Thingsty operates Pakistan's energy stack from both ends. AMI energy-metering infrastructure reads consumption, generation and power quality at every site, second by second. EV-charging infrastructure gives the network its largest controllable load. Measurement everywhere plus demand you can actually move is the definition of a smart grid — and it is precisely what flattens the duck curve, keeps the network healthy, and shrinks the capacity payments that dominate the national power bill.
A conventional distribution network is blind between the substation and the wall socket. Utilities forecast demand, contract enough generation for the worst hour of the year, and shed load when they guess wrong. A smart grid adds the two things the old one never had: measurement everywhere, so the network knows its true state moment to moment, and controllable demand, so it can shift consumption to when energy is cheap, clean and abundant instead of chasing every peak with yet more supply. Thingsty runs both of those primitives in production today — metering to sense, charging to actuate.
Neither half is a smart grid on its own. Together they are the sense-and-actuate loop the network has always been missing.
Advanced Metering Infrastructure: smart meters, data concentrators and a head-end that turn every connected site into a live, two-way sensor on the network.
An OCPP charging backend that operates the fastest-growing, most flexible load on the network — and can turn it up, down or off on command.
AMI is more than a smarter meter — it is a full data path from the socket to the control room. Meters measure, concentrators aggregate, a head-end collects, and a meter-data management layer validates and turns readings into grid intelligence. This is the network's nervous system.
Single- & three-phase, DLMS/COSEM. Interval energy, voltage, current, power factor, tamper.
Feeder/DT-level gateways aggregating many meters over RF-mesh, PLC or cellular.
Secure two-way collection: schedules reads, pushes commands, handles firmware & keys.
Validate–estimate–edit, store load profiles, feed billing, losses, forecasting and the grid loop.
15/30-minute reads reveal the real shape of demand per site and feeder — the raw material for every downstream decision.
Prepaid, postpaid and time-of-use tariffs from the same meter, so price can follow the clock and recovery improves.
Bidirectional measurement of rooftop solar export — settlement you can trust and the data DERs need.
Feeder-in vs meters-out energy balance flags AT&C losses and tamper — the number that decides distribution viability.
Service actions and load limiting without a truck roll — and the switch a demand-response event ultimately rides on.
Voltage, sags/swells and last-gasp outage alarms turn "a whole area called in" into "this transformer, this minute."
The meter is the sensor; the charger is the actuator. One reads the network's state, the other changes it — and the platform closes the loop between them.
As rooftop and utility solar grow, midday supply floods the grid while demand is low — the belly of the duck. Then the sun sets exactly as households switch on, and net demand rockets up the neck. That daily whipsaw forces utilities to curtail cheap solar at noon and fire expensive, fast-ramping plants at dusk. A smart grid fixes it not by building more supply, but by moving demand into the belly and out of the neck.
AMI interval reads and net-metering export data give the platform the real duck curve per feeder — where the belly is deepest and when the neck ramps, not a textbook average.
Time-of-use pricing and smart-charging profiles pull EV load into the midday belly, so cheap solar is absorbed by cars instead of curtailed or dumped.
The same profiles throttle or pause charging during the dusk ramp — and, with V2G, let parked cars push energy back — so the steep neck of the duck is flattened.
A flatter load curve is the headline, but the same sense-and-actuate loop improves the day-to-day physics and economics of the distribution network.
Metered voltage and power-factor data let charging setpoints ease back on stressed feeders, holding voltage in band and cutting the sags a sudden EV load would cause.
Flattening peaks reduces the highest-current hours — and losses rise with the square of current — so a smoother curve directly means less energy burned as heat in the wires.
Feeder energy balance from AMI exposes where AT&C losses hide, so recovery improves and the network's real health is measured, not estimated.
Transformers and lines age with peak heat. Shaving the neck keeps assets off their thermal limits, extending life and deferring reinforcement spend.
Absorbing the midday belly with EV load means less rooftop and utility solar has to be thrown away — more clean energy actually used.
Last-gasp outage alarms and live telemetry turn "an area is dark" into "this DT, this minute," shrinking restoration time and improving reliability indices.
Pakistan's power bill is dominated not by the energy actually consumed but by capacity payments — fixed charges owed to generators for standing ready, whether or not their plants run. That obligation is sized by the system's peak demand and its need for fast-ramping "peaker" capacity. Attack the peak, and you attack the single largest, most political line item in the tariff.
Contracted capacity — and the payments for it — track the annual peak. Every megawatt shaved off the duck's neck is capacity the system no longer has to pay to keep on standby.
Moving EV load out of the evening ramp does the job a peaker plant would — without the capital, the fuel, or the fixed capacity charge attached to it.
Pooling metered sites and controllable chargers into one dispatchable resource lets a distributor lean on demand at peak — deferring new generation contracts entirely.
Meters measure the true system peak → the platform prices and schedules EV load away from it → the peak flattens → the utility contracts and pays for less standby capacity, and defers building fast-ramp plants. Because these payments are fixed and recur every year, a permanent shave off the peak compounds into savings that dwarf the energy cost of the charging itself.
Each block is a real primitive in the platform — not a slide. The pill says how far along it is.
Meters and chargers both stream usage on an interval, giving the platform one honest picture of demand across every connected site.
LiveOCPP charging profiles cap or curve power per connector and per site, so the largest flexible load can be dialled in real time.
LiveTariffs that follow the clock, pushing consumption toward off-peak, cheaper, greener hours through the driver wallet.
LiveFeeder-level energy balance from AMI surfaces AT&C losses and tamper for targeted recovery.
In progressFeed meter and DER readings into charging setpoints so sites soak up local solar before pulling from the grid.
In progressDispatch a coordinated throttle across many chargers to cut load during a system peak on command.
NextPool metered sites and controllable chargers into one dispatchable resource a distributor can call on at peak.
NextLet parked EVs push energy back when the network is stressed — the meter proves the export, the charger enables it.
VisionTurn historical interval data into per-feeder forecasts that pre-position charging and DER dispatch.
VisionSmart-grid decks are cheap. What is rare is already operating both the metering and the controllable load in the same country, on the same platform.
AMI hardware, concentrators and a head-end report interval consumption and export per site — the sensing half is deployed, not theoretical.
An OCPP 1.6J gateway with remote start/stop and charging profiles is in production — the actuator half of a smart grid exists today.
Metering and charging land in the same platform, so state and control share a language instead of being stitched across vendors.
Time-of-use tariffs and a driver wallet demonstrably shift charging behaviour — demand response with a working feedback loop.
Load-shedding, weak feeders, capacity-payment pressure and rooftop solar are the design constraints from day one.
Role-based access for platform, distributor and site operators means a DISCO can plug in without a bespoke integration.
AMI interval reads and OCPP-controlled chargers both in production, with time-of-use pricing already steering demand.
Charging setpoints react to live meter and DER readings so a site self-consumes local solar — filling the belly of the duck — before drawing from the grid.
Coordinated peak-shaving events and a virtual power plant across metered sites and chargers — capacity a distributor can dispatch instead of contract.
Parked EVs discharge to support the network at peak, metered and settled end to end — the grid finally two-way.
Distributor, regulator, solar operator or fleet — if any of this maps to a problem you own, we should talk. The primitives are running; the next step is putting them to work on your network.