Breadcrumbs
The risks of ignoring methane emissions in coal mining
Unreported coal mine methane emissions could increase coal sector risks and hinder Indonesian coal companies’ decarbonisation efforts.
Available in: Indonesia
Highlights
922 Mt
Approved total coal production quota for coal companies in 2024
4
Out of 10 companies reported coal mine methane in sustainability reports
>2x
Coal companies’ total emissions could be more than double because of unreported coal mine methane
About
This report analyses emission profiles of ten big coal mining companies in Indonesia. It also includes an assessment on emissions reduction actions and the decarbonisation pathway of selected coal companies. In addition, we also estimate coal mine methane (CMM) emissions from companies which currently exclude CMM in their emission inventories. The data is mainly collected from published annual and sustainability reports of coal mining companies.
Executive summary
Coal mine methane: a key missing piece in coal mining decarbonisation
Coal mining companies will benefit from measuring and reporting methane emissions. The process helps companies understand the scale of the problem, assess environmental and investment risks and support the development of effective mitigation strategies.
Aryanto Nugroho National Coordinator - Indonesia, Publish What You Pay
This report serves as an important basis in presenting the facts that the coal mining sector could potentially contribute to larger greenhouse gas emissions beyond their use for generating electricity. The recommendations of this report can be used as the initial steps for the government and coal mining businesses to further contribute to net-zero. Furthermore, as an implementing member of the Extractive Industries Transparency Initiatives (EITI), Indonesia urges oil and gas as well as coal and mineral mining companies to publish their emissions data in accordance with the latest 2023 EITI Standard.
Coal mining outlook
Indonesia’s coal production and demand
The Indonesian government expects a long-term decline in coal demand. However, the recent quota approval of close to 1 billion tonnes of new coal brings into question the potential risks of this latest expansion.
Coal mining sector emissions
Coal companies are not fully disclosing their emissions
Coal mining also releases significant methane emissions which could be similar or greater than mining emissions from fossil fuel combustion and purchased electricity combined. However, most coal companies failed to measure and report these emissions.
Decarbonisation pathways
Decarbonisation measures have been initiated but highly insufficient
Coal companies have implemented measures to reduce emissions and have started business diversification into the clean energy sector. However, none has addressed coal mine methane emissions.
Recommendations
Measuring methane for effective mitigation measures
Developing a comprehensive GHG emissions inventory and including fugitive coal mine methane will help coal companies understand their emission profiles and be able to devise effective mitigation strategies.
There are two steps for coal companies to reduce methane emissions. In the long-term, coal companies should diversify their business and gradually reduce coal production. This is inline with broader global demand projections, coal investment risks and business opportunities in the clean energy sector. In the short-term, coal companies should start implementing mitigation measures to cut methane emissions.
The International Energy Agency (IEA) estimated that 26% of Indonesian coal mine methane emissions could be technically abated using existing technologies. This includes pre-mine drainage and ventilation air methane (VAM) mitigation. Pre-mine drainage is implemented by drilling boreholes into the coal seam to extract methane prior to mining. VAM refers to extracted methane from a ventilation system to reduce methane concentrations in underground coal mines. The extracted methane will then be captured and either utilised or destroyed through oxidation.
Coal companies should be actively investigating opportunities to implement pre-mine drainage across their surface mining assets. Such technologies have become widespread in China, the US and Australia, with early investment support from the Clean Development Mechanism (CDM) in the late 2000’s, and through government support and carbon market regulations.
This is also not limited to underground mines. In Australia, the Conorado’s Curragh mine has implemented a pre-mine drainage system that is able to profitably capture its waste gas and sell it for electricity generation. The company has also successfully trialled substituting diesel fuel in its truck fleet with gas, leading to substantial onsite emissions reductions and fuel cost savings.
However, underground coal mines have even more opportunities to mitigate their emissions. While these mines have similar opportunities to explore pre-mine drainage, they also have the opportunity to partner this mitigation approach with VAM mitigation.
In 2012, a consortium involving Bayan Resources and Enel Trade SpA submitted a CDM project design for pre-mining drainage and VAM mitigation projects at the Wahana Baratama mine in South Kalimantan. Unfortunately, there is no further information whether the project has moved forward or halted. However, the technical feasibility of VAM mitigation technology has been proven in a variety of mine settings around the world over the last 25 years.
Supporting Material
Methodology
Disclaimer
We have identified instances where reported emissions or estimates may significantly underestimate the actual amount of emissions released. It is important to note that this information is intended for informational or educational purposes only and should not be construed as financial, legal, or other professional advice.
The data presented in this report is based on materials outlined below. While the findings are derived from an analysis of this material, we cannot guarantee the completeness, accuracy, or reliability of the statements or representations arising from it. There may also be additional reporting that may not be publicly available or that we are not aware of. We have contacted all coal mining companies mentioned in the reports on two separate occasions and requested clarification if this is the case. The companies are Bumi Resources, Adaro Energy, Golden Energy Mines, Bayan Resources, Bukit Asam, Indika Energy, Kideco Jaya Agung, Berau Coal, ABM Investama, Indo Tambangraya Megah and Baramulti Suksessarana.
Data sources
Information on Indonesian coal production outlook was gathered based on a press conference by the Ministry of Energy and Mineral Resources (MEMR). Coal production quota was collected from MEMR during a public hearing with parliament. Coal export and domestic consumption data was collected from the Handbook of Energy and Economic Statistics of Indonesia.
Coal production, energy intensity and emission data of 10 big coal companies were collected from annual and sustainability reports of coal mining companies. In addition, coal production data of other companies were collected from Global Energy Monitor. For companies with multiple business lines, such as Bukit Asam, Adaro Energy and Indika Energy, we only selected specific information (including energy consumption and emissions) related to the coal mining business.
Coal mine methane (CMM) estimates
Ember estimated CMM emissions of six coal companies which did not include it in emissions reporting. The CMM emissions were calculated by multiplying annual coal production data with methane emission factors for surface coal mines following national standard and IPCC guidelines.
Indonesia currently does not have country-specific or basin-specific methane emission factors for coal mining. Consequently, coal companies could use global emission factors from IPCC guidelines or use Kholod et al’s method. In general, both methods agree that methane emissions will increase following the mining depth. And since we did not have information on each company’s mine depth, we utilised average emission factors for surface coal mines from IPCC guidelines. In addition, we used methane’s global warming potential of 29.8 from the Sixth Assessment Report.
Reporting standards and guidelines
At national level, MEMR Regulation No. 22/2019 provides general guidelines on emissions inventory for the energy sector. Emission sources include fuel combustion, fugitive emissions from coal mining and gas infrastructures, leakage in CO2 injection and venting and flaring in oil and gas.
Specifically for the coal sector, GRI sector standard for coal, IFRS climate-related disclosure and CDP provide specific guidelines. GRI provides specific recommendations for GHG emissions reporting. This includes reporting GHG emissions from CH4 and the breakdown of scope 1 GHG emissions by type of source (stationary combustion, process, fugitive). Similar to GRI, IFRS and CDP also require companies to disclose GHG emissions and the breakdown. In addition, the company needs to outline a strategy to manage emissions and set emissions reduction targets.
These standards are also closely aligned with GRI 305, GHG protocol and ISO 14064 on emission inventory.
Acknowledgements
Reynaldo Dizon and Jivan Thiru for all the data visualisation. Rini Sucahyo and Ardhi Arsala Rahmani who contributed through text editing. Eleanor Whittle who reviewed the report.
Our appreciation also goes to Publish What You Pay (PWYP) Indonesia who provides valuable inputs during the writing of this report.
Cover imageOpen pit coal mining in Borneo, Indonesia.
Credit: Ariyanto Ariyanto / Alamy Stock Photo