydrogen.

Vehicle Availability

This model year, auto manufacturers are producing fewer models than in years past. In order to get more vehicle options, you may choose to retrofit your own vehicle.

Fuel Availability

CNG fueling stations are located in most major cities and in many rural areas. Public LNG stations are limited and used mostly by fleets and heavy-duty trucks. LNG is available through suppliers of cryogenic liquids.

Vehicle Safety

Natural gas vehicles are just as safe as today's conventional gasoline and diesel vehicles. They use pressurized tanks, which have been designed to withstand severe impact, high external temperatures, and environmental exposure.

Adequate training is required to operate and maintain natural gas vehicles because they are different than gasoline or diesel vehicles. Training and certification of service technicians is required.

Vehicle Costs

In general, a natural gas vehicle can be less expensive to operate than a comparable conventionally fueled vehicle depending on natural gas prices. Natural gas can cost less than gasoline and diesel (per energy equivalent gallon); however, local utility rates can vary.

Purchase prices for natural gas vehicles are somewhat higher than for similar conventional vehicles. The auto manufacturers' typical price premium for a light-duty CNG vehicle can be $1,500 to $6,000, and for heavy-duty trucks and buses it is in the range of $30,000 to $50,000. Federal and other incentives can help defray some of the increase in vehicle acquisition costs. In addition, fleets may need to purchase service and diagnostic equipment if access to commercial CNG/LNG vehicle maintenance facilities is not available.

Retrofitting a conventional vehicle so it can run on CNG may cost $2,000 to $4,000 per vehicle.

Maintenance Considerations

High-pressure tanks that hold CNG require periodic inspection and certification by a licensed inspector.

Fleets doing on-site maintenance may need to upgrade their facilities to accomodate NGVs. Costs for upgrading maintenance facilities will depend on the number of modifications required.

Some natural gas vehicle manufacturers now recommend oil changes at intervals twice as long as similar gasoline or diesel models (10,000-12,000 miles). Refer to the vehicle owner's manual or consult the manufacturer to determine proper maintenance intervals.

Benefits

Compared with vehicles fueled by conventional diesel and gasoline, NGVs can produce significantly lower amounts of harmful emissions such as nitrogen oxides, particulate matter, and toxic and carcinogenic pollutants. NGVs can also reduce emissions of carbon dioxide, the primary greenhouse gas. For details, see the following publications from the U.S. Environmental Protection Agency:

  • The cost of a gasoline-gallon equivalent of CNG can be favorable compared to that of gasoline, but varies depending on local natural gas prices.
  • Natural gas is mostly domestically produced. In 2004, net imports of natural gas were approximately 15% of the total used, with almost all the imports coming from Canada.
  • Some natural gas vehicle owners report service lives 2 to 3 years longer than gasoline or diesel vehicles and extended time between required maintenance.

Performance

  • Vehicle range for CNG and LNG vehicles generally is less than that of comparable gasoline- and diesel-fueled vehicles because of the lower energy content of natural gas. Extra storage tanks can increase range, but the additional weight may displace some payload capacity.
  • NGV horsepower, acceleration, and cruise speed are comparable with those of an equivalent conventionally fueled vehicle.
  • Depending on the number of cylinders and their locations, some payload capacity may be compromised with NGVs.
  • Bi-fuel NGVs offer a driving range similar to that of gasoline vehicles.

Synthetic Gas

We provide "turnkey" Biomass Gasification solutions, and plan to be the leading provider of Biomass Gasification systems which generate clean, renewable "BioMethane" which in turn, provide a "Renewable Energy Credit." We also provide Biomass Gasifiers, Synthesis Gas and Methane Gas Recovery products and services which provide fuel for generating renewable energy and power as well as fuel for our cogeneration and trigeneration plants.

BioMethane is generated from Anaerobic Digesters, Anaerobic Lagoons, Biomass Gasification, Biomass Gasifiers, Biogas Recovery, BioMethane, and Concentrated Animal Feeding Operations Landfill Gas to Energy, and Methane Gas Recovery. Unlike most companies, we are equipment supplier/vendor neutral. This means we help our clients select the best equipment for their specific application. This approach provides our customers with superior performance, decreased operating expenses and increased return on investment.

We provide Cooler, Cleaner, Greener Power & Energy Solutions project development services that are Kyoto Protocol compliant and generate clean energy and significantly reduce carbon dioxide emissions. Unlike most companies, we are equipment supplier/vendor neutral. This means we help our clients select the best equipment for their specific application. This approach provides our customers with superior performance, decreased operating expenses and increased return on investment.

Renewable Energy Technologies provides project development services that generate clean energy and significantly reduce greenhouse gas emissions and carbon dioxide emissions. Included in this are our turnkey "ecogeneration" products and services which include renewable energy technologies, waste to energy, waste to watts and waste heat recovery solutions. Other project development technologies include; Anaerobic Digester, Anaerobic Lagoon, Biogas Recovery, BioMethane, Biomass Gasification, and Landfill Gas To Energy, project development services. Additional products and services provided by Renewable Energy Technologies include the following power and energy project development services:

  • Project Engineering Feasibility & Economic Analysis Studies
  • Engineering, Procurement and Construction
  • Environmental Engineering & Permitting
  • Project Funding & Financing Options; including Equity Investment, Debt Financing, Lease and Municipal Lease
  • Shared/Guaranteed Savings Program with No Capital Investment from Qualified Clients
  • Project Commissioning
  • 3rd Party Ownership and Project Development
  • Long-term Service Agreements
  • Operations & Maintenance
  • Green Tag (Renewable Energy Credit, Carbon Dioxide Credits, Emission Reduction Credits) Brokerage Services; Application and Permitting

We are Renewable Energy Technologies specialists and develop clean power and energy projects that will generate a "Renewable Energy Credit," Carbon Dioxide Credits and Emission Reduction Credits. Some of our products and services solutions and technologies include; Absorption Chillers, Adsorption Chillers, Automated Demand Response, Biodiesel Refineries, Biofuel Refineries, Biomass Gasification, BioMethane, Canola Biodiesel, Coconut Biodiesel, Cogeneration, Concentrating Solar Power, Demand Response Programs, Demand Side Management, Energy Conservation Measures, Energy Master Planning, Engine Driven Chillers, Geothermal Heat pumps, Ground source Heat pumps, Solar CHP, Solar Cogeneration, Rapeseed Biodiesel, Solar Electric Heat Pumps, Solar Electric Power Systems, Solar Heating and Cooling, Solar Trigeneration, Soy Biodiesel, Synthesis Gas, Synthetic Gas, Trigeneration, and Water source Heat pumps.

What is Synthetic Gas?

Synthetic gas, synthesis gas, or syngas, are the names given to gas of different (yet closely similar) to composition that are generated in coal gasification, coal liquefaction, gas liquefaction – also known as natural gas to liquids plants and other types of waste-to-energy facilities.

Gas Liquefaction Plant
A natural gas to liquids, or "gas liquefaction" ultra clean fuels facility in the U.S.

What is Natural Gas to Liquids?

Natural Gas to Liquids is also referred to as "Natural Gas Liquefaction," which is the process in which natural gas is converted from the gaseous to the liquid phase. At the end of the Natural Gas Liquefaction process, the product is referred to as Liquefied Natural Gas" or "LNG."

More about Natural Gas To Liquids or "Gas Liquefaction"

A first-of-its-kind, natural gas-to-liquids or "gas liquefaction" facility was built in the U.S. that produces high-performance, sulfur-free fuel. The gas liquefaction plant produces approximately 70 bbls of ultra clean fuel per day from natural gas.

New technologies in the "natural gas to liquids" industry decreases expenses through increased efficiencies and converts natural gas to ultra clean fuel. These facilities typically consist of three primary components: an autothermal reformer that converts the natural gas into synthesis gas, a mixture of carbon monoxide and hydrogen; a Fischer-Tropsch unit that produces synthetic crude oil from the synthetic gas; and a refining unit that upgrades the synthetic crude to ultra clean fuels. These fuels, which can then be transported through existing pipelines, are now being tested in bus fleets operated by the Washington, DC, Metropolitan Area Transit Authority and the National Park Service in Denali, Alaska.

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