Energy Crossroads: Exploring North Carolina’s Two Energy Futures

140 ENERGY CROSSROADS
natural gas capacity additions—which were attributed to North Carolina
to replace retiring coal facilities in the state—additions were then split
between North Carolina and South Carolina based on Duke Energy’s
revenue share between the two states. Finally, the rest of North Carolina
electricity providers were assumed to match Duke Energy’s renewable
energy additions. Total capacity additions amounted to 27,086.4 MW
while total capacity retirements were 10,649.7 MW—equating to a net increase
of 16,436.7 MW. Capacity additions include 20,608.6 MW of wind,
solar, and storage facilities, as well as 6,400 MW of natural gas.
Duke Energy
Annual capacity additions were based on Portfolio B annual capacity
additions (listed on Page 105 of DEC’s IRP and Page 107 of DEP’s IRP)
and extrapolated to match capacity additions listed for Portfolio D (on
Page 16 of DEC’s IRP and Page 17 of DEP’s IRP). Capacity retirements
were based on the “Earliest Practicable” coal retirement schedule listed
on Page 175 of DEC’s IRP and Page 174 of DEP’s IRP. Total capacity
additions for this scenario amounted to 26,876 MW while total capacity
retirements were 11,529.5 MW—equating to a net increase of 15,346.5
MW. Capacity additions include 20,399 MW of wind, solar, and storage
facilities, as well as 6,400 MW of natural gas.
Portfolio D Scenario
For both the Duke Energy and North Carolina scenario, $7.5 billion in
transmission costs were included. Duke Energy’s Portfolio D was used
because it is more aggressive, in terms of greenhouse gas emissions
reductions, than Portfolios A-C, but is not as unrealistic as Scenario F,
which would allow no new natural gas plants to be built. Scenario D
is also the most similar to the proposals put forward by North Carolina
Governor Roy Cooper.