Channel × AssetStack · Marsden Point Terminal

Terminal energy, carbon & VOC boundaries

Whangārei Harbour · Ruakākā · Pacific/Auckland · NZDT (UTC+13 at demo snapshot)

DEMO · Synthetic operating records as at 28 October 2026. Not live telemetry, actual contracts, inspection evidence or operational authority.

3 loaded of 3 · calculations apply to loaded records

Quantified model · t CO₂e/year

1173.8

Modelled energy spend / year

NZ$2,065,500

Streams missing factors or prices

Stream · DEMO	Boundary	Annual quantity	Assumed factor	t CO₂e / year	Energy NZD/year	Basis
DEMO-CI-E01 · Marsden terminal electricity	Scope 2 · Purchased electricity	2,400,000 kWh	0.1 kg CO₂e/kWh	240.0	NZ$480,000	Source & gaps DEMO · annual scenario quantities, NZD prices and emission factors. Not metered data, official NZ factors, consent evidence or verified savings. Factor vintage is unverified; replace with reporting-year NZ factors and an approved inventory boundary. Electricity factor assumed 0.10 kg CO2e/kWh, energy price NZ$0.20/kWh; location-based Scope 2 only. Record: 6ae2416a6716ed279f147664. Factor × annual quantity ÷ 1,000 = tonnes. Quantity × unit cost = NZD.
DEMO-CI-E02 · Pipeline pumping electricity	Scope 2 · Purchased electricity	8,400,000 kWh	0.1 kg CO₂e/kWh	840.0	NZ$1,512,000	Source & gaps DEMO · annual scenario quantities, NZD prices and emission factors. Not metered data, official NZ factors, consent evidence or verified savings. Factor vintage is unverified; replace with reporting-year NZ factors and an approved inventory boundary. Assumed 0.10 kg CO2e/kWh and NZ$0.18/kWh. No ownership claim is made over customer-owned terminal or truck-rack loads. Record: 6ae2416a6716ed279f147665. Factor × annual quantity ÷ 1,000 = tonnes. Quantity × unit cost = NZD.
DEMO-CI-E03 · Standby generator diesel	Scope 1 · Direct combustion	35,000 litres	2.68 kg CO₂e/litres	93.8	NZ$73,500	Source & gaps DEMO · annual scenario quantities, NZD prices and emission factors. Not metered data, official NZ factors, consent evidence or verified savings. Factor vintage is unverified; replace with reporting-year NZ factors and an approved inventory boundary. Assumed combustion-only 2.68 kg CO2e/litre and NZ$2.10/litre. Upstream fuel-cycle, customer product combustion, tank VOCs and refrigerants are excluded, not zero. Record: 6ae2416a6716ed279f147666. Factor × annual quantity ÷ 1,000 = tonnes. Quantity × unit cost = NZD.

Pumping-efficiency scenario · not verified savings

Electricity reduction assumption · %Carbon shadow price · NZ$/t CO₂e

Energy saving allowanceNZ$199,200/year

Avoided modelled footprint108.0 t CO₂e/year

Separate shadow valuationNZ$8,100/year

Assumed reduction applies only to loaded electricity streams, at unchanged throughput and unit prices. Shadow value is not an ETS liability, tradable credit, cash saving or additional booked benefit. Verify before funding.

Inventory boundaries, VOCs and verification

Synthetic annual quantities, factors and prices, not an official or verified inventory. No standard factor fallback is applied. Electricity is location-based Scope 2; standby diesel is direct Scope 1 combustion. A renewable grid share is not used to zero emissions. Missing sources remain unquantified, not zero.

Tank breathing, loading losses, VOCs, refrigerants and customer fuel use are outside this calculation. VOCs are not silently converted into CO₂e or called methane. Establish product-specific vapour pressure, tank/roof/seal configuration, throughput, vapour recovery and consent conditions before estimating or assessing compliance.

The energy/environment lead should reconcile meter and invoice data, NZ factor vintage and reporting boundary. After pump-control changes, compare metered kWh per ML transferred against a throughput-normalised baseline over an agreed period; retain meter calibration, operating conditions and independent finance/environment review.