Many of the newer O&G leases do have a some what vague Audit clause but I do not know of any lease that has a clause regarding Digital vs. Analog measurement.
Your question is regarding verifying volume. Another question is, "What percentage of that volume contains the higher valued gases other than cheap methane?" How can the landowner ever know that?
" ... Natural gas processing consists of separating all of the various hydrocarbons and fluids from the pure natural gas, to produce what is known as 'pipeline quality' dry natural gas. Major transportation pipelines usually impose restrictions on the make-up of the natural gas that is allowed into the pipeline. That means that before the natural gas can be transported it must be purified. While the ethane, propane, butane, and pentanes must be removed from natural gas, this does not mean that they are all 'waste products'.
In fact, associated hydrocarbons, known as 'natural gas liquids' (NGLs) can be very valuable by-products of natural gas processing. NGLs include ethane, propane, butane, iso-butane, and natural gasoline. These NGLs are sold separately and have a variety of different uses; including enhancing oil recovery in oil wells, providing raw materials for oil refineries or petrochemical plants, and as sources of energy. ... "
Kathi: a landowner should request a gas sample be run through a gas chromagraph, before the gas leaves their ground. this will give you a breakdown of the % of elememts that make up the Natural Gas stream leaving your lease. ( ex. methane 82%/ propane 5% / ehtane12% ) rest would be smaller % to total 100%. This ex. would be wet gas, high hydrates.
Depends on flow rate. Anything over 2 million per day should have one a month. Over 10 million should have chromatagraph on site to provide updates to the data in the measurment inst. every 10 minutes or so. One BTU difference in the measurement in high flow can make a large error. electronic inst. are very accurte, but only as good as the info. installed and the calibration.