How are they figuring or going to figure the royalty payments when they drill cross-lateral units? How will the royalty owner know what he is due? How will that affect the royalty already received on a well drilled in one of the units? I have a 160 acre interest in a unit that has a gas well on it and want to know how I'll be affected should they decide to include that unit in a cross-lateral.
Cross Unit Lateral wells, the state denotes them with "HC" in the name, do not effect royalties from existing "non-HC" unit wells. When a company drills and completes an HC well, they file an "as drilled" form with the state. The report gives the length of the perforated portion of the lateral and the linear feet that lie in each unit. The report also provides a percentage of production that well be allocated to each section.
SS and Steverino, the allocation formula is straight forward however I think it is time to point out a lurking problem. I have received a number of questions on the subject of royalty for HC wells. Even though the correct formula is used inaccuracies can, and do, arise from improper unit surveys. Any mineral owner or their representative should be able to go to the state database, SONRIS, and get a copy of their unit survey. A proper survey provides the exact size in acres of the unit and of each individual tract within the unit. The plat has the names of the mineral owners, their tract acreage and the percentage of the tract's interest in the unit. The problem is this: the majority of unit survey plats are not entered in the database. This has been the case for a number of years since the units began production but has become a serious concern with the advent of production from and royalties paid on HC wells.
Yep, Chesapeake has cut a lot of corners with their Haynesville operations however the problem with missing and in some cases inaccurate surveys is one shared by all the Haynesville shale companies.
Good catch. Ever wonder how many of the allocation calculations may be incorrect?