MTEP16 Futures Development Workshop 1/15/15

MTEP16 Futures Development Workshop 1/15/15

Overview Objectives MTEP16 proposed futures Uncertainty variables definitions Next steps 2

Objective Ensure MTEP16 Futures are effective and are developed in a timely manner Purpose today Review stakeholder feedback received Present proposed MTEP16 Futures Key Takeaways Five futures are being developed considering stakeholder feedback received MISO will commence resource forecasting analyses using futures developed 3

Proposed MTEP16 Futures Business As Usual High Demand Low Demand Regional CPP Compliance Sub-regional CPP Compliance 4

Business As Usual The baseline, or Business as Usual, future captures all current policies and trends in place at the time of futures development and assumes they continue, unchanged, throughout the duration of the study period. All applicable EPA regulations governing electric power generation, transmission and distribution (NAICS 2211) are modeled. Demand and energy growth rates are modeled at a level equivalent to the 50/50 forecasts submitted into the Module E Capacity Tracking (MECT) tool. All current state-level Renewable Portfolio Standard (RPS) and Energy Efficiency Resource Standard (EERS) mandates are modeled. To capture the expected effects of environmental regulations on the coal fleet, a total of 12.6 GW of coal unit retirements are modeled, including units which have either already retired or publicly announced they will retire. 5

High Demand The High Demand future is designed to capture the effects of increased economic growth resulting in higher energy costs and medium high gas prices. The magnitude of demand and energy growth is determined by using the upper bound of the Load Forecast Uncertainty metric and also includes forecasted load increases in the South region. All current state-level Renewable Portfolio Standard (RPS) and Energy Efficiency Resource Standard (EERS) mandates are modeled. All existing EPA regulations governing electric power generation, transmission and distribution (NAICS 2211) are incorporated. To capture the expected effects of environmental regulations on the coal fleet, 12.6 GW of coal unit retirements are modeled, including units which have either already retired or publicly announced they will retire. Additional, age-related retirements are captured using 60 years of age as a cutoff for non-coal thermal units and 100 years for conventional hydroelectric. 6

Low Demand The Low Demand future is designed to capture the effects of reduced economic growth resulting in lower energy costs and medium low gas prices. The magnitude of demand and energy growth is determined by using the lower bound of the Load Forecast Uncertainty metric. All current state-level Renewable Portfolio Standard (RPS) and Energy Efficiency Resource Standard (EERS) mandates are modeled. All applicable EPA regulations governing electric power generation, transmission and distribution (NAICS 2211) are modeled. To capture the expected effects of environmental regulations on the coal fleet, 12.6 GW of coal unit retirements are modeled, including units which have either already retired or publicly announced they will retire. Additional, age-related retirements are captured using 60 years of age as a cutoff for non-coal thermal units and 100 years for conventional hydroelectric. 7

Regional Clean Power Plan Compliance The Regional Clean Power Plan future focuses on several key items from a footprint wide level which combine to result in significant carbon reductions over the course of the study period. Assumptions are consistent with previous CPP sensitivity analysis, and include the following: To capture the expected effects of existing environmental regulations on the coal fleet, 12.6 GW of coal unit retirements are modeled, including units which have either already retired or publicly announced they will retire. 14 GW of additional coal unit retirements, coupled with a $25/ton carbon cost, state mandates for renewables, and half of the EE annual growth used by the EPA, result in a significant reduction in carbon emissions by 2030. Additional, age-related retirements are captured using 60 years of age as a cutoff for non-coal thermal units and 100 years for conventional hydroelectric. Solar and wind include an economic maturity curve to reflect declining costs over time. Demand and energy growth rates are modeled at levels as reported in Module E. 8

Sub-Regional Clean Power Plan Compliance The Sub-Regional Clean Power Plan future focuses on several key items from a zonal or state level which combine to result in significant carbon reductions over the course of the study period. Assumptions are consistent with previous CPP sensitivity analysis, and include the following: To capture the expected effects of existing environmental regulations on the coal fleet, 12.6 GW of coal unit retirements are modeled, including units which have either already retired or publicly announced they will retire. 20 GW of additional coal unit retirements, coupled with a $40/ton carbon cost, state mandates for renewables, and half of the EE annual growth used by the EPA, result in a significant reduction in carbon emissions by 2030. Additional, age-related retirements are captured using 60 years of age as a cutoff for non-coal thermal units and 100 years for conventional hydroelectric. Solar and wind include an economic maturity curve to reflect declining costs over time. Demand and energy growth rates are modeled at levels as reported in Module E. 9

Uncertainty Variables

Future Business as Usual Demand and Energy Growth 0.9% MTEP16 Futures Matrix Retirement Level* (GW) No Additional Peak Natural Gas Price (2015 $/MMBtu) $4.30 Incremental Renewables (GW) N/C: North/Central S: South N/C: 4.2 Wind/ 1.4 Solar S: 0 Wind/ 0 Solar CO 2 Cost (2015 $/ton N/A High Demand 1.6% Age-related $4.30 Low Demand 0.2% Age-related $3.44 N/C: 7.2 Wind/ 1.6 Solar S: 0 Wind/ 0 Solar N/C: 2.4 Wind/ 1.3 Solar S: 0 Wind/ 0 Solar N/A N/A Regional CPP Compliance 0.9% 14 GW coal + agerelated $5.16 N/C: 4.2 Wind/ 1.4 Solar S: 0 Wind/ 0 Solar + economically chosen wind/solar based on cost maturity curves $25 / ton Sub-Regional CPP Compliance 0.9% 20 GW coal + agerelated $5.16 N/C: 4.2 Wind/ 1.4 Solar S: 0 Wind/ 0 Solar + economically chosen wind/solar based on cost maturity curves $40 / ton *12 GW of MATS related coal-retirements are assumed in all Futures Age-related retirement assumption applies to non-coal generation only 11

MTEP15 BAU Demand Growth Rate Granularity MISO 0.9% MISO N/C 0.6% MISO South 1.5% LRZ 1 0.9% LRZ 2 0.6% LRZ 3 1.2% LRZ 4 0.3% LRZ 5 0.2% LRZ 6 1.1% LRZ 7 0.1% LRZ 8 1.8% LRZ 9 1.4% LBA 1 1.6% LBA 1 1.1% LBA 1 0.7% LBA 1 0.3% LBA 1 0.2% LBA 1 4.6% LBA 1 0.2% LBA 1 1.8% LBA 1 1.0% LBA 2 0.9% LBA 2 0.9% LBA 2 1.1% LBA 2 1.5% LBA 2 2.1% LBA 2 0.9% LBA 2 0.1% LBA 2 1.4% LBA 3 1.2% LBA 3 0.1% LBA 3 0.6% LBA 3 0.8% LBA 3 1.4% LBA 3 1.7% LBA 4 2.3% LBA 4 0.4% LBA 4-0.2% LBA 4 0.3% LBA 5 0.6% LBA 5 0.3% LBA 5 0.6% LBA 5 1.1% LBA 6 0.7% LBA 6 0.0% LBA 7 3.3% All growth rates represent a 10-year compound annual growth rate, beginning in 2015 January 15, 2015 Planning Advisory Committee 12

Natural Gas Forecasts (Real, 2015 dollars) $7 $6 $5 Natural Gas Price (Real 2015 $/MMBtu) $4 $3 $2 $1 $0 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 Bentek 20% Bentek Baseline Bentek +20% Baseline forecast developed as part of Phase III Electric-Natural Gas Infrastructure Analysis by Bentek 13

Retirements Baseline 12 GW of coal retirements assumed to occur on 12/31/15 unless publicly announced date available Additional 14 GW and 20 GW of coal retirements occur in the Regional and Sub-Regional CPP Futures in the 2020 2025 timeframe Age-related retirements occur in the year in which the age threshold is reached in all futures except the BAU Coal retirements are captured through MATS and CPP impacts, and hence age-related retirement assumption is only applied to non-coal thermal units (as noted in slide 11). 14

MISO BAU Retirements 15

MISO Age-Related High/Low Demand Retirements Note: Non-coal thermal units retired at 60 years, hydro at 100 years. No nuclear units reach that age in the 15-year study period. 16

MISO Age-Related CPP Regional Retirements Note: Non-coal thermal units retired at 60 years, hydro at 100 years. No nuclear units reach that age in the 15-year study period. 17

MISO Age-Related CPP Sub-Regional Retirements Note: Non-coal thermal units retired at 60 years, hydro at 100 years. No nuclear units reach that age in the 15-year study period. 18

Retirements, cont. Including age-related coal leaves all non-bau futures with high retirements Future 2030 MATS CPP Age Related Total Coal Coal Coal Gas Oil Nuclear Hydro Retirements Retirements BAU 12 12 High/Low Demand 12 12.1 8.5 0.5 0.7 34 Regional CPP 12 13.9 5.3 8.5 0.5 0.7 41 Sub Regional CPP 12 19.5 2.9 8.5 0.5 0.7 44 Without age-related coal, more balanced retirements can be studied Future 2030 MATS CPP Age Related Total Coal Coal Coal Gas Oil Nuclear Hydro Retirements Retirements BAU 12 12 High/Low Demand 12 8.5 0.5 0.7 22 Regional CPP 12 13.9 8.5 0.5 0.7 36 Sub Regional CPP 12 19.5 8.5 0.5 0.7 41 19

Carbon Cost Regional and Sub-Regional CPP futures will use $25/ton and $40/ton prices, respectively beginning in 2020 20

DSM State mandates for DR / EE modeled in BAU / High Demand / Low Demand Half of the EE annual growth used by the EPA from the CPP analysis is modeled in the Regional and Sub-regional CPP Futures. Energy Efficiency Growth Comparison 14% 12% 10% Energy Efficiency % 8% 6% 4% EPA BB4 1/2 of EPA growth Mandates 2% 0% 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 Year 21

Possible Solar Maturity Curves 22

Possible Wind Maturity Curves 23

Capital Costs for New Generation Utilize EIA capital cost data, released April 2013* Escalate costs using GDP Implicit Price Deflator** to convert to 2015 baseline values Mid value for wind to be modeled 10% lower than EIA estimates Mid value for solar to be modeled 25% lower than EIA estimates High and Low values will be set +/- 25% from Mid values for all generator types An economic maturity curve will be applied to solar and wind to reflect declining costs over time. * Full capital cost report: http://www.eia.gov/forecasts/capitalcost/ ** As defined in the EIA Short Term Energy Outlook: http://www.eia.gov/forecasts/steo/report/us_eco.cfm 24

Historical CPI Growth Comparisons 1914 1916 1918 1920 1922 1924 1926 1928 1930 1932 1934 1936 1938 1940 1942 1944 1946 1948 1950 1952 1954 1956 1958 1960 1962 1964 1966 1968 1970 1972 1974 1976 1978 1980 1982 1984 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 20% 15% 10% 5% 0% 5% 10% 15% 15 year 20 year 1 year Data from US Department of Labor, Bureau of Labor Statistics Consumer Price Index (CPI) 25

Notes on Inflation Most-recent 20-year growth rate for the CPI is 2.4%; since 1960, the maximum 20-year growth is 6.3% and the minimum is 1.9% Based on this information, MISO recommends the following inflation rates for use in the MTEP futures (no change from MTEP15): Level Inflation Value Low 2.0% Mid 2.5% High 4.0% 26

Futures Development Timeline 27

Next Steps Post final Futures definitions with sensitivities matrix Begin model building Perform resource forecasting analysis including Siting 28