Canada Oil and Gas Geophysical Operations Regulations — 38
38 (1) Subject to subsection (3), within 12 months after the date of termination of a geophysical operation, every operator shall submit to the Chief Conservation Officer a report that includes (a) a title page that indicates the number that is assigned to the operation that is the subject of the geophysical operation authorization, the report title, the type of operation conducted, the location of the operation, the duration of operations at that field location, the names of the contractors, the operator, the interest owners, if any, as defined in section 2 of the Canada Petroleum Resources Act , and the author, and the date of the report; (b) a table of contents; (c) an introduction or abstract; (d) location maps that show the boundaries of the area that is subject to each interest covered by the operation and the identification number of each such interest; (e) a summary of significant dates, the number of members of the complement, if applicable, the number of members of the geophysical crew, the type and number of each type of equipment used, the production data, the total distance surveyed, the downtime per day, and the number of kilometres of data recorded per day; (f) a summary of weather, sea, ice and topographic conditions and their effect on the operation; (g) a general description of the operation including the instrument type, the accuracy of the navigation, positioning and survey systems, the parameters for the energy source and recording system and the field configuration of the source lines and the receiver lines; (h) a detailed description of the geophysical data processing method including the processing sequence and the processing parameters for seismic, magnetic, gravimetric and other geophysical surveys; (i) shotpoint maps, track plots, flight lines with numbered fiducial points, gravity station maps and, for seabed surveys, location maps for core holes, grab samples and seabed photographs; (j) a fully processed, migrated seismic section for each seismic line recorded and, in the case of a 3-D survey, each line generated from the 3-D data set; (k) a high-resolution section for each line recorded in a well-site seabed survey or a pipeline route survey; (l) a series of gravity and magnetic profiles across all gravimetric and magnetic surveys for which interpretative maps have not been made; (m) shotpoint location data; (n) bathymetric and topographic maps that are compiled from the data collected; (o) interpretative maps that are appropriate to the data collected including (i) structure and isopach maps, time structure and time interval maps, velocity and residual velocity maps, and seismic amplitude and character change maps, (ii) final Bouguer gravity maps and any residual or other processed gravity maps, and (iii) final total magnetic intensity contour maps and any residual, gradient or other processed magnetic maps; (p) synthetic seismograms and seismic modelling studies that use synthetic seismograms, vertical seismic profiles at wells that were used in the interpretation of the operation data, amplitude versus offset studies, and seismic inversion sections, if any; and (q) the interpretation of maps and seismic sections including (i) geological and geophysical correlations, (ii) where applicable, correlations between gravity, magnetic and seismic data, (iii) in the case of seabed surveys, the geophysical correlation of shallow seismic data with data from cores and geotechnical boreholes, (iv) details of corrections or adjustments that were applied to the data during processing or compilation, and (v) the operator’s velocity information that was used in a time-to-depth conversion. (2) An operator shall incorporate in a map submitted pursuant to paragraph (1)(o) any previous data collected by the operator that are related to the area covered by the map and that are of a type similar to the data from which the map was produced. (3) An operator who has conducted a non-exclusive survey need not, in the repo