Data observatory

Disjoint cohort population control48 unique cohorts sum to 763000; modelled control 763000.

Linked sample meter register5000 unique modelled NMIs; minimum sample 104.

Joint meter-day weights and separated channels2304 joint daily samples, each 48 intervals; each cohort/season/day-type weight sums to one.

Export only for solar cohortsB1/export channel is never netted against E1/import.

Full six-year fixed-AEST coverage2191 complete days 2021-07-01–2027-06-30, 48 shape intervals per day. Settlement archive keeps original source resolution.

72 linked months per cohort3456 monthly cohort records; static modelled population, future months labelled scenario.

Effective-dated tariff coverage without overlapsEvery cohort/month has exactly one retail tariff; QCA published versions replace modelled design versions for the same period.

104 linked CTS activities104 source-row-linked EGC activities with non-empty cohort allocation weights. Exact cost parity is separately tested against the pinned CTS engine.

Traceable workload event lags15 modelled event→activity elasticities with unit-sum lag distributions.

Credit fields are integer centsGenerated credit ledgers use integer cents; runtime tariff multiplication uses the shared decimal engine.

No modelled observations claim measured authorityOnly independently retained public schedules/sources may be published. modelled book, register and elasticities remain modelled.

No non-finite generation outputsFinite non-negative usage and finite prices; negative wholesale prices remain valid. Missing ingestion data is separately tested as unknown.

Full six-year NEM12 archive generated5000 gzip files; 17343956 channel-days; 2054 explicitly blank unknown reads; 1704 estimated-quality reads.

Residential annual usage vs QCA typical customermodelled residential mean 4958.23kWh in2025–26. QCA typical 4748kWh; difference 4.43%. Mean-vs-tariff-median scopes differ and are stated explicitly.

Published typical T11 bill reproductionAt 4748kWh: calculated GST-inclusive $2030.78, QCA $2031; difference 0.011%. No feed-in/concession applied to this reference bill.

Gross import shape vs QLD1 ≥0.8Pearson correlation of 48-point average day over 1888 common source days: gross import 0.359243. This original gross-load gate is not met; no reclassification to a different metric.

Net grid shape diagnostic vs QLD1Net import minus export correlation 0.844284. QLD1 operational demand is a net regional measure. This diagnostic does not silently replace the gross-import acceptance gate.

Joint shapes vs full sample source energy ±2%All 5000 meter index totals compared with the joint model's sample-weighted six-year import+export energy; worst cohort difference 0.001749%. Blank gaps are excluded from observed totals, never converted to zero. Full parser validation independently verifies indexed totals.

AER weighted hardship/concession controlsmodelled residential shares hardship 2.051384%, concession 33.586058%. AER Q1 2026 rates applied to modelled 663808 residential accounts; not a claim that modelled counts equal the 741,548-account observed retail population.

All market inputs are public observationsNot met: future prices/weather, pre-2025 modelled retail schedules, earlier network schedules, losses, green/market fees and hedge book assumptions remain modelled. Published records are specifically identified; a modelled history is not relabelled real.