Yes but that’s not the only issue. Look at the termination kit dimensions. Make sure you have adequate space to route the cables away from each other especially after the stress relief area.
On some switchgear the only practical routing from a top tray involves mounting a “high hat” which is an extended enclosure and terminating there and routing and landing unshielded cables at the bus bars. The area between the lug and termination is greatly increased and spacing maintained by cutting pieces of glastic channel and strapping them between the cables.
Coming from the bottom (and top too) another issue especially with three conductor cable is that the bend radius in the three conductor jacket is also impossible. I’ve had to cut back the outer jacket before cable entry for bend radius purposes. Fully jacketed might have say a 36” bend radius on large MV-105, 500 MCM cables.
Planning for bend radius and stress relief is part of the construction issues in switchgear. This is the reason most installations fail within 5-10 years. Inexperienced installers don’t know what they are doing and fail to follow proper installation techniques. Switchgear manufacturers are generally clueless too and fail to provide enough space for proper clearances in critical areas. Quite often “optional” extra “prepared space”, “high hats”, and the like are NOT optional or nit considered. Looking at this at the design stage massively decreases issues during installation.
In your planning sketch routjng. Be aware of adequate minimum bend radii and adequate clearances. For instance with 4.5” phase to phase as something of an industry standard for 5 kV plus cable diameter this often means those “huge” termination spaces are anything but. Even tray dimensions often muss the mark. If you tie wrap cables to maintain spacing you can take advantage of increased ampacity. And unlike duct banks cables can be removed and inspected. Burial is cheap only on initial installation. After that maintaining it is horrible.
Also so-called metal clad is anything but. The phases are fully isolated usually in the internal bus work to the breakers and phase barriers (nit metal) are between phases in the draw out breaker. Within the termination compartment usually everything is wide open. In theory metal clad is safer but in practice it’s not. You don’t get to decrease arc flash and lower short circuit bolted faults by assuming single phase for instance. The critical connections are not metal clad.
May also want to look at metal enclosed gear. Much cheaper. Theoretically it’s only fused disconnects but since the spec means “anything goes” you can find breakers in thus configuration too with or without draw out cassettes. May want to review if draw out even makes sense. It adds tons of cost with a minor benefit...usually the breakers aren’t the major failure point and it adds draw out which IS a major failure point. As an example Siemens WL breakers and similar GE drawout panelboard are available. These are essentially insulated breakers (ICCB) or MV vacuum breakers on a draw out style frame (lead screw) or bolted in. Instead of ANSI style open frame $20k each breakers you pay half that.
May also want to look at GIS. It’s expensive but what you get is a sealed design with a 40+ year life with almost no required maintenance. You test and regrease once a decade. That’s it. And if you go with pressurized SF6 it shrinks the overall gear size dramatically. I e seen 35 kv GIS at a oil refinery in Ohio with 24” wide sections. 24”! That’s 5 kv dimensions. It cut the footprint in half with associated costs. In my mind GIS delivers on what metal clad promises but fails to deliver. If you look at the maintenance instructions and realize metal clad gear is supposed to be pulled for maintenance EVERY 3 years it doesn’t look so good. On metal enclosed gear often there is little or no lubrication (sealed bearings).
Often newer breakers are using say Molykote 3451 instead of Mobil 28. The difference is Mobil 28 is the industry standard. It’s a clay thickened oil. The oil evaporates substantially in 3 years. So thus drives breakers to be exercised annually and pulled for regressing every three years. GE AK series or Powerbresk for instance requires this. 3451 uses a fluorosilicone oil that does not evaporate. This is why the GIS guys use it. It lasts at least 10 years in third party testing. Think about it...in GIS you test the trip units only every 6-8 years (SEL 751A), and exercise the breakers. Every 10-15 years you grease. So with a 40 year life you only test the relays 6 times and regrease 3 times. Metal clad ANSI gear on the other hand requires annual exercising, regrease/test every 3 years. That’s 40 cycles and 13 lubrication cycles. That’s a lot of built in downtime and expense.
My personal feeling is most customers are much better served by either the more expensive higher reliability GIS gear despite the fact that it puts my company out of business (switchgear maintenance) or going the other way and buying the more cost effective “lower quality” (not really) metal enclosed rating.
