Oil & Gas
Telemetry and safety systems for demanding process environments.
- Scope
- Ground to Cloud
- Approach
- Retrofit first
- Base
- Bangalore, India
The brief
What this sector asks of a control system
Process environments carry consequences that other industries do not. We work to the safety and reliability expectations the sector demands — hardened telemetry from remote assets, redundant control paths, and instrumentation rated for the area classification it sits in.
Every engagement starts the same way: we walk the floor, read the existing drawings, and write down what is actually installed before anyone proposes a platform. The sector decides the priorities — the plant decides the design.
Constraints we engineer around
What we bring
Disciplines we lead with in oil & gas
The same engineering team carries the work from the panel to the dashboard, so nothing is lost at a handover between vendors.
In detail
What shapes the work here
The constraints that decide how a system for this sector gets engineered.
Area classification drives everything
In classified areas the equipment specification is not a preference, it is a legal and safety constraint. Certification, protection method and installation practice all follow the zone, and the drawings must show it.
This shapes cost and lead time more than any other factor here, which is why classification is settled at the start rather than discovered during installation.
Safety functions stand apart
Safety instrumented functions are engineered, tested and documented separately from process control. Mixing the two — putting a trip in the same logic that runs the process — is how a single fault takes out both the control and the protection.
Independence, proof testing and documented function descriptions are what make the protection layer credible when it is examined.
Telemetry from places nobody visits
Wellheads, pipelines and remote stations report over links that are slow, intermittent, or both. Protocols are chosen for tolerance rather than throughput, and edge buffering keeps the record whole across an outage.
Power is often the harder constraint than signal, so the instrument set is specified for the energy budget available at the site.
Typical scope
What we are brought in to do
- Instrumentation and control for classified areas
- Safety instrumented functions engineered independently of process control
- Remote telemetry from wellheads, pipelines and unmanned stations
- Redundant control paths for continuous process
- Tank gauging, flow measurement and custody transfer support
Engineering constraints
- Area classification
- Zone decides every specification
- Safety integrity
- Protection independent of control
- Remote power
- Energy budget shapes instrument set
Common questions
- Do you carry hazardous-area certification?
- We do not issue certification and we do not claim any. We specify certified equipment appropriate to the zone and install to the practices the classification requires, with the documentation your safety authority needs.
- Can safety functions share the process controller?
- They should not. A shared controller means one fault can remove both the control and the protection, which is exactly what the separation exists to prevent.
- What if the remote site has no reliable power?
- Then the instrument set is specified to the energy available, which usually means fewer measurements sampled less often. It is better to design to that honestly than to install something that browns out.
Elsewhere
