USCG & MMS guidelines for most drilling & well control equipment are based on API Specifications & recommended practices.
When you say “the BOP on the rig floor” I believe you are speaking of the driller’s remote operating station. There are actually numerous blow out preventers (BOPs) which are in the stack. I never inspected the Horizon’s well control equipment, but my guess would be that it was in a standard configuration of two double ram BOPs stacked together (this gives you four separate blowout preventers which greatly increases ability to configure the stack for multiple tasks without having to bring it back to the surface e.g. Blind shear rams in the bottom cavities, variable rams above that, 5" rams above that & 5 1/2" rams in the top cavities). Then above your ram-type preventers, you would have 2 annular BOPs (often just referred to as your Hydrils. . . kind of like a crescent wrench) which are mounted in the lower marine riser package (LMRP) with your control pods (MUX [multiiplex] in this case).
API considers the hydraulic control manifold to be the primary operating station (the one with the manual valves that the subsea engineers operate while testing) and the driller’s panel to be a remote control station.
As per API Specification 16D (Control Systems For Drilling Well Control Equipment):
2.2.2.6 - " All functions on the hydraulic control manifold shall be remotely operable from the driller’s panel. The control manifold interface shall be designed so that all control signals and power fluid supplies have redundant access (two separate jumpers, umbilical hose bundles, reels and control pods) to the shuttle valves on the BOP stack functions."
2.2.2.7 - “All control manifold functions shall be operable from and/or indicated at one or more remote panels conntected in parallel with the driller’s panel. All panels shall be designed and connected in such a way that component failure in one panel should not effect the operation or indication of the other panel(s) or the manifold”.
So, we have the main hydraulic manifold controls & must have a remote control panel on the drill floor and one additional panel (location covered in a moment). Since the remote panels are required to be connected in parallel with the driller’s panel (if they were in series, you would be out of luck), destruction of the remote on the drill floor would not render the other remotes inoperable. This is tested by various surveyors/inspectors with different regulatory agencies as well as being covered in Transoceans maintenance system to be tested by the subsea engineers on a regular basis.
2.2.2.7.2 - “The secondary remote panel shall be located at a place away from the drill floor. The preferred location for the panel shall be either at the toolpusher’s office, or at a location close to the lifeboat station”.
The toolpusher’s panel is required to be able to control & monitor all the same functions as the hyd manifold & driller’s panel extcept that it is not required to have controls for your primary & secondary wellhead connectors and your pod latches. In practice, what you usually see are identical remote panels in the driller’s shack & the toolpusher’s office. You are allowed to add additional remote operating panels if desired, but you are only required to have two remote operating panels onboard & one has to be on the drill floor. Despite some of the comments being thrown out in the news and in a few posts here, this is also true under Bureau Veritas, NORSOK & UKOOA codes & specifications.
2.2.2.7.3 - “The primary electric power supply connected for remote control of the control manifold shall automatically switch to an alternate source of electrical supply when the primary source of power is interrupted. The secondary power source shall be an uninteruptible power supply or a battery pack & shall be capable of maintaining operation of the remote functions for a minimum of two hours following the loss of primary electric power”.
Additionally, section 2.2.4.6 requires that all diverter functions shall be operable from a remote panel located on the drill floor.
Hope that answered some of your questions, if not holler & I’ll try & find what your curious about in the standards for you.