Green Gas Solutions is a Nordic technology and project partner for green-gas and biogas projects.

We represent selected international technology suppliers and help customers evaluate solutions for gas treatment, upgrading, compression, grid injection and liquefaction. Our support can extend from early technical evaluation and contracting through delivery, commissioning, service and maintenance.

The name reflects the breadth of our work across the green-gas value chain.

Our solutions include H₂S removal, air and odour treatment, NH₃ stripping, biogas upgrading, gas compression, grid injection, CO₂ recovery and liquefaction, LBG production and hydrogen applications. These technologies are often integrated into biogas projects, but they can also support standalone industrial and energy applications.

Green Gas Solutions is based in Denmark and supports customers and projects across Denmark, Sweden, Norway, Finland and Iceland.

We combine local Nordic market knowledge with direct access to the specialists behind the technologies we represent.

We work with biogas producers, utilities, municipalities, EPC contractors, engineering companies, technology integrators, industrial operators and project developers.

Our role is adapted to the customer and project, from initial technology evaluation to equipment delivery, commissioning and long-term service.

Green Gas Solutions should ideally be involved during the feasibility or concept stage.

Early involvement allows gas composition, capacity, product specifications, utilities, site constraints and commercial priorities to be evaluated before the main technology and interfaces are fixed. We can also support later-stage projects, retrofits and replacement of existing equipment.

Hydrogen sulphide, or H₂S, is a toxic and corrosive gas commonly found in raw biogas.

Removing H₂S protects upgrading membranes, compressors, engines, pipelines and liquefaction equipment. The required outlet concentration depends on the downstream process, equipment guarantees and final gas specification.

There is no single H₂S removal technology that is best for every plant.

The right solution depends on the gas flow, inlet H₂S concentration, total sulphur load, load variation, required outlet concentration, oxygen limits, available utilities, footprint and operating priorities. GGS and ECOTEC evaluate these parameters before recommending biological, chemical or polishing technology.

Plant capacity alone should not determine the choice.

A dBiox® Bioscrubber separates H₂S absorption from biological regeneration. H₂S is first transferred from the biogas into a circulating liquid, which is then regenerated in a separate bioreactor.

A dBiox® Biotrickling system combines gas treatment and biological activity in a packed treatment unit where the circulating liquid, gas and microorganisms interact.

The appropriate system depends on sulphur load, gas flow, required outlet quality, available footprint and the requirements of downstream equipment.

No. ECOTEC’s dBiox® Bioscrubber is designed to remove H₂S without introducing oxygen into the treated biogas stream.

The biological regeneration takes place separately in the liquid phase. This helps preserve gas quality and avoids adding oxygen to downstream upgrading, compression or liquefaction processes.

Yes. ECOTEC H₂S removal systems can be engineered for both new plants and existing installations.

A retrofit assessment normally considers the raw-gas flow, H₂S concentration and variability, required outlet specification, pressure, temperature, available footprint, utilities and interfaces with existing equipment.

Yes. ECOTEC’s portfolio extends beyond biogas desulphurisation.

Available technologies include chemical scrubbers, biofilters and biotrickling systems for industrial air and odour treatment, as well as absorption and stripping solutions for ammonia-containing streams. Each system is configured according to the air or liquid flow, contaminant load and required emission or outlet limit.

Biogas upgrading is the process of removing CO₂ and specified contaminants from raw biogas to produce biomethane.

Depending on the required specification, the biomethane can be injected into the gas grid, compressed as CBG/CNG, liquefied into LBG or used in an industrial process.

BIMEO’s valorGas® system uses Evonik Sepuran® hollow-fibre membranes to separate methane from carbon dioxide.

Pretreated biogas is compressed and passed through the membrane system at a defined pressure, typically between 12 and 20 bar. CO₂ permeates through the membrane faster, while CH₄ is concentrated in the retained gas stream.

The three-stage membrane configuration recirculates lower-quality partial streams to improve methane recovery and product quality.

The achievable biomethane quality depends on the raw-gas composition, pretreatment, operating conditions and required product specification.

Product methane concentration, methane recovery and methane slip are different performance measures and should be specified separately. GGS and BIMEO define the relevant performance guarantees for each project rather than applying one figure to every installation.

Energy consumption depends on the feed-gas composition, inlet pressure, compression requirements, plant capacity, product pressure and selected configuration.

For this reason, energy performance should be calculated for the specific project. GGS and BIMEO provide expected consumption and operating data as part of the technical proposal.

A preliminary assessment normally requires:

• Raw-biogas flow in Nm³/h

• Minimum, normal and maximum flow

• CH₄ and CO₂ concentrations

• H₂S, oxygen, nitrogen, water and trace contaminants

• Feed pressure and temperature

• Required biomethane quality and delivery pressure

• Intended use: grid injection, CBG/CNG, LBG or industrial use

• Available utilities and site conditions

• Expected annual operating hours

The more complete the input data, the more accurately the system and its operating performance can be evaluated.

Potentially, yes. Biogas upgrading produces a CO₂-rich stream that may be captured, purified and liquefied instead of being released.

The commercial potential depends on CO₂ volume, composition, contaminants, required product grade, energy consumption, storage, transport and access to an off-taker. A concentrated CO₂ stream is therefore a starting point—not automatically a market-ready product.

No. A high CO₂ concentration alone does not make the gas food-grade.

The CO₂ must be cleaned, dried, purified, liquefied and verified against the applicable product and market requirements. The required process depends on the impurities in the incoming CO₂ stream and the intended application.

Depending on its quality and further processing, recovered biogenic CO₂ can support:

• Liquid CO₂ for industrial applications

• Food and beverage applications when the required quality is achieved and verified

• Greenhouse enrichment

• Carbon capture and utilisation, or CCU

• Power-to-X processes, including e-methanation, e-SAF and other synthetic fuels

• Carbon capture and storage, or CCS, for permanent underground storage

The most suitable route depends on local demand, logistics, product specifications and project economics.

LBG, also called bio-LNG, is upgraded biomethane that has been cooled to approximately −162°C and converted into liquid form.

Liquefaction significantly reduces its volume, making biomethane easier to store and transport where pipeline distribution or compressed gas is impractical. It can be used in applications designed for LNG, including heavy-duty road transport, maritime transport and off-grid energy supply.

Yes. Biomethane liquefaction and CO₂ purification and liquefaction can be integrated within the same biogas project.

MachOne solutions can be configured for LBG production, liquid CO₂ production or a combined plant. The optimal configuration depends on gas volumes, product specifications, available utilities, storage requirements and the intended markets for both products.

Through Fornovo Gas, GGS supplies reciprocating compressor solutions for raw biogas, biomethane, CNG, CO₂, hydrogen and other technical gases.

Applications include biogas upgrading, grid injection, pipeline boosting, gas storage and loading, CNG filling stations, carbon capture and liquefaction processes.

Oil-free or non-lubricated compression helps prevent cylinder lubricant from contaminating the process gas.

This can be important in biomethane upgrading, grid injection, high-purity gas applications and processes where oil carryover could affect downstream equipment or product quality. The appropriate compressor design depends on gas composition, inlet pressure, discharge pressure and operating profile.

Yes. GGS supplies Fornovo Gas compressor solutions for private, fleet and public CNG or compressed-biomethane filling applications.

The required solution depends on vehicle demand, filling profile, available gas pressure, storage capacity, target filling pressure and required redundancy.

A virtual pipeline transports biomethane by road rather than through a fixed gas pipeline.

The gas is compressed into high-pressure storage modules or liquefied into LBG, transported to another location and then unloaded for use. Compression, loading, storage and control systems must be designed around the required capacity and transport cycle.

There is no single grid-injection specification covering every Nordic project.

Requirements vary by country, grid operator and connection point. They can include methane content, oxygen, water and hydrocarbon dew points, sulphur compounds, pressure, Wobbe Index, metering, odourisation, control systems and documentation.

GGS supports the technical coordination, but the applicable requirements must always be confirmed with the relevant grid operator for the specific connection.

The delivery scope is defined for each project.

GGS can provide individual equipment packages, coordinate several complementary technologies or support a more integrated project delivery. Battery limits, responsibilities, civil works, electrical interfaces, installation, commissioning and service are clearly defined in the technical and commercial proposal.

Yes. GGS supports customers after commissioning and works with Terotech as its service and maintenance partner across the Nordic region.

Depending on the installation and service agreement, support can include preventive and corrective maintenance, planned shutdowns, troubleshooting, field mobilisation, rotating-equipment service, spare-parts support and maintenance planning.

There is no reliable standard lead time for every project.

The schedule depends on project maturity, permitting, data availability, engineering scope, equipment capacity, interfaces, manufacturing, site readiness and commissioning requirements. Once the technical scope has been defined, GGS provides a project-specific delivery schedule.

Send the information currently available, even if the project is still at an early stage.

Useful initial data includes:

• Gas or air flow

• Gas composition and contaminant levels

• Minimum, normal and maximum operating conditions

• Inlet and required outlet pressure

• Required product or emission specification

• Site location and available footprint

• Available utilities

• Intended application

• Expected operating hours

• Target project schedule

GGS will review the information, identify any missing data and bring the relevant technology specialists into the next stage of the assessment.