Amu Darya full-cycle energy complex

Project description

The complex envisages phased development of distributed energy and computing nodes. The model considers 10 nodes with 20 MW IT load each. Generation and users would be connected through electrical networks and control systems; not all sources need to occupy the same site.

The study scope covers the Amu Darya from the Panj–Vakhsh confluence to the delta, including Uzbekistan and transboundary reaches involving Tajikistan, Afghanistan and Turkmenistan. The main stem is approximately 1,415 km long. This is a site-screening scope, not a continuous construction strip or allocated land parcel.

Generation portfolio

The baseline includes 200 MW hydropower, 300 MW wind and 500 MWac solar PV, totalling 1,000 MW installed capacity. Plant locations and country allocations will follow resource assessment and approvals.

Assumed capacity factors of 50% for hydro, 35% for wind and 22% for solar yield 2,759.4 GWh annual gross generation, before curtailment, network losses and plant auxiliary demand. These capacity factors are not site-measured.

The 200 MW hydropower component is an option to be tested. Feasibility depends on available flows, heads, environmental constraints and water management regimes. River presence or length alone does not substantiate this capacity.

Digital facilities and electrical demand

The preliminary architecture comprises 10 computing nodes with 20 MW IT load each. At an assumed PUE of 1.25, facility demand is 250 MW, including 50 MW of supporting systems inside the PUE boundary. External heat supply heat pumps are counted separately.

The scenario includes 100 MW / 400 MWh battery storage: four hours at 100 MW before operating constraints, not four hours of autonomy for the entire complex. Connections at 110–220 kV are considered; substation and line configurations require power system studies.

At a 90% annual equivalent load factor and constant modelled PUE, annual data centre demand is 1,971 GWh. Annual balance does not establish hourly supply adequacy: seasonality, deficit hours, grid capacity, backup and dispatch need modelling.

Integrated heat recovery

At full 200 MW IT load and an assumed 80% recovery fraction, the available low-grade heat flow is 160 MW. At an assumed heating COP of 4, heat pumps consume 53.3 MW electricity and deliver 213.3 MW heat at their condensers.

After an assumed 5% delivery loss, useful heat at the user boundary is 202.7 MW. At 4,500 equivalent full-load delivery hours, annual heat delivery is 912 GWh and heat pump electricity demand is 240 GWh. COP, operating conditions and losses need validation for selected temperatures and pipe routes.

The simultaneous modelled data centre and heat pump demand is 303.3 MW. Their combined annual electricity demand is 2,211 GWh; external distribution pumps, grid losses and generation auxiliaries are not separately quantified. Summer uses include hot water and process heat, with independent heat rejection when demand is absent.