Move mixed production streams with fewer constraints, lower cost, and less separation-driven complexity.

Fluidstream multiphase compression helps operators recover production, reduce methane exposure, and simplify facilities in liquid-heavy field conditions conventional gas-only systems struggle to handle.

Based on patented operating methods for liquid-influenced compression behavior, including US11098709B2.

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Early proof

Real field results that show what the technology can do.

Fluidstream’s strongest credibility comes from measurable field outcomes: uptime, lower maintenance, reduced emissions, and meaningful production or revenue improvement under real operating conditions.

ALLIED ENERGY II

17+ months of continuous operation with no maintenance.

Fluidstream highlights sustained operation, eliminated venting, and winter-duty reliability as proof that its platform is built for field reality rather than brochure-only assumptions. The result shows dependable performance in demanding operating conditions.

100% uptime 17+ months • 0 maintenance • gas venting eliminated

VERMILION ENERGY

Production restored from near-zero to meaningful revenue.

The most commercially powerful multiphase proof point on the site is the Alberta case where Fluidstream helped revive two liquid-loaded wells without adding separation equipment or extra site infrastructure, showcasing unmatched efficiency.

C$1.5M+/year 10e3 m³/d gas restored • 5 m³/d condensate • no added separation

WHY THIS MATTERS

Performance proven in severe multiphase duty.

Severe liquid-influenced multiphase operation is a more demanding proof point than clean-gas service. If the technology is stable there, the differentiation argument becomes much stronger anywhere liquids create reliability, restart, or maintenance problems.

Higher credibility Severe field-condition proof

Field conditions

Where conventional compression starts to lose its fit.

Conventional compression is usually selected on the assumption that gas can be kept clean enough for the machine. In real field service, that assumption is often the problem. Liquids do not always stay upstream. Slugs do not arrive on schedule. Restarts do not happen under ideal conditions. Once the stream violates dry-gas assumptions, conventional systems often become protection-driven instead of production-driven.

Liquid carryover

Once liquids break through, the compressor is exposed to instability, damage risk, and a heavier maintenance burden.

Result: more trips, more intervention, less confidence.

Slugging and unstable flow

Conventional trains are easier to destabilize when inlet quality changes quickly or liquid fraction rises suddenly.

Result: shutdowns, throughput loss, and upset-driven downtime.

Shut-ins and restarts

Liquid fallback after shutdowns creates repeated unloading, cycling, and delayed return to stable operation.

Result: longer restarts and recurring lost production.

Separation-first dependence

Protecting a gas-only compressor often means adding more scrubbers, and site complexity.

Result: more equipment, more failure points, and weaker economics.

Fluidstream Technology Advantage

Designed for the hardest part of multiphase compression.

Multiphase compression is not just about accepting liquids. The real advantage is how the system responds to liquid-rich, unstable, and changing field conditions while maintaining control, containment, and reliability.

Liquid Response

Incompressible-liquid handling methodology

Fluidstream is engineered around liquid-influenced compression behavior, including liquid events inside the compression chamber that challenge gas-only compressor assumptions.

Controls

Autonomous target-pressure control

Operators define a target pressure and the system automatically modulates operation as flow, liquid content, slugs, and pressure conditions change.

Sealing

Patent-pending contained gland sealing

Advanced gland sealing is engineered for contained operation with reduced routine process-fluid leakage, reduced operator intervention, and improved site cleanliness.

Reliability

Seal-condition visibility

Electronic seal-condition monitoring provides operators real-time insight into seal wear, enabling proactive maintenance and preventing unplanned downtime or reliability issues.

Why operators choose Fluidstream

Why operators use multiphase compression.

Operators choose Fluidstream when too much equipment, too many failure points, and too much dependence on clean inlet assumptions are limiting production and weakening project economics.

Simplified production systems

Reduce dependence on separators, tanks, scrubbers, and flare-dependent process steps in suitable applications so the facility does less defensive work before production can move.

Flow-through production approach

Move mixed streams directly instead of forcing early processing before useful work can be done. This creates a cleaner path from wellstream to value.

Broader commercial deployment

Support lower-cost, lower-maintenance applications beyond niche or premium multiphase projects by improving the commercial fit at ordinary sites.

Why conventional systems create drag

Separation-first design adds cost, footprint, and operating constraints.

Conventional oil and gas facilities are built around separation. Production is processed through multiple stages: separators, tanks, scrubbers, and compressors before gas can be transported. That approach increases capital cost, expands footprint, adds interconnections, and creates operating constraints that are hard to justify when the stream itself is variable. The more unstable the stream, the more expensive this defensive architecture becomes.

Eliminate equipment

Reduce or remove separators, tanks, scrubbers, and flare-dependent process steps where the operating envelope supports a flow-through design.

Lower cost

Minimize capital investment, installation complexity, and lifecycle maintenance burden by simplifying the facility around fewer major pieces of equipment.

Increase uptime

Maintain performance across changing flow conditions, liquid slugs, and unstable production profiles that create difficulty for separation-first systems.

A simpler production path

Simplifying the production system.

Fluidstream supports a facility-design shift toward less separation-first infrastructure, fewer major equipment items, and a clearer flow-through production approach where the technology can create value earlier in the process. The comparison is not cosmetic. It changes how many pieces of equipment have to work correctly before production moves.

Conventional system

separator flare gas compressor oil tank oil pump

High equipment count, larger footprint, more interconnections, more potential failure points, and more dependence on keeping the inlet stream clean enough for the compressor.

Fluidstream system

MultiphaseCommander™

Reduced infrastructure, simplified operation, lower cost structure, earlier production movement, and broader applicability across challenging field conditions.

Commercial advantage

Lower cost. Broader deployment. Better fit for hard-duty service.

Conventional multiphase technologies are often limited to high-value applications because their capital cost and maintenance complexity restrict where they can be economically deployed. Fluidstream is positioned differently: lower cost and lower maintenance support use across more wells, pads, facilities, and brownfield opportunities where the value case is easier to justify.

Lower capital cost

Simplified system design reduces upfront investment compared with conventional multiphase solutions that depend on more equipment, more integration, and more field complexity.

Reduced maintenance

Fewer wear-sensitive elements and a simpler system architecture decrease service frequency and lifecycle costs, which strengthens economics long after installation.

Expanded applications

Improved economics allow deployment beyond niche or premium projects and into standard wellsites, pads, and facilities where the technology otherwise would not clear the hurdle.

Best-fit applications

Not every site needs multiphase compression. The right sites need it badly.

Multiphase compression creates the most value where liquids, slugging, restart issues, or unstable production are already limiting performance. In cleaner, more stable dry-gas service, conventional compression may remain an acceptable fit. Where field conditions are harder, Fluidstream offers a stronger operating and economic case.

Usually not required

Clean, dry, stable gas with little upset risk.

If the stream is consistently conditioned, liquids are truly controlled, and the application already fits conventional dry-gas compression, the need for multiphase capability is lower.

High-value fit

Liquids, slugging, restart issues, or unstable production are already costing money.

This is where Fluidstream creates the strongest advantage: fewer workarounds, less dependence on protective separation, and a better chance of keeping production moving under field conditions that do not stay tidy.

Applications

Where it creates value.

Fluidstream creates the most value where production is being limited by liquids, unstable flow, backpressure, restart problems, or unnecessary surface complexity.

Patent reference, where relevant to application fit: US11098709B2 supports the liquid-aware compression behavior behind Fluidstream’s broader multiphase operating approach.

Production recovery

Liquid-loaded and declining wells

Restore,extend producing life and improve the economics of marginal wells.

Why conventional fails: Gas-only compression loses stability when liquid fallback and intermittent loading disrupt normal suction conditions and turn compression into a recurring intervention problem.

Maintains production as liquid fraction increases
Reduces compression limits created by liquid carryover
Helps keep late-life wells onstream longer

Flow stability

Slugging and unstable multiphase streams

Protect throughput and reduce trips when flow conditions change rapidly.

Why conventional fails: Conventional trains depend on steadier inlet quality and often require more upstream separation as slug frequency rises, which adds complexity without solving the root instability.

Handles intermittent slugs without full phase conditioning
Reduces upset-driven downtime
Supports more continuous operation under unstable flow

System constraints

Constrained gathering and high backpressure systems

Increase deliverability without a full facility rebuild.

Why conventional fails: Adding more surface equipment often increases complexity without materially lowering flowing pressure at the well or improving the stream fit to compression.

Reduces wellhead flowing pressure
Improves response under fixed line constraints
Adds production without new separation capacity

Restartability

Shut-in and intermittent operations

Shorten restart time and reduce repeat cycling after shutdowns.

Why conventional fails: Liquid accumulation after shut-ins often requires unloading or repeated cycling before stable compression returns, extending downtime and frustrating operators.

Tolerates liquid-rich restart conditions
Reduces dependence on pre-unloading steps
Supports a steadier return to production

Remote deployment

Infrastructure-limited and remote sites

Lower field burden where access, power, and maintenance resources are limited.

Why conventional fails: Separation-heavy layouts add equipment, controls, and intervention requirements that are harder to support in remote service environments and cost more to keep alive.

Minimizes equipment count and interdependencies
Reduces maintenance exposure in low-access areas
Supports compact deployment strategies

Commercial impact

Emissions reduction and production value capture

Capture more gas value with fewer process steps and less wasted production.

Why conventional fails: Processing requirements can exceed the value of lower-rate or variable mixed streams when too many steps are needed before compression, leaving gas stranded or uneconomic to recover.

Supports gas capture under variable liquid loading
Reduces venting and flaring dependence
Applies across vapor, casing gas, and mixed production streams

Request technical review

Find out whether your compression problem is actually a multiphase problem.

Use Fluidstream’s technical review when liquids, unstable flow, restart pain, scrubber breakthrough, or excessive maintenance suggest that the current compression approach is mismatched to the stream.

Use this review when you need to assess

Whether liquids or unstable flow are driving the current bottleneck
Whether separation-first design is adding avoidable cost and complexity
Whether multiphase compression can improve uptime, gas capture, or restartability
Whether the application fits Fluidstream’s technical and commercial envelope

Request Technical Review Contact Us