A Barrel Fulll Archive

22 December 2023 Seatrium Limited (Seatrium, or the Group) is pleased to announce that it has successfully delivered a Floating Storage and Regasification Unit (FSRU), Energos Celsius, to New Fortress Energy (NFE), one of the world’s leading LNG project developers. Energos Celsius is owned by Energos Infrastructure, a global marine infrastructure platform backed by Apollo funds (NYSE:APO) and NFE, and the vessel is on long-term charter to NFE in Brazil.  The FSRU was completed safely, on time and within budget, and has departed the Seatrium shipyard for Brazil. It will subsequently be deployed at NFE’s completed LNG terminal in Barcarena , Pará state, Brazil.  Mr Marlin Khiew, Executive Vice President, Oil & Gas (Americas), Seatrium said, "We would like to express our appreciation to New Fortress Energy for their trust and confidence in our commitment and capabilities as well as for the strong teamwork throughout the duration of the project. We are proud to successfully deliv

9 October 2015 We are pleased to announce that PT Medco Energi Internasional Tbk (MedcoEnergi), has signed a Sale and Purchase Agreement (“SPA”) with Lundin SEA Holding AB to acquire the Indonesian operations of Lundin Indonesia Holding B.V. on Thursday, October 8, 2015. The Indonesian assets include the non-operated interest in Lematang Block and operated interests in the South Sokang and Cendrawasih VII Blocks, as well as the Joint Study Agreement (JSA) in respect of the Cendrawasih VIII Block. Completion of this transaction is conditional upon approval from the Government of Indonesia. Lundin Indonesia Holding B.V, an affiliate of Lundin Petroleum AB (“Lundin”), a Swedish independent oil and gas exploration and production company active in Europe and Southeast Asia. Lundin holds a 25.8824 percent participating interest in the Singa Field (Lematang PSC), a 100 percent participating interest in the Cendrawasih VII Block (Cendrawasih VII PSC), a 100 percent participating interest in

October 05, 2020  Lummus Technology today announced that it has been awarded a contract by Enter Engineering Pte. Ltd. for the Shurtan Gas Chemical Complex in Uzbekistan. Lummus’ scope includes the design and supply of four proprietary Short Residence Time (SRT®) VI and VII type cracking furnaces, which will more than double the production of ethylene at Shurtan’s facility.   “Our advanced SRT® ethylene furnaces optimize reliability in capacity, yield, run-length and energy efficiency,” said Leon de Bruyn, President and Chief Executive Officer of Lummus Technology. “We are grateful to continue our partnership at Shurtan and look forward to working with Enter Engineering to expand the ethylene production while reducing relative emissions and operating costs at the Shurtan Gas Chemical Complex.” Lummus was selected due to its leading ethylene technology position and its extensive experience with ethylene furnaces, having developed pyrolysis furnaces as part of its proprietary equipment

June 6, 2017 McDermott International, Inc announced it has been awarded an engineering, procurement, construction, installation and commissioning (EPCIC) contract from BP Trinidad & Tobago, LLC (bpTT) for the Angelin gas field , located 25 miles (40 kilometers) off the east coast of Trinidad and Tobago. This EPCIC contract follows the successful completion of a multi-phase engineering contract, including pre-front end engineering design (pre-FEED), front-end engineering design (FEED), and pre-execution engineering contracts previously awarded by bpTT to McDermott for the initial design and execution planning of Angelin. McDermott’s team in Houston led the engineering and execution planning efforts with support and work share from the Company’s engineering center in Chennai, India. “This is a great opportunity for us to build on the relationship and trust developed through the execution of the FEED for the Angelin project,” said Scott Munro, McDermott Vice President for Americas, Eu

26 February 2019 Third major project to begin production for BP globally in 2019, builds on significant Trinidad business, adds to advantaged gas portfolio. BP Trinidad and Tobago (BPTT) today announced first gas production from its Angelin development. The project was delivered on time and under budget. The Angelin development, originally discovered by the El Diablo well in 1995, includes a new platform and four wells. It is located 60 kilometres off the south-east coast of Trinidad in a water-depth of approximately 65 metres. The new platform, BPTT’s 15th installation offshore Trinidad & Tobago, has a production capacity of 600 million standard cubic feet a day (mmscfd). Gas flows from the platform to the existing Serrette hub via a new 21-kilometre pipeline. BP Upstream chief executive Bernard Looney said: “This safe and successful start-up, less than two years after sanction, is a credit to our BP teams and contractors. Angelin is BP’s 22nd new upstream project to come online

20 September 2021 bp Trinidad and Tobago LLC (bpTT) today confirms its Matapal project has safely achieved first gas. The major milestone was achieved ahead of schedule and under budget despite the constraints brought about by the COVID-19 pandemic. Matapal is bpTT’s second subsea development. It’s comprised of three wells, which tie back into the existing Juniper platform , helping minimize development costs and the associated carbon footprint. It’s located approximately 80km off the south-east coast of Trinidad and approximately 8km east of Juniper, in a water depth of 163 metres. Matapal will deliver gas into the Trinidad gas market from resources discovered by the Savannah exploration well, drilled in 2017. The initial production from this development is expected to be in the range of 250-350 million standard cubic feet per day (mmscfd), once all wells are fully ramped up. Claire Fitzpatrick, president bpTT, said: “Natural gas will play an important role in the energy transition

14 December 2018 BP Trinidad and Tobago (BPTT) today announced the sanction for two new gas developments offshore Trinidad, Cassia Compression and Matapal. The Cassia Compression project will enable BPTT to access and produce low pressure gas reserves from currently-producing fields in the Greater Cassia Area, maximizing recovery from these existing resources. The project will involve the construction of a new platform, Cassia C, BPTT’s 16th offshore facility. Gas production from the Greater Cassia Area will be routed to Cassia C for compression before being exported via the adjacent existing Cassia B platform. First gas from the facility is expected in 3Q 2021. BPTT Regional President Claire Fitzpatrick said: “The Cassia Compression project will be important in maintaining the stability of Trinidad’s gas production and the supply to downstream customers and Atlantic LNG. The final investment decision for this project was made possible with the conclusion of the first phase of negotia

29 November 2022 bp Trinidad and Tobago LLC (bpTT) today confirms its Cassia C development has safely delivered first gas. Cassia C is bpTT’s first offshore compression platform and its biggest offshore facility. It will enable bpTT to access and produce low pressure gas resources from the Greater Cassia Area . The platform, bpTT’s 16th offshore facility, is connected to the existing Cassia hub which lies approximately 35 miles off Trinidad’s southeast coast. Cassia C is expected to produce, at peak, about 200-300 million standard cubic feet a day of gas. Production will go towards meeting bpTT’s gas supply commitments and will be important to sustaining T&T’s LNG and petrochemical industries. David Campbell, bpTT president, said: “First gas from Cassia C is an important milestone for bp in Trinidad and Tobago. This first offshore compression facility will allow us to unlock new resources and bring much-needed gas to market. I am immensely proud of the teams which have been working

CEPSA has acquired exploration and production rights from Hupecol Caracara LLC on a block located in the Los Llanos Basin in central Colombia. Once all the required regulatory approvals have been obtained, CEPSA will assume operatorship of the Block, with a 70% stake, the remaining 30% held by the Colombian national oil company ECOPETROL.  This transaction fits into CEPSA’s Strategic Plan, one of the targets being to slightly raise the Company’s current level of reserves and production. CEPSA Colombia S.A., a wholly-owned subsidiary of CEPSA, has signed a Purchase and Sale Agreement with Hupecol Caracara LLC, an affiliated entity of Houston American Energy Corp., to acquire the Caracara Block, located to the south of the Los Llanos Basin in central Colombia. This deal fits into the key targets set out in CEPSA’s 2008-2012 Strategic Plan as regards its upstream activities, which earmarks roughly $1,800 million in order to slightly raise the current level of crude oil reserves and produc

1 October 2020 Global investment firm, The Carlyle Group (NASDAQ: CG), today announced that it has agreed to acquire Occidental’s entire onshore portfolio in Colombia (“Colombia Onshore”) for a total consideration of approximately $825 million with $700 million to be paid up-front, and the remainder payable subject to certain production and commodity price targets. The transaction is subject to customary regulatory approvals and is expected to close in Q4 2020. Active in Colombia for over four decades, Colombia Onshore has well-established oil operations producing 33 thousand barrels of oil per day, on a net basis. The company’s 14 onshore blocks consist of six blocks in oil production and eight blocks in oil exploration. Its most significant activities are in the Llanos Norte Basin (Department of Arauca) where the business has produced more than 1.4 billion barrels of oil since the discovery of the Caño Limón field in 1983, and in the Middle Magdalena Basin (Department of Santander) w

10/15/2018 San Donato Milanese (MI), October 15, 2018 - Saipem has signed new Offshore E&C contracts in Azerbaijan, the North Sea and the Republic of Congo. The overall value of the contracts is approximately 400 million USD. In Azerbaijan, Total has awarded a SURF contract to the consortium between Saipem’s subsidiary, Saipem Contracting Netherlands BV, Boshelf LLC and STAR GULF FZCO, for the development of the Absheron field operated by JOCAP, a JV between TOTAL E&P Absheron (50%) and SOCAR Absheron (50%), from 10 mt to 500 mt of water depth, located under the Caspian Sea. The scope of work includes engineering, procurement, fabrication and offshore installation, assistance to commissioning and to performance testing of a 12” single production flowline and its Flowline End Termination structure (FLET), and of a main umbilical, both being approximately 34 km in length. Saipem was also assigned by Humberside Gathering System Limited, on behalf of the Tolmount Development Partn

19 September 2020 The operator of the Heydar Aliyev Baku Deep Water Jacket Factory, BOS Shelf has completed the construction of four main jackets and subsea structures for the Absheron field . The field is located in the Azerbaijani sector of the Caspian Sea, at 500 m water depths and about 100 km south east of Baku. The reserves of the field are estimated at 350 billion m3 of gas and 45 million tons of condensate. Absheron field is one of the largest gas-condensate fields in Azerbaijan, as well as the greatest discovery made by TOTAL in the past decade, being developed by JOCAP, a joint-venture company between SOCAR and TOTAL. The development of the field will provide a substantial contribution to meeting the growing domestic demand for natural gas in Azerbaijan. In 2018, JOCAP awarded BOS Shelf a contract on construction of the Absheron platform and all the related structures, basing on the company’s extensive experience in the implementation of large-scale oil and gas projects, suc

23RDNOV 2006 Santos was advised late yesterday evening of a serious incident involving the East Java gas pipeline, operated by Pertamina, in the vicinity of the Banjar Panji 1 well site. Initial reports indicate that there has been a pipeline failure resulting in a number of casualties including some fatalities. Santos is seeking further information regarding the cause of the incident, its impact and the response measures being implemented by both government authorities and the pipeline operator. Incident effect on Santos production The Maleo gas project in the Madura Offshore PSC (Santos 67.5%) has shut in production as a consequence of this incident. Maleo gas, along with gas from other fields in the area, is delivered into the East Java pipeline. Santos net entitlement production from the Maleo field was approximately 7,000 barrels of oil equivalent per day prior to the incident.

01/12/2021 With the presence of the Minister of Hydrocarbons and Energy, Franklin Molina, and the Executive President of YPFB, Wilson Zelaya, TotalEnergies EP Bolivie celebrated the connection of the ICS-5 Well in a ceremony held on November 26 at the Incahuasi Plant. The gas production of the Incahuasi 5 Well (ICS-5) will allow the incorporation of up to 2 MMmcd of gas to the production of the Incahuasi field and the maintenance of the production plateau of 11 MMmcd. The ICS-5 Well connection project required 500,000 man-hours during construction, meeting the goal of "zero" incidents, an investment of USD 25 million, which will be added to the USD 74 million already invested in the drilling of Well ICS-5. In September 2019, the basic engineering work began, in April 2021 the construction phase began with the opening of the right-of-way, in September the hydrostatic test was carried out on the pipe of the collection line successfully and in November the well was linked to th

19/03/2020 Drilling of the first appraisal well at Karabagh oil field was started on December 23, 2019. The well was drilled in water depth of 180 meters by the Dada Gorgud semi-submersible drilling rig operated by SOCAR’s Caspian Drilling Company (CDC). The reservoir is at a depth of approximately 3.4 kilometers. Estimated size of the discovered volumes of oil and gas are satisfactory for pursuing commercial development of the Karabagh field. SOCAR’s President, Rovnag Abdullayev said: “Karabagh is the first oil field discovered during the independence period of our country and its oil reserves estimated more than 60 million tons. The successful delivery of the appraisal well to the target safely and on time is the result of effective collaboration of SOCAR and Equinor. Development of the Karabagh field will significantly contribute to Azerbaijan’s oil incomes. The field proudly bears the name of the heart of our Motherland - Karabagh.” The Karabagh prospective structure was identifie

15 August 2020 The exclusive operator of the Heydar Aliyev Baku Deep Water Jacket Factory, BOS Shelf has completed the construction of Karabakh Jacket , the largest offshore jacket in the history of oil and gas fields development in the Caspian Sea. The structure with a height of 187 meters and a weight of 16,302 tons will be installed at a depth of 182 meters. The jacket was built within two years with achievement of a 3,200,000 man-hours indicator. 95% of people employed on the construction site were local workforce. The construction process was completed in full compliance with international health, safety and environmental standards. “We are pleased to announce the completion of construction of the Karabakh Jacket, epitomizing industrial breakthrough, and the start of its load out onto the STB1 barge after which it will be transported to the Karabakh oil and gas field,” the company said. SOCAR and the Norwegian company Equinor confirmed the discovery of the Karabakh field in the A

May 30, 2018 Statoil Azerbaijan (part of the Equinor group) and Azerbaijan’s state oil company SOCAR have today, 30 May, signed a Risk Service Agreement (RSA) related to the appraisal and development of the Karabagh oilfield and a Production Sharing Agreement (PSA) for the Ashrafi, Dan Ulduzu, Aypara area. The Karabagh oilfield is located 120 kilometres east of Baku, close to the SOCAR operated Shallow Water Gunashli (SWG) field and the BP operated Azeri Chirag Gunashli (ACG) field, in which Statoil Azerbaijan has a 7.27% interest. The Ashrafi, Dan Ulduzu, Aypara exploration area is located around 100-110 kilometres north-east of Baku. “The agreements signed today represent a natural next step in the region. This will strengthen our position in a prolific basin and develop growth options. The licenses lie in close proximity to the ACG field in a basin we know well. We now look forward to work on these new exploration projects in partnership with SOCAR,” says Eldar Sætre, President and

22 DECEMBER 2023 Equinor and SOCAR (State Oil Company of Azerbaijan Republic) have signed an agreement whereby Equinor will divest all its remaining assets in Azerbaijan to SOCAR. The assets comprise a 7.27% non-operated interest in the Azeri Chirag Gunashli (ACG) oil fields in the Azerbaijan sector of the Caspian Sea, 8.71% interest in the Baku-Tbilisi-Ceyhan (BTC) pipeline and 50% in the Karabagh field. SOCAR already holds a 25.0% stake in ACG, a 25.0% stake in BTC via Azerbaijan BTC Limited, and 50% in Karabagh . Equinor has been present in Azerbaijan since 1992. ACG, operated by bp, is the largest oilfield in the Azerbaijan sector of the Caspian basin and the BTC pipeline is used to transfer crude oil to the Turkish Mediterranean coast. Philippe Mathieu, Equinor's executi (Photo: SOCAR) “Azerbaijan has been an important part of Equinor’s international portfolio over the past 30 years. Together with SOCAR and the other partners in ACG, we have created significant value for the

February 28, 2019 Bayport Polymers LLC (Baystar™) , the 50/50 joint venture owned by Total Petrochemicals & Refining USA, Inc. (TPRI) and Novealis Holdings LLC – itself a joint venture co-owned by Borealis AG (“Borealis”) and NOVA Chemicals Inc. (“NOVA Chemicals”) – held its official groundbreaking ceremony for the construction of a new 625,000 metric ton-per-year Borstar® polyethylene unit at its production site in Pasadena, Texas, with an anticipated start-up in 2021. The state-of-the-art Borstar® technology, which will be used in North America for the first time, will allow Baystar to produce enhanced polyethylene products for the most demanding applications. Approximately 1,750 jobs will be created during the peak engineering and construction activity. Baystar is also building a one-million-ton per year steam cracker in Port Arthur, Texas. The new cracker will process ethane, which is abundantly available and competitively priced in the U.S., and will supply feedstock for its e

20.08.2015   PJSC LUKOIL closed a deal to sell its 50% share in Caspian Investments Resources Ltd. to China-based Sinopec. The required permits from the state authorities of the Republic of Kazakhstan were acquired in late July 2015. According to the contract LUKOIL receives USD 1,087 million. Caspian Investments Resources Ltd. has been participating in the development of 5 hydrocarbon fields in Kazakhstan ( Alibekmola and Kozhasai in the Aktyubinsk Region and Karakuduk, North Buzachi and Arman in the Mangistau Region). LUKOIL joined these projects in December 2005. Over the last decade, more than 1,600 wells were drilled, oil production capacities were expanded, injection systems were upgraded and a series of associated petroleum gas utilization facilities was launched. Since 2006, LUKOIL's share of the cumulative production of these fields amounted to over 13 million tonnes of oil and over 300 million cubic meters of commercial gas. LUKOIL currently continues its participation i

  01.07.2005    LUKOIL and ConocoPhillips have finalized the creation of the OOO Naryanmarneftegaz joint venture to develop resources in Timan-Pechora hydrocarbon province in the northwest of Russia. ConocoPhillips has a 30 percent interest in the joint venture. The amount of the transaction involving acquisition of this interest is approximately US$500 million. The companies will govern the joint venture 50/50.   Production from the joint-venture fields is expected to be transported via pipeline to LUKOIL's existing terminal at Varandey Bay on the Barents Sea (Nenets autonomous district) and then shipped via tanker to international markets.   The Naryanmarneftegaz joint venture is part of a larger strategic alliance between ConocoPhillips and LUKOIL that was formed on Sept. 29, 2004.

December 1, 2017 OMV, the international integrated oil and gas company based in Vienna, has completed the acquisition of a 24.99% share in the Yuzhno Russkoye natural gas field located in Western Siberia from Uniper SE following fulfillment of all closing conditions including regulatory and co-shareholder approvals. The purchase price paid by OMV to Uniper amounts to EUR 1,719 mn and includes customary closing adjustments. The transaction takes retroactive economic effect as of January 1, 2017 and was largely funded out of proceeds generated from disposals and OMV’s strong cash flow. Rainer Seele, Chairman of the OMV Executive Board and CEO: “The closing of this landmark transaction is a further milestone in OMV´s successful delivery on its corporate strategy to establish Russia as a new core region of OMV. Our stake in Yuzhno Russkoye adds 100,000 boe/d to OMV´s production. This boosts OMV´s total production to more than 430,000 boe/d.” Johann Pleininger, OMV´s Deputy CEO and Board M

Feb. 26, 2009 TransCanada Corporation (TSX:TRP) (NYSE:TRP) (TransCanada) today announced the successful completion of a binding open season, securing support for firm transportation contracts of 378 million cubic feet per day to connect new shale gas supply in the Horn River basin north of Fort Nelson B.C. to the Alberta System. "The positive commercial response is a result of the tremendous, largely untapped source for unconventional natural gas in the northeastern B.C. shale basins, combined with TransCanada's ability to meet this demand economically and efficiently," said Hal Kvisle, TransCanada president and chief executive officer. "Looking forward, we expect to add future capacity to the line as the right opportunities present themselves." The Horn River pipeline project is approximately 155 kilometres (km) and is expected to use new pipelines up to 36-inch diameter and an existing pipeline in the area to transport sweet natural gas from the Horn River ar

Aug. 1, 2008 TransCanada Corporation (TSX:TRP) (NYSE:TRP) (TransCanada) today received the support of the Alaska Legislature to award the company a license for the Alaska Pipeline Project under the Alaska Gasline Inducement Act (AGIA). "The Legislature's decision represents a significant milestone in advancing this major natural gas pipeline project to connect stranded U.S. natural gas reserves to Alaskan and Lower 48 consumers. We are pleased to receive this vote of confidence from the representatives of the people of Alaska," stated Hal Kvisle, TransCanada's president and chief executive officer. "This ratification of our license under AGIA will facilitate TransCanada's continuing commercial negotiations with potential shippers, improving the likelihood of a successful open season and the construction of a natural gas delivery system from Prudhoe Bay to Lower 48 markets." Today's positive vote was the conclusion of a special session of the Legisla

December 19, 2006  TC PipeLines, LP (the Partnership) today announced it has closed its acquisition of Sierra Pacific Resources’ 50 per cent interest in Tuscarora Gas Transmission Company (Tuscarora) for approximately US$100 million. The Partnership has also indirectly assumed US$37 million of Tuscarora debt. TC PipeLines, LP now owns or controls 99 per cent of Tuscarora. TransCanada Corporation (TransCanada), the parent company of the Partnership’s general partner, TC PipeLines GP, Inc., indirectly holds a 1 per cent ownership interest.  “Tuscarora is a high quality asset with a strong long-term contract profile, rate stability and a history of steady organic growth,” said Russ Girling, president and chief executive officer of TC PipeLines GP, Inc., general partner of TC PipeLines, LP. “These attributes, combined with the Partnership’s existing ownership of Tuscarora and the pipeline’s physical connection to TransCanada’s system, make Tuscarora an excellent investment for TC PipeLine

February 22, 2007 TC PipeLines, LP (the Partnership) today announced it has closed the acquisition of a 46.45 per cent interest in Great Lakes Gas Transmission Limited Partnership (Great Lakes) from El Paso for approximately US$962 million, subject to certain closing adjustments, including US$212 million of assumed debt. “With the acquisition of Great Lakes, the Partnership now has interests in more than 3,600 miles of federally regulated U.S. interstate natural gas pipelines delivering to a diverse market base in the Western, Midwestern, and Northeastern U.S. as well as Eastern Canada,” said Russ Girling, chief executive officer of the general partner, TC PipeLines GP, Inc. “As a result of the Partnership’s acquisition activity in the past year, we have significantly expanded the size of our asset base and strengthened the Partnership.” The acquisition was partially financed through a private placement of 17,356,086 common units at $34.57 per common unit for gross proceeds of $600

October 12, 2018 Commonwealth LNG signed an engineering service contract with TechnipFMC, a world-wide leader in LNG engineering, for engineering services and development of Resource Report 13 for the proposed 8.4 MTPA LNG export terminal located on the western shore at the mouth of the Calcasieu Ship Channel in Cameron Parish, Louisiana. Commonwealth LNG signed a master services agreement with Lloyd Engineering for marine facility and turning basin design, and support of the Water Suitability Assessment (WSA), with the U.S. Coast Guard. Collectively with the Maritime Pilots Institute in Covington, Louisiana, the group completed simulations and then subsequently prepared a draft WSA. Commonwealth LNG CEO Paul Varello said, “The strength of our team lies not only in the diverse LNG experience of our executive management, but also with the industry-leading partners we have chosen for this development. Commonwealth LNG will achieve its goal of being the low-cost provider for the next wav

18 January 2021 Commonwealth LNG , in association with Gunvor Group (“Gunvor”), announced today the launch of a formal process to solicit bids to reserve offtake from its planned 8.4 million tons per annum (MTPA) LNG facility in Cameron, Louisiana. It is the first ever tender process in which prospective LNG customers can secure future term supply at volumes, pricing and durations of their choosing through competitive bidding. LNG will be made available under tolling, free on board (FOB) or delivered at place (DAP) offtake agreements to match customer preferences. Commonwealth officials say that a different approach is warranted following changes in the energy market resulting from the global pandemic. Commonwealth Founder and CEO Paul Varello said the innovative approach to selling LNG benefits the project as well as potential buyers. “We believe this process offers a mutually advantageous, low-risk solution for buyers to address their long-term needs while allowing Commonwealth to ad

Sept. 5, 2022 Commonwealth LNG , a subsidiary of Commonwealth Projects (Commonwealth), and Woodside Energy Trading Singapore Pte Ltd, a subsidiary of Woodside Energy Group Ltd (Woodside), are pleased to announce the conversion of their non-binding heads of agreement (HOA) into two binding LNG Sale and Purchase Agreements (SPAs), signed 2 September 2022. The SPAs are for the supply of up to 2.5 million tonnes per annum (Mtpa) of LNG over 20 years from Commonwealth’s LNG export facility under development in Cameron Parish, Louisiana. Key terms in the HOA previously announced on 19 January 2022 remain unchanged in the binding SPAs, with first deliveries expected to commence in mid-2026. The SPAs will become fully effective upon the satisfaction of customary conditions including an affirmative final investment decision on the project. “We’re very pleased to have Woodside involved in our project,” said Commonwealth Executive Chairman Paul Varello. “Woodside is known throughout the LNG indus

Aug. 14, 2023  Commonwealth LNG announced today that it has closed an investment of development capital from private funds managed by Kimmeridge Energy Management Company, LLC (Kimmeridge), an alternative asset management firm focused on the energy sector. This investment completes the development funding required for Commonwealth LNG to reach final investment decision (FID) on its 9.3 million tons per annum (mtpa) LNG export facility in Cameron, Louisiana. Commonwealth LNG and Kimmeridge have also agreed in principle on terms for a 20-year, 2 mtpa LNG offtake commitment from the facility along with the associated gas supply. The agreement also includes key terms for Kimmeridge’s participation to provide further equity in Commonwealth LNG to support construction of the facility. “We are delighted to partner with Kimmeridge, a company that is committed to the transition toward a lower carbon future,” said Paul Varello, Executive Chairman and Founder of Commonwealth LNG. “This agreement

August 21, 2023 Commonwealth LNG announced today that it has signed a strategic agreement with Baker Hughes related to Commonwealth LNG’s liquefied natural gas facility under development in Cameron Parish, Louisiana. Baker Hughes will work with Commonwealth LNG on maximizing the project’s output and minimizing emissions through the use of Baker Hughes’ LM9000 aeroderivative gas turbine technology – the most efficient in the 65+ MW power range. The LM9000 equipment order is expected to be granted in conjunction with financial close of the Commonwealth LNG project, which is expected in the first quarter of 2024. The collaboration will also feature other key Baker Hughes equipment, services and software in support of the project, including its proven compressor technology, spare parts, maintenance services and Cordant Asset Performance Management suite. Commonwealth LNG views its relationship with Baker Hughes as vital to ensuring that Commonwealth LNG commences production in early 2027

12th January 2021 Wintershall Noordzee B.V. (a 50:50 Joint Venture of Wintershall Dea GmbH and Gazprom EP International B.V.) has started up the production of the D12-B3 well, the Sillimanite South field discovery well. This gas field was discovered last year following the completion of the second Sillimanite development well which was taken into production in June last year. The D12-B3 well is the third new well which Wintershall Noordzee has taken into production in the past 12 months. The Sillimanite South field discovery well was directly converted from an exploration well to a production well. “Delivery of a well directly from the exploration phase straight into the production phase is a unique performance in itself. Doing so whilst having to operate under stringent measures due to the COVID-19 pandemic makes it even more so”, says Jone Hess, Managing Director of Wintershall Noordzee B.V. “The fact that we worked together with our own strong, dedicated team and those of Maersk

20th February 2020 Wintershall Noordzee B.V. (a Joint Venture of Wintershall Dea and Gazprom EP International) has successfully started gas production from its operated Sillimanite field . Discovered in June 2015, the unitized gas field stretches across the UK and the Dutch Continental Shelves and is located approximately 200 kilometers off the coast of Den Helder. “With first gas from Sillimanite we once more underline our ability to successfully explore for hydrocarbons and transfer development projects successfully into production. As Sillimanite will increase the amount of gas produced in Europe, it underlines Wintershall Dea’s capabilities as Europe’s leading, independent gas and oil producer”, says Hugo Dijkgraaf, Chief Technology Officer and Board Member at Wintershall Dea. THIRD LIFE FOR PLATFORM TOPSIDE Wintershall Noordzee, active for over 50 years as a full cycle operator in exploration, development, production and decommissioning, has for the second time recycled the topsid

28 Mar, 2016 Board of Directors of ONGC have, in its 280th meeting held today, approved the Field Development Plan (FDP) for the development of fields falling under Cluster 2 of the Deep-water NELP Block KG-DWN-98/2 . The development would involve a Capital expenditure of USD 5,076.37 million (equivalent to INR 34,012 Crore 1 USD = INR 67). Cluster 2 of the Block has been divided into two parts (i) Cluster 2A which has estimated In-place reserves of 94.26 MMt of crude oil and 21.75 BCM of Associated Gas (i.e. Solution Gas + Gas Cap Gas); and (ii) Cluster 2B which has estimated In-place reserves of Free Gas of 51.98 BCM. Production is envisaged at a peak oil rate of 77,305 bopd and 3.81 MMSCMD of associated gas through 15 producer wells along with 12 water injection wells with a peak water injection rate of 9,400 m3/d from Cluster 2A oil fields. Peak production rate of free gas is envisaged at 12.75 MMSCMD from 8 wells of Cluster-2B free gas fields. Total oil and gas producti

28 JANUARY 2021 Entrepose Contracting, VINCI Construction Grands Projets and Taylor Woodrow, all VINCI Construction subsidiaries, have been awarded an EPC* contract by National Grid to construct a 190,000 m3 liquefied natural gas (LNG) tank in the United Kingdom. This project is part of the programme to expand the capacity of the largest LNG terminal in Europe, located on the Isle of Grain - east coast of England, 60 km from London. This full containment tank has a 9% nickel steel inner tank with a pre-stressed concrete outer shell, poured in-situ using slipforming. The works, for a budget of €200 million, are set to continue until June 2025. VINCI has already built about 20 LNG tanks worldwide over the past 15 years, including three which are still under construction: two in Russia (160,000 m3 each) and one in Canada (225,000 m3). The Group is recognised for its capacity to meet the expectations of major players in the sector and confirms its leading position in the design-build of l