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USA - Washington Cap-and-invest Program

ETS Status
in force
Jurisdictions
Washington
Start of operation (year)
2023
Sectoral coverage
Mining and extractives
Transport
Buildings
Industry
Power
Allocation
Free Allocation (Grandparenting, Fixed Benchmarking, Output-based Benchmarking), Auctioning
Offsets and credits
Domestic offset credits are allowed with quantitative limits
Cap or total emissions limit
53.7 MtCO2e (2025)
GHGs covered
CO2, CH4, N2O, SF6, HFCs, PFCs, NF3, and other fluorinated GHGs
Average auction price
USD 31.64
Total revenue since beginning
USD 2.6 billion of state revenue (USD 3.3 billion including consigned auctions)
Total revenue
USD 810.8 million (USD 1.1 billion including consigned auctions)

General Information

Washington’s cap-and-invest program began operating in January 2023. It covers around 70% of the state’s emissions, and its cap trajectory is consistent with the long-term target to reduce statewide emissions to 95% below 1990 levels by 2050.

The program covers emissions from 97 entities in the mining, energy, industrial, buildings, and transport sectors. Many of the Cap-and-Invest Program’s design elements are similar to those of California’s Cap-and-Trade Program. Covered entities must surrender allowances for all their covered emissions. Allowances are distributed through auctioning and free allocation, with the latter based primarily on benchmarking. The program has a cost containment reserve and auction reserve price to support market stability and moderate covered entities’ compliance costs. 

The Cap-and-Invest Program was established by the Climate Commitment Act (CCA), signed into law by then-Governor Jay Inslee in May 2021. Washington is the second state in the United States to pass a law requiring such an economy-wide program, after California. Launched as a standalone system, the CCA directed the Department of Ecology to pursue linking. Senate Bill 6058, which is designed to facilitate linkage, went into effect in January 2025.

2024 was a pivotal year for Washington's Cap-and-Invest Program. In March, Initiative 2117, aimed at repealing the CCA, was certified for the ballot. Later in March, the governments of Washington, California, and Québec issued a joint statement on the potential to form a shared carbon market through linkage. At the end of the month, Governor Inslee signed Senate Bill 6058 into law. The bill modified certain provisions of the CCA to facilitate linkage with California and Québec. Some provisions went into effect on 1 January 2025, and some will be implemented through rulemaking.* Discussions about potential linkage with California and Québec are ongoing. 

The year's most significant event occurred in November’s polling day, when Initiative 2117 was defeated by a margin of almost 24 percentage points, securing the program’s future and paving the way for a potential future linkage.


 

*Washington Department of Ecology CCA Market Notice on Senate Bill 6058 implementation available here.

Mining and extractives
Transport
Buildings
Industry
Power

Emissions & Targets

96.1 MtCO2e (2021)

By 2030: 45% reduction from 1990 GHG levels (“Greenhouse Gas Emission Limits – Amendment 2020”)

By 2040: 70% reduction from 1990 GHG levels (Greenhouse Gas Emission Limits – Amendment 2020)

By 2050: 95% reduction of total GHG emissions below 1990 levels and achievement of net-zero emissions (Greenhouse Gas Emission Limits – Amendment 2020)

Size & Phases

68.20MtCO2e
CO2, CH4, N2O, SF6, HFCs, PFCs, NF3, and other fluorinated GHGs

FIRST COMPLIANCE PERIOD: Four years (2023 to 2026)

SECOND COMPLIANCE PERIOD: Four years (2027 to 2030)

THIRD COMPLIANCE PERIOD: Four years (2031 to 2034)

Under Senate Bill 6058, the Department of Ecology may be required to revise the definition of “compliance period” through rulemaking to align with a linked jurisdiction. However, the length of the first compliance period will not change.

A cap limits the total emissions allowed in the system.

FIRST COMPLIANCE PERIOD: The cap for 2023 was set at 63 MtCO2e, which is equal to 93% of average emissions levels of covered entities between 2015 and 2019. The cap declines annually by 7%, to reach 49 MtCO2e in 2026.

SECOND COMPLIANCE PERIOD: The cap for 2027 will be set at 93% of the sum of the 2026 cap and emissions from new entities entering the program for the second compliance period. The cap declines by 7% annually through 2030.

THIRD COMPLIANCE PERIOD AND BEYOND: The cap for 2031 will be set at 98.2% of the sum of the 2030 cap and emissions from new entities entering the program for the third compliance period. In the period from 2032 to 2042, the cap declines annually by 1.8%. 

In the period from 2043 to 2049, the cap declines annually by 2.6%, reaching a 95% reduction from 1990 emissions levels by 2050.

FIRST COMPLIANCE PERIOD: All facilities with emissions over 25,000 tCO2e, including industrial facilities, electricity generators, importers of electricity, fuel distributors, and natural gas suppliers. Excludes emissions from waste-to-energy and solid waste management. From 2025 onward, Senate Bill 6058 reduces the threshold for inclusion for some unspecified electricity imports to zero.   

SECOND COMPLIANCE PERIOD: Waste-to-energy facilities with emissions over 25,000 tCO2e in at least one year between 2023 and 2025 will be added.

THIRD COMPLIANCE PERIOD: Railroad companies with emissions over 25,000 tCO2e in at least one year between 2027 and 2029 will be included.

VOLUNTARY OPT-IN PARTICIPATION: Any facility that is already covered by the mandatory MRV system but with emissions below the 25,000 tCO2e Cap-and-Invest Program inclusion threshold may voluntarily participate as an opt-in entity. Other facilities, including federal power marketing administrations (FPMA), can also participate as opt-in entities. Opt-in entities become covered by the mandatory MRV system and must follow the same MRV requirements as other covered entities. 

Upstream (building, power [imported electricity] transport); point source (mining, industry, power).

97 covered entities and 96 general market participants, offset providers, and utilities that do not have a compliance obligation but receive allowance allocation (2023)

Allowance Allocation & Revenue

Allowances are distributed via free allocation, free allocation with consignment, and auction.

FREE ALLOCATION: Emissions-intensive, trade-exposed facilities receive free allowances to mitigate the risk of carbon leakage. Allocation is done using facility-specific benchmarks, based on their average carbon intensity over the period between 2015 and 2019. Facilities could request free allocation based on their average emissions (i.e., grandparenting) only in a few instances where they were unable to calculate the emissions intensity of their production over this period. The reduction schedule that is applied to the allocation of no-cost allowances to eligible facilities will be based on four-year periods that are specified in the statute, instead of compliance periods. 

FIRST COMPLIANCE PERIOD: Set at 100% of the benchmark multiplied by actual production, or historical emissions level. 

SECOND COMPLIANCE PERIOD: Set at 97% of the benchmark multiplied by actual production, or historical emissions level.

THIRD COMPLIANCE PERIOD: Set at 94% of the benchmark multiplied by actual production, or historical emissions level.

FREE ALLOCATION WITH CONSIGNMENT: Electricity utilities receive free allowances based on forecasts of the electricity supply and administrative costs associated with complying with the Cap-and-Invest Program. During the first compliance period, they can choose to consign up to 100% of their allowances to auction. Natural gas facilities received an initial free allocation equal to 93% of their average emissions in the period from 2015 to 2019. The amount reduces annually in line with the cap decline factor. In 2023, 65% of free allowances must have been consigned for auction. This amount increases by 5% each year, reaching full consignment in 2030. Freely allocated allowances that are not consigned for auction may only be used for surrender and cannot be traded. Whether consigned or not, the allowance value allocated to electricity utilities and natural gas suppliers is required to be used for ratepayer benefit.

AUCTIONING: Auctions occur four times a year. Unsold allowances are held for future auctions and only sold if the settlement price is above the auction floor price for two consecutive auctions. Any that remain unsold within 24 months are transferred to an emissions containment reserve (see ‘Market Stability Provisions’ section).

USD 2.6 billion of state revenue since the beginning of the program (USD 3.3 billion including consigned auctions)

USD 810.8 million in 2024 (USD 1.1 billion including consigned auctions)

USE OF REVENUE FROM FREE ALLOWANCES CONSIGNED FOR AUCTION: Revenues raised from the auctioning of free allowances on behalf of electricity utilities and natural gas facilities must be used to benefit rate payers or customers, prioritizing those from low-income groups. In most cases how the revenues are used is determined by the state’s Utilities and Transportation Commission.

USE OF REVENUES FROM ALLOWANCES AUCTIONED BY THE DEPARTMENT OF ECOLOGY: Proceeds from auctions are split into seven accounts: 

  • Carbon Emissions Reduction Account (CERA); 
  • Climate Active Transportation

Account (CATA); 

  • Climate Transit Programs Account (CTPA); 
  • Climate Investment Account (CIA);
  • Climate Commitment Account (CCA);
  • Natural Climate Solutions Account (NCSA); and
  • Air Quality and Health Disparities Improvement Account (AQHDIA). 

Each account is intended for different environmentally beneficial activities. Not all projects funded from these accounts are intended to reduce GHG emissions. Funds in each of these seven accounts are to be appropriated for specific types of climate, environmental justice, and ecological projects. The CCA requires that a minimum of 35%, with a goal of 40%, of money from CCA accounts be used for projects that provide a direct and meaningful benefit to vulnerable populations within overburdened communities. At least 10% of CCA account funds are required to be used for projects formally supported by the resolution of a Tribe. 

During fiscal year 2024 (1 July 2023 through 30 June 2024), 37 agencies received appropriations totaling USD 3.2 billion and approximately USD 472 million was spent.* During the 2024 legislative session, the Legislature specified that approximately USD 645 million of the USD 3.2 billion in appropriations could not be spent until January of 2025, pending the results of Initiative 2117. As the initiative failed to pass, agencies will have until June 30, 2025, to spend these funds. Of the amount already spent, approximately USD 200 million was through CTPA and about USD 100 million through each of CCA and NCSA. 


 

* The annual report titled “Distribution of Funds from CCA Accounts” for Fiscal Year 2024 is available here.

Flexibility & Linking

Unlimited banking is allowed between periods; however, covered entities are subject to general holding limits, which depend on the cap level. Allowances held in a compliance account to be used for compliance or that are to be consigned for auction do not count towards the holding limit.

Borrowing is not allowed.

The use of offset credits is allowed.

QUALITATIVE LIMITS: Washington has adopted – with modifications – the following offset credit protocols developed under the California Cap-and-Trade Program:

  • Livestock projects;
  • Ozone depleting substance projects;
  • US forest projects; and
  • Urban forestry projects.

QUANTITATIVE LIMITS: 

First compliance period: Up to 5% of an entity’s compliance obligation from projects not located on federally recognized tribal land. The ongoing rulemaking process will increase this limit to 8%. An additional 3% can be met from projects located on federally recognized tribal land.

Second compliance period: Up to 4% of an entity’s compliance obligation from projects not located on federally recognized tribal land. The ongoing rulemaking process will increase this limit to 6%. An additional 2% can be met from projects located on federally recognized tribal land.

Third compliance period and beyond: Up to 4% of an entity’s compliance obligation, which can include projects located on federally recognized tribal land. An additional 2% can be met from projects located on federally recognized tribal land.

In the event of a link to another trading system, at least 50% of offset credits must provide direct environmental benefits to the state (DEBS) in the first compliance period, rising to 75% from the second compliance period. Without a link, all offset credits must provide DEBS.

Entities surrendered 26,280 offset credits in 2023, corresponding to 0.13% of total instruments surrendered for compliance.

The Washington Cap-and-Invest Program is not currently linked with any other system. However, in November 2023, the Department of Ecology announced that it would pursue linkage with the cap-and-trade programs of California and Québec. In March and September 2024, joint statements from the governments of Washington, California and Québec affirmed their commitment to explore potential linkage.

Compliance

Four years

Except for the year following the last year of a compliance period, compliance instruments equal to at least 30% of the previous year’s verified emissions must be surrendered annually, by the start of November (or the first business day thereafter). Compliance instruments equal to all remaining emissions must be surrendered by the start of November (or the first business day thereafter) of the year following the last year of a compliance period.

REPORTING FREQUENCY: Annual

VERIFICATION: All reports are verified by independent third-party verifiers and by the Department of Ecology.

FRAMEWORK: The MRV framework was established by the regulation “Reporting of Emissions of Greenhouse Gases”.

Should an entity have insufficient allowances to cover its annual and final compliance obligations, within six months of the deadline it must submit four allowances for each missing allowance it did not surrender. If the entity fails to comply, a fine of up to USD 10,000 per day per missing allowance will be incurred.

Market Regulation

MARKET PARTICIPATION: Compliance entities, including opt-in entities; non-compliance entities, including offset project participants; individuals with primary residence in the United States.

MARKET TYPES: 

Primary: Auctions are held four times per year, with a calendar giving dates and volumes published in January of each year. Participants must have an account in the Compliance Instrument Tracking System Service (CITSS). Auctions are delivered through the Western Climate Initiative, Inc.

Secondary: Futures and options contracts for allowances are traded on the Intercontinental Exchange and Nodal Exchange. Allowances can be traded over the counter directly between market participants. 

AUCTION PRICE FLOOR
Instrument type: Price-based instrument
Functioning: The auction price floor is set at USD 25.85 for 2025. It increases by 5% plus inflation annually, as measured by the nationwide Consumer Price Index for All Urban Consumers (CPI-U) identified by the US Bureau of Labor Statistics.

ALLOWANCE PRICE CONTAINMENT RESERVE (APCR)
Instrument type: Price-based instrument
Functioning: The APCR is a separate account managed by the Department of Ecology, from which allowances can be auctioned at pre-defined prices in the event of unexpectedly high allowance costs. The APCR was frontloaded, with 5% of the caps in the first and second compliance periods (covering 2023 to 2030) set aside at the outset of the program. The APCR has two price tiers, which in 2025 are set at USD 60.43 and USD 77.63 for Tiers 1 and 2 respectively.* Prices increase annually by 5% plus inflation, as measured by the CPI-U.

Auctions from the APCR are held if the settlement price in the last auction reaches the Tier 1 price level. These sales may only be held once a year before the compliance deadline, and only covered and opt-in entities can participate. Bids must be at one of the two price levels. Purchased allowances are deposited directly into entities’ compliance accounts and cannot be traded on secondary markets. Any unsold allowances are carried over to future APCR auctions. Three APCR Auctions (in August 2023, November 2023 and October 2024) have taken place since the Program’s launch, with a total of just over 7 million allowances sold.

PRICE CEILING UNITS
Instrument type: Price-based instrument
Functioning: If there are no units remaining in the APCR, price ceiling units are made available to covered entities with insufficient allowances to meet their compliance obligations. Price ceiling unit sales only occur at the end of a compliance period and following the request of a covered entity, which must be at least ten days before the compliance deadline. The ceiling price is USD 94.85 for 2025, increasing annually by 5% plus inflation, as measured by the CPI-U.

EMISSIONS CONTAINMENT RESERVE (ECR) 
Instrument type: Price-based instrument
Functioning: Allowances can be withheld from an auction and placed in the ECR if auction settlement prices fall below the ECR trigger price. The trigger price is currently suspended, and this provision is therefore not operational.


 

* Until a linkage agreement is signed, APCR auctions only include allowances at the Tier 1 price.

Other Information

Department of Ecology: Responsible for the program rules and implementation of the Cap-and-Invest Program.

Western Climate Initiative Inc.: Non-profit organization responsible for administering auctions, the CITSS registry, and conducting market surveillance.

By December 2027, and every four years thereafter, the Department of Ecology is required to submit a comprehensive review of the program to the legislature.

Climate Commitment Act

Climate Commitment Act Program Rule

Senate Bill 6058

 

 

 

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Indonesian Economic Value of Carbon (Nilai Ekonomi Karbon) Trading Scheme

ETS Status
in force
Jurisdictions
Indonesia
Sectoral coverage
Power
Allocation
Free Allocation (Output-based Benchmarking)
Offsets and credits
Domestic
Cap or total emissions limit
~ 256.8 MtCO2e in 2024
GHGs covered
CO2, CH4 and N2O
Average auction price
IDR 12,000 (USD 0.76), representing the carbon price from emission trading, specifically purchasing PTBAE-PU carbon units through over-the-counter transactions.
Average secondary market price
IDR 58,800 (USD 3.66), indicative of the carbon price from transactions involving Sertifikat Pengurangan Emisi (SPE, Indonesia Certificate of Emission Reduction) in IDXCarbon for offset credits.

General Information

Indonesia’s Economic Value of Carbon, or Nilai Ekonomi Karbon (NEK), Trading Scheme is a mandatory, intensity-based ETS for the power sector that was launched in early 2023. In its first phase spanning from 2023 to 2024, it exclusively targeted coal-fired power plants connected to the Perusahaan Listrik Negara (PLN) grid with a capacity of 25 MW or greater. In 2023, the ETS covered 99 coal-fired power plants, estimated to represent around 37% of the national power generation capacity or around 67.6% of the national coal-fired power plant capacity. In 2024, 47 additional coal-fired power plants were covered under the ETS, bringing the total number of covered installations in the scheme to 146. 

The Indonesian government has established intensity targets, known as “Technical Emissions Ceiling Approvals”, or Persetujuan Teknis Batas Atas Emisi (PTBAE). These targets determine the number of allowances that installations receive for each MWh of electricity generated. Covered entities must surrender allowances for all their covered emissions, with allocation based on PTBAE, emission intensity, and emission average. Additionally, entities have the option to purchase allowances via auctions. 

The majority of the plants covered by the ETS are operated by the state-owned electricity company PLN. The government anticipates a reduction of approximately 25.73 MtCO2e through the ETS in its first year.

Eventually, the Indonesia ETS is expected to function as a hybrid “cap-tax-and-trade” system, operating concurrently with a carbon tax. Facilities failing to meet their obligations under the ETS will be subject to this tax, the rate of which will be aligned with the domestic carbon market’s price.

The Indonesian Carbon Exchange (IDXCarbon) was officially launched in September 2023, under the supervision of the Financial Services Authority of Indonesia (Otoritas Jasa Keuangan, OJK).

In 2024, the scope of the ETS was expanded to cover installations with a capacity of 25 MW or more, adding another 47 coal-fired power plants to the scheme. According to current plans, captive coal-fired power plants (CFPPs) that are not connected to the electricity grid and gas power plants (gas fired power plants, gas engine power plants and combined cycled power plants) will join the ETS in its second phase, from 2025. 

Power

Emissions & Targets

1,070.5 MtCO2e (2022)

By 2030: 31.9% below BAU including LULUCF (unconditional, enhanced NDC); up to 43.2% below BAU including LULUCF (conditional on international support, enhanced NDC)

By 2060: Climate neutrality (“Long-Term Strategy for Low Carbon and Climate Resilience”, July 2021)

Size & Phases

CO2, CH4 and N2O

PHASE 1: Two years (2023 and 2024) 

PHASE 2: Three years (2025 to 2027)

PHASE 3: Three years (2028 to 2030)

Note: These phases apply exclusively to the power sector.

The total emissions limit under the Indonesian ETS is the sum of the bottom-up output-based emissions limits for all individual covered entities.

The Ministry of Energy and Mineral Resources (MEMR) establishes the PTBAE, or the emissions limit, for the power sector. This is based on: (i) actual emissions, which must be below the emissions reduction target set for the sector, and (ii) the carbon trading roadmap for the power sector.

PHASE 1: 

The ETS was applicable only to coal-fired power plants connected to PLN’s grid. The total emissions limit was approximately 256.8 MtCO2e.

The emissions limit for the power subsector for Phase 1 was as follows:

  • non-mine mouth coal-fired power plants with a capacity of ≥25 MW to <100 MW: 1.297 tCO2e/MWh
  • mine mouth coal-fired power plants with a capacity of ≥100 MW: 1.089 tCO2e/MWh
  • non-mine mouth coal-fired power plants with a capacity of 100 MW to ≤400 MW: 1.011 tCO2e/MWh
  • non-mine mouth coal-fired power plants with a capacity of >400 MW: 0.911 tCO2e/MWh

PHASE 2 and PHASE 3:

The emissions limits for the second and third phases have not yet been determined, but they are expected to be more stringent than in the first.

PHASE 1: Coverage was limited to coal-fired power generators connected to PLN’s grid only. Details on thresholds are provided below.

PHASE 2: The government plans to expand the scheme to include coal-fired power plants with capacity above 25 MW and not connected to PLN’s grid (captive CFPPs), gas-fired power plants, gas engine power plants and combined cycled power plants connected to PLN’s grid. 

PHASE 3: The expansion will encompass all fossil fuel power plants, including diesel power plants with a capacity of 2 MW or greater and coal-fired power plants with capacity below 25 MW regardless of their connection to PLN’s grid.

INCLUSION THRESHOLDS: In 2024, coal-fired power generation facilities with installed capacity exceeding 25 MW are included. Smaller coal and fossil fuel plants will be incorporated at a later point (see above).

The Ministry of Environment (MoE) has indicated that the government plans to implement emission caps for four additional sectors in the future: forestry, industrial processes and product use, agriculture, and waste management.

Point source

In 2023: 42 entities covering 99 installations

In 2024: 63 entities covering 146 installations

Note: The number of entities and installations is expected to continue increasing as new installations commence operations and additional categories are included, in line with the roadmap's expansions.

Allowance Allocation & Revenue

In Indonesia, allowances are referred to as Persetujuan Teknis Batas Atas Emisi Pelaku Usaha (PTBAE-PU).

PHASE 1: 

Auctioning: In the Indonesian ETS, auctioning is conducted through a system managed by IDXCarbon, where bid and offer instructions are matched based on a time and price priority scheme (refer to the ‘Market Design’ section).

  • Auction share: 0% (2024)
  • Auction volume: None

To date, no auction has taken place. Details regarding auction shares and related requirements or provisions are yet to be determined.

Benchmarking: MEMR sets intensity targets based on cap/PTBAE, installations’ average emissions of the previous year, and installations’ average emissions intensity of the previous year. These targets dictate the number of PTBAE-PU allowances allocated for every MWh of electricity generated. If the necessary data is unavailable, allocation is based on comparison with similar plants of equivalent installed capacity. In the first year, allowances will be given 100% for free. For the second year or the following year, installations will receive either 75% or up to 85% of their allowances for free. The deduction percentage depends on the installation’s compliance with the ETS.

Covered entities that receive allowances must participate in trading. If they do not, they receive a written warning and free allocation for the next compliance period is reduced to 75%.

Not defined

Flexibility & Linking

Banking is allowed within phases, though PTBAE-PUs are valid for a maximum of two years from the end of the previous compliance period. Banking is not allowed across phases.

Borrowing is not allowed.

The use of domestic offset credits – known as carbon reduction units, or Sertifikat Pengurangan Emisi Gas Rumah Kaca (SPE-GRK) – is allowed. Credits equivalent to SPE-GRKs may also be used.

QUALITATIVE LIMITS: Offset credits must stem from mitigation activities from:

  1. New and renewable energy power plants;
  2. Transportation, construction, and industry including energy efficiency activities; or
  3. Other activities in the energy sector.

They must also be issued on the national registry.

QUANTATIVE LIMITS: None

In 2023, 6,260 tCO2 in offset credits were retired, all from the Geothermal Lahendong project.

The Economic Value of Carbon NEK Trading Scheme is not linked with any other system.

Carbon tax: Indonesia carbon tax (upcoming)[1]

Domestic crediting mechanism: Indonesia Emissions Reduction Certification    


 

[1] The carbon tax is expected to be launched in 2025

Compliance

The compliance period for the Indonesian ETS is one year, with trading occurring from 1 January to 20 April of the following year. Surplus allowances at the end of the trading period may be traded in the following period, provided it is within the same phase.

MONITORING: An MRV system is currently in operation in the industrial sector and the power generation sub-sector. Pilot MRV programs are also being conducted in the cement and fertilizer sectors. 

REPORTING: Reports are submitted to the MEMR through the Directorate General of Electricity via an online platform, the APPLE-Gatrik. These reports must be submitted by the end of January for the preceding year. Installations must report emissions of CO2, CH4, and N2O, expressed in units of CO2e.

VERIFICATION: Emissions must be verified by a third-party verifier that is accredited by the Komite Akreditasi Nasional (KAN), Indonesia’s national accreditation body. This verification should be completed by the end of March, following the January reporting deadline. Verifiers are required to adhere to the guidelines for GHG emission verification in the power subsector.

The plan was to concurrently implement carbon trading and a carbon tax, with the latter serving as a penalty mechanism. However, as discussions on carbon tax regulations continue and its implementation is postponed, an alternative enforcement approach was introduced:

  1. Should verified emissions exceed the allocated PTBAE-PU by the end of the period, allocations will be given according to the results of carbon trading transactions in the previous carbon trading period up to a maximum of 85% and the PTBAE-PU will be reduced by up to 15%.
  2. Entities which fail to report their GHG emissions or participate in carbon trading by the end of the period will see a 25% reduction in their PTBAE-PU. 

Market Regulation

MARKET PARTICIPATION:

Compliance entities, specifically those holding an “Electricity Supply Business License for Public Purpose” or “Electricity Supply Business License for Own-Use,” are eligible to engage in carbon trading.

MARKET TYPES

Primary:

In the primary market, allowances and offset credits are traded through a mechanism that may be activated upon request by the relevant ministry. This platform facilitates offset selling, with a potential reserve price set as low as IDR 1 (less than USD 0.01), and bids commencing from this figure or higher. As of January 2025, there have been no auctions conducted under this system, and specific details about auction shares, along with associated requirements and provisions, remain to be defined.

Secondary:

Operated by IDXCarbon, launched at the Indonesia Stock Exchange (IDX) in September 2023 and licensed by the Financial Services Authority (OJK), the secondary market encompasses:

  • Regular Market or ‘Continuous Auction’: Matching of bids and offers based on time and price priority, with minimum prices set at IDR 200 (USD 0.01) and governed by fraction price rules and an ‘auto rejection’ rule.
  • Negotiated Market: Facilitates the settlement of pre-agreed trades through the exchange, requiring details of counterpart, carbon units, price, and volume.
  • Marketplace: Enables project developers to list their projects and set prices.

IDXCarbon is integrated with the national registry, Sistem Registri Nasional Pengendalian Perubahan Iklim (SRN PPI), managed by MoE, ensuring the seamless transfer of carbon credits and preventing double counting.

LEGAL STATUS OF ALLOWANCES: PTBAE-PUs and SPE-GRKs are classified as securities, allowing their transfer and trade in the capital market.

EVALUATION BY MEMR

Instrument type: Quantity-based instrument 

Functioning: The MEMR evaluates on a regular basis the implementation of the ETS. If the evaluation reveals a shortage of allowances, the Minister and Director General may conduct additional auctions of PTBAE-PUs.

Other Information

Coordinating Ministry for Economic Affairs (CMEA): Chair and Vice Chair of the National Steering Committee for Carbon Pricing Implementation; coordinates ministries/agencies in developing the national carbon pricing framework.

Ministry of Environment (MoE): National focal point for UNFCCC; leads NDC development and implementation, including national mitigation and adaptation and implementation of carbon pricing (including providing authorization for national and international emission trading, and overseeing offsetting; oversees MRV; operates the national registry, SRN PPI).

Ministry of Energy and Mineral Resources (MEMR): Coordinates ETS implementation in the power subsector, including oversight of an integrated MRV system with the SRN; responsible for preparing and implementing the 2021 voluntary pilot carbon market.

Ministry of Industry: Coordinates implementation of CPIs on the Industrial Processes and Product Use sector, including an emissions reporting system to be integrated with the SRN. 

Ministry of Finance: Leads the development and implementation of the carbon tax.

Indonesian Environment Fund: Handles climate funding; manages ETS revenues, including any international carbon credit trading.

Financial Services Authority (OJK): Oversees IDXCarbon, which is hosted on the Indonesia Stock Exchange.

The Minister of Energy and Mineral Resources, through the Directorate General of Electricity, evaluates the Indonesian ETS every six months. Results of this evaluation may lead to adjustments in the policy.

Regulation 46/2017 on Environmental Economic Instruments

Law 7/2021 Concerning Harmonization of Tax Regulations

Presidential Regulation 98/2021 on the Instrument for the Economic Value of Carbon for Achievement of the NDC and Control of Carbon Emissions in Development

MoEF Regulation 21/2022 on Guidelines for Carbon Economic Value Implementation

MEMR Regulation 16/2022 on Guidelines for Carbon Economic Value Implementation for the Power Generation Sub-sector

OJK Regulation 14/2023 concerning Carbon Trading Through the Carbon Exchange

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