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HELIUM RECOVERY IN THE UNITED STATES

(Thousand cubic meters)
    2000   2001   2002   2003   2004
Crude helium:
Bureau of Land Management (BLM) sold (in-kind
and open market) -- -- -- 51,800 29,300
Private industry:                  
Private helium accepted and stored by BLM1 23,300 18,000 16,600 19,400 19,100
Helium withdrawn from storage -51,900   -62,900   -56,300   -54,500   -63,100
Total net helium put into storage -28,600 -44,900 -39,700 -35,100 -44,000
Grade-A helium:                  
Private industry sold 127,000 132,000 127,000 122,000 130,000
Total helium stored -28,600 -44,900 -39,700 -35,100 -44,000
Helium recovery from natural gas 98,000   87,000   87,400   86,900   86,000
-- Zero.
1Negative numbers denote a net withdrawal from BLM's underground storage facility, a partially depleted natural gas reservoir at the Cliffside field near Amarillo, TX.

 


In 1900, helium was essentially unknown. Even though it was first detected during the solar eclipse of August 18, 1868, and it was found to exist in rather large quantities in natural gas wells of the mid-continental United States, commercial recovery of helium did not develop until the onset of World War I. At that time, the British Government became interested in helium as a lifting gas and initiated a research program at the University of Toronto. 

By 1918, a small experimental plant was operating near Hamilton, Ontario. When the United States entered World War I, the task of establishing a domestic source of helium was given to the U.S. Bureau of Mines. 

In 1921, the first full scale U.S. helium production plant was completed near Forth Worth, TX, where about 47 million standard cubic feet of helium was produced from the Petrolia Field. It operated until 1929. Because the U.S. Navy was using almost all of the helium produced in the country for the Airship Program, the Bureau of Mines built a new plant near Amarillo, TX, which could produce as much as 25 million cubic feet per year of helium. Later, the Bureau of Mines built the Exell plant, also in Texas, which eventually became its last operating plant. These two plants extracted helium from natural gas produced from the Government’s Cliffside Field. Later, the Cliffside Field reservoir (also known as the Bush Dome) would become the only helium storage reservoir in the world.

In the 1950s, optimism about future markets for helium developed, and helium began to be considered as a resource during the cold war. Widespread use led to the Helium Act of 1960, which created the Helium Conservation Program, allowing for private helium production. As a result, five new private helium extraction plants were built over the next several years. From 1963 to 1973, the U.S. Government purchased helium from the private producers and stored it in Bush Dome.

The helium industry continued to grow as more uses for helium were discovered. By 1996, 14 private companies owned a total of 20 helium plants, and U.S. helium consumption had grown to 2.6 billion standard cubic feet per year.

In 2000, the United States still led the world in helium production, accounting for about 80% of world output. Twelve U.S. private companies owned and operated 21 domestic helium production plants. U.S. helium consumption had grown to over 3.4 billion standard cubic feet per year, and demand for helium continued to grow worldwide. By then, helium uses included cryogenics, pressurizing and purging, welding, atmospheric control, leak detection, breathing mixtures, lifting, and medical applications.

Grade-A helium (99.995% or better purity) sales volumes by private industry were 89.6 million cubic meters2 (3,230 million cubic feet) in the United States in 2000 (table 1). Grade-A helium exports by private producers were 37.0 million cubic meters (1,330 million cubic feet) for total sales of 126.6 million cubic meters (4,564 million cubic feet) of U.S. helium, about an 8% increase from 1999. For 2000, domestic helium sales growth remained relatively stable. However, helium exports increased significantly. The increase in exported helium was mostly due to increased European demand for helium.

 

 



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Legislation and Government Programs

The Federal Helium Program was established to provide all Federal agencies with current and estimated future helium needs to carry out Government programs authorized and funded by the U.S. Congress. The major Federal helium customers were the National Aeronautics and Space Administration, the U.S. Department of Defense, and the U.S. Department of Energy.

On October 9, 1996, the Helium Privatization Act of 1996 (Public Law 104-273) was signed into law. This legislation directed the Federal Helium Program to discontinue production and sale of refined helium by April 9, 1998. Some of the remaining key components of this legislation and applicable status updates are as follows:

• Dispose of all assets related to helium production, refining, and sales not later than 24 months after helium refinery closing.

STATUS: A historical review was initiated in June 1999, and reports were completed in August 1999. The phase 1 environmental site assessment was initiated in early 1999, and reports were completed in July 1999. The National Park Service was preparing a historic architectural engineering report on the Amarillo and Exell Plants. Additionally, an application was been filed with the Texas Voluntary Compliance Program for the Landis property, and a contractor was secured for sampling and assessment. Property disposal actions continued. 

Begin selling Federal crude helium reserves in excess of 16.6 million cubic meters (600 million cubic feet) on or before January 1, 2005, and complete sales by January 1, 2015.

STATUS: Crude helium sales (in kind) for helium that is sold to Federal agencies and their contractors by private companies began in January 1998. Open-market sales of crude helium were reviewed in a legislatively mandated study conducted by the National Academy of Sciences (NAS) concerning the impact on national, scientific, and military interests. The NAS study was completed in March 2000. 

Helium regulations, however, are being developed and, once in place, will be used to guide open-market sales of the crude helium. 

• Continue operation of the helium storage field system, which includes the storage field and the crude helium pipeline used for storage and distribution of Government-owned and privately owned crude helium.

• Continue collection of helium royalties and fees from sales of helium extracted from gas produced from Federal lands.

• Continue helium resource evaluation and reserve tracking to monitor helium availability for essential Government programs.

• Complete land transfer to the Texas Plains Girl Scouts Council.

STATUS: Historical and archeological reviews and environmental assessments were being carried out and were expected to be completed by August 2001.

Production

In 2000, 12 companies operated 21 privately owned domestic helium plants, 15 of which extracted helium from natural gas (table 2; figures 1, 2). All but two extraction plants used cryogenic extraction processes. 

The total sales of U.S. produced helium increased by 12.0% compared with that of 1999. All natural gas processed for helium recovery came from gasfields in Colorado, Kansas, Oklahoma, Texas, Utah, and Wyoming.

During 2000, 11 private plants purified helium by using pressure swing adsorption technology. Nine privately owned plants that produced grade-A helium also liquefied helium. The plant operators and plant locations are listed in table 2.

Domestic production data for helium were developed by the Bureau of Land Management (BLM) from records of its own operations, as well as from its own high-purity helium survey, a single voluntary canvass of private U.S. operations. Of the nine operations to which a survey request was sent, 100% responded. Those data plus data from BLM operations represent 100% of the total helium sales and recovery data listed in table 3.

Domestic measured helium reserves and indicated helium resources as of January 1, 2000, were estimated to be 8.9 billion cubic meters (323 billion cubic feet). The resources include measured helium reserves estimated to be 4.1 billion cubic meters (147 billion cubic feet) in natural gas from which helium is being extracted. The measured reserves included nearly 951 million cubic meters (34.3 billion cubic feet) stored by the BLM in the helium storage conservation system. Measured helium reserves from indicated resources of natural gas with helium content greater than 0.05% are estimated to be 1.8 billion cubic meters (65 billion cubic feet). Indicated helium resources, a category of reserves slightly less certain than measured reserves, in natural gas with less than 0.3% helium were estimated to be 3.1 billion cubic meters (111 billion cubic feet). The majority of these indicated reserves were derived from the Potential Gas Committee designation of unconfirmed/probable reserves
(Curtis, 2000, p. 2-3). 

Approximately 2.6 billion cubic meters (94 billion cubic feet), or 98% of the domestic helium reserves that are under Federal ownership from which helium is being extracted, is located in the Riley Ridge area in Wyoming and the Cliffside Field in Texas.

The changes in how the helium reserves have been reported above are meant to provide the reader a better view of the helium reserves from which helium is being extracted. The 4.1 billion cubic meters (147 billion cubic feet) is estimated helium reserves that can be extracted from natural gas production over the expected life of gasfields from which gas is currently being produced. 

The 1.8 billion cubic meters (65 billion cubic feet) is estimated measured helium reserves in gasfields, from some of which helium could be extracted in the future. The 3.1 billion cubic meters (111 billion cubic feet) is indicated helium resources in probable/unconfirmed natural gas resources from which helium is not likely to be extracted.

Most of the domestic helium resources are in the midcontinent and the Rocky Mountain regions of the United States. The measured helium reserves are in approximately 102 gasfields in 11 States. About 97% of these reserves are contained in the Hugoton Field in Oklahoma, Kansas, and Texas; the Panoma Field in Kansas; the Keyes Field in Oklahoma; the Panhandle West and the Cliffside Fields in Texas; and the Riley Ridge area in Wyoming. 

During 2000, the BLM analyzed 506 natural gas samples from 4 States in conjunction with its program to survey and identify possible new sources of helium. 

Consumption

In 2000, private industry supplied 100% of the domestic demand. The major domestic end uses of helium were cryogenics (24.4%), pressurizing and purging (19.9%), welding (18.2%), and controlled atmospheres (16.0%). Minor uses included leak detection (5.6%), synthetic breathing mixtures (3.1%), and chromatography/lifting gas/heat transfer (total 12.8%) (figure 3). Cryogenics, specifically magnetic resonance imaging applications, dominated liquid helium use. 

Estimated 2000 domestic consumption by end use was based on a 1996 end-use survey conducted by BLM Helium Operations to determine the trends in helium usage.

New regulations, effective November 23, 1998, concerning in-kind crude helium sales were published in 43 CFR chapter II, part 3195. These regulations require that helium refiners selling to Federal agencies and their contractors must buy an equivalent amount of crude helium from the BLM. Such sales are referred to as “in-kind crude helium sales.” In 2000, in-kind crude helium sales were 6.4 million cubic meters (231 million cubic feet) and were made by nine companies through contracts with the BLM.

Stocks

The volume of helium stored in the BLM helium conservation storage system, including the conservation pipeline network and the Cliffside Field, totaled 952 million cubic meters (34.3 billion cubic feet) on December 31, 2000. The storage system contained crude helium purchased under contract by the BLM from 1962 to 1973 and privately owned helium extracted by industry from natural-gas-supplying fuel markets and stored under contract. This and privately owned helium is returned to the owners as needed for purification to supply private demand. 

During 2000, 23.3 million cubic meters (840 million cubic feet of private helium was delivered to the BLM’s helium conservation system, and 51.9 million cubic meters (1,870 million cubic feet) was withdrawn for a net decrease of 28.6 million cubic meters (1,030 million cubic feet) of private helium in storage (table 4).

Transportation

Private producers and distributors shipped helium predominantly as a liquid in semitrailers. These semitrailers delivered the liquid helium to distribution centers where some of it was gasified and compressed into trailers and small cylinders for delivery to end users. The remaining liquid helium was sold as bulk liquid or repackaged in dewars of various sizes for delivery.

Prices

The price charged for crude helium to private companies for in-kind crude helium sales was $1.785 per cubic meter ($49.50 per thousand cubic feet) for fiscal year 2000.

Foreign Trade

In 2000, exports of grade-A helium increased to 37.0 million cubic meters (1.33 billion cubic feet) (table 1). Helium exports increased by 38.1% compared with those of 1999 and accounted for 29.2% of the U.S.-produced helium sales; private industry supplied all U.S. helium exports. The large increase in helium exports is attributed to increased European demand for helium. 

About 55% of the U.S. helium exports went to Asia, with Japan receiving about 71% of those exports. About 24% of the exported helium was shipped to Europe. Collectively, Belgium, France, Germany, and the United Kingdom received 94% of the helium exported to Europe. Other exports were as follows: 

Canada and Mexico, 8%; South America, 5%; Australia-New Zealand, 5%; the Middle East, 2%; Africa, Central America, and the Caribbean, less than 1% each. Import tariffs on helium established on January 1, 1998, remained at the 3.7% rate for normal-trade-relations nations and at the 25% rate for non-normal-trade-relations nations.

World Review

Excluding the United States, world production capacity of helium was estimated to be 29 million cubic meters (1.05 billion cubic feet). All known helium produced outside the United States was extracted in Algeria, Poland, and Russia (table 5).

Outlook

The total market for U.S.-produced helium increased by 8.2% compared with that of 1999. From 1995 to 2000, the market growth rate was about 5.7%. Expansion of the Asian helium market over the next 2 years is expected to moderate owing to the uncertain economic conditions in that region of the world. Competition from foreign helium producers will provide continued uncertainty to the strength of the U.S. exports to the global helium market. 

Helium sales in the private sector are expected to continue at a moderate growth rate of 5% during the next 3 years. Use of high-temperature superconductor materials in electric motor windings and increased fiber optics demands are expected to increase helium demand.

 

What is an Amine Plant?

Amine plants, also known as "Amine Units" are used in "gas sweetening" in the midstream oil and gas sector known as "gas processing." Amine plants provide H2S removal as well as CO2 removal from natural gas and liquid hydrocarbons. The process involves both absorption and chemical reactions. 

We provide amine plant sales and natural gas processing and engineering services.

What is a "Cryogenic Plant"?

A cryogenic plant is another term for a "gas processing plant." Gas processing plants produce natural gas liquids products, including ethane, at very low or "cryogenic" operating temperatures.


What are Gas Compressors?

Gas compressors are mechanical device that increase the pressure of a gas by reducing its volume. Gas compressors are responsible for moving the natural gas from the oil or natural gas production well to homes and businesses via natural gas pipelines and gas compression stations.

Gas compression also increases the temperature of the gas during compression.


What is Gas Gathering?

Gas Gathering are the physical facilities that accumulate and transport natural gas from a well to an acceptance point of a transportation pipeline are called a gas gathering system.
 



Gas Gathering lines are small-diameter pipelines move natural gas from the wellhead to the natural gas processing plant or to an interconnection with a larger mainline pipeline. Transporting natural gas from the wellhead to the final customer involves several physical transfers of custody and multiple processing steps. A natural gas pipeline system begins at the natural gas producing well or field.  Once the gas leaves the producing well, a gas gathering system directs the flow either to a natural gas processing plant or directly to the mainline transmission grid, depending upon the initial quality of the wellhead product. 

The processing plant produces pipeline-quality natural gas.  This gas is then transported by pipeline to consumers or is put into underground storage for future use.  Storage helps to maintain pipeline system operational integrity and/or to meet customer requirements during peak-usage periods. 

Transporting natural gas from wellhead to market involves a series of processes and an array of physical facilities. Among these are:

  • Gas Processing Plant – This operation extracts natural gas liquids and impurities from the natural gas stream.

  • Mainline Transmission Systems – These wide-diameter, long-distance pipelines transport natural gas from the producing area to market areas.

  • Market Hubs/Centers – Locations where pipelines intersect and flows are transferred. 

  • Underground Storage Facilities – Natural gas is stored in depleted oil and gas reservoirs, aquifers, and salt caverns for future use.

  • Peak Shaving – System design methodology permitting a natural gas pipeline to meet short-term surges in customer demands with minimal infrastructure. Peaks can be handled by using gas from storage or by short-term line-packing.  

The Natural Gas Gathering System

A natural gas pipeline system begins at a natural gas producing well or field. In the producing area many of the pipeline systems are primarily involved in "gas gathering" operations. That is, a pipeline is connected to a producing well, converging with pipes from other wells where the natural gas stream may be subjected to an extraction process to remove water and other impurities if needed. Natural gas exiting the production field is usually referred to as "wet" natural gas if it still contain significant amounts of hydrocarbon liquids and contaminants.

Under certain conditions some or all of the natural gas produced at a well may be returned to the reservoir in cycling, repressuring, or conservation operations and/or vented and flared. At this stage it is a mixture of methane and other hydrocarbons, as well as some non-hydrocarbons, existing in the gaseous phase or in a solution with crude oil. The principal hydrocarbons normally contained in the natural gas mixture are methane, ethane, propane, butane, and pentane. Typical non-hydrocarbon gases that may be present in reservoir natural gas are water vapor, carbon dioxide, helium, hydrogen sulfide, and nitrogen.

In proximity to the well are facilities that produce what is referred to as "lease condensate", that is, a mixture consisting primarily of pentanes and heavier hydrocarbons which is recovered as a liquid from natural gas. Other natural gas liquids, such as butane and propane, are recovered at downstream natural gas processing plants or facilities 

Once it leaves the producing area, a pipeline system directs flow either to a natural gas processing plant or directly to the mainline transmission grid. Non-associated natural gas, that is, natural gas that is not in contact with significant quantities of crude oil in the reservoir, is sometimes of pipeline quality after undergoing a decontamination process in the production area, and does not need to flow through a processing plant prior to entering the mainline transmission system.

The Natural Gas Processing Plant

The principal service provided by a natural gas processing plant to the natural gas mainline transmission network is that it produces pipeline quality natural gas. Natural gas mainline transmission systems are designed to operate within certain tolerances. Natural gas entering the system that is not within certain specific gravities, pressures, Btu content range, or water content level will cause operational problems, pipeline deterioration, or even cause pipeline rupture.

Natural gas processing plants are also facilities designed to recover natural gas liquids from a stream of natural gas that may or may not have passed through lease separators and/or field separation facilities. These facilities also control the quality of the natural gas to be marketed. Several types of natural gas processing plants, employing various techniques and technologies to extract contaminants and natural gas liquids, are used to produce pipeline quality "dry" gas. At many processing plants the primary objective is the production of dry gas (demethanizing). Any remaining natural gas liquids extraction stream is directed to a separate plant to undergo what is referred to as a "gas fractionation" process.

But a number of natural gas processing plants do include these gas fractionation plants  where saturated hydrocarbons are removed from natural gas and separated into distinct parts, or "fractions," such as propane, butane, and ethane. Essentially, natural gas is methane, a colorless, odorless, flammable hydrocarbon gas (CH4). Also present in natural gas production, especially that in association with oil production, are a number of petroleum gases. They include (in addition to ethane, propane and butane) ethylene, propylene, butylene, isobutane, and isobutylene. They are derived from crude oil refining or natural gas fractionation and are liquefied through pressurization.

The Transmission Grid and Compressor Stations

The natural gas mainline (transmission line) is a wide-diameter, often-times long-distance, portion of a natural gas pipeline system, excluding laterals, located between the gathering system (production area), natural gas processing plant, other receipt points, and the principal customer service area(s). The lateral, usually of smaller diameter, branches off the mainline natural gas pipeline to connect with or serve a specific customer or group of customers.

A natural gas mainline system will tend to be designed as either a grid or a trunkline system. The latter is usually a long-distance, wide-diameter pipeline system that generally links a major supply source with a market area or with a large pipeline/LDC serving a market area. Trunklines tend to have fewer receipt points (usually at the beginning of its route), fewer delivery points, interconnections with other pipelines, and associated lateral lines.

A grid type transmission system is usually characterized by a large number of laterals or branches from the mainline, which tend to form a network of integrated receipt, delivery and pipeline interconnections that operate in, and serve major market areas. In form, they are similar to a local distribution company (LDC) network configuration, but on a much larger scale.

Between the producing area, or supply source, and the market area, a number of compressor stations are located along the transmission system. These stations contain one or more compressor units whose purpose is to receive the transmission flow (which has decreased in pressure since the previous compressor station) at an intake point, increase the pressure and rate of flow, and thus, maintain the movement of natural gas along the pipeline.

Gas compressors are used on a natural gas mainline transmission system are usually rated at 1,000 horsepower or more and are of the centrifugal (turbine) or reciprocating (piston) type. The larger gas compression stations may have as many as 10-16 units with an overall horsepower rating of from 50,000 to 80,000 HP and a throughput capacity exceeding three billion cubic feet of natural gas per day. Most compressor units operate on natural gas (extracted from the pipeline flow); but in recent years, and mainly for environmental reasons, the use of electricity driven compressor units has been growing.

Many of the larger mainline transmission routes are what is generally referred to as "looped." Looping is when one pipeline is laid parallel to another and is often used as a way to increase capacity along a right-of-way beyond what is possible on one line, or an expansion of an existing pipeline(s).   These lines are connected to move a larger flow along a single segment of the pipeline system. Some very large pipeline systems have 5 or 6 large diameter pipes laid along the same right-of-way. Looped pipes may extend the distance between compressor stations, where they can transfer part of their flow, or the looping may be limited to only a portion of the line between stations. In the latter case, the looping often serves as essentially a storage device, where natural gas can be line-packed as a way to increase deliveries to local customers during certain peak periods.

To address the potential for pipeline rupture, safety cutoff meters are installed along a mainline transmission system route. Devices located at strategic points are designed to detect a drop in pressure that would result from a downstream or upstream pipeline rupture and automatically stop the flow of natural gas beyond its location. Monitoring the pipeline as a whole are apparatus known as SCADA which means Supervisory Control and Data Acquisition.  SCADA systems provide monitoring staff the ability to direct and control pipeline flows, maintaining pipeline integrity and pressures as natural gas is received and delivered along numerous points on the system, including flows into and out of storage facilities.

Natural Gas Market Centers/Hubs

Natural gas market centers and hubs evolved, beginning in the late 1980s, as an outgrowth of natural gas market restructuring and the execution of a number of  Federal Energy Regulatory Commission’s (FERC) Orders culminating in Order 636 issued in 1992. Order 636 mandated that interstate natural gas pipeline companies transform themselves from buyers and sellers of natural gas to strictly natural gas transporters. Market centers and hubs were developed to provide new natural gas shippers with many of the physical capabilities and administrative support services formally handled by the interstate pipeline company as “bundled” sales services.

Two key services offered by market centers/hubs are transportation between and interconnections with other pipelines and the physical coverage of short-term receipt/delivery balancing needs.  Many of these centers also provide unique services that help expedite and improve the natural gas transportation process overall, such as Internet-based access to natural gas trading platforms and capacity release programs. Most also provide title transfer services between parties that buy, sell, or move their natural gas through the center.

As of the end of 2008, there were a total of 33 operational market centers in the United States (24) and Canada (9).

Underground Storage Facilities

At the end of the mainline transmission system, and sometimes at its beginning and in between, underground natural gas storage and LNG (liquefied natural gas) facilities provide for inventory management, supply backup, and the access to natural gas to maintain the balance of the system. There are three principal types of underground storage sites used in the United States today: depleted reservoirs in oil and/or gas fields, aquifers, and salt cavern formations. In one or two cases mine caverns have been used. Two of the most important characteristics of an underground storage reservoir are the capability to hold natural gas for future use, and the rate at which natural gas inventory can be injected and withdrawn (its deliverability rate).

Most underground storage facilities, 327 out of 399 at the beginning of 2008, are depleted reservoirs, which are close to consumption centers and which were relatively easy to convert to storage service. In some areas, however, most notably the Midwestern United States, some natural aquifers have been converted to natural gas storage reservoirs. An aquifer is suitable for natural gas storage if the water-bearing sedimentary rock formation is overlaid with an impermeable cap rock. While the geology of aquifers is similar to that of depleted production fields, their use in natural gas storage usually requires more base (cushion) gas and greater monitoring of withdrawal and injection performance. Deliverability rates may be enhanced by the presence of an active water drive.

During the past 20 years, the number of salt cavern storage sites has grown significantly because of its rapid cycling (inventory turnover) capability coupled with its ability to respond to daily, even hourly, variations in customer needs. The large majority of salt cavern storage facilities have been developed in salt dome formations located in the Gulf Coast States. Salt caverns leached from bedded salt formations in Northeastern, Midwestern, and Western States have also been developed but the number has been limited due to a lack of suitable geology. Cavern construction is more costly than depleted field conversions when measured on the basis of dollars per thousand cubic feet of working gas capacity, but the ability to perform several withdrawal and injection cycles each year reduces the per-unit cost of each thousand cubic feet of natural gas injected and withdrawn.

Peak Shaving

Underground natural gas storage inventories provide suppliers with the means to meet peak customer requirements up to a point. Beyond that point the distribution system still must be capable of meeting customer short-term peaking and volatile swing demands that occur on a daily and even hourly basis. During periods of extreme usage, peaking facilities, as well as other sources of temporary storage, are relied upon to supplement system and underground storage supplies.

Peaking needs are met in several ways. Some underground storage sites are designed to provide peaking service, but most often LNG (liquefied natural gas) in storage and liquefied petroleum gas such as propane are vaporized and injected into the natural gas distribution system supply to meet instant requirements. Short-term linepacking is also used to meet anticipated surge requirements.

The use of peaking facilities, as well as underground storage, is essentially a risk-management calculation, known as peak-shaving. The cost of installing these facilities is such that the incremental cost per unit is expensive. However, the cost of a service interruption, as well as the cost to an industrial customer in lost production, may be much higher. In the case of underground storage, a suitable site may not be locally available. The only other alternative might be to build or reserve the needed additional capacity on the pipeline network. Each alternative entails a cost.

A local natural gas distribution company (LDC) relies on supplemental supply sources (underground storage, LNG, and propane) and uses linepacking to "shave" as much of the difference between the total maximum user requirements (on a peak day or shorter period) and the baseload customer requirements (the normal or average) daily usage. Each unit "shaved" represents less demand charges (for reserving pipeline capacity on the trunklines between supply and market areas) that the LDC must pay. The objective is to maintain sufficient local underground natural gas storage capacity and have in place additional supply sources such as LNG and propane air to meet large shifts in daily demand, thereby minimizing capacity reservation costs on the supplying pipeline.


Prior to FERC Order 636 in 1992, many interstate pipeline companies had a completely integrated supply system that was capable of delivering natural gas from the wellhead to the ultimate retail gas consumer. But, following Order 636, which separated gathering, marketing, and transmission operations, many pipeline companies reorganized and broke up this system into discrete parts and assigned them to affiliated companies. 

The facilities, functions, and services required for gathering, processing, and transportation were placed in affiliated companies or were spun off or sold to other companies. Since most gas prices were no longer regulated, gas gathering service charges became subject to market forces and were a function of buyer/seller negotiation, isolated from the transmission charges imposed by the pipeline transporter.

More about Gas Gathering

The corporate reorganizations brought about under the influence of FERC Order 636 caused a shift in the jurisdictional entities regulating the various facilities and services. The Federal Energy Regulatory Commission (FERC) had once regulated the entire integrated interstate pipeline system, but after the reorganizations, FERC became the regulating entity for only the interstate pipeline transportation and processing facilities and services. The spun-off or affiliated gathering facilities and services generally fell under state jurisdiction or other Federal agencies, such as the Department of the Interior, but in some cases FERC maintained jurisdiction. Especially unclear, and still contested in 2004, is the jurisdictional status of some Gulf of Mexico gathering systems.




These cases involve FERC's reclassification of portions of a pipeline's system operating on the Outer Continental Shelf (OCS) as non-jurisdictional gathering facilities and FERC's determination that a pipeline company can transfer those facilities to its non-jurisdictional gathering affiliate. The key consideration in these, and similar onshore cases, is that FERC retains rate jurisdiction over those reclassified facilities that the pipeline retains and thus may regulate rates charged for transportation on the pipeline's own gathering facilities performed in connection with jurisdictional transportation. Rates on non-jurisdictional facilities are market based and not subject to FERC oversight or review. Consequently, some shippers have raised complaints that rates on non-jurisdictional facilities may exceed a reasonable rate by an undue degree.

As a result of FERC's decision in Order 636 to promote competition by requiring interstate pipelines to "unbundle" their previously bundled sales and transportation into separate services and to transport natural gas for all qualified shippers, some such pipelines have sought to shed OCS facilities that primarily perform a gathering function. Accordingly, those pipelines have asked FERC to reclassify OCS facilities that were previously classified as transportation, and to authorize "spin-downs" of OCS gathering facilities to affiliates.

To differentiate jurisdictional transportation and non-jurisdictional gathering for pipelines, FERC for many years has employed two principal tests. Under the "behind-the-plant" test, facilities upstream of compressors and processing plants (i.e., toward the wellhead where the gas comes out of the ground) were presumptively gathering facilities, while facilities downstream of the plants (i.e., toward the consumer) were presumptively transportation facilities. For gas that requires no processing, FERC employed a "central-point-in-the-field" test, under which lateral lines that collect and transport gas from separate wells that then converge into a single large line were classified as gathering facilities, while facilities downstream of the collection point in a field were classified as transportation. Since 1983, FERC has subsumed those two tests into a "primary function" test that focuses on a number of physical factors (e.g., length, diameter, and configuration of a pipeline) and certain other criteria, to determine whether facilities are primarily devoted to gathering or transportation. Under the primary function measure, no one factor is determinative, nor do all factors apply in every situation.

FERC developed its primary function test in the context of onshore gathering patterns. For natural gas produced on the Outer Continental Shelf (OCS), pipelines generally are configured differently and typically do not gather gas at a local, centralized point within a field as they would onshore to prepare it for traditional transportation. As stated in EP Operating Co. v. FERC (5th Circuit, 1989), "Rather, on the OCS, relatively long lines are constructed to carry the raw gas from offshore platforms where 'only the most rudimentary separation and dehydration operations' are conducted, to the shore or a point closer to shore, where it can be processed into 'pipeline quality' gas." It also notes that pipelines on the OCS must construct large pipes to carry (often over a 100 miles away) the raw gas from offshore rigs to the shore for processing. In response to the practical and physical differences between onshore and offshore pipeline configurations, FERC modified its primary function test for the OCS to allow for the increasing length and diameter of OCS gathering lines, and later announced that it would "presume facilities located in deep water [over 200 feet] are primarily engaged in gathering or production."


What is Gas Processing?

Natural Gas Processing plants separate the various hydrocarbons and natural gas liquids from the pure natural gas (methane or CH4) to produce what is known as 'pipeline quality'  natural gas. Natural gas pipeline companies have requirements on natural gas they buy from producers which is why the natural gas processing plants are located where they are, and why they separate the ethane, propane, butane, and pentanes from the methane.  Natural gas liquids or NGLs include ethane, propane, butane, iso-butane, and natural gasoline.


What is Gas Sweetening?

Sulfur exists in natural gas and is known as hydrogen sulfide (H2S).  Natural gas is usually considered "sour" if hydrogen sulfides content exceeds 5.7 milligrams of H2S per cubic meter of natural gas. The process hydrogen sulfide removal from sour gas is commonly referred to as "gas sweetening."



Diagram of the Gas Sweetening Process

The primary process for sweetening sour natural gas is quite similar to the processes of glycol dehydration and NGL absorption. In this case, however, amine solutions are used to remove the hydrogen sulfide. This process is known simply as the 'amine process', or alternatively as the Girdler process, and is used in 95 percent of U.S. gas sweetening operations. The sour gas is run through a tower, which contains the amine solution. This solution has an affinity for sulfur, and absorbs it much like glycol absorbing water. There are two principle amine solutions used, monoethanolamine (MEA) and diethanolamine (DEA). Either of these compounds, in liquid form, will absorb sulfur compounds from natural gas as it passes through. The effluent gas is virtually free of sulfur compounds, and thus loses its sour gas status. Like the process for NGL extraction and glycol dehydration, the amine solution used can be regenerated (that is, the absorbed sulfur is removed), allowing it to be reused to treat more sour gas.

Although most sour gas sweetening involves the amine absorption process, it is also possible to use solid desiccants like iron sponges to remove the sulfide and carbon dioxide.

Sulfur can be sold and used if reduced to its elemental form. Elemental sulfur is a bright yellow powder like material, and can often be seen in large piles near gas treatment plants, as is shown. In order to recover elemental sulfur from the gas processing plant, the sulfur containing discharge from a gas sweetening process must be further treated. The process used to recover sulfur is known as the Claus process, and involves using thermal and catalytic reactions to extract the elemental sulfur from the hydrogen sulfide solution. 

Some of the above information from www.NaturalGas.org with our thanks.


What is Glycol Dehydration?

Glycol dehydration is used in the production and processing of natural gas by using a liquid desiccant that removes water from natural gas and natural gas liquids (NGL). 

Various types of glycols are used in this process including;

TEG is the most commonly used glycol in the natural gas industry.


What is H2S Removal?

H2S, or Hydrogen Sulfide, is a hazardous and corrosive element found in oil and natural gas which needs to be removed from the hydrocarbon before the oil or natural gas can be sold.  The hydrogen sulfides are usually removed in a mid-stream gas processing facility by either iron sponges or amine plants.

What is a Heater Treater?

A "Heater Treater" is used in the oil and gas production process and is used to removes water and gas from the produced oil - and to improve its quality for sale into a crude oil pipeline or for other transport. A heater treater typically combines the following components inside the heater treater:  a heater, free-water knockout, and oil and gas separator.

We provide gas gathering, gas compressors, and other E&P services. 

We are presently acquiring "midstream" energy plants and operations such as natural gas and natural gas liquids - along with the plant assets that treat natural gas - are found between exploration and production of oil and natural gas and the delivery to commercial, residential and industrial customers. Midstream energy assets include over 1 million miles of natural gas pipelines and 500 natural gas processing plants.


What is Natural Gas Treating?

As natural gas is produced from either a natural gas well, or from an oilwell which contains "associated gas," the natural gas must be treated or processed before it can be used at a home or business as a fuel.

Natural gas treating or natural gas processing, takes place at gas processing plants to remove the impurities and other hydrocarbons other than the methane itself, or CH4. 

The by-products and impurities of natural gas that must be treated or processed include; ethane, propane, butane, isobutane, pentane, isopentane and higher molecular weight hydrocarbons, as well as H2S or elemental sulfur, carbon dioxide (CO2), water vapor and sometimes helium and nitrogen.


What is "NGL Fractionation"?

NGL, or natural gas liquids fractionation plants purpose is to separate the mixed natural gas liquids stream into separated products. These natural gas liquids that are separated by heat at NGL Fractionation plants include; ethane, propane, normal butane, isobutane and natural gasoline.

 

Enhanced Oil Recovery
www.EnhancedOilRecovery.com

The "Green" Way to 
Produce America's Oil &
Provide for America's Energy Security

EOR Technologies is a new company that seeks to expand the use Enhanced Oil Recovery technologies in the U.S. and to end our dependence on foreign fossil fuels. 

EOR Technologies represents a significant opportunity for oil and natural gas well owners and operators to significantly increase their oil production and revenues through our range of EOR technologies and services.

With the recent plunge in oil prices, our principal investor is now "on the sidelines" and we are seeking a new strategic partner/investor and provider of "turnkey" EOR services. 

In the U.S., Enhanced Oil Recovery represents a $24 Trillion market opportunity according to the U.S. The Department of Energy.  The $24 Trillion figure is based on oil at $100/bbl.  The DOE's studies and reports indicate we can recover 240 billion barrels of oil through Enhanced Oil Recovery. 

Enhanced Oil Recovery also has the environmental benefits of removing Carbon Dioxide from the atmosphere and sequesters the CO2 in oil & gas reservoirs.  Through CO2 Injection, the "stranded oil and gas" that would not have otherwise been recovered, is produced, leaving behind the Carbon Dioxide.

We are committed to reducing and eliminating greenhouse gas emissions and carbon dioxide emissions through our sustainable power and energy operations.

In association with the Renewable Energy Institute, affiliate companies and investors, we provide "turnkey" Renewable Energy Project development services that range from initial Engineering Feasibility & Economic Analysis Studies through "turnkey" project development, including construction/installation, start-up and commissioning, Operations & Maintenance, and Long Term Service Agreements for the lifetime of our power plants and energy systems.


EOR Technologies include:

Carbon Capture and Sequestration
www.CarbonCaptureAndSequestration.com


CO2 - EOR
www.CO2-EOR.com


CO2 Injection
www.CO2Injection.com



CO2 Flooding
www.CO2Flooding.com


EOR Technologies

www.EORtechnologies.com


Nitrogen Injection
www.NitrogenInjection.com


Stranded Oil and Gas
www.StrandedOilAndGas.com


Stranded Gas
www.StrandedGas.com

Stranded Oil
www.StrandedOil.com


Steam Injection

www.SteamInjection.com


Steam Assisted Gravity Drainage

www.SteamAssistedGravityDrainage.com


Toe to Heel Air Injection

www.ToeToHeelAirInjection.com


For more information about EOR Technologies,  
send email to:  info@EnhancedOilRecovery.com

 

We Support American Energy Independence, 
and While We Also Believe We Need to "Go Green"
And to Go-Green at "Full Speed Ahead,"
America Needs to Produce America's Oil,
Without Being Dependent on Saudi Arabia, Venezuela, Russia or OPEC

 

Never Again, Will America Be Held Hostage to Oil Sheiks, OPEC and
From Countries that Don't Like Us.

 

America Needs America's Oil!
www.AmericaNeedsAmericasOil.com

 

Drill Baby Drill!
www.DrillBabyDrill.com

 

We develop renewable energy projects, and specialize in solar power and energy project development. Our company provides the total, turnkey solar energy system "in-house" as well as with affiliates and strategic partners.  This means our capabilities and core competencies include solar project:

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When It Comes to Energy Independence,
Biomethane, Not Coal, is America's "Ace in the Hole"
and One of the Greenest of All Biofuels


It's Time to Start Building Our Country's Biomethane Infrastructure &
Producing Biomethane, the Cleanest/Greenest Biofuel!


By:  Monty Goodell, MBA
Biomethane Technologies
www.Biomethane.com

Biomethane, NOT Coal, is America's True "Ace in the Hole" when it comes to our energy future, economics, the environment, sustainability and America's “Energy Independence.” And biomethane is also receiving recognition as one of the greenest of all biofuels.   

For years now, the coal industry has been touting "coal is America's 'Ace in the Hole'" when they discuss the abundance of our coal reserves here in the U.S. and the role they hope coal will play in America's energy future.

But coal is far from being the “Ace in the Hole” the coal lobby would have everyone believe.  That’s due to the proverbial “black eye” not to mention the “black lungs” and other problems that are inherent with “dirty coal.”  

While there may be a place for coal in America's energy future, coal must become "clean" for America to value it as a possible energy resource. Plans or building 18 new Coal fired power plants were cancelled in Texas last year due to the fact that coal isn't clean, and utilities aren't interested in investing the extra costs for building power plants that use "Clean Coal Technology" or "Integrated Gasification Combined Cycle" power plants that also now need to include "Carbon Capture and Sequestration" technologies to remove the carbon dioxide emissions from the stacks. Plans for many other coal fired power plants are being cancelled. And even now, owners of coal fired power plants (pulverized coal) are switching from coal, to biomass, and biomass gasification technologies, as the writing is on the wall.

Unless our society relishes the thoughts of moving back to the caves, and using candles, and foregoing our modern-day comforts, we need to move forward with renewable energy technologies such as biomethane, as the alternative is power shortages and blackouts.

We believe biomethane represents the best and greenest of all biofuels. There are no supply problems with biomethane, and we have a virtually unlimited supply for using biomethane wherever natural gas is presently used as a fuel.

It should be pointed out that biomethane is chemically no different than natural gas from the "fossil fuel" form of natural gas or CH4.

However, one important distinction between biomethane and the fossil-fuel variety of natural gas, is that the production and use of biomethane is “carbon neutral” in that the greenhouse gas emissions from biomethane use do not add any new net greenhouse gas emissions.

Biomethane starts out as “biogas” but must be cleaned and purified before it can be used as a renewable fuel.  The process of cleaning and purifying the biogas is called “biogas to biomethane.”  The impurities that are found in biogas include hydrogen sulfides, siloxanes, and carbon dioxide. When the impurities are removed from biogas, it is then referred to as biomethane and available for use as a clean fuel, just as the fossil-fuel form of natural gas is used. 

Biomethane reserves and supplies, unlike fossil-fuel natural gas, are virtually unlimited. Biomethane is produced from many sources including anaerobic digesters, wastewater treatment systems, landfills and most agricultural and forestry operations. Last year, the first Biomethane NGV refueling station was opened in Eugendorf, Austria.  Like a gas station provides gasoline for cars, the the NGV Biomethane station in Eugendorf provides biomethane for NGVs (Natural Gas Vehicles).  Presently, the station provides a blend of biomethane and natural gas.  Eventually, they hope to provide 100% biomethane for natural gas vehicles.  Companies and researchers in Germany and Austria have determined that “Cellulosic Biomethane” is the greenest of all biofuels, and the least expensive biofuel to produce.  Germany and Austria are now planting vast amounts of a form of Kentucky Bluegrass which will be harvested for use in producing “Cellulosic Biomethane,” through anaerobic digesters and fermentation.

Researchers from around the world, starting in Austria, are finding that grasses such as Kentucky Bluegrass are easily converted into biomethane as well as organic fertilizer. Cellulosic Biomethane production doesn’t require the fermentation of sugars or starches - as the first generation of liquid biofuels – requiring grains and oilseeds from food crops. As the Austrian Cellulosic Biomethane project shows, biomethane can be produced from a cellulosic biomass feedstock like grass. Yield estimates from the Austrian Cellulosic Biomethane research indicate that one natural gas vehicle can travel 10,000 to 15,000 miles on just one acre of Kentucky Bluegrass that was processed into biomethane.

At a Jan. 8, 2009 public workshop held by the California Natural Gas Vehicle Coalition, they documented the superior benefits and potential of biomethane as a clean, renewable energy resource.  The California Natural Gas Vehicle Coalition stated that Biomethane should be classified as a "Super Ultra Low Carbon fuel."  Super Ultra Low Carbon fuel is defined as providing at least an 82 percent reduction in greenhouse gas emissions - based on the California Air Resource Board’s analysis of biomethane from landfill gas.

Biomethane has a carbon dioxide emissions intensity of only 11 as compared with:

                                                                        67.9 for natural gas
                                                                        95.8 for diesel
                                                                        96.7 for gasoline

Biomethane can displace and substitute the equivalent of 29% percent of all petroleum diesel transportation fuel used - almost immediately.

According to the California Energy Commission and the Biomass Collaborative, landfills, wastewater treatment, and dairy waste sources - which are "developable today" and can start producing Biomethane almost immediately, with low investment/high returns, could yield 121 billion cubic feet of Biomethane. At $8.00/mmbtu, that's a $1 billion market opportunity in California alone.  The 121 billion cubic feet of Biomethane equals about 860 million gallons of petroleum diesel. California alone uses about 3 billion gallons of diesel annually for transportation. Emerging biomass gasification and Biomethanation technologies could more than double Biomethane supplies.

Biomethane - like natural gas from "fossil fuels" - can be compressed or liquefied. And using "Compressed Biomethane" is a significantly better choice as a transportation fuel than traditional "natural gas."

Biomethane is the "natural, natural gas" and is far better for the environment and the economy than natural gas. Biomethane, when "vented" to the environment, is 21 times more hazardous to the climate than carbon dioxide emissions which are the only emissions (and water vaport) from compressed natural gas vehicles' engines when used as a fuel.

Again, we are reminded that Biomethane is the same chemical compound as natural gas: CH4, and completely replaces and substitutes for natural gas. Engines, turbines, boilers and every other natural gas appliance can use Biomethane without any adjustments or modifications - just like natural gas.

Biomethane supplies, as opposed to natural gas supplies from the fossil fuel industry, are available in an unlimited supply.

Moving forward with a “Biomethane Infrastructure” is the direction our country needs to be moving as one of our fuel choices as we become energy-independent.  Every MCF of Biomethane that we use displaces about 8 gallons of gasoline and creates jobs that will never be outsourced or downsized.

(Some of the above information from the California Natural Gas Vehicle Coalition.)

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Please Support H.R. 1158, The Biogas Production Incentive Act of 2009 
to Help Create our Nation's Biomethane Infrastructure 
& Biomethane Reserves

SUMMARY:  The Biogas Production Incentive Act of 2009 if enacted, will amend the Internal Revenue Code to allow a business-related tax credit for the production, sale, or use of biogas. Defines biogas as a gas that is derived by processing qualified energy feedstock (i.e., manure of agricultural livestock and other organic agricultural or food industry byproduct waste material) in an anaerobic digester and that contains at least 52% methane and carbon dioxide and trace gases. Provides an increased credit for biogas produced from qualified cellulosic energy feedstock.


Dear Senator or Representative ________

I am writing to you in support of HR 1158, the Biogas Production Incentive Act of 2009 and recommend that Congress develops and passes this much needed legislation that provides a $4.27 per MMBTU tax credit for the production of Biogas – also known as "Renewable Natural Gas," "Renewable Biogas" or "Biomethane."

            H.R. 1158, the Biogas Production Incentive Act would establish this tax credit that will help jumpstart this vital industry.  Renewable biogas and biomethane have been heralded by many as being the greenest of all biofuels.  Biomethane has a carbon dioxide emissions intensity of only 11 as compared with 67.9 for natural gas, 95.8 for diesel and 96.7 for gasoline.  Biomethane can displace and substitute the equivalent of 29% percent of all petroleum diesel transportation fuel used - almost immediately.  The California Natural Gas Vehicle Coalition stated that Biomethane should be classified as a "Super Ultra Low Carbon fuel."  Super Ultra Low Carbon fuel is defined as providing at least an 82 percent reduction in greenhouse gas emissions - based on the California Air Resource Board’s analysis of biomethane from landfill gas.

The U.S. Congress has wisely supported the expanded use of domestic renewable resources through a variety of tax incentives and other programs.  Up to this point, Congress has focused primarily on measures that support the production of renewable liquid transportation fuels or electricity.  In the U.S., however, natural gas represents 23 percent of the energy consumed.

            Natural gas is the fuel of choice to provide residential and commercial heat for space and hot water in most applications and is used to produce steam in a variety of commercial and industrial applications. Natural gas is also the fuel that provides the energy to manufacture many industrial products including aluminum, steel, glass, chemicals, fertilizer, and ethanol.  

            Incentivizing the production of renewable natural gas or "Biomethane" from sources that include animal manure, landfills, renewable biomass and agricultural wastes will support expanding the role of renewables into this existing energy sector, where little opportunity exists today.   It will also create another business investment prospect for renewable project developers and the potential to expand rural economies while supporting existing industrial jobs and dramatically reducing carbon emissions.     

Please consider the following:

           Renewable Biomethane is a versatile form of bio-energy. It can be used directly at the site of production, or placed in the pipeline to support a variety of residential commercial or industrial applications.

           Renewable Biomethane produced from renewable sources including animal manure, landfills, renewable biomass and agricultural wastes can be produced at high efficiencies ranging from 60–70 percent.  Additionally, all of the technology components to produce renewable gas from this variety of sources exist today.

           Renewable Biomethane can be delivered to customers via the existing U.S. pipeline infrastructure.

           Renewable Biomethane can provide a renewable option for many heavy industries, which could save existing industrial jobs in a carbon constrained economy - while creating new rural green jobs to produce Renewable Biomethane.

           Renewable Biomethane production in digesters provides the agricultural sector additional environmental benefits by improving waste management and nutrient control. 


We believe this is a fiscally responsible proposal that will provide the following benefits:              

           Jump-start new biomethane gas production

           Begin the creation of the biomethane infrastructure and biomethane industry

           Increase biomethane “reserves”

           Creation of green jobs

           Expand the rural economy and increase revenues for farming and agricultural operations

           Increase energy independence

           Reduce greenhouse gas emissions.

Thank you for your support and consideration of this legislation.

Sincerely,

_______________________
Signature and address


Please write to your Representative and Senators, and ask them to support H.R. 1158 and the $4.27 per MMBTU tax credit for the production of Biomethane/Renewable Natural Gas, using the above letter as a suggested letter you are welcome to use as your own.

Thank you!  

For more information on Biomethane, see www.Biomethane.com

____________________________________________________________________________________

We help clients with tax credits when they use renewable energy technologies
such as the Synthesis Gas produced from Biomass Gasification plants.
__________________________________________________________________


Section 45 Tax Credits
Renewable Energy Tax Credits

Our renewable energy project development expertise has made us a leading authority of helping our clients with Section 45 Tax Credits.  Our company and our attorneys are skilled in the areas of renewable energy project finance and tax issues relating to renewable energy projects. We are able to assist our clients in connection with Section 45 tax credit project finance.

Our experience in Section 45 tax credits has helped us structure optimal renewable energy project solutions that match our clients unique economic and tax goals and requirements, which include regulatory constraints and regulatory compliance for most any state. 

Section 45 tax credits generate $.021 cents per kwh of electricity produced by the taxpayer and sold to an unrelated person or company. Section 45 tax credits are available for renewable electricity produced from certain renewable energy projects including, closed-loop biomass, open-loop biomass, geothermal power plants, solar energy, small irrigation power, municipal solid waste, and qualified hydro power production, refined coal and wind power generation.

See one of our following sites at: 

www.Section45TaxCredits.com   or  www.RenewableEnergyTaxCredits.com  

for more information or call:  (832) 758 - 0027 for more information

______________________________________________________________________________________________

Biomethane
www.Biomethane.com
The "Renewable Natural Gas"


The Unlimited Potential for Biomethane and Renewable Natural Gas 


Regarding Greenhouse Gas Emissions and 
Biomethane
/Renewable Natural Gas vs. Gasoline


Other Benefits and Incentives of Biomethane: 
The Federal Biogas/Biomethane Tax Credit:

Equal to 2.0 cents per KWH (approximately $5.66 per MMBtu) for electricity produced on-site from Biomethane.

All other uses of biogas and Biomethane in vehicles and producing electricity off-site) do not presently qualify for the Federal Biogas/Biomethane Tax Credit.


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Sewage Sludge
www.SewageSludge.com

We Turn Your City or County's Sewage Sludge 
Problems  into Profits and Green Energy

Sewage Sludge problems are a thing of the past!  and other organic waste streams with one or more of the following: Anaerobic Digester, Anaerobic Lagoon, Biogas Recovery, BioMethane, Biomass Gasification, Biosolids to Energy, Landfill Gas To Energy and Sewage Sludge "problems into profits"  project development services.  We provide the following power and energy project development services:

Biomethane: the Perfect Renewable Fuel!
Biomethane Far Better than B100 Biodiesel or E100 Ethanol

As Biomethane is a near perfect fuel, and since Biomethane represents the best of all biofuels in terms of Recycling Carbon, and has the highest Net Energy Balance, and as Biomethane technologies such as Anaerobic Digesters and Biomass Gasification development increases and becomes even more commonplace, one of the fundamental questions is: what is the size of the potential biomass resource supply in the U.S.?

In April 2005, the DOE and the U.S. Department of Agriculture (USDA) co-published a report assessing the potential of the land resources in the U.S. for producing sustainable biomass: Biomass as Feedstock for a Bioenergy and Bioproducts Industry: The Technical Feasibility of a Billion-Ton Annual Supply. Looking at forestland and agricultural land, the two largest potential biomass sources, this study estimates that the U.S. can sustainably produce up to 1.3 billion tons of biomass feedstock by mid-century. This would be enough feedstock to produce 60 billion gallons of B100 Biodiesel and E100 Ethanol with today's technologies.

This study doesn't address the opportunities for Biomethane production from biomass feedstock or Biomass Gasification technologies. Some recent estimates indicate that Biomethane could replace up to 50% of present natural gas consumption in the U.S. and in some countries, such as Iceland, Biomethane already provides 100% of the natural gas requirements.

There are many assumptions in the Billion Ton Study report that impact these estimates, but we believe the estimates reasonably reflect the potential availability and impact of biomass resources.

Of the total estimated resource, the study suggests that forestlands in the contiguous United States can produce approximately 368 million dry tons annually. This projection includes 52 million dry tons of fuelwood harvested from forests and woodlands, 145 million dry tons of residues from wood processing mills and pulp and paper mills, 47 million dry tons of urban wood residues including construction and demolition debris, 64 million dry tons of residues from logging and site clearing operations, and 60 million dry tons of biomass from fuel treatment operations.

Biomass to Biofuels

By "converting" biomass wastes – such as municipal solid waste, sewage sludge, crop residues, energy crops, and manure – into biofuels, this will resolve the energy, environmental and political problems in an economical and environmentally sound manner - that will produce over one million new jobs.

According to Jeff Seisler, Director of the European Natural Gas Vehicle Association, "Biomethane has an outstanding potential as a multifaceted solution to multifaceted social problems: urban and agricultural waste management, water purification, and clean air. Urban and agricultural waste can be processed into usable methane, as can the sewage during the water purification process. Cleaning and compressing the gas for use in vehicles then provides cleaner air than petroleum-consuming vehicles."

Continuing, Mr. Seisler states about Biomethane; "this environmental 'closed loop waste-to-energy-to-fuel used in vehicles that again truck the next load of waste to the energy processing plants-substitutes fossil fuels with a renewable resource and reduces greenhouse gases 100% as compared to over gasoline vehicles (on a well-to-wheel basis).

According to Peter Boisen Chairman, of ENGVA, "various well respected European research institutes now estimate more than three times better fuel output per hectare of land used than if going for ethanol or biodiesel. Sweden currently has a 51% Biomethane share, and Switzerland 37%. France, Norway, Germany and Austria use smaller amounts for vehicles. Iceland, completely without natural gas, uses 100% biomethane in its NGVs," Boisen says.  Continuing, Boisen adds, "China, India, Korea, the Ukraine, Spain and Italy are other examples of countries now starting up projects where Biomethane will be used as a vehicle fuel." 

"With the energy efficiency of the gas production process at 50% to 70% it's hard to think of a more socially acceptable and economic energy value for the transportation sector," Boisen says.

"Governments need to get out of their liquid fuel paradigm to refocus and balance their policies and communications to support the development of a Biomethane infrastructure. In Europe Biomethane has the potential to replace 20% of the petroleum consumed in the transport sector by 2030."


Biomethane is the Best of All BioFuels,
Biomethane Can Do It All!


BIOMETHANE FACTS

1.  Biomethane is One of the Most Common and Harmful of All Greenhouse Gas Emissions.

2.  Biomethane is 21 Times More Harmful to the Climate than Carbon Dioxide Emissions. Stated another way, Biomethane Causes Global Warming and Climate Change to Increase 21 Times Faster than Carbon Dioxide Emissions

3.  Biomethane Is A "Renewable Natural Gas."

4.  Biomethane is One of the Easiest and Most Profitable of all Greenhouse Gas Emissions to Recover and Control and is the perfect fuel for heating your home, drying your clothes, cooking your dinner, water heating, and even fueling your car!  Biomethane is also the cleanest of all fuels or biofuels for generating electricity in power plants.

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California and Sweden Sign Agreement to Jointly Develop 
Biomethane
and Other Renewable Fuels

Thursday, 29 June 2006
Sacramento, California USA and Sweden 

In a ceremony held at the Ministry of the Environment in Stockholm, representatives of the Kingdom of Sweden and the State of California signed an agreement pledging the two governments and their related industries to work together to develop bioenergy, with a particular emphasis on Biomethane

“Through a strong working relationship between its industry and government, Sweden is showing how bioenergy can be developed in a cost-effective manner that benefits its economy and environment. We are extremely pleased to have signed this Memorandum of Understanding (MOU) that will provide a basis for intensified collaboration between Swedish and California officials to develop a thriving bioenergy industry in California,” said Joe Desmond, Undersecretary for the California Resources Agency.

In particular, Sweden has been a global leader in terms of converting biowaste, largely agricultural material and residues, into usable Biomethane. This gas is then used to either generate electricity, residential heating, or as a transportation fuel.

More than 8,000 vehicles in Sweden are powered by a combination of natural gas and Biomethane. The vehicles include transit buses, refuse trucks, and more than 10 different models of passenger cars. There are more than 25 Biomethane production facilities in Sweden and 65 filling stations. The Swedish Biomethane industry has been growing at an annual rate of about 20 percent over the last five years.

According to the Swedish Gas Association, more than 50 percent of the methane used to power Sweden’s natural gas vehicles now comes from biological sources, up from 45% last year. Natural gas vehicle sales in Sweden are increasing at the rate of 25% per annum. 

Sweden was motivated to develop its Biomethane industry because it has no natural gas reserves, to more efficiently manage its waste, and to meet its obligations under the Kyoto Accord. Since Biomethane is developed from methane sources that would normally release into the atmosphere, it’s considered one of the most climate friendly fuels. Methane (and Biomethane) is 21 times more reactive as a greenhouse gas than carbon dioxide (CO2). Sweden is currently meetings its objectives and schedule as outlined in the Kyoto accord.

Biomethane is developed by heating up and breaking down biomaterials in an (Anaerobic Digesters) digester. Among other raw materials, Swedish operators feed their Anaerobic Digesters with slaughterhouse waste, swine manure, and even grassy crops. After the materials breakdown over a 20 day period, technology is then used to remove the impurities and produce Biomethane. Once cleaned-up, Biomethane is 98 percent methane and easily meets the Swedish and California pipeline standards.

The Memorandum of Understanding can be accessed on the California Resources Agency Web site: http://resources.ca.gov/press_documents/CaliforniaSwedenBiofuelsMOU.pdf

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Anaerobic Digesters recover valuable and toxic Biomethane from organic materials and prevents the Biomethane - which has a Global Warming Potential that is 21 times more harmful to our climate than Carbon Dioxide Emissions - from entering the atmosphere.  

Biomethane, which we also refer to as "Renewable Natural Gas" is used as a renewable fuel for our cogeneration and trigeneration power plants. Alternatively, we may sell the Biomethane to a customer and transport it to them from our Anaerobic Digesters via natural gas pipelines.

We believe Anaerobic Digesters and Biomethane represent exciting opportunities for generating renewable natural gas and profits - for multiple reasons:

1.  Anaerobic Digesters take an existing liability and waste (Biomethane) and convert it into an asset and " profit generator."

2.  Anaerobic Digesters mitigate and reverse climate change and global warming by preventing Biomethane to escape into the atmosphere, which is one of the major causes of climate change and global warming.  

Of all Greenhouse Gas Emissions, Biomethane is 21 times more harmful to the environment than Carbon Dioxide Emissions.

3.  Anaerobic Digesters are vital for renewable energy production and helping our country's drive for energy independence. 

4.  EVERY wastewater treatment plant as well as ALL Concentrated Animal Feeding Operations (CAFO's) - IN EVERY COUNTRY - will soon be installing Anaerobic Digesters to prevent Biomethane from entering the atmosphere and help reverse climate change as well as for use as a renewable fuel. Or, they will be replacing their existing inefficient and inferior mechanical wastewater treatment plants, with our "Natural Wastewater Treatment" plants! 

5.  The country of Sweden is the global leader in Biomethane production.  Sweden has identified the Biomethane opportunities and is converting biowaste derived from agricultural material and residues into usable Biomethane. The Biomethane is used to generate clean, renewable electricity, residential heating, and also as a transportation fuel. Biomass sources make up 45% of Sweden’s Biomethane.  Sweden's Biomethane industry has been growing at an annual rate of around 20% over the last five years.  Biomethane powers more than 8,000 transit buses, garbage trucks, and 10 different models of passenger cars in Sweden. Sweden now has more than 25 Biomethane production facilities and 65 filling stations. The country believes that since Biomethane is developed from natural, organic sources that would have been released into the atmosphere, that Biomethane is considered one of the most climate-friendly fuels. Biomethane is 98% methane and easily meets the Swedish and California pipeline standards.

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What is "Decentralized Energy"?

Decentralized Energy is the opposite of "centralized energy."  Decentralized Energy energy generates the power and energy that a residential, commercial or industrial customer needs, onsite. Examples of decentralized energy production are solar energy systems and solar trigeneration energy systems.

Today's electric utility industry was "born" in the 1930's, when fossil fuel prices were cheap, and the cost of wheeling the electricity via transmission power lines, was also cheap.  "Central" power plants could be located hundreds of miles from the load centers, or cities, where the electricity was needed. These extreme inefficiencies and cheap fossil fuel prices have added a considerable economic and environmental burden to the consumers and the planet.

Centralized energy is found in the form of electric utility companies that generate power from "central" power plants. Central power plants are highly inefficient, averaging only 33% net system efficiency.  This means that the power coming to your home or business - including the line losses and transmission inefficiencies of moving the power - has lost 75% to as much as 80% energy it started with at the "central" power plant.  These losses and inefficiencies translate into significantly increased energy expenses by the residential and commercial consumers.

Decentralized Energy is the Best Way to Generate Clean and Green Energy! 

How we make and distribute electricity is changing! 

The electric power generation, transmission and distribution system (the electric "grid") is changing and evolving from the electric grid of the 19th and 20th centuries, which was inefficient, highly-polluting, very expensive and “dumb.”  

The "old" way of generating and distributing energy resembles this slide:

 

The electric grid of the 21st century (see slide below) will be Decentralized, Smart, Efficient and provide "carbon free energy" and “pollution free power” to customers who remain on the electric grid.  The electric grid of the future will be comprised of both Onsite Power Generation plants and "utility scale power plants" that are fueled/powered with Biomass Gasification, Biomethane, Concentrating Solar Power, B100 Biodiesel, Distributed PV, EcoGeneration Systems, Geothermal Power Plants, Synthesis Gas, Rooftop PV, Solar Cogeneration, Solar Energy Systems, Solar Power Parks, Solar Trigeneration and Wind Power Generation  - located at Residential, Commercial, Industrial and City/Municipal Locations. 

Some customers will choose to dis-connect from the grid entirely.  (Electric grid represented by the small light blue circles in the slide below.)

The transmission grid will be upgraded to a "Transmission Superhighway" with green electrons now being wheeled via "High Voltage Direct Current."

Typical "central" power plants and the electric utility companies that own them will either be shut-down, closed or go out of business due to one or more of the following:  failed business model, inordinate expenses related to central power plants that are inefficient, excessive pollution/emissions, high costs, continued reliance on the use of fossil fuels to generate energy, and the failure to provide efficient, carbon free energy and pollution free power

Carbon free energy and pollution free power reduces our dependence on foreign oil and makes us Energy Independent while reducing and eliminating Greenhouse Gas Emissions.

For more information, call us at: 832 - 758 - 0027

* Some of the above information from the Department of Energy website with permission.

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Amazing Solar Fact!

Did you know that the silicon contained in only one ton of sand, 
and used in manufacturing solar photovoltaic panels, could 
produce as much electricity as burning 500,000 tons of coal?

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How To Reduce Greenhouse Gas Emissions

You can easily and affordably reduce or eliminate your company's "carbon footprint." 

Did you know that the United States Congress will be passing the S. 2191 "Cap and Trade" Law in 2009?  Did you know that Supreme Court ruled in April (2008) that the EPA already has the authority to regulate Greenhouse Gas EmissionsCap And Trade narrowly passed in the U.S. House of Representatives, and is now in the U.S. Senate, who has threatened to make even greater reductions of Greenhouse Gas Emissions in their final Bill of the Cap And Trade legislation. 

Are you ready for these new regulations?  We can help you get ready!

According to Monty Goodell, MBA, the Founder and Chairman of the Renewable Energy Institute, “Greenhouse Gas Emissions and Carbon Dioxide Emissions will be the world’s biggest commodity market and will probably soon be the world’s largest market, period." In fact,  Mr. Goodell anticipates that Greenhouse Gas Emissions and Carbon Dioxide Emissions will become one of the fasting-growing commodities and markets ever.

Every day, leading companies are spending millions of dollars going "GREEN" and reducing their Greenhouse Gas Emissions.

The Greenhouse Gas Emissions and Carbon Dioxide Emissions Market Potential is staggering!  According to a recent New York Times article, carbon trading is one of the “fastest-growing specialties in financial services.” 

Already, Greenhouse Gas Emissions Trading and International Carbon Trading markets are worth in excess of $50 billion/year. The United Nations expects this market to be valued in excess of $2 Trillion/year by 2012 and others are saying this could easily exceed $5 Trillion/year within the next several years!

DO THE MATH on the Carbon Dioxide Emissions market! 

You may be wondering, how can such a relatively new commodity grow so rapidly?  Here in the USA, 40 billion tons of Carbon Dioxide Emissions are produced every year. At the present price of $50 per ton of carbon dioxide, the Carbon Dioxide Emissions market is valued at $2.0 Trillion (40 billion tons of Carbon Dioxide Emissions x $50.00/ton).

How to Reduce Your Carbon Footprint

Carbon Emissions, Carbon Dioxide Emissions, and Greenhouse Gas Emissions can be reduced or completely eliminated with renewable energy technologies, such as our Solar Energy Systems - including our super high efficiency Solar Cogeneration and Solar Trigeneration energy systems.  Brown buildings can be upgraded in to green buildings and  "Net Zero Energy Buildings" through the products and services that we offer.  

Qualified commercial, government, industrial and municipal clients can affordably have one of our Solar Cogeneration and Solar Trigeneration energy systems installed, with ZERO up-front costs, with our Power Purchase Agreement.  Call (832) 758 - 0027 to learn more and find out if your business qualifies.

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Why We Need Renewable Energy, 
and a Feed In Tariff, NOW!

Monty Goodell, MBA, Founder and President of the Renewable Energy Institute, along with the Renewable Energy Institute's Scientific Advisory Board, which is comprised of several of our nation's leading experts, engineers, attorneys, professors and universities, is calling for our nation and all 50 states to adopt a Renewable Portfolio Standard (RPS) of at least 25% by 2025.

And even better than a Renewable Portfolio Standard, according to Mr. Goodell, is a "Feed In Tariff," which is the route Germany took, and why they have had such great success in their transition to a solar based economy. The fastest paths to jump-start the renewable energy industry, is through a "Feed In Tariff

A Feed In Tariff is superior to a Renewable Portfolio Standard," according to Mr. Goodell.  "For example, look at Germany's success in their transition to an economy based on the installation of solar energy systems, they adopted a Feed In Tariff, are further north from the Equator than we are here in the U.S., and they are placing solar panels on every rooftop and wind turbine generators throughout their country. They are leading the world in renewable energy technologies, primarily due to their early adoption of a Feed In Tariff"

What is a Feed In Tariff

A Feed In Tariff is a utility rate that is established by a state or federal government, that requires a utility to pay higher electricity rates for green electricity generated by the owners of the solar energy systems, whether that is a homeowner or business owner. Feed In Tariffs shifts the expenses of subsidizing green energy from taxpayers, to electricity ratepayers. Feed In Tariffs also include guarantee that the Feed In Tariffs' artificially higher rates, will continue for periods as long as 25 years.  

Germany's great success for jump-starting the solar energy industry there, first established Feed In Tariffs in 1999.  Germany now has about five times as many solar photovoltaic panels installed as the United States - even though their total combined installations of PV panels  still only account for about 0.5% of the electricity generated there. 

"So, we go with a Feed In Tariff in lieu of a Renewable Portfolio Standard.  Simultaneously, we need to start re-building our national electric grid, and transforming it into 'Transmission Superhighway' or 'Unified Smart Grid' and dramatically increase the nation's power supply as well as implement greater use of 'Energy Efficiency Measures' - also referred to as Energy Conservation Measures.  And we need to implement "real" 'Demand Side Management' programs.  Failure to move in these areas and to do so immediately increases the risks to our country, our national security and the climate" according to Mr. Goodell. 

According to Mr. Goodell, our nation is at a crossroads and we have been 'over the Middle Eastern barrel of their fossil fuels' long enough. We must shift from energy dependence to energy independence and place significant emphasis and investments in our national energy security and lower greenhouse gas emissions.    

Renewable energy, and only renewable energy provides the significant economic and environmental dividends our country now needs.  Preferably, our fledgling renewable energy  industry in the U.S., will be "jump-started" with a Feed In Tariff.  

Some of the economic and environmental dividends that renewable energy will provide our country, include:

According to the Energy Information Administration, the total US primary energy consumption is expected to increase from 100 quadrillion Btu (quads) in 2005 to 131 quads in 2030. However, the renewable electricity generation remains at 9% while use of coal increases 50 percent in 2030 to 57%.  Ethanol use is expected to increase from 4 billion gallons in 2005 to 14.6 billion gallons in 2030, yet that is only about 8% of total gasoline consumption.

In January (2008) the National Climatic Data Center (NCDC) blamed the burning of fossil fuels as a key contributor to global warming and accelerating climate change. The NCDC warned that the rate of the warming is accelerating and that the rise in temperatures over the past 9 years is “unprecedented in the historical record." This was underscored in February (2008) in the consensus report by the Intergovernmental Panel on Climate Change that concluded with near certainty that human activity was the main contributor to global warming.

The renewable energy industry, single-handedly, provides a powerful argument and solutions for these problems. 

Global warming and climate change are symptoms of a sick planet and the results of unrestrained "dumping" of huge amounts of pollution - in the form of carbon dioxide emissions and greenhouse gas emissions into the atmosphere.

The vast majority of carbon dioxide emissions and greenhouse gas emissions comes from "dirty" fossil fuels (coal, oil, and natural gas) used in making electricity at power plants and dirty fuels (gasoline and petroleum diesel) that run our internal combustion engines in our cars, trains, planes, and trucks. Our planet is home to millions and millions of internal combustion engines that run on dirty fossil fuels - whether they are fueled with gasoline for running our cars and lawnmowers or running on diesel fuel in the engines of trucks and ships like the very large crude carriers that transport the crude oil all around the world...... every internal combustion engine that is running on dirty fossil fuels is dumping millions and millions of tons of carbon dioxide emissions and greenhouse gas emissions into our atmosphere - which is aggravating and exacerbating our sick planet - and making manmade climate change and global warming more difficult to resolve through manmade remedies and solutions.

________________________________________________________________________ Why the U.S. Needs A "Unified Smart Grid" or 
"Transmission Superhighway"

According to Monty Goodell, the Chairman and Founder of the Renewable Energy Institute, "our country desperately needs to upgrade its' national electric grid.  The grid of today is a relic from the past, that is inefficient and costly.  Originally built in the 1930's, it is costing our nation approximately $120 billion every year due to its' outdated and out-lived existence.  The national power grid as designed and built in the 1930's does not have the efficiencies and capabilities to keep pace with the national power grid's demands of today." 

"What we need" according to Mr. Goodell, is what former Vice President Al Gore calls a "Unified Smart Grid" or what we prefer to call a "Transmission Superhighway."

A Transmission Superhighway would be buried underground and "wheels" or transmits the renewable power ("green electricity") from the wind farms of the midwest, and solar farms of the southwest, and geothermal farms of the west, to load centers throughout every corner of the U.S."

According to many estimates, the "Unified Smart Grid" or "Transmission Superhighway" could be built for about $400 billion.  Through its' increased efficiencies, savings and reliability improvements that it will provide, the nation's new "unified smart grid" will be paid in full, in less than 4 years. 

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For more information, call us at: 832 - 758 - 0027

* Some of the above information from the Department of Energy website with permission. 

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Greenhouse Gas Emissions Linked to 
the Loss of Polar Bears

Photo courtesy of Alaska Image Library. U.S. Fish and Wildlife Service


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“spending hundreds and hundreds and hundreds of billions of dollars every year for oil, much of it from the Middle East, is just about the single stupidest thing that modern society could possibly do. It’s very difficult to think of anything more idiotic then that.”   R. James Woolsey, Jr., former Director of the CIA

Price of Addiction
###
to Foreign Oil


About the Renewable Energy Institute, Climate Science,
Tax-payer Subsidies for Fossil Fuel & Nuclear Industries,
Peak Oil & America's Clear and Present Danger


Monty Goodell, MBA
Founder and Chairman
Renewable Energy Institute

The Renewable Energy Institute (REI) does not take a stand in the debate on global warming, and if there is global warming, is it "anthropogenic" or is it caused by the sun, or the sun's normal cycles.  Or, if there is " climate change," is it "global cooling" caused by the water vapor in the atmosphere? The stand we take is that we need to invest in renewable energy technologies, producing clean, renewable energy that doesn't pollute the planet, and end America's addiction to crude oil from foreign countries where we now spend OVER $1 Billion/day, to buy the oil we need, and some of those suppliers (muslims in foreign countries) take our dollars and make bombs and bullets and send our boys back in body bags. We need to stop this, and put American's back to work, generating "green power and energy" right here at home.

At the Renewable Energy Institute, we are waiting for the "true" scientists who doing the real research, to provide us with the science and answers critically needed to formulate correct policy - and not the phony " scientists" who are following politically-motivated and profit-driven agendas of the United Nations and government leaders. These phony scientists are not interested in conducting real scientific research.  Their very livelihoods are dependent on the government grants to fund their phony research that have pre-determined conclusions before and "research" is conducted.  

Political-interference by governments, governmental agencies, and bureaucrats that hand out billions of tax-payers dollars to phony scientists to conduct "junk science" and research,  expect the conclusions that supports anthropogenic global warming, or climate change. 

When scientists conclude in their research that they find no evidence of anthropogenic climate change or global warming, they are summarily dismissed, and black-balled from their communities and colleagues, and never again receive funding or grants.  Grants and funding by government bureaucrats with politically-driven agendas to "scientists" expecting their pre-determined results and conclusions supporting anthropogenic global warming must stop.

According to the International Energy Agency (IEA), in 2007

And since 1960:

Taxpayers have bankrolled the oil and gas industry, and the coal industry for 100 years now, and the nuclear industry for 50 years, to keep these dirty fuels and energy "cheap." Take away the tax-payer incentives and tax dollars, and we believe the real cost of gasoline, would be similar to the gasoline cost in Europe - $7.00 - $8.00/gallon!

In the meantime, our U.S. Military is spending billions of tax-payer dollars each year protecting the Straits of Hormuz where much of the world's crude oil is produced and shipped through the straits' international shipping lanes.  Each day, hundreds of "very large crude carriers" pass through the Straits of Hormuz carrying oil from OPEC and the Middle-East to the U.S. and many other countries. 

Isn't it time we take some of the tax-payer dollars supporting the nuclear, coal and oil and gas industries, and start incentivizing clean, renewable energy technologies that don't pollute or harm the environment in any way?  Isn't it time that America ends its reliance on non-sustainable energy sources and stop over $1 billion every day, to oil suppliers from foreign countries, and start putting this money in "solar on every rooftop?!?

Mercury Emissions from Coal Fired Power Plants Far More Harmful to the Planet and People than Greenhouse Gas Emissions

Regarding the harm being caused to our planet from energy use, far more harm is being done to the planet, as well as to people and plants and animals, particularly fish, from the mercury emissions from coal fired power plants than from the coal fired power plants' greenhouse gas emissions.  We surmise that if any polar bears have died as a result of an environmental problem, it was more likely from the high levels of mercury in their food chain, than from greenhouse gas emissions

The Renewable Energy Institute is supporting and advancing renewable energy technologies, as well as reducing and eliminating greenhouse gas emissions and the fossil-fuel problems related to America's oil addiction and ending our dependence on foreign oil.  The renewable energy technologies we support are already deemed to be economic, viable and practical. Solutions such as Solar Trigeneration energy systems (see www.SolarTrigeneration.com for more information) for any kind of facility or building - office buildings, shopping centers, data centers, university campuses, etc. 

Since 2003, a Solar Trigeneration energy system has been providing 100% of the power and energy for a 5,300 sq. ft. office building near downtown Los Angeles, and doing so without any connection to the electric grid, whether its 12 noon or 12 midnite!  

The Renewable Energy Institute is also involved in research and advocacy of "Net Zero Energy" (see: www.NetZeroEnergy.com for more information) and "Net Zero Energy Buildings" (see:  www.NetZeroEnergyBuildings.com for more information).  Net Zero Energy Buildings generate as much (or more) energy than they use, and export their excess power to the grid, which we believe needs to be updated into a "Transmission Superhighway."

Climate Change, Global Warming or Global Cooling?

The past 10 years indicates the opposite of "global warming" has occurred - that the "Earths Fever" has and that global cooling has taken place. 

Weather, on a daily basis, or even an annual basis, is not climate, and climate is not weather. 

"Climate change" is always taking place, from one day to the next, and one week to the next, as well as one year to the next. The planet's climate is an ever-evolving, changing and dynamic process.  

Again, researchers and scientists need to refrain from being political, and stay out of politics, and politicians need to stay out of the way of the scientists and researchers, and let them do their work.  Politicians, government leaders and bureaucrats scientists need true and accurate data and climate research from scientists that do not have a political agenda.

In the meantime, as there may still be 30 years of research before there are conclusive answers concerning anthropogenic climate change, can we "risk" 30 years of our children and grand children's future, should there is a link between climate change and greenhouse gas emissions?  Should we not err on the side of caution?

Hubbert's Peak Oil Predictions Now Proving True?

Marion King Hubbert was a geologist and scientist who worked at Shell Oil company's research lab in Houston, Texas.  Hubbert made several important contributions to geology, geophysics and petroleum geology.  Hubbert is most recognized for the "Hubbert Curve" and " Hubbert Peak Theory" which is now referred to as " Peak Oil. 

Hubbert's life work determined that the world has a finite amount of petroleum that can be produced.  (Similarly, there is a finite amount of coal.) Many scientists and engineers believe we have reached Hubbert's "peak oil" limit.  Hubbert's espouses that when 50% of domestic crude oil production has been reached, that there will be such significant upward demand on prices of the limited supplies of oil production, that the U.S. economy will experience severe economic, social, and political turmoil.

Hubbert's Peak Oil predictions have proven to be true and this is validated as the U.S. in the early 1970's produced about 60% of its' oil demand and imported 40%.  That equation has flipped since then, because our domestic oil production has been on the decline since 1970, so now, due to our declining domestic oil production, we have to import 60% of our oil supplies, to meet our country's oil/energy demands.

The Next Oil Shock Could be the "mother" of All Oil Shocks

How severe our economic calamity and next "oil shock" will depend upon a number of factors, including when this occurs, as well as the following:

1.  the dependence of the individual country upon its own crude oil production to meet its energy needs and to subsidize consumer imports; 

2.  the rate of relative decline in crude oil production; 

3.  the degree of difficulty encountered in replacing missing energy inputs; 

4.  the degree to which our country had prepared in advance for this inevitable geological and economic calamity.

Examples of past "oil shocks" and the economic and political calamities that followed:

United States: Our peak crude oil production of domestic oil occurred in 1970; the first "oil shock" and oil crisis followed in 1973 with the Arab/OPEC Oil Embargo.

Iran: Their peak crude oil production occurred in 1974; They had their islamic revolution 1979 that overturned government and replaced it with radical islam.

Soviet Union: Their peak crude oil production was in 1989; what happened next? 
Their country disintegrated and the collapse of the Soviet Union followed in 1991. 

Indonesia: Their peak crude oil production was in 1991; their financial and government crisis followed in 1997.

Iraq: Iraq's crude oil production was in 1989; they then invaded Kuwait (for their oil) in 1991.

Using Mr. Hubbert's predictions, that beginning around 2000  we would see peak (global) oil production, then, if the country's not weaning themselves off of their oil addiction, and had not begun making the switch to renewable energy, that the negative economic and political calamities would soon follow, including ever-increasing prices of energy that is from fossil fuels. 

Now is the time to begin weaning ourselves off of fossil fuels and making the transition to and increasing the use of renewable energy. If you don't believe in climate change, or global warming, GREAT! Join us in the switch to renewable energy and a fossil-free economy!

America's "Clear and Present Danger"

America Has INCREASED its' Dependence on Foreign 
Sources of Energy by 50% Since 1973.

America is even more "addicted" to foreign oil today, than we were in 1973 - 1974 when OPEC, Saudi Arabia and other suppliers from the Middle-East  stopped selling us their fossil fuels, and created a significant blow to our economy.

According to the CIA Fact Book, Every Day, the U.S.:

PRODUCES:      7,460,000 bbls of oil (within its borders)

CONSUMES:   20,800,000 bbls of oil


This Means that 65% of America's Energy Supplies are Now Imported from Suppliers from Foreign Countries.  

Simply put, about 65% of the gasoline in your car's gas tank, comes from a foreign country.

EVERY day, the U.S. must IMPORT over 13 million bbls of oil from foreign countries and foreign suppliers to meet demand. 


At $80/barrel of oil, this also means that $1,040,000,000.00 American Dollars leave our country, EVERY DAY, to foreign countries/suppliers of our fossil fuels, to pay for the energy we need. 


That's $1 Billion EVERY day leaving our economy, and going to support a foreign country's economy. 


Talk about our foreign trade deficit..... nearly $400 Billion each year, leaves our country to pay for our oil addiction and the energy we need.  To be exact, that's $379,600,000,000.00 American Dollars.

This is NOT acceptable.

America needs to quickly transition to Energy Independence. 

Renewable Energy is the Only Way America Can Achieve Energy Independence. 

Millions of new and sustainable American jobs would be created here at home, if we would end our addiction to foreign fossil fuels, and quickly transition to an economy based on renewable energy and renewable fuels, produced here in the U.S.A. 

The good news is that today, America already has all of the Renewable Energy Resources and Renewable Energy Technologies needed to make American Energy Independence a reality. 



Green Energy

According to Monty Goodell, Founder and Chairman of the Renewable Energy Institute, "our increased dependence and reliance on foreign energy supplies represents a Clear and Present Danger to our national security, our economy, and the lives and livelihood of every American. Energy - including the energy we use from imported fossil fuels, is the very "lifeblood" of the American economy as it is for every industrialized country.  An economy dies without it's lifeblood of energy. This Clear and Present Danger we face is far more serious than the problems related to greenhouse gas emissions.  And while greenhouse gas emissions are very serious issue, in the long-term, pales in comparison to America's vital national security interests and America's economic stability in the short term.  For this reason alone, America needs to transition away from its addiction to foreign energy supplies. And America's abundant renewable energy resources such as the energy we receive from the sun, and renewable energy technologies such as concentrated solar power (CSP) plants - can supply 100% of America's power requirements with a concentrating solar power plant measuring 75 miles by 75 miles, located in the Southwest U.S.  By generating America's power from concentrating solar power plants, America resolves its' short-term Clear and Present Danger as it relates to importing its energy from foreign countries, and the long-term problems relating to greenhouse gas emissions."

Continuing, Mr. Goodell states that "too many Americans have forgotten what happened to us in 1973, when the Arabs and OPEC brought the United States economy to a screeching halt during the OPEC Oil Embargo.  This happened because they (mainly the country of Saudi Arabia) disagreed with our foreign policy and is the reason why they "turned off the tap" of our need for their oil supplies. When Saudi Arabia and OPEC stopped the vital flow of oil to our country in 1973, they caused an "oil shock" that severely and negatively impacted our economy. 

Mr. Goodell's question for us to ponder is, "do these countries who sell us 60% of our daily energy requirements, like us and our foreign policy, or might they leverage our addiction to their fossil fuels, and turn off the tap to make us adjust or revise our foreign policy??  Like any addict, America's foreign policy may be held hostage to its addiction, and in this case, our addiction to foreign oil, may over-ride our national interests."

Have American's forgotten the gas shortages and long lines at 
their gas stations to get gas during the Arab Oil Embargo of 1973? 

"Apparently so."  Mr. Goodell states that "in 1973, America was 'addicted' and 'over the barrel' of foreign oil to the amount of 40%.  Forty percent of our energy 'needs' in 1973 came from countries - many of which didn't like us then, and I'm afraid, many of them still don't.  The difference between 1973 and today - is that today we receive 50% MORE foreign oil now than we did in 1973.  And now we know about the problems relating to greenhouse gas emissions that we didn't know then.  America needs to change course, and change course now, in terms of its' energy supplies and how we keep America's economy strong, without the threat of being held hostage to a middle-east tyrant or regime, that could once again, turn on us, and turn off our supply of foreign oil." 

Remember ????


" Sadly," Monty Goodell continues, " most Americans have forgotten the long lines of people waiting in their cars - lined up and waiting for gasoline at their nearby gas station, with lines that were many blocks long.  And, after waiting 4-5 hours, many even waiting overnight in many places, to finally take their turn to fill up their car with gasoline, only to find that the gas station had run out of gas." 

"Let me Repeat.... That was 1973 when we imported 40% of our daily energy requirements in the form of crude oil from overseas, and from foreign countries - and many of these from countries that don't like us.

Today, over 35 years later, America has yet to learn the lesson.  We cannot continue our reliance on energy from foreign countries that supply us with 60% of the crude oil that our refineries use as a feedstock for producing gasoline and diesel fuel for our cars and trucks comes from overseas. 

America is "over the barrel" and it's not our barrel, but the barrels of oil that we are addicted by and owned by other countries.  Why have we not learned the lessons we needed to learn in 1973 when we were cut-off from the vital energy supplies we need? 

Countries like China, are growing rapidly, and have an insatiable need for crude oil. China, with their booming economy, is increasingly growing in its clout and control over international supplies of crude oil - whether they do this through their ability to buy as much oil as they need on a daily basis, or whether they simply but American drilling rigs, technology, and explore and produce oil and gas from their own fields. China, is buying large amounts of oil for their country, and causing upward pricing on declining supplies. What happens if Russia, with all of their oil and natural gas, along with China and Venezuela, with or without the help of OPEC, decided to NOT sell oil to us????

To be sure, greenhouse gas emissions are a problem, and to some, greenhouse gas emissions are also a Clear and Present Danger, but not to the extent that it presents an imminent Clear and Present Danger

America's reliance for 60% of our energy "needs" coming from foreign suppliers is un-acceptable.

The "driver" to get America to begin reducing and eliminating fossil fuel use should be our nation's national security and the welfare and safety of its citizens. And this can all begin with developing and investing in our own renewable energy resources and renewable energy technologies, let's start by putting solar on every rooftop that has a clear and unobstructed view of the Southern sky. See www.RooftopPV.com  or  www.DistributedPV.com  for more information.  Let's create incentives begin with adopting a national "Feed In Tariff" as Germany did in 1990. 

America, we simply do NOT have the luxury of time on our hands.  We need to end our dependence and reliance on foreign fossil fuels, especially from countries that don't like us! We need to rapidly begin expanding renewable energy resources and renewable energy technologies from our vast and abundant renewable energy resources, such as; solar, solar energy systems, solar cogeneration, solar trigeneration, "solar on every roof," waste to energy, waste to fuel, biomass gasification, B100 Biodiesel, Biomethane, Synthesis Gas, geothermal, E100 Ethanol (from sugar cane and NOT from corn), and wind, where it makes economic sense."   


 

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