How to read the facility detail

Reading the labels

The most important distinction is whether a value came from a public record or was created by the tool.

Facility header and decision snapshot

The top of the detail identifies the facility, keeps the portfolio-ranking score visible, and summarizes technical fit, the energy case, grid exposure, timing, and the recommended next action.

Sector

A plain-language grouping based on the facility’s primary NAICS industry code.

Heat band

The largest published useful process-heat share in the below-160°C, 160–250°C, or above-250°C bands for a validated research match. Facilities without a usable research match retain their sector band. This portfolio filter is a screening classification, not a measured site temperature or a statement that every process has the same temperature.

Confidence

How suitable the sector is for a first-pass model, based on the expected consistency of its thermal processes. It is not a statistical confidence interval.

Address

The public facility location used for the map and geographic joins.

What the score means

The 1–99 score ranks facilities inside this tool. A larger estimated heat load contributes most, followed by the assumed electrifiable share, flexibility, model confidence, and lower-temperature fit.

The heat scale is log10(addressable MW + 1) ÷ 2, limited to a value from 0 to 1. Confidence contributes 12 points for medium-high, 9 for medium, 7 for low-medium, or 4 for low. For a research match, temperature fit is 15 × low share + 10 × medium share + 4 × high share, using useful process-heat fractions that sum to one. The bands are below 160°C, 160–250°C, and above 250°C. The fallback retains 15, 10, or 4 points from its sector temperature anchor. Confidence, electrifiable share, and flexibility remain sector assumptions.

The score is clamped between 1 and 99 and labeled as a technical score. It is not a probability, project return, technical-feasibility grade, grid-readiness grade, or credit score. The separate decision cards keep evidence quality, energy economics, grid exposure, and timing visible without folding them into one opaque number.

How the decision snapshot is assigned

Client brief exports

Download Report opens a purpose-built, printer-friendly client report using the current scenario. It starts with a facility-specific executive assessment, then separates the analysis into eight sections covering the evidence foundation, process and technology fit, energy and economics, grid readiness, wholesale timing, commercial context, diligence actions, and the source trail. Every section explains what the data measures, how to interpret this facility's result, and its implication for the client; detailed tables preserve the underlying evidence without simply reproducing the webpage. Choose Save as PDF in the browser dialog to download it. Download Data exports the active scenario assumptions, calculated loads, public grid context, evidence summary, and recommended next action as CSV for further analysis.

Reported facility facts

These fields establish the public-data starting point.

Stationary combustion

Annual greenhouse-gas emissions reported for burning fuel in stationary equipment. The 2023 value supplies the EPA fallback heat proxy; it does not replace the research study's 2022 heat boundary.

Total direct emissions

All direct greenhouse-gas emissions reported by the facility across applicable GHGRP categories.

Other / process difference

Total direct emissions minus stationary-combustion emissions. It may contain process chemistry and combustion reported under other subparts. The EPA proxy excludes it; the research study separately estimates heat-producing combustion where supported, including cement kilns. The full difference is never substituted for heat emissions.

Primary NAICS

The industry classification reported for the facility. The tool uses it to select a sector profile.

GHGRP facility ID

The identifier for the facility in EPA’s Greenhouse Gas Reporting Program.

FRS ID

EPA’s Facility Registry Service identifier. It is used to connect GHGRP records with ECHO air-program records.

Reported combustion equipment and fuels

This section comes from the GHGRP unit and fuel files. It helps reveal what the facility reported behind its annual combustion total.

Reported unit groups

The number of unit records for 2023. A record can represent one device or a grouped collection of equipment.

Rated heat input

The sum of disclosed maximum fuel-input capacities in MMBtu per hour. It is a nameplate-style capacity, not measured average demand.

Fuel classes

Fuel categories appearing in the unit records. The model currently uses a natural-gas-equivalent emissions conversion because fuel energy is not allocated by unit.

First GHGRP appearance

The earliest year that a comparable record appears in the downloaded GHGRP history.

Unit name and type

The public labels supplied by the reporter. These are the main evidence used by the process-screening rules.

Unit CO₂

The reported carbon dioxide associated with that record for the reporting year.

Reporting method

The GHGRP calculation or monitoring method attached to the unit or fuel record.

2023 NEI / CARB process inventory

The original implementation plan used the 2020 National Emissions Inventory until the 2023 release became available. EPA published the 2023 point/process archive in 2026, so this version uses the newer inventory rather than knowingly preserving the 2020 fallback.

For California records, the EPA process file carries CARB as the program system, CARB agency identifiers, and source-dataset labels such as 2023CARB. CARB explains that CEIDARS is its statewide system of record for facility, device, process, control, stack, and emissions information. Full CEIDARS device/process tables are not offered as a separate bulk public download, so the tool uses the CARB-submitted records distributed through NEI and keeps their provenance visible.

How the facility join works

Each distinct EIS facility is compared with the 74 GHGRP facilities. A join requires both geographic proximity and facility-name agreement. A record with a changed owner or site name can pass only when its street number also matches within 150 meters. The result exposes distance, normalized-name similarity, method, and confidence. Sixty-five facilities pass this conservative join; nine remain explicit coverage gaps.

EIS facility ID

EPA’s Emissions Inventory System identifier for the matched inventory site.

CARB facility ID

The agency facility identifier retained in the California submission. It is useful for tracing the state or district record.

Agency unit / process ID

Identifiers for the reported equipment group and its emissions process. They are not GHGRP unit IDs.

SCC

Source Classification Code, EPA’s code for the emitting activity or process.

Unit and process description

Public labels such as boiler, dryer, furnace, kiln, heater, coating line, or other reported activity.

Design capacity

A capacity and unit of measure when the inventory reports one. Blank means the process file did not supply a value.

Calculation method

The reported basis for estimating the pollutant emissions, such as a state/local emission factor.

Heat term present

A transparent keyword aid that moves explicit boilers, furnaces, dryers, heaters, steam systems, and similar descriptions to the top of the list. It is not an engineering classification.

Process-aware technology match

The tool screens each reported GHGRP unit before recommending electrification technologies. The rules look for explicit words and equipment types; they do not use a hidden probabilistic model. If the GHGRP labels identify no likely target, the joined 2023 NEI/CARB process descriptions can supply a transparent fallback shortlist.

Portfolio confidence and resolution share

The resolution share is the portion of unit evidence that could be placed confidently into likely target or likely non-target groups. A high value means fewer records remain ambiguous; it does not prove the inferred process.

Reported capacities stay visible, but the technology screen does not silently revise the selected heat baseline. Grouped records and incomplete capacity reporting require site validation. Research end-use allocations are retained separately from the current equipment classifications.

Operating context and project comparables

This section adds two reference layers without pretending they are facility measurements: EIA’s 2022 Manufacturing Energy Consumption Survey for national sector energy patterns, and DOE’s Industrial Training and Assessment Centers database for observed recommendation-level costs and savings.

MECS operating context

The tool selects the facility’s three-digit NAICS sector in MECS Table 5.2 and divides each reported end-use total by total sector fuel consumption. The result shows how much sector energy is associated with process heating, conventional boilers, CHP/cogeneration, and natural gas nationally.

Process-heating share

Reported process-heating energy divided by total fuel consumption for the national three-digit NAICS sector.

Conventional-boiler share

Energy assigned to conventional boiler use, separate from CHP/cogeneration.

CHP / cogeneration share

Energy assigned to combined heat-and-power or cogeneration processes.

Natural-gas share

Natural gas divided by total sector energy across the published fuel columns.

MECS suppression symbols such as Q, *, and -- are not converted into invented values. The affected end-use totals omit those cells, so the displayed share can be conservative. This national sector pattern does not reveal the facility’s actual operating mix.

ITAC project ranges

The current cohort starts in 2018. Thermal-system projects use ARC 2.1 Combustion Systems and ARC 2.2 Thermal Systems. Fossil-to-electric projects use ARC 2.1321, “Replace fossil fuel equipment with electrical equipment.” The tool uses the same three-digit NAICS sector when at least four recent recommendations exist; otherwise it clearly falls back to all recent manufacturing assessments.

Recommendations

Count of recommendation records in the displayed cohort, not a count of facilities or completed projects.

Implementation cost

The 25th-to-75th percentile of positive ITAC implementation-cost fields in nominal dollars.

Annual savings

The 25th-to-75th percentile of the recommendation’s reported annual dollar savings across its resource fields.

Simple payback

Median implementation cost divided by annual savings at the recommendation level when the workbook does not cache a payback value.

Implemented

Share marked implemented among records with a final implemented or not-implemented status. Pending and unknown records are excluded from the denominator.

P25–P75

The middle half of observed values. It reduces the influence of extreme records but is not a confidence interval.

Air permit and compliance record

The tool uses the FRS ID to join the facility to EPA ECHO’s ICIS-Air download. It summarizes the available federal air-program record; California’s local air districts remain the permitting authorities for stationary sources.

Air-district assignment and local permit records

Every facility is first assigned to one of California’s local air districts by intersecting its GHGRP coordinate with CARB’s published air-district boundary. All 74 facilities receive a jurisdiction assignment across 11 districts. This answers “which agency is responsible?” It does not, by itself, identify a district facility record or permit.

The working district adapters query public systems for 60 facilities: 32 in San Joaquin Valley, 14 in South Coast, 11 in the Bay Area, and 3 in Mojave Desert. Fifty-nine have a current reviewed facility match. New-Indy Ontario is retained as a historical-only exact-address match because South Coast FIND exposes a duplicate legacy record rather than a usable current permit history.

District jurisdiction

A point-in-polygon result from the facility coordinate and CARB’s published district boundary. It identifies the permitting agency to search, not a permit or facility-record match.

Permit join not yet built

The jurisdiction is known, but this release has not yet connected that district’s facility search, equipment permits, and dated actions. This applies to 14 facilities outside the four working adapters.

District facility ID

The identifier published by the local permitting agency. The join requires an exact district ID and address for San Joaquin, or a reviewed name-and-address match in South Coast.

Representative heat permits

Up to four San Joaquin Permit-to-Operate records whose equipment descriptions explicitly mention boilers, furnaces, dryers, ovens, heaters, kilns, or related process heat. The full district facility record remains linked.

Application date

The date South Coast FIND reports for the application. It establishes when the permitting process began, not when equipment began operating.

Bay Area application record

The district’s public recent-applications table supplies the facility and plant references, application number, initial submission date, description, and current status. The table does not expose an installation date or a complete equipment inventory.

Mojave equipment permit

The district facility page supplies permit number, permit and equipment descriptions, issue date, expiration date, and a permit link. Representative heat permits are selected by explicit equipment terms; issue and expiration dates are not treated as installation age.

Deemed complete

The date South Coast reports the application as sufficiently complete for review. It is a permitting milestone, not project completion.

Permit to Construct issued

A district-reported issuance date where present. A blank field means no issuance date was exposed in the joined record.

Estimated construction

A planned start or end date reported on a South Coast application dashboard. It may change and is not proof of installation or commissioning.

Public notice action

A dated San Joaquin notice such as public comment, final decision, or Authority-to-Construct issuance, joined by district facility and project ID.

Permit expiration

The expiration printed on a San Joaquin permit PDF. It describes the permit term, not equipment age.

ICIS-Air district

The district name associated with the federal program record. It is retained separately from the CARB spatial jurisdiction assignment.

Operating status

The status recorded in the program database, such as operating or inactive.

Source classification

The program’s major, synthetic-minor, minor, or other source classification where reported.

Title V program

Whether a matched federal operating-permit program record is present.

Latest program record update

The newest database update date among the matched program records.

Current HPV field

The available High Priority Violator status field. “Not reported” is not the same as “no violation.”

Five-year activity

Counts of inspections, stack-test records, formal and informal enforcement actions, and violation records in the selected five-year window.

Timeline

Dated activity with the record category, agency, purpose, and penalty where those fields are available.

Commercial timing signals

The feed puts dated public events in one chronology so a researcher can see recent activity without confusing it with technical potential. It normalizes local permit milestones and expirations, public notices, ICIS-Air inspections and enforcement, and matched California Energy Commission projects.

Permit action / decision

A dated application, issuance, final decision, amendment, renewal, or other milestone from a joined district record.

Public notice

A district notice or comment-period event. It indicates public permitting activity, not construction completion.

Permit expiration

The expiration date printed in the joined equipment-permit record. It can suggest a renewal cycle but is not equipment age.

Inspection / stack test

A dated ICIS-Air activity record. It is context, not evidence of a violation.

Violation / enforcement

A federal, state, or local activity represented in ICIS-Air, including formal or informal actions and penalties where reported.

CEC-funded project

An exact reviewed recipient-and-city match to the CEC Food Production Investment Program project register.

Within three years

Events whose reported date is within three years before or after the feed’s August 11, 2026 snapshot.

Latest signal

The newest dated record in the normalized feed, regardless of category.

CEC date boundary

The FPIP register supplies an agreement/project start date, end date, recipient, city, description, and CEC funding amount. The feed uses the start date and labels it as such. It does not relabel that date as the award decision or infer that all equipment was installed then. Multi-site projects are joined only where the listed project locations include the facility city.

Editable screening assumptions

These eight inputs let you test a heat-and-energy scenario. Conservative, Base, and High potential presets are directional cases—not statistical confidence intervals. Selecting a preset replaces all eight values; manually editing one of these inputs changes the label to Custom. Sector anchors and tool-wide defaults are screening assumptions, not reported facts for the individual facility.

The separate heat-source control selects Stanford useful process heat (2022) or the EPA gas-equivalent proxy (2023). Validated research matches default to Stanford; missing or invalid matches use the EPA fallback. The choice is saved with the facility scenario. Presets retain the selected source; Reset restores the default source and assumptions.

Base sector anchors

The Base preset takes electrifiable share, shiftable share, and conversion performance from the facility’s sector. The temperature anchors below apply to the EPA fallback; a validated research match supplies a distribution instead. Neither temperature basis automatically changes the heat-energy arithmetic or these sector assumptions.

Preset definitions

Heat, electric demand, and cost model

The calculation starts with a selected useful-heat baseline and works forward to annual energy, annual-average load, operating load, and a planning peak. Source and reporting year remain visible because the two heat baselines describe different years and emissions boundaries.

Choosing the heat baseline

For the research baseline, the tool sums published Annual Heat Demand across all end uses except Space Heat, then converts PJ/year to MWh/year. The published values already include the study's fuel-to-useful-heat efficiencies and temperature allocations. The model applies neither boiler efficiency nor Energy Share a second time. It does not scale 2022 heat by 2023 emissions. The comparison EPA estimate uses the same active boiler-efficiency assumption as the scenario.

Study process heat includes the thermal portion of CHP. Its published 40% CHP fuel-to-heat factor excludes electricity from useful heat, but the associated fuel and combustion CO₂ still support both products. The app therefore withholds on-site displacement for research CHP facilities and labels it “Needs CHP study.” Comparing research heat against 2023 rated equipment capacity would mix years and boundaries, so research-based implied utilization is also withheld.

1. Research useful process heatMWh-thermal/year = sum(non-Space-Heat Annual Heat Demand in PJ/year) × 1,000,000 ÷ 3.6

   Source year: 2022. Published efficiencies and allocations are already included; the research fuel-demand column is not substituted for useful heat.

2. EPA fallback fuel proxyMMBtu/year = 2023 stationary combustion tCO₂e ÷ 0.05306

   The factor represents 53.06 kg CO₂ per MMBtu for natural gas. Applying a CO₂ factor to reported CO₂e, and assuming gas for mixed fuels, makes this a screening proxy.

3. EPA fallback useful heatMWh-thermal/year = EPA fuel proxy × 0.293071 × boiler efficiency

   0.293071 converts MMBtu to MWh. This efficiency multiplier applies only to the fallback useful-heat calculation.

4. Addressable heatMWh-thermal/year = useful heat × electrifiable heat share
5. Average thermal loadMW-thermal = addressable heat ÷ 8,760
6. Operating thermal loadMW-thermal = addressable heat ÷ annual operating hours

   This represents the average heat rate while the process is assumed to operate, rather than an all-hours annual average.

7. Electric energyMWh-electric/year = addressable heat ÷ conversion COP or efficiency
8. Average electric demandMW-electric = electric energy ÷ 8,760
9. Operating electric demandMW-electric = electric energy ÷ annual operating hours
10. Peak electric demandMW-electric = operating electric demand × peak factor
11. Flexible demandMW-electric = operating electric demand × shiftable share
12. Gas-reference inputMMBtu/year = addressable heat ÷ 0.293071 ÷ boiler efficiency

    A hypothetical natural-gas boiler delivering the same useful heat. This is not observed site fuel consumption or the full input to a CHP plant.

13. Gas-reference energy cost$/year = gas-reference input × delivered gas price
14. Electric energy cost$/year = electric energy × electric energy price
15. Energy-only annual differencegas-reference cost − electricity cost

    A positive result is a saving against the gas reference; a negative result is a premium. Actual cement-fuel, other mixed-fuel, and CHP savings require separate fuel prices and heat/electricity allocation.

16. Research on-site CO₂ ceiling, without CHPtCO₂/year = published heat-related CO₂ excluding Space Heat × electrifiable heat share

    A proportional screening ceiling. Research CHP sites return no displacement estimate until the thermal and electric fuel/emissions boundary is established.

17. EPA fallback on-site CO₂e ceilingtCO₂e/year = 2023 stationary combustion tCO₂e × electrifiable heat share

    Both ceilings are gross on-site values. Neither subtracts electricity-system or life-cycle emissions; research CO₂ and EPA CO₂e retain distinct units.

Outputs in the facility detail

Addressable heat

Average thermal load covered by the selected electrifiable share.

Operating heat load

Annual addressable thermal energy divided by selected operating hours. It is closer to equipment duty than the all-hours average, but it is not a measured peak.

Annual-average electric demand

Annual electricity divided by all 8,760 hours; retained for consistent portfolio comparison.

Operating electric demand

Annual electricity divided by the selected operating hours.

Peak electric demand

Operating demand multiplied by the selected planning peak factor. This is the value compared directionally with Load ICA.

Flexible demand

The part of operating electric load assumed shiftable.

On-site emissions ceiling

A proportional gross on-site ceiling using the selected source: published heat-related CO₂ for research or reported stationary-combustion CO₂e for the EPA proxy. Research CHP sites display “Needs CHP study.” This is not a life-cycle reduction.

Energy cost savings or premium

The annual gas-reference-versus-electricity energy difference under the selected prices. It does not estimate a mixed-fuel or CHP facility's actual savings.

Electric energy

Annual MWh implied by the scenario.

Reported rated heat input

Disclosed fuel-input capacity converted from MMBtu/hour to MW.

Implied equipment utilization

For the EPA proxy only, gas-equivalent average fuel input divided by disclosed rated capacity. Incomplete capacity or mixed fuels can push it above 100%. The research baseline does not calculate it across 2022 heat and 2023 rated-equipment boundaries.

Research provenance

Source, year, useful-heat comparison, modeled temperatures, end-use mix, and representative fuels are retained in the dossier, client report, and CSV export.

What the research estimates assume

The supplementary method uses fuel-specific emissions factors, separates process emissions from combustion, and applies fuel-to-heat efficiencies of 94% for natural-gas boilers, 75% for process heating, and 40% for CHP thermal output. Most temperatures derive from NREL's 2014 thermal-energy database and older sector process descriptions. Grouped or ambiguous units inherit sector distributions. For multi-fuel units the study selects a representative fuel using reported methane emissions, so the imported fuel profile is not a measured complete fuel mix.

Cement estimates include combustion recovered from combined kiln emissions using an assumed 40% combustion share and a national cement-fuel mix. The imported workbook allocates approximately 83% of process heat to 1,482°C and 17% to 163°C. The supplementary text describes a different 90%/10% split at 1,483°C/163°C; Radar preserves the supplied workbook values and records this discrepancy for review. These estimates address the stationary-combustion boundary gap without treating all cement process CO₂ as heat. Semiconductor and automotive heat are assigned 500°C under limited data; automotive paint-curing temperatures are described as lower in the supplementary text. Verify these temperatures before ruling out a technology. See supplementary sections S1.2.2, S2.4–S2.5, S4.25, S4.37, and S4.38.

Grid, utility, tariff, and flexibility model

This section adds local power-system context without substituting a generic market hub when facility-level public evidence is unavailable.

Geographic matches

Electric service territory

Matched from published utility territory geometry or an official municipal service rule. Boundaries can overlap or change and are not legal service confirmation.

Nearest public LOAD pricing node

The great-circle nearest published CAISO load-node coordinate with at least 55 of the latest 60 archived day-ahead market days.

Node distance

Straight-line distance from the facility coordinates to the published node coordinates.

Tariff candidates

Official schedules that appear plausible from public location and load context. The actual rate depends on billed demand, voltage, commodity provider, and special contracts.

The nearest public node is a locational signal. It is not proof of the meter’s confidential settlement configuration.

Public distribution capacity

For facilities in PG&E or SCE territory, the tool queries the utility’s official Load Integration Capacity Analysis (Load ICA) line layer. It measures from the EPA facility coordinate to each returned line geometry and retains the nearest published segment only when it is within 1,600 meters.

MW added-load screen

The utility’s published estimate of incremental uniform load that the selected line segment could host before significant distribution upgrades, subject to the utility’s study method and data vintage.

Published line

The utility feeder, circuit, substation, node, or line-section identifiers attached to the nearest returned segment. These identifiers do not prove that the facility is served from that line.

Voltage

The nominal line or circuit voltage published for the selected segment.

Limiting criterion

The grid condition that most restricts added load where the utility publishes it, such as steady-state voltage or thermal loading.

Analysis vintage

The utility’s analysis or map-update date. Capacity can change as circuits switch, loads connect, or upgrades enter service.

Line distance

The shortest calculated distance from the EPA facility coordinate to the published line geometry. It makes the spatial uncertainty visible.

Modeled peak-demand comparison

The selected scenario’s planning peak compared with published line capacity. This is more decision-relevant than annual average, but remains directional because the line may not be the service feeder and the capacity is not reserved.

Explicit gap

No value is invented when no line is within the evidence radius, the utility does not publish comparable data, or source terms prevent this site from republishing downloaded values.

Dispatch controls

Shift duration

How many hours of flexible electric heat move from a higher-price period to a lower-price period. The facility needs thermal storage, process buffering, hybrid fuel, or schedule flexibility to bridge this interval.

Round-trip efficiency

Energy retained after charging, storing, and delivering shifted heat.

Available dispatch days

How many days per week the process is assumed able to participate.

Capturable wholesale value

The assumed portion of the modeled wholesale spread that could become customer value after commercial and operational constraints.

Dispatch defaults and ranges

How the day-ahead value is calculated

For each complete matched-node day, the model identifies the selected number of lowest-price hours to run electric heat harder, preheat, or build thermal inventory. It selects the same number of non-overlapping highest-price hours to reduce electric input while drawing on stored heat, hybrid fuel, or process buffers. It does not assume that production simply stops. The model adjusts the charging-hour cost for round-trip efficiency and keeps only days with a positive modeled spread.

1. Flexible electric loadMW = operating electric demand × shiftable share
2. Energy moved per eventMWh = flexible electric load × shift duration

   This is an electric-equivalent inventory requirement, not a detailed thermal-storage design.

3. Daily day-ahead spread$/MW-day = sum(high-price hours) − sum(low-price hours ÷ round-trip efficiency)

   Days at or below zero are assigned no dispatch and no value.

4. Annual available daysdays/year = 52 × available dispatch days per week
5. Positive-spread frequencyfraction = positive-spread sample days ÷ evaluated sample days
6. Annual shifted energyMWh/year = energy per event × annual available days × positive-spread frequency
7. Indicative day-ahead timing value$/year = sum(positive daily spreads) × flexible MW × (annual available days ÷ evaluated days) × capturable share

For the real-time backtest, the model retains the hours selected from day-ahead prices, settles those same hours against complete hourly real-time observations, assigns zero to days without a positive day-ahead schedule, and annualizes across the complete real-time sample. It never selects a different schedule with hindsight. The displayed real-time persistence percentage is the annualized real-time result divided by the annualized day-ahead result.

Indicative day-ahead timing value

The annualized wholesale spread from the matched node under the selected controls and capturable-value assumption. It is a prioritization signal, not utility-bill savings.

Negative observations

Day-ahead hourly prices below zero in the archived sample.

Run / build-heat hours

The CAISO hour-ending periods most often selected for increased electric-heat output or building thermal inventory.

Reduce / draw-heat hours

The periods most often selected to reduce electric input while maintaining the process with stored heat, hybrid fuel, or production buffers.

Real-time nodal backtest

The value of the same day-ahead-selected hours when settled against the matched node’s historical five-minute real-time prices, averaged to hourly. It tests whether the advance scheduling signal persisted; it is not a hindsight-optimized strategy.

The price chart uses the exact matched public LOAD node for both markets. The green line is the day-ahead planning-price average, the orange line is the historical real-time average, and shading shows how often each hour was selected. No trading-hub price is used to fill a missing node.

What to verify before outreach or investment

Use the dossier to prepare better questions. A serious next step should obtain the following evidence.

• Equipment

  Confirm which public unit groups represent boilers, furnaces, CHP, thermal oxidizers, emergency units, or facility-wide aggregation.

• Age and permits

  Retrieve installation, rebuild, burner-replacement, and permit issuance dates from nameplates and local air-district documents.

• Process conditions

  Confirm end uses, heat-transfer medium, supply and return temperatures, steam pressure, production hours, turndown, and redundancy requirements.

• Energy use

  Request 12–24 months of interval electric data, fuel use, bills, tariff details, and contract terms.

• Electrical service

  Check service capacity, billed maximum demand, voltage, feeder constraints, upgrade scope, and interconnection timeline.

• Flexibility

  Identify batch timing, clean-in-place windows, product buffers, thermal storage, and controls that can move load safely.

• Project economics

  Add equipment, construction, downtime, maintenance, financing, incentives, emissions compliance, and residual-value assumptions.

Public sources

The links below lead to the primary public programs used by the tool. Individual facility details also link to the relevant ECHO dossier, territory evidence, tariff book, and map location.

Source vintage is shown in the interface because public databases update on different schedules. Always re-open the linked primary source before making a time-sensitive decision.

Integrated research source

Glossary

MMBtu

One million British thermal units, a common unit for fuel energy.

PJ

Petajoule: one quadrillion joules. One PJ equals 277,777.7778 MWh; the research workbook reports annual heat and fuel demand in PJ/year.

MWh

Megawatt-hour, a unit of energy. One MW used for one hour equals one MWh.

MWth

Megawatts of thermal power: the rate at which useful heat is delivered.

MWe

Megawatts of electric power.

COP

Coefficient of performance: useful heat output divided by electric input.

tCO₂e

Metric tons of carbon-dioxide equivalent, combining greenhouse gases on a common basis.

tCO₂

Metric tons of carbon dioxide only; the research workbook's heat-related emissions use this unit.

CHP

Combined heat and power: fuel produces useful heat and electricity. Thermal displacement requires allocation of both outputs and their associated fuel and emissions.

NAICS

North American Industry Classification System code.

GHGRP

EPA Greenhouse Gas Reporting Program.

FRS

EPA Facility Registry Service, used to connect records across programs.

NEI

EPA National Emissions Inventory for criteria and hazardous air pollutants.

CEIDARS

California Emissions Inventory Data Analysis and Reporting System, CARB’s statewide inventory database.

SCC

Source Classification Code for an emissions process or activity.

MECS

EIA Manufacturing Energy Consumption Survey.

ITAC

DOE Industrial Training and Assessment Centers program and public assessment database.

FPIP

California Energy Commission Food Production Investment Program.

Title V

A federal operating-permit program for major and certain other air-emission sources.

HPV

High Priority Violator, an EPA air-enforcement designation or database field.

PNode

A CAISO pricing node representing a location on the wholesale power system.

DAM

Day-ahead market, where power is scheduled and priced before the operating day.

RTM

Real-time market, where prices respond closer to actual system operation.

Load ICA

Load Integration Capacity Analysis, a utility planning estimate of how much incremental load a distribution line segment may accommodate before significant upgrades.

Tariff

The utility’s published rates, charges, eligibility rules, and service conditions.