TECHNICAL PROGRAMME | Energy Technologies – Future Pathways
Research, Technology Start-ups and Funding
Forum 19 | Hall 10 - PRINCIPAL BUYER Technical Programme 4
12
October
16:15
17:30
UTC+3
Technology and innovation are the key to energy transition. Significant advancements have been achieved for conventional energies production in terms of efficiency and emission reductions. New energies such as solar, wind, hydrogen, nuclear, hydro, biomass etc. together with energy storage and complementary technologies, have boomed and are playing more and more important roles in energy transition. This forum will discuss the latest progress and achievements including research, experiments, applications, management and investment, with a particular focus on the roles of start-ups and venture capitals in projects initiation, planning and commercialisation.
The global energy sector is undergoing a fundamental transition toward low-carbon and renewable energy systems to address climate change challenges. As the world's largest energy consumer and carbon emitter, China has established ambitious carbon neutrality targets, compelling its oil and gas industry to accelerate clean energy transitions. Confronting the inherent conflict between traditional oil and gas development and green transformation, PetroChina Tarim Oilfield Company has developed an innovative management-technology-production integrated approach. In terms of management integration, a specialized management institution for new energy and carbon assets was established, creating a four-level “strategy-management-execution-technology” linkage mechanism. This framework introduced innovative dual-dimensional assessment standards that integrate oil/gas production with new energy development, ensuring deeper alignment between low-carbon objectives and operational tasks. In the aspect of technological integration, a technical system of energy consumption potential exploration - energy conservation and consumption reduction - clean energy substitution has been constructed, and new green and low-carbon technologies for the energy systems of oil and gas fields have been conquered. The production integration initiative implements unified planning and construction of three core networks, while optimizing regional collaborative allocation mechanisms and deploying intelligent regulation platforms. This establishes an integrated production and energy supply system that dynamically matches renewable energy inputs with hydrocarbon production demands, creating a closed-loop “clean supply-efficient use-intelligent control” ecosystem. The practice indicates that this mode has increased the oil and gas equivalent of the Tarim Oilfield from 30.8 million tons in 2020 to 33.53 million tons in 2024. Meanwhile, the total amount of energy consumption and carbon emissions has witnessed a substantial decline, with the energy consumption intensity dropping by 13.95% and the carbon emission intensity by 39.08%. The practice of the Tarim Oilfield offers a referable Chinese solution for the green transformation of global deep oil and gas fields and holds significant exemplary significance for promoting the high-quality development of the energy industry.
The shift to a sustainable hydrogen economy is vital, with underground LOHC storage presenting a pioneering approach for secure and large-scale hydrogen storage. The implementation of large-scale underground hydrogen storage using liquid organic hydrogen carriers (LOHCs) requires comprehensive reservoir modeling that captures the complete storage and retrieval cycle of both lean and hydrogenated carriers. This study presents an advanced reservoir simulation approach that utilizes pore network model-derived relative permeability data to evaluate the performance of toluene and methylcyclohexane (MCH) injection and production in subsurface formations, representing an operational scenario for LOHC storage systems.
Building upon detailed pore-scale characterization through micro-CT imaging and pore network modeling of Berea sandstone, relative permeability and capillary pressure curves were derived for both toluene-brine and MCH-brine systems through multiphase displacement simulations. These pore-scale derived flow functions, which incorporate experimentally measured wettability and interfacial tension properties, were upscaled and integrated into a comprehensive reservoir simulation framework implemented in CMG-GEM. The simulation approach represents a significant advancement over single-well studies by modeling the simultaneous operation of two injection wells within a shared reservoir system, enabling evaluation of the complete LOHC storage cycle, including both hydrogen loading (toluene injection) and storage (MCH injection) phases.
The reservoir model was designed to simulate field-scale with two strategically positioned injection wells: one for toluene injection during hydrogen loading phases and another for MCH injection during hydrogen storage phases. This dual-well configuration enables the simulation of complete operational cycles where toluene is injected and subsequently converted to MCH through hydrogenation, followed by MCH storage and eventual dehydrogenation back to toluene for hydrogen release. The model incorporates heterogeneous reservoir properties, realistic boundary conditions, and operational constraints to represent actual subsurface storage scenarios. Multiple injection-production cycles were simulated to evaluate long-term storage performance, including assessment of fluid distribution patterns, pressure evolution, and storage efficiency metrics.
Simulation results demonstrate the feasibility of simultaneous LOHC operations within a single reservoir system, revealing distinct flow behaviors and storage characteristics for each carrier. The toluene injection well exhibited superior sweep efficiency and faster pressure equilibration due to its more favorable wettability characteristics, while the MCH injection well showed different displacement patterns consistent with its distinct interfacial properties. The dual-well approach enables optimization of injection strategies, well placement, and operational scheduling to maximize storage capacity utilization while maintaining reservoir integrity. The simulations provide critical insights into interference effects between wells, optimal spacing requirements, and the impact of reservoir heterogeneity on storage performance.
This work represents the first comprehensive reservoir simulation study to model the complete LOHC storage cycle using pore network-derived flow functions in a dual-well configuration. The methodology provides a robust framework for designing and optimizing commercial-scale underground LOHC storage facilities, supporting the development of economically viable hydrogen storage infrastructure that can accommodate the full spectrum of LOHC operations required for large-scale energy storage applications.
Building upon detailed pore-scale characterization through micro-CT imaging and pore network modeling of Berea sandstone, relative permeability and capillary pressure curves were derived for both toluene-brine and MCH-brine systems through multiphase displacement simulations. These pore-scale derived flow functions, which incorporate experimentally measured wettability and interfacial tension properties, were upscaled and integrated into a comprehensive reservoir simulation framework implemented in CMG-GEM. The simulation approach represents a significant advancement over single-well studies by modeling the simultaneous operation of two injection wells within a shared reservoir system, enabling evaluation of the complete LOHC storage cycle, including both hydrogen loading (toluene injection) and storage (MCH injection) phases.
The reservoir model was designed to simulate field-scale with two strategically positioned injection wells: one for toluene injection during hydrogen loading phases and another for MCH injection during hydrogen storage phases. This dual-well configuration enables the simulation of complete operational cycles where toluene is injected and subsequently converted to MCH through hydrogenation, followed by MCH storage and eventual dehydrogenation back to toluene for hydrogen release. The model incorporates heterogeneous reservoir properties, realistic boundary conditions, and operational constraints to represent actual subsurface storage scenarios. Multiple injection-production cycles were simulated to evaluate long-term storage performance, including assessment of fluid distribution patterns, pressure evolution, and storage efficiency metrics.
Simulation results demonstrate the feasibility of simultaneous LOHC operations within a single reservoir system, revealing distinct flow behaviors and storage characteristics for each carrier. The toluene injection well exhibited superior sweep efficiency and faster pressure equilibration due to its more favorable wettability characteristics, while the MCH injection well showed different displacement patterns consistent with its distinct interfacial properties. The dual-well approach enables optimization of injection strategies, well placement, and operational scheduling to maximize storage capacity utilization while maintaining reservoir integrity. The simulations provide critical insights into interference effects between wells, optimal spacing requirements, and the impact of reservoir heterogeneity on storage performance.
This work represents the first comprehensive reservoir simulation study to model the complete LOHC storage cycle using pore network-derived flow functions in a dual-well configuration. The methodology provides a robust framework for designing and optimizing commercial-scale underground LOHC storage facilities, supporting the development of economically viable hydrogen storage infrastructure that can accommodate the full spectrum of LOHC operations required for large-scale energy storage applications.
One of the key challenges hindering widespread EV adoption in India is range anxiety. While as of Dec 2024 India has over 25000the public EV chargers and the number is steadily increasing, they are primarily concentrated in urban centres and along highways, leaving large semi-urban and rural areas without adequate coverage. Furthermore, the lack of incentives for the owners of underutilized charging stations often results in poor maintenance and limited operational uptime due to inadequate monitoring. This inconsistency in charging infrastructure affects both commercial and personal mobility, ultimately weakening public confidence in electric vehicles. This has resulted poor EV 4 Wheeler penetration of just 2% and EV 2 Wheeler penetration of only 6% in India as of FY 2025 new vehicle registration data (Vahan Vehicle Registration Portal).
To address this issue, our energy company initiated an open innovation challenge to scout for emerging technologies with the potential to reshape the EV ecosystem. Through this initiative, we reviewed 92 startup applications coming from all over India and after a thorough evaluation process, selected a promising startup offering a transformative approach.
Their innovation is a fully portable, renewable energy-powered charging solution that operates independently of the electricity grid. Designed for on-the-go deployment, this mobile energy unit integrates clean energy sources like solar panels with advanced battery storage and intelligent and smart system controlling unit. It can be dispatched to EVs wherever they are—on highways, remote delivery routes, or in emergency scenarios—ensuring uninterrupted charging support. By bypassing the need for permanent charging stations, it removes one of the major limitations of current EV infrastructure.
Beyond addressing range anxiety, this solution also tackles the issue of low utilization rates of lesser than 2% in case of fixed charging stations at many of our retail outlets. A mobile charging model allows 10x more utilization than typical fixed EV Charger for demand-based deployment, leading to better asset utilization and cost efficiency. It reduces the need for heavy capital investments in infrastructure that may remain idle for long periods.
This innovation not only bridges the charging gap but also strengthens the foundation for a more reliable and accessible EV ecosystem across India.
To address this issue, our energy company initiated an open innovation challenge to scout for emerging technologies with the potential to reshape the EV ecosystem. Through this initiative, we reviewed 92 startup applications coming from all over India and after a thorough evaluation process, selected a promising startup offering a transformative approach.
Their innovation is a fully portable, renewable energy-powered charging solution that operates independently of the electricity grid. Designed for on-the-go deployment, this mobile energy unit integrates clean energy sources like solar panels with advanced battery storage and intelligent and smart system controlling unit. It can be dispatched to EVs wherever they are—on highways, remote delivery routes, or in emergency scenarios—ensuring uninterrupted charging support. By bypassing the need for permanent charging stations, it removes one of the major limitations of current EV infrastructure.
Beyond addressing range anxiety, this solution also tackles the issue of low utilization rates of lesser than 2% in case of fixed charging stations at many of our retail outlets. A mobile charging model allows 10x more utilization than typical fixed EV Charger for demand-based deployment, leading to better asset utilization and cost efficiency. It reduces the need for heavy capital investments in infrastructure that may remain idle for long periods.
This innovation not only bridges the charging gap but also strengthens the foundation for a more reliable and accessible EV ecosystem across India.
Recently, the production of in-situ upgraded oil and hydrogen in some heavy oil field pilots became a reality. This was achieved with the Toe-to-Heel Air Injection (THAI) process, which consists of a combination of in-situ combustion with horizontal wells. Also, field testing of nano-catalysts and nanofluids in heavy oil reservoirs has recorded the first positive results.
THAI is the first enhanced oil recovery process that upgrades heavy oil underground, while recovering it, without any external heat sources; its second feature is the hydrogen contained in the produced gases. With the special completion of the THAI horizontal producers, an add-on new process called CAPRI can achieve a secondary upgrading.
THAI has been technically validated by seven field pilots located in India, Canada and China. Kerrobert Pilot, in Canada, has been in operation for 16 years; oil upgrading of 3-4 0API and viscosity decrease from 54,000cp to 3,000 cp have been achieved. Canadian, Athabasca THAI pilot, showed hydrogen in the range of 2%-6%, but in some conditions it was up to 14%.
Unintentional in-situ upgrading was recorded in eight very old conventional in-situ combustion (ISC) field projects, with or without special modifications. Not being designed to produce hydrogen (H2), for most of them, the mechanisms are deciphered only today. The most important project was Marguerite Lake wet ISC pilot in Canada, which produced 2-3% H2 during air-sustained wet ISC and up to 10-21% during oxygen (O2) sustained wet ISC, applied by alternative injection of O2 and water (with 10% H2 during O2 injection and up to 21% during water injection). Recently, a simulation model for the generation and production of H2 was developed, and it was validated by history matching of Marguerite Lake project.
Intensive laboratory investigations have indicated a maximum of 36% H2 in the case of catalyst use and for a combination of ISC with steam injection, which showed the best perspectives.
Obtaining ISC-generated hydrogen directly in-situ has been under investigation for 7 years. Although there are two main challenges – development of H2-selective, robust membranes and forcing CO2 to remain underground - some small progress has been made.
Recently, using nano-catalysts, important field successes were recorded for heavy oil production via the oil viscosity decrease, leading to enhanced recovery up to 200% per cycle in cyclic steam stimulations. The most important results are presented and discussed. Therefore, nano-catalysts’ successful use for a short-distance action is almost proven, technically.
Typical results of oil upgrading and hydrogen production in heavy oil fields and laboratory investigations correlated with recent simulations of laboratory and field tests will be presented and discussed. This way, the future pathways in field testing and in main research directions will be indicated to accelerate the potential commercial application.
THAI is the first enhanced oil recovery process that upgrades heavy oil underground, while recovering it, without any external heat sources; its second feature is the hydrogen contained in the produced gases. With the special completion of the THAI horizontal producers, an add-on new process called CAPRI can achieve a secondary upgrading.
THAI has been technically validated by seven field pilots located in India, Canada and China. Kerrobert Pilot, in Canada, has been in operation for 16 years; oil upgrading of 3-4 0API and viscosity decrease from 54,000cp to 3,000 cp have been achieved. Canadian, Athabasca THAI pilot, showed hydrogen in the range of 2%-6%, but in some conditions it was up to 14%.
Unintentional in-situ upgrading was recorded in eight very old conventional in-situ combustion (ISC) field projects, with or without special modifications. Not being designed to produce hydrogen (H2), for most of them, the mechanisms are deciphered only today. The most important project was Marguerite Lake wet ISC pilot in Canada, which produced 2-3% H2 during air-sustained wet ISC and up to 10-21% during oxygen (O2) sustained wet ISC, applied by alternative injection of O2 and water (with 10% H2 during O2 injection and up to 21% during water injection). Recently, a simulation model for the generation and production of H2 was developed, and it was validated by history matching of Marguerite Lake project.
Intensive laboratory investigations have indicated a maximum of 36% H2 in the case of catalyst use and for a combination of ISC with steam injection, which showed the best perspectives.
Obtaining ISC-generated hydrogen directly in-situ has been under investigation for 7 years. Although there are two main challenges – development of H2-selective, robust membranes and forcing CO2 to remain underground - some small progress has been made.
Recently, using nano-catalysts, important field successes were recorded for heavy oil production via the oil viscosity decrease, leading to enhanced recovery up to 200% per cycle in cyclic steam stimulations. The most important results are presented and discussed. Therefore, nano-catalysts’ successful use for a short-distance action is almost proven, technically.
Typical results of oil upgrading and hydrogen production in heavy oil fields and laboratory investigations correlated with recent simulations of laboratory and field tests will be presented and discussed. This way, the future pathways in field testing and in main research directions will be indicated to accelerate the potential commercial application.
Recently, the production of in-situ upgraded oil and hydrogen in some heavy oil field pilots became a reality. This was achieved with the Toe-to-Heel Air Injection (THAI) process, which consists of a combination of in-situ combustion with horizontal wells. Also, field testing of nano-catalysts and nanofluids in heavy oil reservoirs has recorded the first positive results.
THAI is the first enhanced oil recovery process that upgrades heavy oil underground, while recovering it, without any external heat sources; its second feature is the hydrogen contained in the produced gases. With the special completion of the THAI horizontal producers, an add-on new process called CAPRI can achieve a secondary upgrading.
THAI has been technically validated by seven field pilots located in India, Canada and China. Kerrobert Pilot, in Canada, has been in operation for 16 years; oil upgrading of 3-4 0API and viscosity decrease from 54,000cp to 3,000 cp have been achieved. Canadian, Athabasca THAI pilot, showed hydrogen in the range of 2%-6%, but in some conditions it was up to 14%.
Unintentional in-situ upgrading was recorded in eight very old conventional in-situ combustion (ISC) field projects, with or without special modifications. Not being designed to produce hydrogen (H2), for most of them, the mechanisms are deciphered only today. The most important project was Marguerite Lake wet ISC pilot in Canada, which produced 2-3% H2 during air-sustained wet ISC and up to 10-21% during oxygen (O2) sustained wet ISC, applied by alternative injection of O2 and water (with 10% H2 during O2 injection and up to 21% during water injection). Recently, a simulation model for the generation and production of H2 was developed, and it was validated by history matching of Marguerite Lake project.
Intensive laboratory investigations have indicated a maximum of 36% H2 in the case of catalyst use and for a combination of ISC with steam injection, which showed the best perspectives.
Obtaining ISC-generated hydrogen directly in-situ has been under investigation for 7 years. Although there are two main challenges – development of H2-selective, robust membranes and forcing CO2 to remain underground - some small progress has been made.
Recently, using nano-catalysts, important field successes were recorded for heavy oil production via the oil viscosity decrease, leading to enhanced recovery up to 200% per cycle in cyclic steam stimulations. The most important results are presented and discussed. Therefore, nano-catalysts’ successful use for a short-distance action is almost proven, technically.
Typical results of oil upgrading and hydrogen production in heavy oil fields and laboratory investigations correlated with recent simulations of laboratory and field tests will be presented and discussed. This way, the future pathways in field testing and in main research directions will be indicated to accelerate the potential commercial application.
THAI is the first enhanced oil recovery process that upgrades heavy oil underground, while recovering it, without any external heat sources; its second feature is the hydrogen contained in the produced gases. With the special completion of the THAI horizontal producers, an add-on new process called CAPRI can achieve a secondary upgrading.
THAI has been technically validated by seven field pilots located in India, Canada and China. Kerrobert Pilot, in Canada, has been in operation for 16 years; oil upgrading of 3-4 0API and viscosity decrease from 54,000cp to 3,000 cp have been achieved. Canadian, Athabasca THAI pilot, showed hydrogen in the range of 2%-6%, but in some conditions it was up to 14%.
Unintentional in-situ upgrading was recorded in eight very old conventional in-situ combustion (ISC) field projects, with or without special modifications. Not being designed to produce hydrogen (H2), for most of them, the mechanisms are deciphered only today. The most important project was Marguerite Lake wet ISC pilot in Canada, which produced 2-3% H2 during air-sustained wet ISC and up to 10-21% during oxygen (O2) sustained wet ISC, applied by alternative injection of O2 and water (with 10% H2 during O2 injection and up to 21% during water injection). Recently, a simulation model for the generation and production of H2 was developed, and it was validated by history matching of Marguerite Lake project.
Intensive laboratory investigations have indicated a maximum of 36% H2 in the case of catalyst use and for a combination of ISC with steam injection, which showed the best perspectives.
Obtaining ISC-generated hydrogen directly in-situ has been under investigation for 7 years. Although there are two main challenges – development of H2-selective, robust membranes and forcing CO2 to remain underground - some small progress has been made.
Recently, using nano-catalysts, important field successes were recorded for heavy oil production via the oil viscosity decrease, leading to enhanced recovery up to 200% per cycle in cyclic steam stimulations. The most important results are presented and discussed. Therefore, nano-catalysts’ successful use for a short-distance action is almost proven, technically.
Typical results of oil upgrading and hydrogen production in heavy oil fields and laboratory investigations correlated with recent simulations of laboratory and field tests will be presented and discussed. This way, the future pathways in field testing and in main research directions will be indicated to accelerate the potential commercial application.
Mutaz Alsubhi
Speaker
Ph.D Candidate
King Abdullah University of Science and Technology (KAUST)
Saudi Arabia
The shift to a sustainable hydrogen economy is vital, with underground LOHC storage presenting a pioneering approach for secure and large-scale hydrogen storage. The implementation of large-scale underground hydrogen storage using liquid organic hydrogen carriers (LOHCs) requires comprehensive reservoir modeling that captures the complete storage and retrieval cycle of both lean and hydrogenated carriers. This study presents an advanced reservoir simulation approach that utilizes pore network model-derived relative permeability data to evaluate the performance of toluene and methylcyclohexane (MCH) injection and production in subsurface formations, representing an operational scenario for LOHC storage systems.
Building upon detailed pore-scale characterization through micro-CT imaging and pore network modeling of Berea sandstone, relative permeability and capillary pressure curves were derived for both toluene-brine and MCH-brine systems through multiphase displacement simulations. These pore-scale derived flow functions, which incorporate experimentally measured wettability and interfacial tension properties, were upscaled and integrated into a comprehensive reservoir simulation framework implemented in CMG-GEM. The simulation approach represents a significant advancement over single-well studies by modeling the simultaneous operation of two injection wells within a shared reservoir system, enabling evaluation of the complete LOHC storage cycle, including both hydrogen loading (toluene injection) and storage (MCH injection) phases.
The reservoir model was designed to simulate field-scale with two strategically positioned injection wells: one for toluene injection during hydrogen loading phases and another for MCH injection during hydrogen storage phases. This dual-well configuration enables the simulation of complete operational cycles where toluene is injected and subsequently converted to MCH through hydrogenation, followed by MCH storage and eventual dehydrogenation back to toluene for hydrogen release. The model incorporates heterogeneous reservoir properties, realistic boundary conditions, and operational constraints to represent actual subsurface storage scenarios. Multiple injection-production cycles were simulated to evaluate long-term storage performance, including assessment of fluid distribution patterns, pressure evolution, and storage efficiency metrics.
Simulation results demonstrate the feasibility of simultaneous LOHC operations within a single reservoir system, revealing distinct flow behaviors and storage characteristics for each carrier. The toluene injection well exhibited superior sweep efficiency and faster pressure equilibration due to its more favorable wettability characteristics, while the MCH injection well showed different displacement patterns consistent with its distinct interfacial properties. The dual-well approach enables optimization of injection strategies, well placement, and operational scheduling to maximize storage capacity utilization while maintaining reservoir integrity. The simulations provide critical insights into interference effects between wells, optimal spacing requirements, and the impact of reservoir heterogeneity on storage performance.
This work represents the first comprehensive reservoir simulation study to model the complete LOHC storage cycle using pore network-derived flow functions in a dual-well configuration. The methodology provides a robust framework for designing and optimizing commercial-scale underground LOHC storage facilities, supporting the development of economically viable hydrogen storage infrastructure that can accommodate the full spectrum of LOHC operations required for large-scale energy storage applications.
Building upon detailed pore-scale characterization through micro-CT imaging and pore network modeling of Berea sandstone, relative permeability and capillary pressure curves were derived for both toluene-brine and MCH-brine systems through multiphase displacement simulations. These pore-scale derived flow functions, which incorporate experimentally measured wettability and interfacial tension properties, were upscaled and integrated into a comprehensive reservoir simulation framework implemented in CMG-GEM. The simulation approach represents a significant advancement over single-well studies by modeling the simultaneous operation of two injection wells within a shared reservoir system, enabling evaluation of the complete LOHC storage cycle, including both hydrogen loading (toluene injection) and storage (MCH injection) phases.
The reservoir model was designed to simulate field-scale with two strategically positioned injection wells: one for toluene injection during hydrogen loading phases and another for MCH injection during hydrogen storage phases. This dual-well configuration enables the simulation of complete operational cycles where toluene is injected and subsequently converted to MCH through hydrogenation, followed by MCH storage and eventual dehydrogenation back to toluene for hydrogen release. The model incorporates heterogeneous reservoir properties, realistic boundary conditions, and operational constraints to represent actual subsurface storage scenarios. Multiple injection-production cycles were simulated to evaluate long-term storage performance, including assessment of fluid distribution patterns, pressure evolution, and storage efficiency metrics.
Simulation results demonstrate the feasibility of simultaneous LOHC operations within a single reservoir system, revealing distinct flow behaviors and storage characteristics for each carrier. The toluene injection well exhibited superior sweep efficiency and faster pressure equilibration due to its more favorable wettability characteristics, while the MCH injection well showed different displacement patterns consistent with its distinct interfacial properties. The dual-well approach enables optimization of injection strategies, well placement, and operational scheduling to maximize storage capacity utilization while maintaining reservoir integrity. The simulations provide critical insights into interference effects between wells, optimal spacing requirements, and the impact of reservoir heterogeneity on storage performance.
This work represents the first comprehensive reservoir simulation study to model the complete LOHC storage cycle using pore network-derived flow functions in a dual-well configuration. The methodology provides a robust framework for designing and optimizing commercial-scale underground LOHC storage facilities, supporting the development of economically viable hydrogen storage infrastructure that can accommodate the full spectrum of LOHC operations required for large-scale energy storage applications.
Jayasurya Tsunduru
Speaker
DGM-Business Development
Hindustan Petroleum Corporation Ltd.
India
One of the key challenges hindering widespread EV adoption in India is range anxiety. While as of Dec 2024 India has over 25000the public EV chargers and the number is steadily increasing, they are primarily concentrated in urban centres and along highways, leaving large semi-urban and rural areas without adequate coverage. Furthermore, the lack of incentives for the owners of underutilized charging stations often results in poor maintenance and limited operational uptime due to inadequate monitoring. This inconsistency in charging infrastructure affects both commercial and personal mobility, ultimately weakening public confidence in electric vehicles. This has resulted poor EV 4 Wheeler penetration of just 2% and EV 2 Wheeler penetration of only 6% in India as of FY 2025 new vehicle registration data (Vahan Vehicle Registration Portal).
To address this issue, our energy company initiated an open innovation challenge to scout for emerging technologies with the potential to reshape the EV ecosystem. Through this initiative, we reviewed 92 startup applications coming from all over India and after a thorough evaluation process, selected a promising startup offering a transformative approach.
Their innovation is a fully portable, renewable energy-powered charging solution that operates independently of the electricity grid. Designed for on-the-go deployment, this mobile energy unit integrates clean energy sources like solar panels with advanced battery storage and intelligent and smart system controlling unit. It can be dispatched to EVs wherever they are—on highways, remote delivery routes, or in emergency scenarios—ensuring uninterrupted charging support. By bypassing the need for permanent charging stations, it removes one of the major limitations of current EV infrastructure.
Beyond addressing range anxiety, this solution also tackles the issue of low utilization rates of lesser than 2% in case of fixed charging stations at many of our retail outlets. A mobile charging model allows 10x more utilization than typical fixed EV Charger for demand-based deployment, leading to better asset utilization and cost efficiency. It reduces the need for heavy capital investments in infrastructure that may remain idle for long periods.
This innovation not only bridges the charging gap but also strengthens the foundation for a more reliable and accessible EV ecosystem across India.
To address this issue, our energy company initiated an open innovation challenge to scout for emerging technologies with the potential to reshape the EV ecosystem. Through this initiative, we reviewed 92 startup applications coming from all over India and after a thorough evaluation process, selected a promising startup offering a transformative approach.
Their innovation is a fully portable, renewable energy-powered charging solution that operates independently of the electricity grid. Designed for on-the-go deployment, this mobile energy unit integrates clean energy sources like solar panels with advanced battery storage and intelligent and smart system controlling unit. It can be dispatched to EVs wherever they are—on highways, remote delivery routes, or in emergency scenarios—ensuring uninterrupted charging support. By bypassing the need for permanent charging stations, it removes one of the major limitations of current EV infrastructure.
Beyond addressing range anxiety, this solution also tackles the issue of low utilization rates of lesser than 2% in case of fixed charging stations at many of our retail outlets. A mobile charging model allows 10x more utilization than typical fixed EV Charger for demand-based deployment, leading to better asset utilization and cost efficiency. It reduces the need for heavy capital investments in infrastructure that may remain idle for long periods.
This innovation not only bridges the charging gap but also strengthens the foundation for a more reliable and accessible EV ecosystem across India.
The global energy sector is undergoing a fundamental transition toward low-carbon and renewable energy systems to address climate change challenges. As the world's largest energy consumer and carbon emitter, China has established ambitious carbon neutrality targets, compelling its oil and gas industry to accelerate clean energy transitions. Confronting the inherent conflict between traditional oil and gas development and green transformation, PetroChina Tarim Oilfield Company has developed an innovative management-technology-production integrated approach. In terms of management integration, a specialized management institution for new energy and carbon assets was established, creating a four-level “strategy-management-execution-technology” linkage mechanism. This framework introduced innovative dual-dimensional assessment standards that integrate oil/gas production with new energy development, ensuring deeper alignment between low-carbon objectives and operational tasks. In the aspect of technological integration, a technical system of energy consumption potential exploration - energy conservation and consumption reduction - clean energy substitution has been constructed, and new green and low-carbon technologies for the energy systems of oil and gas fields have been conquered. The production integration initiative implements unified planning and construction of three core networks, while optimizing regional collaborative allocation mechanisms and deploying intelligent regulation platforms. This establishes an integrated production and energy supply system that dynamically matches renewable energy inputs with hydrocarbon production demands, creating a closed-loop “clean supply-efficient use-intelligent control” ecosystem. The practice indicates that this mode has increased the oil and gas equivalent of the Tarim Oilfield from 30.8 million tons in 2020 to 33.53 million tons in 2024. Meanwhile, the total amount of energy consumption and carbon emissions has witnessed a substantial decline, with the energy consumption intensity dropping by 13.95% and the carbon emission intensity by 39.08%. The practice of the Tarim Oilfield offers a referable Chinese solution for the green transformation of global deep oil and gas fields and holds significant exemplary significance for promoting the high-quality development of the energy industry.
