AGA Report No. 7 governs the measurement of natural gas by turbine meters — installation practices, performance verification, and the operating conditions under which a turbine meter can be expected to hold its accuracy. It's a mature standard, but compliance failures are still common, usually not because operators disagree with the standard but because they lack a systematic way to prove ongoing conformance.
The most frequent gap we see is upstream and downstream piping configuration drifting out of spec after a station is modified — a bypass added, a regulator relocated — without the flow conditioning being re-evaluated. AGA-7 is explicit about straight-run and flow conditioner requirements precisely because turbine meters are sensitive to swirl and velocity profile distortion. A meter that passed its factory acceptance test can still under- or over-register in the field if the installation no longer matches what was verified.
The second common pitfall is treating meter proving as a one-time event rather than a recurring discipline. Turbine meters wear mechanically, and that wear shows up first as a shift in the meter factor at specific flow rates, not as a uniform error across the whole range. Without periodic proving and trend tracking, that shift accumulates quietly until an audit — or a counterparty's own metering — flags a discrepancy.
A third area worth attention is documentation: AGA-7 audits go smoothly when there's a continuous record connecting installation records, proving history, and uncertainty calculations. They go badly when that record has to be reconstructed from spreadsheets after the fact.
Automated validation software addresses all three by keeping installation records, drift detection, and uncertainty budgets in one continuously updated system — so compliance is a byproduct of normal operation rather than a scramble before an audit.