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SERC Tennessee Valley (SRTV)
Data Center Record tracks 27 facilities across Kentucky and Tennessee in the SERC Tennessee Valley (SRTV) regional power market.
Modeled wholesale electricity price effect and regional load
- 2024 to 2025 wholesale price effect
- 5.8 percent (+$2.03 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate.
- 2028 projected wholesale price effect
- 8.7 percent (+$2.91 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate.
- Data center share of regional electricity load (2025)
- 5.9 percent, modeled data center load share, Dallas Fed WP 2606r1, third party estimate.
- Fixed cost share of retail electricity bill
- No separate retail pass through parameter reported in Table A8 of Dallas Fed WP 2606r1.
States in SERC Tennessee Valley
| State | Tracked records (CC BY-NC 4.0) | State scorecard |
|---|---|---|
| Kentucky | 7 | View Kentucky record |
| Tennessee | 20 | View Tennessee record |
Tracked facilities in SERC Tennessee Valley (27)
A blank cell means no source states a figure.
All 23 regional markets in Dallas Fed WP 2606r1
| Region | States | Tracked records (CC BY-NC 4.0) | 2024 to 2025 wholesale price effect | 2028 projected wholesale price effect |
|---|---|---|---|---|
| Northwest Power Pool (NWPP) | WA, OR, ID, MT, NV, UT | 105 | 15.4 percent (+$5.68 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 25.9 percent (+$7.77 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC Virginia and Carolina North (SRVC-N) | VA, NC | 55 | 15.0 percent (+$5.22 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 27.6 percent (+$9.76 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| WECC California (CAMX) | CA | 69 | 8.6 percent (+$3.70 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 17.2 percent (+$6.96 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| MRO West (MROW) | IA, MN, ND, NE, SD | 76 | 12.1 percent (+$3.45 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 15.7 percent (+$4.59 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| ERCOT All (ERCT) | TX | 67 | 12.6 percent (+$3.15 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 28.0 percent (+$6.10 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC Virginia and Carolina South (SRVC-S) | NC, SC | 46 | 7.5 percent (+$3.01 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 14.7 percent (+$4.94 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| WECC Southwest (AZNM) | AZ, NM | 41 | 8.6 percent (+$2.93 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 14.7 percent (+$4.32 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| WECC Rockies (RMPA) | CO, WY | 42 | 7.7 percent (+$2.51 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 12.2 percent (+$3.76 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| NPCC NYC and Westchester (NYCW) | NY | 13 | 5.2 percent (+$2.46 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 6.0 percent (+$2.63 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| NPCC Long Island (NYLI) | NY | 4 | 4.5 percent (+$2.40 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 5.3 percent (+$2.62 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| RFC West (RFCW) | IN, OH, PA, WV, IL | 134 | 6.7 percent (+$2.29 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 15.7 percent (+$5.11 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| NPCC Upstate New York (NYUP) | NY | 15 | 5.3 percent (+$2.14 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 8.7 percent (+$3.34 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC Tennessee Valley (SRTV) | KY, TN | 27 | 5.8 percent (+$2.03 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 8.7 percent (+$2.91 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SPP North (SPNO) | KS, NE, MO | 8 | 6.5 percent (+$1.87 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 8.2 percent (+$2.54 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| RFC East (RFCE) | DC, DE, MD, NJ, PA | 127 | 5.1 percent (+$1.81 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 13.3 percent (+$4.61 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC South (SRSO) | AL, GA | 51 | 4.2 percent (+$1.47 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 5.3 percent (+$1.73 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC Midwest (SRMW) | IL, MO | 28 | 4.7 percent (+$1.46 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 7.0 percent (+$2.28 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| MRO East (MROE) | WI, MI | 22 | 4.0 percent (+$1.39 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 7.9 percent (+$2.60 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| NPCC New England (NEWE) | CT, MA, ME, NH, RI, VT | 34 | 2.4 percent (+$1.28 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 3.1 percent (+$1.71 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| RFC Michigan (RFCM) | MI | 25 | 3.8 percent (+$1.27 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 8.8 percent (+$2.89 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SPP South (SPSO) | OK, AR, LA, TX | 16 | 3.1 percent (+$0.99 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 3.5 percent (+$1.12 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| SERC Mississippi Valley (SRMV) | AR, LA, MS | 26 | 3.0 percent (+$0.93 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 4.7 percent (+$1.48 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
| FRCC All (FRCC) | FL | 33 | 1.0 percent (+$0.42 per MWh, 2024 to 2025), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. | 0.8 percent (+$0.34 per MWh, 2028 projected), modeled wholesale price effect, Dallas Fed WP 2606r1, third party estimate. |
Wholesale price effects are third party estimates from Dallas Fed WP 2606r1 (opens in a new tab) (March 2026, revised October 2026). Tracked record counts are Data Center Record rows licensed under CC BY-NC 4.0.
What researchers have found
These studies measure different things. Some model wholesale market prices. Some measure what households actually paid. Some model what would happen under a policy change. The record shows each one as the authors stated it and does not rank them.
These studies measure different things. Some model wholesale market prices. Some measure what households actually paid. Some model what would happen under a policy change. The record shows each one as the authors stated it and does not rank them.
| Study | What it measured | Finding | Years covered | Method | Who funded or published it |
|---|---|---|---|---|---|
| Plante, Carrasco, Miranda Pineda and Patel, Federal Reserve Bank of Dallas Working Paper 2606r1 (opens in a new tab) | Wholesale electricity price effect and retail electricity rate pass through | Data center demand accounts for an average 6.5 percent increase in wholesale electricity prices across 23 regional markets in 2024 and 2025, reaching 15.0 percent (+$5.22 per MWh) in SERC Virginia and Carolina North and 15.4 percent (+$5.68 per MWh) in the Northwest Power Pool, with wholesale changes passing into retail prices roughly in proportion to the wholesale share of the retail bill over 12 to 24 months. | 2019 to 2025 historical and 2026 to 2028 scenario projections | Synthetic supply stack model across 23 regional power markets combined with reduced form retail pass through regressions | Federal Reserve Bank of Dallas (government research working paper; views are the authors') |
| Watten, Bistline and Blanford, Electric Power Research Institute (arXiv:2606.19777) (opens in a new tab) | State level retail electricity rate change across all customer classes | Where data centers pay standard industrial rates and improve grid utilization, state average retail rates could fall by roughly 1 percent nationally by 2030 (up to 4 percent in high growth states, or roughly $7 billion per year in fixed cost spreading); outcomes reverse toward higher residential bills if new generation and transmission upgrades outpace load revenues. | 2026 to 2030 | Capacity expansion and utility revenue requirement model allocating fixed transmission and distribution costs across customer classes | Electric Power Research Institute (nonprofit energy research institute funded primarily by member electric utilities) |
| Meeks, Pless, Qi and Wang, MIT Center for Energy and Environmental Policy Research (opens in a new tab) | Realized utility revenue and customer bill changes from historical data center openings | In the 6 years following data center entry (1998 to 2018), average electric utility revenue rose 8 percent (+$104 million per utility per year), residential bills rose 2 percent (+$30 per household per year) and commercial bills rose 4 percent (+$262 per customer per year), driven by peak coincident demand charges and infrastructure capital additions. | 1998 to 2018 | Difference in differences event study of historical data center openings matched to utility level EIA Form 861 billing and revenue panels | MIT Center for Energy and Environmental Policy Research (university working paper) |
| Norris, Profeta, Patino Echeverri and Cowie, Duke University Nicholas Institute (NI R 26-04) (opens in a new tab) | Grid headroom and new gigawatts of large load accommodated under minimal peak hour curtailment | Across 22 major US balancing authorities, roughly 76 GW of new data center load can be integrated without building new peaking capacity if facilities curtail load by 0.25 percent of annual operating hours (roughly 22 hours per year), expanding to 98 GW at 0.5 percent annual curtailment and 126 GW at 1.0 percent annual curtailment. | 2025 to 2035 | Hourly balancing authority load duration and reserve margin modeling across 22 US power systems | Duke University Nicholas Institute for Energy, Environment & Sustainability (university research institute) |
| Jeremiah Johnson et al., North Carolina State University (Environmental Research Letters) (opens in a new tab) | Wholesale electricity prices, residential bills by state and power sector carbon emissions through 2030 | Projected data center and crypto load growth raises US electricity demand 6 to 12 percent by 2030 and increases residential electricity bills up to 57 percent in the most heavily affected states (including Virginia at roughly $32 per month or $384 per year for an average household) while adding 49 to 125 million metric tons of CO2 per year. | 2024 to 2030 | National capacity expansion and unit commitment dispatch model (TEMOA) across US grid regions | North Carolina State University researchers in Environmental Research Letters (peer reviewed journal) |
| Monitoring Analytics, PJM Independent Market Monitor (Q1 2026 State of the Market Report) (opens in a new tab) | PJM Base Residual Auction capacity market clearing prices and total wholesale capacity bill attributable to data center load | Data center load growth was the primary driver of the PJM 2025/2026 and 2026/2027 capacity market tightness, accounting for $9.3 billion of the $14.7 billion total PJM capacity cost in the 2025/2026 delivery year and driving a 76 percent surge in PJM wholesale power costs in Q1 2026. | 2025 to 2027 delivery years and Q1 2026 | Counterfactual PJM Base Residual Auction clearing runs removing forecast and existing data center peak load additions | Monitoring Analytics, LLC (independent market monitor for PJM Interconnection, mandated by FERC) |
| Union of Concerned Scientists, Billions of Dollars in Unreported Data Center Costs in PJM (opens in a new tab) | Local transmission network upgrade costs triggered by data center interconnections in PJM | In PJM alone, $4.36 billion in transmission upgrades across 150 supplemental transmission projects in 2024 were triggered by data center connections and socialized across regional utility ratepayers under PJM tariff rules. | 2022 to 2024 PJM transmission expansion filings | Project by project audit of PJM Regional Transmission Expansion Plan (RTEP) and utility Attachment M-3 supplemental project filings | Union of Concerned Scientists (nonprofit advocacy group study) |
| Energy and Environmental Economics (E3), Understanding the Drivers of Rising Electricity Rates and the Role of Data Centers (opens in a new tab) | Historical drivers of US retail electricity rate increases and utility rate design for large loads | Historical US retail electricity rate increases from 2020 to 2025 were driven primarily by distribution capital spending, wildfire mitigation, natural gas price spikes and inflation rather than data centers, and well designed large load tariffs can keep new data center additions net neutral or beneficial for existing ratepayers. | 2020 to 2025 historical and forward rate design case studies | Decomposition of historical utility revenue requirements and illustrative utility tariff cost of service modeling | Energy and Environmental Economics (E3), industry commissioned consulting report |
| Nicholas Z. Muller, National Bureau of Economic Research Working Paper 35100 (opens in a new tab) | Monetized air pollution and greenhouse gas health and climate damages per megawatt hour of data center electricity use | Marginal air pollution and greenhouse gas damages from fossil fuel generation serving US data centers average $49 to $94 per MWh ($0.049 to $0.094 per kWh), rivaling or exceeding the direct wholesale price of electricity in coal and gas heavy interconnects such as PJM, MISO and SERC. | 2022 to 2025 | Integrated assessment marginal emissions and air quality transport model (AP4T) coupled with EPA CEMS unit level generation data | National Bureau of Economic Research (university working paper by Nicholas Z. Muller, Carnegie Mellon University) |
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Data Center Record. SERC Tennessee Valley (SRTV) grid region. Last verified October 28, 2026. https://datacenterrecord.org/grid/srtv. Accessed October 30, 2026.
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