Subsea 7 today announced the award of a sizeable1 contract by Aker BP for the Trell & Trine field development, located in the Alvheim area of the North Sea.
The project involves a subsea tie-back of approximately 21 kilometers to the Alvheim FPSO, via the existing East Kameleon subsea manifold. The contract scope includes engineering, procurement, construction and installation (EPCI) of the pipelines, spools, protection covers and tie-ins using key vessels from Subsea 7’s fleet. The production pipeline is a pipe-in-pipe design.
Project management and engineering will commence immediately at Subsea 7’s offices in Stavanger, Norway. Fabrication of the pipelines will take place at Subsea 7’s spoolbase at Vigra, Norway and offshore operations are expected to take place in 2023 and 2024.
Monica Th. Bjørkmann, Vice President for Subsea 7 Norway said: “This award is a continuation of Aker BP’s exciting development of the Alvheim area. The Trell & Trine field development is an excellent example of how our collaboration with Aker BP and Aker Solutions, through the Aker BP Subsea Alliance2, builds upon our collective experience from previous and ongoing projects. The partnership enables Subsea 7 to engage early in the field development process, optimising design solutions and contributing to a positive final investment decision. Subsea 7 is looking forward to continuing our collaboration for the Trell & Trine field development, with a focus on safe, efficient and reliable operations.”
Friday, 19 August 2022
Wednesday, 17 August 2022
Santos announces Pikka FID
Santos, as operator of the Pikka Unit joint venture, today announced a final investment decision (FID) has been taken to proceed with the US$2.6 billion gross (US$1.3 billion Santos-share) Pikka Phase 1 oil project located on the North Slope of Alaska.
Pikka Phase 1 is expected to produce 80,000 barrels a day of oil gross with first oil anticipated in 2026.
The project has strong fundamentals, is located in a world-class oil producing province with significant existing infrastructure, has low unabated emissions intensity and is supported by key stakeholders, including the State of Alaska, the North Slope Borough, the landowner company Kuukpik Corporation and the Arctic Slope Regional Corporation (ASRC).
Taking FID on Pikka Phase 1 is consistent with Santos’ goal of achieving net-zero (scope 1 and 2, equity share) by 2040. Santos is committed to delivering a net-zero project (scope 1 and 2, equity share) and has entered into Memorandums of Understanding with Alaska Native Corporations to deliver carbon offset projects, including a Strategic Alliance with ASRC Energy Services, a wholly-owned subsidiary of ASRC, on leading technology development for carbon solutions in the Arctic.
Alaska has a rich and proud oil and gas history – welcoming the jobs, investment and community development the industry provides. Pikka Phase 1 represents one of the lowest-cost and lowest unabated emissions intensity new oil projects in the region.
Santos is focussed on local procurement and local employment as part of the project, with 98 per cent of current employees living in Alaska. Phase 1 of the project is expected to create more than 500 jobs and construction of the project will deliver approximately 2,600 jobs.
The Pikka Phase 1 project represents compelling value for Santos shareholders given its robust economics and strong local stakeholder support.
Santos Managing Director and Chief Executive Officer Kevin Gallagher said Pikka Phase 1 is the right project at the right time in the right location.
“Global oil and gas markets are seeing increased volatility and countries are looking to diversify their supply sources away from Russia, which according to the International Energy Agency, currently produces 18 per cent of the world’s gas and 12 per cent of its oil,” Mr Gallagher said.
“Low-carbon oil projects like Pikka Phase 1 respond to new demand for OECD supply and are critical for global and United States energy security, that has been highlighted since the Russian invasion of Ukraine.
“Santos has emission reduction plans to achieve scope 1 and 2 net-zero emissions by 2040 and in-line with that commitment, Pikka will be a net-zero project.
“The project will add further diversification to our portfolio and reduces geographic concentration risk.
“Pikka Phase 1 will execute a responsible development plan with a small surface footprint and utilise existing infrastructure, including the Kuparuk transportation pipeline and the Trans-Alaska pipeline system.
“We have a world-class team with a rich history of successfully carrying out work on the North Slope. With approximately 90 per cent of project spend within North America minimising supply chain risk and civils work already completed, the project is well positioned for execution.”
Santos has a 51% interest in the Pikka Unit. The remaining interest is held by Repsol.
Pikka Phase 1 is expected to produce 80,000 barrels a day of oil gross with first oil anticipated in 2026.
The project has strong fundamentals, is located in a world-class oil producing province with significant existing infrastructure, has low unabated emissions intensity and is supported by key stakeholders, including the State of Alaska, the North Slope Borough, the landowner company Kuukpik Corporation and the Arctic Slope Regional Corporation (ASRC).
Taking FID on Pikka Phase 1 is consistent with Santos’ goal of achieving net-zero (scope 1 and 2, equity share) by 2040. Santos is committed to delivering a net-zero project (scope 1 and 2, equity share) and has entered into Memorandums of Understanding with Alaska Native Corporations to deliver carbon offset projects, including a Strategic Alliance with ASRC Energy Services, a wholly-owned subsidiary of ASRC, on leading technology development for carbon solutions in the Arctic.
Alaska has a rich and proud oil and gas history – welcoming the jobs, investment and community development the industry provides. Pikka Phase 1 represents one of the lowest-cost and lowest unabated emissions intensity new oil projects in the region.
Santos is focussed on local procurement and local employment as part of the project, with 98 per cent of current employees living in Alaska. Phase 1 of the project is expected to create more than 500 jobs and construction of the project will deliver approximately 2,600 jobs.
The Pikka Phase 1 project represents compelling value for Santos shareholders given its robust economics and strong local stakeholder support.
Santos Managing Director and Chief Executive Officer Kevin Gallagher said Pikka Phase 1 is the right project at the right time in the right location.
“Global oil and gas markets are seeing increased volatility and countries are looking to diversify their supply sources away from Russia, which according to the International Energy Agency, currently produces 18 per cent of the world’s gas and 12 per cent of its oil,” Mr Gallagher said.
“Low-carbon oil projects like Pikka Phase 1 respond to new demand for OECD supply and are critical for global and United States energy security, that has been highlighted since the Russian invasion of Ukraine.
“Santos has emission reduction plans to achieve scope 1 and 2 net-zero emissions by 2040 and in-line with that commitment, Pikka will be a net-zero project.
“The project will add further diversification to our portfolio and reduces geographic concentration risk.
“Pikka Phase 1 will execute a responsible development plan with a small surface footprint and utilise existing infrastructure, including the Kuparuk transportation pipeline and the Trans-Alaska pipeline system.
“We have a world-class team with a rich history of successfully carrying out work on the North Slope. With approximately 90 per cent of project spend within North America minimising supply chain risk and civils work already completed, the project is well positioned for execution.”
Santos has a 51% interest in the Pikka Unit. The remaining interest is held by Repsol.
Monday, 8 August 2022
Angola: TotalEnergies is Rolling out its Multi-Energy Strategy by Launching Three Projects in Oil, Gas and Solar Energy
As part of the rollout of its multi-energy strategy in Angola, TotalEnergies announces the launch of the Begonia oil field, and Quiluma and Maboqueiro gas fields developments, as well as its first photovoltaic project in the country, with a capacity of 35 MWp and the possibility of adding 45 MWp in a second phase.
Begonia, the first development on Block 17/06
TotalEnergies today announces the final investment decision for Begonia, the first development of block 17/06, located 150 kilometers off the Angolan coast, in agreement with concession holder Agência Nacional de Petróleo, Gás e Biocombustíveis (ANPG) and its partners on Block 17/06.
The Begonia development consists of five wells tied back to the Pazflor FPSO (floating production, storage and offloading unit), already in operation on Block 17. After commissioning, expected in late 2024, it will add 30,000 barrels a day to the FPSO's production.
After CLOV Phase 3, another satellite project that produces 30,000 barrels a day and was launched on Block 17 in June 2022, Begonia is the second TotalEnergies-operated project in Angola to use a standardized subsea production system, saving up to 20% on costs and shortening lead times for equipment delivery.
The project represents an investment of $850 million and 1.3 million man-hours of work, 70% of which will be carried out in Angola.
Quiluma and Maboqueiro, Angola's first non-associated natural gas projects
TotalEnergies also announces the final investment decision for the “Non Associated Gas 1” (NAG1) project, in which the Company holds an 11.8% interest alongside its partners, Eni (operator with 25.6%), Chevron (31%), Sonangol P&P (19.8%) and bp (11.8%).
NAG1 is the first non-associated natural gas project developed in Angola. Gas produced from the Quiluma and Maboqueiro offshore fields will supply the Angola LNG plant, improving Angola's LNG production capacity and the availability of domestic gas for the country's industrial development. Production is scheduled to start in mid-2026.
Quilemba, Angola's first TotalEnergies solar plant
TotalEnergies, alongside the Ministry of Energy and Water as well as its partners Sonangol and Greentech, was also awarded by the Angolan authorities, the concession for the construction of the Quilemba photovoltaic plant, with initial capacity of 35 MWp and the possibility of adding 45 MWp in a second phase.
The plant will be located in the southern city of Lubango and should come on stream at the end of 2023. It will contribute to the decarbonization of Angola’s energy mix and, through a fixed-price Power Purchase Agreement (PPA), deliver significant savings for the Angolan government compared to the fuel used in existing power plants. TotalEnergies holds an 51% interest in Quilemba solar, alongside affiliates of Sonangol EP (30%) and Angola Environment Technology (Greentech, 19%).
"Begonia, NAG1 and Quilemba illustrate the deployment of our multi-energy strategy in Angola, where TotalEnergies has been active for nearly seventy years," said Patrick Pouyanné, Chairman and CEO of TotalEnergies. “With Begonia, the first subsea tieback to another block, we are leveraging the existing Pazflor infrastructure, reducing costs, thanks largely to the standardization of subsea equipment, and continuing to innovate in the deep offshore. With the NAG1 project, we will contribute to the country’s industrial development and enable Angola, from 2026, to increase its LNG production and to contribute to the security of supply of Europe and Asia. Quilemba will allow us to harness the country's solar potential and develop a sustainable model for the production of electricity. These three projects demonstrate TotalEnergies' ambition to support Angola during the energy transition by producing energy with low carbon intensity and developing renewables in a country with strong potential."
Begonia, the first development on Block 17/06
TotalEnergies today announces the final investment decision for Begonia, the first development of block 17/06, located 150 kilometers off the Angolan coast, in agreement with concession holder Agência Nacional de Petróleo, Gás e Biocombustíveis (ANPG) and its partners on Block 17/06.
The Begonia development consists of five wells tied back to the Pazflor FPSO (floating production, storage and offloading unit), already in operation on Block 17. After commissioning, expected in late 2024, it will add 30,000 barrels a day to the FPSO's production.
After CLOV Phase 3, another satellite project that produces 30,000 barrels a day and was launched on Block 17 in June 2022, Begonia is the second TotalEnergies-operated project in Angola to use a standardized subsea production system, saving up to 20% on costs and shortening lead times for equipment delivery.
The project represents an investment of $850 million and 1.3 million man-hours of work, 70% of which will be carried out in Angola.
Quiluma and Maboqueiro, Angola's first non-associated natural gas projects
TotalEnergies also announces the final investment decision for the “Non Associated Gas 1” (NAG1) project, in which the Company holds an 11.8% interest alongside its partners, Eni (operator with 25.6%), Chevron (31%), Sonangol P&P (19.8%) and bp (11.8%).
NAG1 is the first non-associated natural gas project developed in Angola. Gas produced from the Quiluma and Maboqueiro offshore fields will supply the Angola LNG plant, improving Angola's LNG production capacity and the availability of domestic gas for the country's industrial development. Production is scheduled to start in mid-2026.
Quilemba, Angola's first TotalEnergies solar plant
TotalEnergies, alongside the Ministry of Energy and Water as well as its partners Sonangol and Greentech, was also awarded by the Angolan authorities, the concession for the construction of the Quilemba photovoltaic plant, with initial capacity of 35 MWp and the possibility of adding 45 MWp in a second phase.
The plant will be located in the southern city of Lubango and should come on stream at the end of 2023. It will contribute to the decarbonization of Angola’s energy mix and, through a fixed-price Power Purchase Agreement (PPA), deliver significant savings for the Angolan government compared to the fuel used in existing power plants. TotalEnergies holds an 51% interest in Quilemba solar, alongside affiliates of Sonangol EP (30%) and Angola Environment Technology (Greentech, 19%).
"Begonia, NAG1 and Quilemba illustrate the deployment of our multi-energy strategy in Angola, where TotalEnergies has been active for nearly seventy years," said Patrick Pouyanné, Chairman and CEO of TotalEnergies. “With Begonia, the first subsea tieback to another block, we are leveraging the existing Pazflor infrastructure, reducing costs, thanks largely to the standardization of subsea equipment, and continuing to innovate in the deep offshore. With the NAG1 project, we will contribute to the country’s industrial development and enable Angola, from 2026, to increase its LNG production and to contribute to the security of supply of Europe and Asia. Quilemba will allow us to harness the country's solar potential and develop a sustainable model for the production of electricity. These three projects demonstrate TotalEnergies' ambition to support Angola during the energy transition by producing energy with low carbon intensity and developing renewables in a country with strong potential."
First Gas introduced at Tinrhert Field Development project in Algeria
A major milestone has been achieved in the delivery of Sonatrach’s Tinrhert Field Development Project in Algeria, with the safe introduction of the first hydrocarbons for the start-up of production. When completed, the development will boost natural gas production capabilities for both local and export markets, enabling economic growth in-country.
Located in Ohanet, around 1,500km southeast of Algiers, Petrofac’s scope of work has included a new inlet separation and compression centre, extending the existing Central Processing Facility which the Company were involved in delivering in 2002. The centre will remove CO2 and mercury from the field’s gas reserves, so the gas is within specifications for the global market. The second part of the project involves the construction of a pipeline network of approximately 400km to connect 36 new wells, along with commissioning, start-up and performance testing of facilities.
Manish Bhojwani, Petrofac’s Algeria Country Manager said:
“The introduction of first gas is a significant step in bringing the project online. The teams are now focused on full start up as we head towards a safe completion. We’re proud that this continues to build on our successful track record, Petrofac has been working to support Algeria’s oil and gas production for more than two decades since our first major contract, the original development here in Ohanet, in 2000.”
Petrofac typically employ more than 800 people in Algeria, more than half of whom are Algerian nationals. Through the Company’s sub-contractors, several thousand more people are generally employed on Petrofac led projects and in 2021, more than 85% were Algerian nationals. Trainees have been recruited locally to support project delivery, with criteria that all are resident in the Ouragla or Ilizi Wilaya regions.
Located in Ohanet, around 1,500km southeast of Algiers, Petrofac’s scope of work has included a new inlet separation and compression centre, extending the existing Central Processing Facility which the Company were involved in delivering in 2002. The centre will remove CO2 and mercury from the field’s gas reserves, so the gas is within specifications for the global market. The second part of the project involves the construction of a pipeline network of approximately 400km to connect 36 new wells, along with commissioning, start-up and performance testing of facilities.
Manish Bhojwani, Petrofac’s Algeria Country Manager said:
“The introduction of first gas is a significant step in bringing the project online. The teams are now focused on full start up as we head towards a safe completion. We’re proud that this continues to build on our successful track record, Petrofac has been working to support Algeria’s oil and gas production for more than two decades since our first major contract, the original development here in Ohanet, in 2000.”
Petrofac typically employ more than 800 people in Algeria, more than half of whom are Algerian nationals. Through the Company’s sub-contractors, several thousand more people are generally employed on Petrofac led projects and in 2021, more than 85% were Algerian nationals. Trainees have been recruited locally to support project delivery, with criteria that all are resident in the Ouragla or Ilizi Wilaya regions.
Thursday, 21 July 2022
Liza Unity safely commissioned in industry-leading time, achieves background flare
The gas compression and injection systems on the Liza Unity Floating Production, Storage and Offloading (FPSO) vessel have been safely commissioned in around half normal industry time, achieving background flare as designed and within the 60-day period outlined in the Liza Phase 2 Environmental Permit.
Liza Unity safely commissioned in industry-leading time, achieves background flare
The start-up period involved temporary, non-routine flaring to safely commission the production and gas compression systems.
“This achievement is a testament to the team’s dedication to steady, safe operations. It also demonstrates ExxonMobil’s capabilities as an industry leader and our commitment to operational excellence,” ExxonMobil Guyana Production Manager Mike Ryan said.
The Liza Phase 2 project design eliminates routine flaring by using produced gas to power the FPSO and by reinjecting gas into the reservoir to conserve the gas and to improve oil recovery, thereby reducing emissions compared with traditional methods.
The team was also able to commission the water-injection system, which is now online and operational. The next step is to start up additional new wells in the ramp up to full production of 220,000 barrels of oil per day during the third quarter.
Meanwhile, a new, redesigned Flash Gas Compressor for the Liza Destiny FPSO has arrived in country for installation after extensive testing in Germany. The team is working towards start up in mid-July with the aim of also achieving background flare on that vessel as designed.
“We have relentlessly pursued a solution to this highly complex issue and have never lost sight of that goal. We are pleased that the newly designed machine is now offshore and the teams are methodically removing the original machine in preparation for the upgraded Flash Gas Compressor installation and startup,” the production manager indicated.
Over the last several months, the performance of the second- and third-stage flash gas compressor on the Liza Destiny has been stable and more than 96 percent of the gas produced was reinjected and/or used to power the vessel.
“Recent optimisation tests have confirmed the performance of the previously upgraded equipment and we were able to boost production to more than 140,000 barrels of oil per day, while maintaining the flare rates to a minimum,” Ryan added. “Contrary to reports, with the previously installed machine, production on the Destiny would have had to be zero in order to achieve background flare. Since start up in December 2019, we have managed production in a manner that balances the environmental commitment and economic needs of the country, in alignment with government priorities.”
ExxonMobil Guyana continues to work with the relevant government agencies to ensure compliance with regulations and responsible development of the country’s natural resources.
Liza Unity safely commissioned in industry-leading time, achieves background flare
The start-up period involved temporary, non-routine flaring to safely commission the production and gas compression systems.
“This achievement is a testament to the team’s dedication to steady, safe operations. It also demonstrates ExxonMobil’s capabilities as an industry leader and our commitment to operational excellence,” ExxonMobil Guyana Production Manager Mike Ryan said.
The Liza Phase 2 project design eliminates routine flaring by using produced gas to power the FPSO and by reinjecting gas into the reservoir to conserve the gas and to improve oil recovery, thereby reducing emissions compared with traditional methods.
The team was also able to commission the water-injection system, which is now online and operational. The next step is to start up additional new wells in the ramp up to full production of 220,000 barrels of oil per day during the third quarter.
Meanwhile, a new, redesigned Flash Gas Compressor for the Liza Destiny FPSO has arrived in country for installation after extensive testing in Germany. The team is working towards start up in mid-July with the aim of also achieving background flare on that vessel as designed.
“We have relentlessly pursued a solution to this highly complex issue and have never lost sight of that goal. We are pleased that the newly designed machine is now offshore and the teams are methodically removing the original machine in preparation for the upgraded Flash Gas Compressor installation and startup,” the production manager indicated.
Over the last several months, the performance of the second- and third-stage flash gas compressor on the Liza Destiny has been stable and more than 96 percent of the gas produced was reinjected and/or used to power the vessel.
“Recent optimisation tests have confirmed the performance of the previously upgraded equipment and we were able to boost production to more than 140,000 barrels of oil per day, while maintaining the flare rates to a minimum,” Ryan added. “Contrary to reports, with the previously installed machine, production on the Destiny would have had to be zero in order to achieve background flare. Since start up in December 2019, we have managed production in a manner that balances the environmental commitment and economic needs of the country, in alignment with government priorities.”
ExxonMobil Guyana continues to work with the relevant government agencies to ensure compliance with regulations and responsible development of the country’s natural resources.
Project management services for Aramco's unconventional gas projects
Worley has been awarded two project management service contracts for Aramco’s unconventional gas program in North and South Arabia and Jafurah.
Under the contracts, we will provide front-end engineering design (FEED), detailed design support, project management services and construction management services.
The term of both contracts is three years with an option for an extension for a further two years. We will carry out the work from our Al-Khobar and Houston offices.
“Being part of a project that not only looks towards sustainability but also contributes to boosting regional economy demonstrates Worley’s commitment to developing future growth in the location,” said Eissa Aqeeli, Senior Vice President and Location Director, Saudi Arabia and Bahrain.
Under the contracts, we will provide front-end engineering design (FEED), detailed design support, project management services and construction management services.
The term of both contracts is three years with an option for an extension for a further two years. We will carry out the work from our Al-Khobar and Houston offices.
“Being part of a project that not only looks towards sustainability but also contributes to boosting regional economy demonstrates Worley’s commitment to developing future growth in the location,” said Eissa Aqeeli, Senior Vice President and Location Director, Saudi Arabia and Bahrain.
Monday, 18 July 2022
The construction phase of the Greece-Bulgaria interconnector is completed
The construction phase of the gas interconnector Greece-Bulgaria has been completed. The event was celebrated at the gas measuring station near the Greek city of Komotini, where the pipeline connects to the gas transmission network of Greece and to the Trans-Adriatic pipeline. ICGB Executive Officers Teodora Georgieva and Konstantinos Karayannakos jointly announced the finalization of this stage of the IGB project, emphasizing the huge importance of the gas pipeline going way beyond the national borders of Greece and Bulgaria.
The landmark event was attended by the Prime Minister of Bulgaria Kiril Petkov, the Prime Minister of Greece Kyriakos Mitsotakis, the Ministers of Energy of the two countries - Alexander Nikolov and Kostas Skrekas, the Minister of Energy of Azerbaijan Parviz Shahbazov, high-ranking representatives from the European Commission (EC) and by the European Investment Bank (EIB) and a number of officials.
"Today we mark together the completion of a key stage in the development of the energy system in the region taking a big step forward towards a stronger, more connected and independent Europe. The end of the construction of IGB comes after a number of challenges and obstacles that we were able to overcome only thanks to the consistent efforts of the ICGB team, the company's shareholders, the political will of the governments of Bulgaria and Greece and the unequivocal support of the EC", stated the Executive Officer of ICGB from the Bulgarian side Teodora Georgieva. According to her, the upcoming commercial launch of the interconnector will guarantee secure supplies of natural gas from various sources not only for Bulgaria and Greece, but also for the entire region of South-Eastern Europe. "We have the opportunity to supply gas to the Western Balkans, to ensure supplies to Moldova and Ukraine," Georgieva emphasized.
"The IGB is being developed from the very beginning with a number of other key projects such as TAP, TANAP and the Alexandroupolis LNG terminal in mind, and this makes it an integral part of Europe's overall energy strategy and priorities. We began working on this project in a completely different international environment, but today IGB is more necessary and important than ever. The Greece-Bulgaria Interconnector is a new route for secure, diversified supplies, and will reshape the energy map of the region," said ICGB Executive Officer from the Greek side Konstantinos Karayannakos.
Since the second half of June, the interconnector has been filled with test quantities of natural gas. The route and its above-ground infrastructure have already been successfully tested including with transfer of natural gas in the direction of Stara Zagora - Komotini, and since the beginning of July the Komotini station has also been filled up with gas. The integration of the system for automated control and overall management of the gas pipeline (the so-called SCADA system) continues. The SCADA is responsible for transmitting the information and all data necessary for the safe operation of the gas pipeline through the communication network and will provide the capability to the dispatchers to monitor & control the entire facility from a remote centralized control centre. IGB is the first fully automated gas pipeline in Bulgaria.
At the beginning of July, ICGB was successfully certified as an independent transmission operator. This will allow the company to operate commercially after the launch of IGB. For this purpose, within one month, ICGB should introduce a completely new internal management structure with two-level control.The last stage before commercial operation includes the implementation of administrative procedures under the jurisdiction of a number of Bulgarian and Greek institutions, the total duration of which should be significantly reduced in order for the pipeline to become operational as soon as possible. ICGB’s management relies on active institutional support and political will in order for this goal to be successfully reached.
The landmark event was attended by the Prime Minister of Bulgaria Kiril Petkov, the Prime Minister of Greece Kyriakos Mitsotakis, the Ministers of Energy of the two countries - Alexander Nikolov and Kostas Skrekas, the Minister of Energy of Azerbaijan Parviz Shahbazov, high-ranking representatives from the European Commission (EC) and by the European Investment Bank (EIB) and a number of officials.
"Today we mark together the completion of a key stage in the development of the energy system in the region taking a big step forward towards a stronger, more connected and independent Europe. The end of the construction of IGB comes after a number of challenges and obstacles that we were able to overcome only thanks to the consistent efforts of the ICGB team, the company's shareholders, the political will of the governments of Bulgaria and Greece and the unequivocal support of the EC", stated the Executive Officer of ICGB from the Bulgarian side Teodora Georgieva. According to her, the upcoming commercial launch of the interconnector will guarantee secure supplies of natural gas from various sources not only for Bulgaria and Greece, but also for the entire region of South-Eastern Europe. "We have the opportunity to supply gas to the Western Balkans, to ensure supplies to Moldova and Ukraine," Georgieva emphasized.
"The IGB is being developed from the very beginning with a number of other key projects such as TAP, TANAP and the Alexandroupolis LNG terminal in mind, and this makes it an integral part of Europe's overall energy strategy and priorities. We began working on this project in a completely different international environment, but today IGB is more necessary and important than ever. The Greece-Bulgaria Interconnector is a new route for secure, diversified supplies, and will reshape the energy map of the region," said ICGB Executive Officer from the Greek side Konstantinos Karayannakos.
Since the second half of June, the interconnector has been filled with test quantities of natural gas. The route and its above-ground infrastructure have already been successfully tested including with transfer of natural gas in the direction of Stara Zagora - Komotini, and since the beginning of July the Komotini station has also been filled up with gas. The integration of the system for automated control and overall management of the gas pipeline (the so-called SCADA system) continues. The SCADA is responsible for transmitting the information and all data necessary for the safe operation of the gas pipeline through the communication network and will provide the capability to the dispatchers to monitor & control the entire facility from a remote centralized control centre. IGB is the first fully automated gas pipeline in Bulgaria.
At the beginning of July, ICGB was successfully certified as an independent transmission operator. This will allow the company to operate commercially after the launch of IGB. For this purpose, within one month, ICGB should introduce a completely new internal management structure with two-level control.The last stage before commercial operation includes the implementation of administrative procedures under the jurisdiction of a number of Bulgarian and Greek institutions, the total duration of which should be significantly reduced in order for the pipeline to become operational as soon as possible. ICGB’s management relies on active institutional support and political will in order for this goal to be successfully reached.
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