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Flare Gas Recovery Flare Gas Recovery & Methane Recovery Advertising, Business Development & Strategic Marketing
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Flare Gas Recovery Flare Gas Recovery & Methane Recovery Advertising, Business Development & Strategic Marketing
Advertise Here and Gain: *
New Customers
The
"only" site for
For more information, call/email:
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Flare Gas Recovery
www.FlareGasRecovery.com
What
is Flare Gas Recovery?
Flare
Gas Recovery units recover
valuable fuels that can be used to provide fuel for
an onsite power generation plant. Our waste-to-energy and waste to fuel
systems significantly or entirely, reduces your facility's emissions (such as
Flare
Gas Recovery
and Vapor
Recovery Units can be located in hundreds of applications
and locations. At a Wastewater Treatment System (or Publicly Owned
Treatment Works - "POTW") gases from the facility can be captured from
the anaerobic digesters, and manifolded/piped to one of our onsite power
generation plants, and make, essentially, "free" electricity for your
facility's use. These associated "biogases"
that are generated from municipally owned landfills or wastewater
treatment plants have low btu content or heating values, ranging around 550-650
btu's. This makes them
Additionally, if heat (steam and/or hot water) is required, we will incorporate our cogeneration or trigeneration system into the project and provide some, or all, of your hot water/steam requirements. Similarly, at crude oil refineries, gas processing plants, exploration and production sites, and gasoline storage/tank farm site, we convert your facility's "waste fuel" and environmental liabilities into profitable, environmentally-friendly solutions.
Flare
Gas Recovery
and Vapor
Recovery Units that are designed and engineered for
these specific applications. It is important to note that there are many
internal combustion engines or combustion turbines that are NOT suited for these
applications. Our systems are engineered precisely for your facility's
application, and our engineers know the engines and turbines that will work as
well as those that don't. More importantly, we are vendor and supplier
neutral! Our only concerns are for the optimum system solution
Our turn-key systems includes design, engineering, permitting, project management, commissioning, as well as financing for our qualified customers. Additionally, we may be interested in owning and operating the flare gas recovery or vapor recovery units. For these applications, there is no investment required from the customer.
For more information, please provide us with the following information about the flare gas or vapor:
Type
of gas being flared or vented (methane, bio-gas, landfill, etc.).
Chromatograph
Fuel/Gas analysis which provides us with the btu's (heating value) and the
composition of the gas and its' impurities such as methane (and the
percentage of methane), soloxanes, carbon dioxide, hydrogen, hydrogen
sulfide, and any other hydrocarbons.
Total amount of gas available, from all sources, at the facility.
* From the Department of Energy website with permission
We provide Flare Gas Recovery, Methane Recovery, Vapor Recovery Units and "Stranded Gas" solutions.
Our company provides turn-key project solutions (some through strategic partners and related companies) that include all or part of the following, some through our strategic partners or affiliated companies/engineers:
Project Engineering Feasibility & Economic Analysis Studies
Engineering, Procurement and Construction
Environmental Engineering & Permitting
Project Funding & Financing Options; including Equity Investment, Debt Financing, Lease and Municipal Lease
Shared/Guaranteed Savings Program with No Capital Investment from Qualified Clients
Project Commissioning
3rd Party Ownership and Project Development
Long-term Service Agreements
Operations & Maintenance
Green Tag (Renewable Energy Credit, Carbon Dioxide Credits, Emission Reduction Credits) Brokerage Services; Application and Permitting
We
also provide mid/upstream products and services, again, on a vendor-neutral
basis. This includes the following products, services and solutions that
include:
Gas Gathering System Sales
Engineering and Economic Feasibility Studies
Project Design & Permitting
Project Construction
Project Funding & Financing Options
Operations & Maintenance
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Flare Gas Recovery
www.FlareGasRecovery.com
_______________________________________________________________
Flare Gas Recovery
www.FlareGasRecovery.com
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www.FlareGasRecovery.com
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What
is a
Vapor Recovery Unit?
A vapor recovery unit is a device that captures or recovers valuable volatile organic compounds and other rich gas streams that may otherwise be a significant environmental pollutant or hazardous air pollutant. A well designed vapor recovery unit can pay for itself in less than 3 years and simultaneously mitigate a company's exposure to environmental liabilities.
What
is "Stranded Gas?" And, how
we help companies generate revenues from Stranded Gas
Stranded Gas refers to natural gas that has been discovered but has not, or will not be developed due to their location or the economics of getting the natural gas delivered to the marketplace.
We provide solutions for oil and gas companies with "Stranded Gas."
One of our solutions for oil and gas companies with Stranded Gas is to use the Stranded Gas as fuel that generates clean electricity with one of our gas turbine generators. For as little as $785/kW (plus shipping costs and any related set-up costs) you could be generating revenues with one of our gas turbine generators!
Did you know that approximately 40% of the world's available natural gas reserves are classified as "Stranded Gas?"
Natural gas pipelines have transported natural gas safely, reliably, and economically to the marketplace whenever large reservoirs of natural gas are found in locations where there were existing pipelines. Even for new natural gas fields, where there are large reservoirs and supplies of natural gas, pipelines were laid to transport the natural gas to markets. However, natural gas supplies from easy to find, and easy to produce fields have been on the decline. This leaves the "stranded gas" from the fields that have not been developed due to the economics, location, or the supply was not large enough. "Stranded gas" wells and reservoirs are becoming increasingly attractive opportunities as we can make the stranded gas a new profit center for your company.
We can help your company turn unproductive, zero revenue stranded gas assets into economic cash flows and a new source or revenues. Stranded gas wells with a nearby electric transmission line with a minimum production of approximately 70,000 cubic feet of natural gas per day - can become a new profit center with our assistance!
We can take wells that have been plugged in years ago, and make them productive by taking the stranded gas and placing one or more of our power plants at or near the site, and convert the stranded gas into electricity, and then selling it to the power grid - thereby creating a new profit center from shut-in wells. Shut-in natural gas wells can be made productive, with new revenues from generating cogeneration power for connection to the grid. It's much easier to transport electrons long distances, than it is to transport natural gas long distances.
Alternatively, depending on the location, we may be able to place our LNG equipment near stranded gas wells and convert the natural gas to Liquefied Natural Gas, and then transport the LNG to a nearby market.
About
Natural Gas Measurement
Natural
gas measurement is needed to accurately measure the flow of natural gas, whether
from an oil and gas production well, gas gathering system, pipeline delivery
point, city gate delivery points for local distribution companies/natural gas
utility companies, as well as sales to residential, commercial and industrial
customers. Natural gas measurement also includes the physical and chemical
makeup of gas mixtures, how the mixtures are affected by temperature and
pressure, and how to best determine and select the best natural gas measurement
equipment for the specific application. Accurate natural gas measurement also
includes the requirements to properly calibrate and maintain natural gas
measurement devices, whether they may be orifices or meters.
About Heater Treaters
A heater treater is utilized in oil and gas production facilities and gas gathering systems to make and transfer/apply heat to the natural gas that is produced from one of more production wells. Heater Treaters prevent the formation of water, ice and natural gas hydrates. These solids can plug the wellhead, chokes and flowlines. As water, and salt water is a by-product of many natural gas and oil production wells, the water may cool during the production process, and up through the well, as it nears the surface or wellhead. Since chokes in the wellhead restrict the flow of the oil and gas from the well, temperatures may drop due to the pressure changes of the choke. This may cause the water or hydrates to freeze and plug the well, thereby slowing or stopping the oil and gas production.
What is a Glycol
Dehydrator?
Glycol dehydrators are utilized in oil and gas production facilities to dry or condition the natural gas before sales to the gathering system or pipeline.
About
Gas Gathering:
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.
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.
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."
* Some of the above information from the Department of Energy website with
permission.
What is "Stranded Oil" and "Stranded Gas?" And, how we help companies generate revenues from Stranded Gas
Stranded Oil and Stranded Gas refers to oil and natural gas that has been discovered but has not, or will not be developed due to their location or the economics of getting the oil and/or natural gas delivered to the marketplace.
We provide solutions for oil and gas companies with Stranded Oil or Stranded Gas.
One of our solutions for oil and gas companies with Stranded Gas is to use the Stranded Gas as fuel that generates clean electricity with one of our gas turbine generators. For as little as $785/kW (plus shipping costs and any related set-up costs) you could be generating revenues with one of our gas turbine generators!
Did you know that about 60% to 75% of the world's "original oil in place" has been left and unproduced, and the wells have been abandoned because it was either too costly or difficult to produce the oil? This is Stranded Oil.
Did you know that 40% of the world's available natural gas reserves are classified as "Stranded Gas?"
Natural gas pipelines have transported natural gas safely, reliably, and economically to the marketplace whenever large reservoirs of natural gas are found in locations where there were existing pipelines. Even for new natural gas fields, where there are large reservoirs and supplies of natural gas, pipelines were laid to transport the natural gas to markets. However, natural gas supplies from easy to find, and easy to produce fields have been on the decline. This leaves the Stranded Gas from the fields that have not been developed due to the economics, location, or the supply was not large enough. Stranded Gas wells and reservoirs are becoming increasingly attractive opportunities as we can make the stranded gas a new profit center for your company.
We can help your company turn unproductive, zero revenue stranded gas assets into economic cash flows and a new source or revenues. Stranded Gas wells with a nearby electric transmission line with a minimum production of approximately 70,000 cubic feet of natural gas per day - can become a new profit center with our assistance!
We can take wells that have been plugged in years ago, and make them productive by taking the stranded gas and placing one or more of our power plants at or near the site, and convert the stranded gas into electricity, and then selling it to the power grid - thereby creating a new profit center from shut-in wells. Shut-in natural gas wells can be made productive, with new revenues from generating cogeneration power for connection to the grid. It's much easier to transport electrons long distances, than it is to transport natural gas long distances.
Alternatively, depending on the location, we may be able to place our LNG equipment near stranded gas wells and convert the natural gas to Liquefied Natural Gas, and then transport the LNG to a nearby market.
What
is an Amine Plant?
Amine plants is used for "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 Amine?
Amine, is the shortened form of " Mono Ethanol Amine" or MEA. MEA removes H2S or acid gases through a chemical reaction with hydrogen sulfide or carbon dioxide which forms a salt compound (see Gas Sweetening diagram below).
When the MEA
has absorbed the H2S ( and carbon dioxide) it is referred to as "
rich" MEA.
When the acid gases have been removed from the mono ethanol amine it's called
lean MEA.
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 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;
triethylene glycol (TEG)
diethylene glycol (DEG)
ethylene glycol (MEG)
tetraethylene glycol (TREG).
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 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"?
Natural gas liquids (NGL) fractionation plants 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.
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Flare Gas Recovery
www.FlareGasRecovery.com
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