This Load Ramp Study sets out an illustrative electrical demand ramp for a planned 160 MW data center campus in Poland. Its purpose is to define the expected progression of load from first energization through full operational capacity of the grid connection, identify the principal phasing assumptions, and provide a practical basis for utility discussions, engineering design, financing review, and customer deployment planning.
This proposal is preliminary in nature and reflects current assumptions based on the information available at this stage of project development. The ultimate delivery timeline, phasing, and ramp profile will depend on a number of factors that are still to be fully determined, in particular the outcomes of permitting processes, grid connection agreements, and broader administrative procedures.
The project is currently progressing key enablers in parallel. We are awaiting issuance of the final grid connection permit, while already holding a formal Letter of Intent from the utility operator confirming that the required power capacity can be made available. In parallel, the technical design has been developed and is being finalized, with supporting documentation now being completed for submission as part of the building permit application process.
At the same time, the project team is actively working to mitigate timing and execution risks by advancing key workstreams in parallel. This includes early and ongoing engagement with relevant authorities, alignment with utility stakeholders, and the pre-advancement of selected off-site infrastructure elements where feasible. Authorities are being proactively engaged to support a well-coordinated and efficient permitting process, with the objective of smoothing and accelerating approvals and enabling a more predictable ramp-up trajectory as the project progresses.
Study Status
Grid connection permit pending. Letter of Intent from utility received confirming 160 MW capacity availability. Building permit application in progress. Technical design at advanced stage.
DB Energy is a Polish industrial energy efficiency partner specializing in advising, designing, financing, and implementing energy efficiency and decarbonization projects across complex industrial facilities. With 15 years of operating history and a guiding philosophy of “decarbonization that pays off,” the firm helps medium and large industrial customers cut energy costs and CO₂ emissions while delivering measurable operational savings.
1,445
Industrial Projects Delivered
EUR 1.3 B
Total Project Value
9.8 TWh
Energy Saved for Clients
EUR 512 M
Annual Customer Savings
Credentials & Recognition
15 years of operating history in industrial energy efficiency consulting and EPC delivery.
Publicly listed on the Warsaw Stock Exchange NewConnect market (GPW) as DB Energy SA.
Capital Group with Willbee Energy and APPS (energydataspot.pl) subsidiaries; DB ESCO entities for ESCO-model financing.
ESCO financing expertise — customers fund energy efficiency investments from realized future savings.
In-house R&D department since 2014, including the DiagSys rotating-machine diagnostics system co-financed under the EU Intelligent Development Programme.
53,000 toe of white certificates secured for industrial client PCC Rokita SA — cited as a benchmark result by the client’s Energy Representative.
02
Study Purpose
1
Establish a comprehensive load growth profile from first energization of the campus through achievement of full operational capacity across all phases.
2
Support grid interconnection planning and capacity reservation discussions with the relevant distribution system operator and transmission network operator.
3
Define the timing and magnitude of demand increases associated with each development phase, enabling coordinated infrastructure delivery across electrical, mechanical, and civil workstreams.
4
Estimate peak demand, annual energy consumption, and load factor at each stage of buildout over the projected operational timeline.
5
Identify the infrastructure deployment triggers governing additions or uprating of transformers, switchgear, cooling systems, UPS modules, and backup generation assets.
6
Provide a reference case for use by the utility network operator, lenders, equity investors, and internal investment and asset management functions.
03
Project Description
Project Name
AI Factory Stargard
Location
Stargard, Poland
Campus Type
AI GPU
Adaptable to Hyperscale / Colocation / AI HPC / Mixed Use deployment models
IT Capacity
131 MW
Total planned installed IT load at full campus buildout
Utility Capacity (Meter)
160 MW
Total planned utility capacity at the grid metering point under full operation
Development Format
2 × 80 MW
Two phased 80 MW blocks; shell built continuously with staged fit-out
Grid Connection Voltage
110 kV
Commercial Operation Start
May 2027
First 80 MW block energized; subject to permitting and grid connection timelines
Full Build-Out
September 2027
Both phases commissioned; full campus operational at 160 MW
04
Key Assumptions
(a)Total campus maximum imported power at the grid metering point under full operation is set at 160 MW. This represents the contractual ceiling for all demand modelling in this study.
(b)Campus buildout occurs in phased increments directly linked to data hall completion milestones and the progression of customer deployment schedules across each phase.
(c)Installed IT load does not necessarily translate to immediate utilization upon commissioning of each phase. Actual utilization depends on the customer take-over schedule, equipment delivery, and acceptance testing processes.
(d)Mechanical and electrical support loads increase with IT utilization but do not scale perfectly linearly — a base level of fixed energy consumption persists even under low IT utilization conditions due to lighting, control systems, and standby equipment.
(e)Power Usage Effectiveness (PUE) is expected to improve progressively after initial commissioning, stabilizing as campus occupancy increases. Partial utilization can be optimized through smart design approaches and power train separation between individual data halls.
(f)Emergency generation and UPS systems are configured as pure backup infrastructure. The utility grid remains the primary and continuous source of power for all normal steady-state operations.
(g)Redundancy philosophy applied throughout the design: 4-to-make-3 (N+1 equivalent) for IT loads; 2N for mechanical loads including chillers and cooling towers.
(h)Grid import from the utility network remains the primary source of steady-state power supply for all phases. No reliance on on-site generation for normal operations is assumed in the load modelling.
(i)Annual energy consumption figures are calculated by applying a load factor of 92% to the plateau imported power value for each phase. This factor accounts for scheduled maintenance windows, partial capacity deployment during ramp-up periods, and normal operational variability.
05
Development Phasing
Load Ramp — Cumulative Capacity by Phase
Construction
0.5 MW
Month 0 – 8
Phase 1
80 MW
Month 8 – 12
Phase 2
160 MW
Month 12 – 14
M+0M+4M+8M+12M+14+
Phase 1 — 80 MW
First Grid Energization
Initial utility interconnection works delivering the first 80 MW grid import capacity block to the site, including energization of the initial transformer capacity and associated stepped-down on-site electrical distribution infrastructure. Target energization from Month 8, with Phase 1 import capacity available from Month 12 onwards.
Phase 2 — 160 MW
Full Grid Capacity
Second-stage utility interconnection works delivering the additional 80 MW grid import capacity block to the site, including energization of the remaining transformer capacity and associated stepped-down on-site electrical distribution infrastructure. Target energization from Month 12, with full 160 MW site import capacity available from Month 14 onwards.
For template purposes, the campus is assumed to be delivered through four principal fit-out sub-phases, each increasing cumulative available imported capacity and corresponding operational load potential: Phase 1a (40 MW), Phase 1b (80 MW cumulative), Phase 2a (120 MW cumulative), and Phase 2b (160 MW cumulative). For the avoidance of doubt, the grid-side ramp reflects only the staged provision and energization of utility import capacity, structured as two 80 MW grid connection blocks. These grid connection milestones are not intended to denote completion of the entire data center project, the full build-out of the campus, or the delivery of all planned data halls and associated infrastructure.
Construction note: The intention is to progress with the construction of the data halls (shell) in full. The staged increments above relate to the fit-out strategy, which is aligned with LLE (Last Large Equipment) delivery and the commissioning capability — we are lining up the Cx agent from the very early stage of the process to accelerate handover.
06
Load Ramp Schedule
Period
Phase
IT Load (MW)
Utilization
Support (MW)
Total (MW)
Month 0 – 8
Construction energization
0
0%
0.5
0.5
Month 8 – 12
Phase 1 commissioning
65.5
50%
14.5
80
Month 12 onwards
Phase 1 operational
65.5
50%
14.5
80
Month 12 – 14
Phase 2 commissioning
131
100%
29
160
Month 14 onwards
Phase 2 stabilized
131
100%
29
160
Month 14 onward
Full campus operation
131
Mature
29
160
The grid load ramp schedule above assumes phasing in 80 MW blocks. LLE procurement and the overall construction programme are planned up to full campus capacity, with phasing overlap applied to increase efficiency and improve delivery timing. We are lining up LLE accordingly — the current longest lead items are generators, primarily in relation to containerization and site acceptance feasibility rather than generator availability itself. We are planning to double or potentially triple commissioning team capacity to work in parallel and overlap fit-out and handover across the data halls.
In parallel, design and construction of the grid connection line and substation is being progressed. Estimated completion time is 12–14 months, consistent with the schedule above.
07
Load Profile Characteristics
Base Load
High Load Factor
Continuous, near-constant demand profile once each hall reaches stable occupancy. Highly predictable compared with conventional industrial load profiles.
Daily Variability
Limited
Intraday demand fluctuations are substantially lower than those of conventional commercial or industrial electricity consumers.
Seasonality
Cooling-Driven
Seasonal variation is primarily driven by ambient temperature effects on cooling system efficiency. Summer peaks are expected to be modest.
Ramp Behaviour
Step Increases
Demand increases in discrete steps at commissioning milestones rather than progressing in a smooth linear curve. Each step is associated with activation of a new phase block.
Energy Optimization
BESS Integration
BESS designed alongside the main power connection for energy arbitrage — capturing daily and seasonal power consumption variance to optimize energy costs and enhance resilience of the overall supply system.
Demand Side Response
Optional
Optional DSR participation with the grid operator to help stabilize the grid, subject to commercial arrangements.
08
Forecast Energy Consumption
Early Phase 1 (37 MW avg)
324,120 MWh
Stabilized Phase 1 (37 MW avg)
324,120 MWh
Stabilized Phase 2 (74 MW avg)
648,240 MWh
Stabilized Phase 3 (110 MW avg)
963,600 MWh
Full Operation (147 MW avg)
1,287,720 MWh
Annual Energy Consumption (MWh) = Average Load (MW) × 8,760 hours Load factor of 92% applied to plateau imported power. Accounts for scheduled maintenance, partial capacity during ramp periods, and operational variability.
09
PUE & Efficiency
Operational Stage
PUE Range
Initial commissioning
1.17 – 1.25
Early stabilized operation
1.14 – 1.18
Mature operation
1.13 – 1.15
Final PUE range for each operational stage is dependent on design ambient conditions, selected cooling architecture, applied redundancy levels, partial load performance characteristics, and the proportion of high-density AI compute deployments within each hall.
10
Infrastructure Triggers
1
Transformer additions or uprating to support incremental demand at each phase step, including both 110/MV transformers and IT hall distribution transformers.
2
New medium-voltage or high-voltage switchgear sections required to accommodate additional intake blocks and extended ring-main distribution.
3
Generator plant expansion to maintain backup N+1 or 2N coverage as the installed load base increases across successive phases.
4
UPS module additions and battery string augmentation to match the incremental IT load introduced with each commissioning milestone.
5
Chiller or dry cooler expansion and additional cooling tower capacity to maintain design cooling margins under increasing IT heat rejection loads.
6
Additional utility connections for water, fuel storage systems, and fire suppression infrastructure commensurate with phased hall activations.
7
Harmonic analysis and power quality mitigation measures, including active filters or passive harmonic traps, as non-linear load density increases with each phase.
8
Reactive power compensation requirements — static or dynamic — to maintain power factor compliance at the 110 kV point of common coupling throughout all phases.
11
Grid Interface Considerations
(a)Maximum permitted import capacity. The project is designed around a target import capacity sufficient to support the full 160 MW load. A formal Letter of Intent has been secured from the utility confirming that the required capacity can be made available.
(b)Timing and sequencing of available capacity. Final grid connection approval and detailed phasing of capacity delivery remain in progress. Active engagement with the utility is ongoing to accelerate the connection timeline and align availability with the planned load ramp.
(c)Temporary versus permanent supply arrangements. Depending on final connection timelines, temporary supply solutions may be considered to enable early-stage energization and commissioning. These would be designed to integrate seamlessly into the permanent infrastructure.
(d)Power factor and reactive power obligations. The facility will be designed to meet all utility requirements regarding power factor and reactive power. This will be addressed through appropriate compensation systems integrated into the electrical design.
(e)Fault level and protection coordination. Detailed studies will be undertaken to ensure compliance with fault level limits and to coordinate protection systems between the facility and the grid operator. This is particularly important as capacity scales and is one of the technical design elements covered later in the programme.
(f)Curtailment or operational restrictions. Any potential curtailment clauses or operational constraints imposed by the utility will be assessed and factored into operational planning and risk mitigation strategies.
12
Risk & Mitigation
Utility Capacity Delivery
Grid Connection Permit
A Letter of Intent has been secured; the final grid connection permit remains pending. Mitigation: active engagement with the utility and relevant authorities to accelerate the process, while advancing enabling works in parallel to minimize downstream impact.
Front-Loaded Demand
Accelerated Customer Uptake
Faster than expected customer deployment would require acceleration of infrastructure delivery. Mitigation: early procurement of long-lead equipment and modular design approaches; schedule is already optimized with limited room to further accelerate.
Deferred Ramp
Lower Occupancy
Slower customer demand could defer certain capital expenditures. The phased approach allows for controlled investment aligned with actual demand realization; we can adjust in the construction phase if the customer schedule shifts.
High-Density AI
Power per Hall
Prevalence of high-density AI workloads will drive higher power and cooling requirements; current design is already optimized considering hall density and overall site power. Flexibility exists to accommodate higher densities per hall, though this would require redesign with impact on the delivery schedule.
Cooling Strategy
Support Load
Changes in cooling strategy could affect support load and PUE outcomes. Mitigation: design flexibility built into mechanical systems with partial-load performance considered across operating scenarios.
Permitting & Administrative
Regulatory Delays
The project is dependent on timely permitting and administrative approvals. Mitigation: documentation is being finalized for submission, and authorities are being proactively engaged and aligned to support an efficient approval process.
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Study Approvals
This technical study has been prepared by the engineering team of ALT Infrastructure SA and reviewed by executive leadership. Acknowledgement of this study confirms receipt and review of its contents. This document is preliminary and subject to revision as permitting and engineering processes advance.
Fully executed · 2 of 2 acknowledgements collected
Prepared by
Wojtek Góralski
Signed · 15 March 2026
Wojtek Góralski
VP of Infrastructure · ALT Infrastructure SA
TECHNICAL AUTHOR
Reviewed & Acknowledged by
Filip Majchrowski
Signed · 15 March 2026
Filip Majchrowski
Co-Founder · Chief of Land Acquisition and Site Preparation · ALT Infrastructure SA
ACKNOWLEDGED — PERMANENT
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