A Barrel Fulll Archive

21 SEPTEMBER 2023 Equinor has, on behalf of the BM-C-33 consortium, submitted to Agência Nacional de Petróleo, Gás Natural e Biocombustíveis (ANP), the Declarations of Commerciality and Plans of Development for two development areas in the BM-C-33 concession in Brazil’s Campos Basin. Equinor (operator) is partnered with Repsol Sinopec Brasil and Petrobras in the consortium. The concession is located approximately 200 kilometers from Rio de Janeiro, in water depths up to 2900 meters. It contains natural gas and oil/condensate recoverable volumes of above one billion barrels of oil equivalent. The suggested names for the areas are Raia Manta and Raia Pintada . The names and Plans of Development are subject to approval by the regulator. “Raia Manta and Raia Pintada are a strategic fit for Equinor’s ambitions in a country where we have a solid history and an intention to further strengthen our presence. Together with our partners, we will employ additional expertise to ensure safe and effi

October 2, 2018 TransCanada Corporation (TSX:TRP) (NYSE:TRP) (TransCanada) announced today that it will proceed with construction of the Coastal GasLink pipeline project (Coastal GasLink) after a decision to sanction the LNG Canada natural gas liquefaction facility in Kitimat, British Columbia (B.C.) was announced earlier today by the joint venture participants of LNG Canada, a consortium comprised of Shell, PETRONAS, PetroChina, Mitsubishi Corporation and KOGAS (the LNG Canada Participants). “Today’s announcement signifies an important step forward for Coastal GasLink as well as for the province of B.C. and the country,” said Russ Girling, TransCanada’s president and chief executive officer. “The magnitude of the work undertaken over the past six years has been extensive. It demonstrates the commitment of our teams, our partners, B.C. communities and Indigenous groups to work together toward a single goal of fostering an LNG industry off Canada’s West Coast that will help maximize t

December 28, 2018 OMV, the international integrated oil and gas company based in Vienna, closes the acquisition of Shell’s Upstream business in New Zealand comprising joint venture interests in Pohokura (48%), the largest gas producing field in New Zealand, and Maui (83.75%) as well as related infrastructure for production, storage and transportation. OMV has been partner in the acquired assets (OMV’s former stakes: 26% in Pohokura and 10% in Maui) and now assumes operatorship in both joint ventures. The economic effective date of the transaction is January 1, 2018. The purchase price is USD 578 mn and subject to customary adjustments.

November 18, 2019 OMV, the international integrated oil and gas company headquartered in Vienna, has agreed to sell its 69% interest in the Maari Field , located in New Zealand’s offshore Taranaki Basin, to Jadestone Energy Inc., an independent oil and gas company focused on the Asia Pacific region. The agreed purchase price is USD 50 mn, subject to closing adjustments. The effective date of the transaction is January 1, 2019 and the closing of the transaction is subject to Joint Venture and New Zealand Government approvals. Average production of the divested assets in 2018 was around 5 kboe/d (net to OMV). “The divestment of the Maari Field further optimizes our portfolio and will shift us in New Zealand to a gas-only producer. This underlines OMV’s strategy to produce significantly more natural gas than oil to reduce the carbon intensity of the product portfolio in the future”, said Johann Pleininger, OMV Board Member Upstream and Deputy Chairman of the Executive Board. OMV will cont

22nd AUG 2018 Santos announced today the acquisition of 100% of Quadrant Energy for US$2.15 billion plus potential contingent payments. Santos Managing Director and Chief Executive Officer Kevin Gallagher said Santos has enjoyed a long-established relationship with Quadrant which has operated its WA natural gas assets for many years developing a well-deserved reputation as a safe, high reliability and low cost operator. “This acquisition delivers increased ownership and operatorship of a high quality portfolio of low cost, long-life conventional Western Australian natural gas assets which are well known to Santos, and importantly significantly strengthens Santos’ offshore operating capability.” “It is materially value accretive for Santos shareholders and advances Santos’ aim to be Australia’s leading domestic natural gas supplier.” “The transaction lowers our proforma 2018 forecast free cash flow breakeven oil price by a further $4/bbl and Quadrant’s stable cash flows provide increase

09 April 2015 A consortium comprised of private equity funds managed by Brookfield Asset Management Inc. (Brookfield) and of Macquarie Capital, a division of Macquarie Group Limited today announced an agreement to acquire Apache Corporation’s Western Australian oil and gas assets for US$2.1 billion. This acquisition will form the foundations of a new intermediate oil and gas producer established by the Brookfield and Macquarie Capital Consortium. The assets being acquired by the Brookfield and Macquarie Capital Consortium through the transaction include: Apache’s interest in operated gas fields of Reindeer , John Brookes and Halyard-Spar and the non-operated interest in the BHP Billiton operated Macedon field ; Apache’s interest in operated oil fields at Coniston-Novara, Van Gogh and Stag and the non-operated interest in the BHP Billiton operated Pyrenees area ; interests in gas processing facilities and associated infrastructure at Devil Creek, Varanus Island and Macedon; and all o

6th September 2016 In collaboration, Wood Group and Technip Oceania formed the Gorgon Upstream Joint Venture (GUJV) in 2005 to deliver front end engineering and design (FEED) services, and transitioned with the project to provide detailed engineering, procurement and construction management (EPCM) services for Gorgon’s Upstream Facilities. The Upstream Facilities encompass infrastructure to connect the deepwater Jansz-Io and Gorgon fields to the LNG plant located on Barrow Island, a Class A reserve. This included more than 800km of onshore and offshore steel pipe and one of the largest subsea installations in the world, with the subsea structures and pipe weighing around 230,000 tonnes. Throughout the project, GUJV has provided a Perth based multidisciplinary team to cover the wide variety of engineering and support services required to engineer and execute a word class project of this scale. At its peak the joint venture supplied over 300 people, with a focus and strong commitment

March 12, 2019 Aker Solutions has been awarded a master contract to support the delivery of a subsea compression system for the Chevron Australia-operated Jansz-Io field offshore Australia. The first service order under the master contract will be for front-end engineering and design of a subsea compression station that will boost the recovery of gas from the field. The FEED scope will also cover an unmanned power and control floater, as well as overall field system engineering services. The field control station will distribute onshore power to the subsea compression station. The gas compression system will boost recovery of gas more cost-effectively and with a smaller environmental footprint than a conventional semi-submersible compressor solution. Aker Solutions in 2015 delivered the world's first subsea compression system for Equinor's Åsgard field offshore Norway. "Aker Solutions has worked closely with its partners MAN Energy Solutions and ABB to reduce the size an

July 6, 2021 Aker Solutions has been awarded a major contract from Chevron Australia Pty Ltd to provide a subsea gas compression system for the Jansz-Io field , offshore Western Australia. The company has booked around NOK 7 billion as order intake in the second quarter of 2021 related to this contract. "Globally, this is the second subsea gas compression system delivered by Aker Solutions and demonstrates our pioneering spirit to create value for our customers. Our world-leading technology improves field recoverability while offering carbon emission efficiencies compared to traditional compression alternatives," said Kjetel Digre, chief executive officer of Aker Solutions. The scope covers engineering, procurement and construction (EPC) of the all-electric subsea gas compression system. It also includes interface responsibility, and assistance during installation and commissioning. The subsea gas compression system will include a complete compression station with three compr

July 2, 2021 Chevron Corporation (NYSE: CVX) today announced that its wholly owned subsidiary Chevron Australia Pty Ltd. (Chevron Australia) as operator and the Gorgon joint venture participants will proceed with the approximately $4 billion (AU$6 billion) Jansz-Io Compression (J-IC) project. Nigel Hearne, Chevron Eurasia Pacific Exploration and Production president, said J-IC represents Chevron’s most significant capital investment in Australia since the sanctioning of the Gorgon Stage 2 project in 2018. “Using world-leading subsea compression technology, J-IC is positioned to maintain gas supply from the Jansz-Io field to the three existing LNG trains and domestic gas plant on Barrow Island,” Hearne said. “This will maintain an important source of clean-burning natural gas to customers that will enable energy transitions in countries across the Asia Pacific region.” A modification of the existing Gorgon development, J-IC will involve the construction and installation of a 27,000-ton

Sept. 08, 2021  Cenovus Energy Inc. (TSX: CVE) (NYSE: CVE) has entered into agreements with its partners in the Atlantic region to restructure its working interests in the Terra Nova and White Rose projects, providing improved economics for the company’s regional portfolio. These agreements will increase Cenovus’s working interest in Terra Nova and, if a decision is taken to restart West White Rose, reduce the company’s working interest in the White Rose field. Cenovus’s working interest in Terra Nova will be 34%, up from 13%. The company will receive $78 million from the exiting partners as a contribution towards future Terra Nova asset retirement obligations. The Terra Nova asset life extension project will proceed, extending the life of the field to 2033. Production is expected to resume before the end of 2022, with gross production expected to reach approximately 29,000 barrels per day in 2023. Including funding from the Government of Newfoundland and Labrador, the net to Cenovus

13th September 2021 McDermott's Amazon vessel, following a sophisticated upgrade to its ultra-deepwater capabilities, is coming to the Gulf of Mexico to support a subsea contract for the Whale Development in Alaminos Canyon "This contract, which will take place in a water depth of more than 9,000 feet, is a massive opportunity to demonstrate how the Amazon, with its industry-leading pipelay capabilities, is redefining what is possible within ultra-deepwater construction," said Samik Mukherjee, Executive Vice President and Chief Operating Officer. "We are also looking forward to bringing the Amazon into the Gulf of Mexico—especially as we use this opportunity to continue our long track record of successful project execution." Under the contract's scope, McDermott will provide engineering, procurement, construction, installation and commissioning (EPCIC) for 30 miles (50 kilometers) of pipeline and approximately nine miles (15 kilometers) of umbilical to conn

25 Jul 2021 Shell Offshore Inc., a subsidiary of Royal Dutch Shell plc, today announces the final investment decision (FID) for Whale, a deep-water development in the U.S. Gulf of Mexico that features a 99% replicated hull and an 80% replication of the topsides from our Vito project. “Whale is the latest demonstration of our focus on simplification, replication and capital projects with shorter cycle times to drive greater value from our advantaged positions,” said Wael Sawan, Shell Upstream Director. “We are building on more than 40 years of deep-water expertise to deliver competitive projects that yield high-margin barrels so that we are able to meet the energy demands of today while generating the cash required to help fund the development of the energy of the future.” Whale will be the second Shell-operated deep-water development in the Gulf of Mexico to employ a simplified, cost-efficient host design. With this development approach, Shell anticipates an internal rate of return es

  August 4, 2021 TULSA, Okla.--(BUSINESS WIRE)--  Williams (NYSE: WMB) announced today that it has reached an agreement with Shell Offshore Inc. and Chevron U.S.A. Inc. to provide offshore natural gas gathering and crude oil transportation services as well as onshore natural gas processing services for the Whale development located approximately 10 miles from the Shell-operated Perdido host facility. Williams plans to expand its existing Gulf of Mexico offshore infrastructure via a 25-mile gas lateral pipeline build from the Whale platform to the existing Perdido gas pipeline and a new 125-mile oil pipeline to the existing Williams-owned GA-A244 junction platform. The natural gas will be transported to Williams’ Markham gas processing plant located in Matagorda, TX. First production is expected to come online in 2024. “Our asset synergies in the Gulf of Mexico are second to none, and we are pleased to strengthen our existing onshore and offshore infrastructure to further serve the grow

16 Feb 2023 Shell Offshore Inc., a subsidiary of Shell plc (Shell), announced that production has started at the Shell-operated Vito floating production facility in the US Gulf of Mexico (GoM). With an estimated peak production of 100,000 barrels of oil equivalent per day, Vito is the company’s first deep-water platform in the GoM to employ a simplified, cost-efficient host design. “Vito is an excellent example of how we are approaching our projects to meet the energy demands of today and tomorrow, while remaining resilient as we work toward achieving net zero emissions by 2050,” said Zoe Yujnovich, Shell’s Upstream Director, adding, “Building on more than 40 years of deep-water expertise, projects like Vito enable us to generate greater value from the GoM, where our production has amongst the lowest greenhouse gas intensity in the world for producing oil.” The Vito development is owned by Shell Offshore Inc. (63.11% operator) and Equinor (36.89%). In 2015, the original host design wa

31st JANUARY 2018 Origin Energy Limited (Origin) today announced completion of the $1,585 million sale of its conventional upstream oil and gas business, Lattice Energy, to Beach Energy with an economic effective date of 1 July 2017. After adjusting for settlement of the acquisition by Lattice Energy of Benaris’ interests in the Otway basin ($190 million)1, transaction costs, adjustments and taxes, the balance of the sale proceeds will be used to close out of oil forward sale agreements ($266 million) and pay down debt (approximately $1 billion). As a result of this transaction Origin expects to record accounting charges of approximately $220 – $240 million, primarily comprising a non-cash post-tax impairment charge of $170 – $180 million as a result of recognising Lattice Energy earnings from 1 July 2017 up to the 31 January 2018 completion date. The aggregate charge is subject to finalisation of the company’s half year financial statements to be released on 15 February 2018. 1 $190 m

 13 January 2022 Beach Energy is pleased to announce the first two wells of its offshore Otway Basin campaign - Geographe 4 and 5 - have been connected to the Otway Gas Plant and are now delivering gas into the East Coast market following the completion of the commissioning phase.  The new wells effectively double the Otway Gas Plant production capacity which now has the well capacity to deliver ~180 TJ/d. Actual production rates will depend on customer nominations which vary on a seasonal and daily basis.  Connecting the remainder of the wells from the offshore campaign and connecting the nearshore Enterprise discovery is required to attain plant nameplate production capacity of 205 TJ/d.   Beach Energy Acting CEO, Morné Engelbrecht said the connection of the Geographe wells is an important step towards delivering on Beach’s growth targets at a time when the East Coast Gas market is potentially facing shortfalls as early as 2023.  “Achieving first gas from these Geographe wells

Wednesday, 12 December 2018 Western Gas (100% owner and Operator) of the Equus Gas Project has signed a Memorandum of Understanding (MOU) with world-leading oil and gas service and technology providers McDermott International, Inc. and Baker Hughes, a GE company (BHGE), for the exclusive provision of project development services from pre-FEED and FEED studies through the engineering, procurement, construction, installation and commissioning (EPCIC) phases of the project. The agreement is for the provision of drilling, subsea, offshore processing, nearshore LNG production and a gas pipeline to shore for domestic gas supply. McDermott and BHGE were also awarded a contract to support the planning phases of the project and pre-FEED studies will commence immediately.  Andrew Leibovitch, Executive Director, said that the integrated design-to-install contracting approach was an Australian first for a project of this size and scale and would help deliver an efficient development plan, enhance

 Thursday, 10 May 2018 Western Gas, owner and Operator of the Equus Gas Project , has completed the Basis of Design for development of the project, and issued a request for proposals to secure a world-class project development partner.  Project development services being sought by Western Gas embrace full field development, including drilling, subsea, offshore processing and a gas pipeline to shore.  Andrew Leibovitch, Executive Director, said that Western Gas has built on the extensive development studies it acquired when it purchased the project and prepared a fit-for-purpose Basis of Design, with first gas planned from 2023.  “It was clear from the start that a new approach would be needed to develop this significant resource in a timely way,” Mr Leibovitch said.  “We have resized the project to match the discovered gas resource and to meet gas customers’ needs for long-term secure contracts and innovative pricing. We’re now moving fo

Dec. 22, 2017 Hess Corporation (NYSE: HES) announced today that it has completed the previously announced sale of its subsidiary Hess Norge, which owns interests in the Valhall and Hod fields in Norway, to Aker BP ASA for total proceeds of $2 billion, effective January 1, 2017. “We are high grading our portfolio by investing in our highest return assets and divesting mature, higher cost assets,” CEO John Hess said. “This strategy is enabling us to prefund our world-class opportunity in Guyana, return capital to shareholders and reduce debt, while at the same time significantly lowering our cash unit costs and bolstering our company’s balance sheet.” Hess Corporation is a leading global independent energy company engaged in the exploration and production of crude oil and natural gas.

15, Aug 23 Repsol Sinopec has awarded a multi-million-pound decommissioning contract to Archer to execute the plug and abandonment (P&A) of 32 wells in the Fulmar Field and two wells in the Halley Field . The contract is a fully integrated P&A project, including removal of the existing drilling facility and installation of a modular rig. The scope of work will be delivered using cutting-edge technology, multiskilled crews and industry- leading digital solutions. Planning and engineering work will commence immediately. The project will be an integrated effort between the Repsol Sinopec and Fulmar Site teams, who have the history and knowledge of the work site, with decommissioning specialist contractor Archer, who will ensure the work is enacted safely and effectively. Adam Sheikh, Repsol Sinopec’s VP of Decommissioning and Energy Transition, said: “We aim to deliver one of the North Sea’s most ambitious decommissioning programmes in the years ahead – including the full decommi

28 Aug 2023 Sarawak Shell Berhad (SSB), a subsidiary of Shell plc, has announced that gas production has started at its Timi platform in Malaysia under the SK318 production sharing contract (PSC) . Timi features Shell’s first wellhead platform in Malaysia that is powered by a solar and wind hybrid power system. This unmanned platform is also more cost efficient, as a result of it being around 60% lighter in weight, than a conventional tender-assisted drilling wellhead platform that relies on oil and gas for power. “Timi demonstrates we are delivering more value with less emissions,” said Zoe Yujnovich, Shell’s Integrated Gas and Upstream Director. “Bringing the project online is also an example of our focus on performance, discipline, and simplification. It shows our ability to innovate and deliver safe, reliable, and sustainable projects that support a balanced energy transition for Malaysia.” Timi is designed to produce up to 50,000 barrels of oil equivalent per day of gas at peak pr

13th Sep 17 Flotta Terminal marked 40 years of service to the North Sea when a special ceremony was held at the island site in August 2017. Officially inaugurated in 1977, the Terminal is still processing on average 100,000 barrels per day, more than 40 years later. Flotta remains a crucially important North Sea facility and a national resource, with an outstanding operational, environmental, and health and safety record. It has received multiple safety awards and has seen no fatalities or major accidents, and no regulatory reportable hydrocarbon releases in the history of the terminal. Guests at the ceremony included Orkney and Shetland MP Alistair Carmichael, Orkney MSP Liam McArthur, and Lord Lieutenant of Orkney Captain Bill Spence. Councillors and officials from Orkney Islands Council, including Convener Harvey Johnston, and representatives from the local charities the terminal has supported over many years were also present, as well as members of the Flotta community. Repsol Sin

07/04/2019 Paris - Total and its partners have approved the launch of Phase 3 development of the onshore Dunga field in the Mangystau Region of western Kazakhstan. Phase 3 of the Total-operated field will consist of adding wells to the existing infrastructure and upgrading the processing plant to increase its capacity by 10% to 20,000 barrels of oil per day by 2022. This will add production of more than 70 million barrels of reserves. The development has been made possible thanks to the approval by the Government of the Republic of Kazakhstan of a 15-year extension of the Production Sharing Agreement (PSA) for the field, originally signed in 1994 and due to expire in 2024. The project requires a $300 million investment and will create 400 more direct jobs in the region at the peak of construction activity. “This low-investment-cost-per-barrel development maximizes the field’s potential and extends plateau production,” said Arnaud Breuillac, President, Exploration & Production at

December 1, 2022 TotalEnergies implements its energy transition strategy in Kazakhstan with, on the one hand, the sale of its affiliate Total E&P Dunga GmbH and, on the other the giant Mirny wind farm project that received the support of the French and Kazakh authorities on the occasion of the visit in France of the President of Kazakhstan, Kassym Jomart Tokayev. On November 28, 2022, TotalEnergies signed an agreement for the sale of its affiliate Total E&P Dunga GmbH to the Kazakh company, Oriental Sunrise Corp Ltd, for an amount of $330 million. Total E&P Dunga GmbH holds a 60% operating interest in the onshore Dunga oil field in Kazakhstan, representing a net production of approximately 7,400 barrels of oil equivalent per day in 2022. The transaction is subject to the approval of the authorities of Kazakhstan and the waiver of the partners’ preemption rights. TotalEnergies also strengthens its presence in renewable energy in the country. In addition to its two solar pow

03/07/2017 The Statoil-operated field Gina Krog in the North Sea started producing 30 June. The recoverable reserves in Gina Krog total 16.8 million standard cubic metres (Sm3) of oil, 11.8 billion Sm3 of gas and 3.2 million tonnes of NGL. “Gina Krog is an important contribution towards maintaining a high level of profitable production from the shelf,” says Tove Francke, the Norwegian Petroleum Directorate’s Assistant Director for the Southern North Sea. She also praises the licensees, headed by the operator, for a well-executed project that delivered on schedule and on budget. The field was developed with a production facility resting on the seabed and an oil storage ship at a water depth of 110-120 metres. The oil is exported via buoy loaders, and the gas is sent to the Sleipner A platform for final processing. Gas for injection is imported from Zeepipe 2A (Gassled). This means that three out of four fields on or near the Utsira High are producing. Edvard Grieg started in November 20

15 SEPTEMBER 2023 On behalf of the partnership, Equinor has submitted a plan for development and operation (PDO) of the Eirin gas field to the Ministry of Petroleum and Energy. Recoverable reserves in the field are estimated at 27.6 million barrels of oil equivalent, most of which is gas. The Eirin field, which was discovered in 1978, will be developed as a subsea facility tied to the Gina Krog platform in the North Sea. Total investments are estimated at just over NOK 4 billion (2023 NOK). “Utilising Gina Krog’s infrastructure will enable Eirin to bring new gas to Europe fast, with good profitability and low CO2 emissions from production. The development will extend Gina Krog’s productive life from 2029 to 2036, and will be vital for the Sleipner area,” says Camilla Salthe, Equinor’s senior vice president for field life extension (FLX). When the energy crisis struck in 2021, there was close cooperation with Norwegian authorities to deliver as much gas as possible to Europe. Increased

07/04/2019 Total and its partners have approved the launch of Phase 3 development of the onshore Dunga field in the Mangystau Region of western Kazakhstan. Phase 3 of the Total-operated field will consist of adding wells to the existing infrastructure and upgrading the processing plant to increase its capacity by 10% to 20,000 barrels of oil per day by 2022. This will add production of more than 70 million barrels of reserves. The development has been made possible thanks to the approval by the Government of the Republic of Kazakhstan of a 15-year extension of the Production Sharing Agreement (PSA) for the field, originally signed in 1994 and due to expire in 2024. The project requires a $300 million investment and will create 400 more direct jobs in the region at the peak of construction activity. “This low-investment-cost-per-barrel development maximizes the field’s potential and extends plateau production,” said Arnaud Breuillac, President, Exploration & Production at Total. “

11 April 2022 Roc Oil Company Pty Limited (ROC) is pleased to announce that, following the successful installation, hook-up and commissioning of facilities for the WZ12-8 East Project, first production has been achieved from the first development well WZ12-8E-A2H. Construction and drilling activities to date have been undertaken safely within budget and on schedule. The remaining 5 production wells of the initial phase of development will be drilled over the next 3 to 4 months.  The development is part of the  Weizhou 6-12 and 12-8 Oil Fields area. The Project is expected to reach an average daily gross production rate of ~4,700 barrels of oil during 2022, with peak production expected to be ~10,000 barrels per day.  ROC is the current operator of the WZ12-8E development project with CNOOC to assume operatorship by the end of 2022. The participants in the license are:  CNOOC Limited (Operator) 51.00%  Horizon Oil (Beibu) Ltd 26.95%  Roc Oil (China) Company 19.60%  Oil Australia Pty Lt

September 23, 2021 CNOOC Limited (the “Company”, SEHK: 00883, NYSE: CEO, TSX: CNU) announced today that Qinhuangdao/ Caofeidian onshore power project has commenced operation successfully. This onshore power project is located in the mid-western Bohai Bay, containing two parts, firstly the Qinhuangdao 32-6 and Caofeidian 11-1 oilfields onshore power project, and secondly the Qinhuangdao 32-6 facility capacity expansion project. The Qinhuangdao 32-6 oilfields are approximately 20 kilometres from the coast, with an average water depth of 19 meters. The Caofeidian 11-1 oilfields are approximately 30 kilometres from the coast, with an average water depth of 25 meters. The onshore power project has built with two onshore high voltage switching stations and two offshore electric power platforms, with a designed power transmission capacity of 200MW. It is positioned to provide electric power to Qinhuangdao 32-6 oilfields, Caofeidian 11-1 oilfields, and Caofeidian 6-4 oilfields. The Qinhuang

1st January 2019 CNOOC Limited (the "Company", SEHK: 16, NYSE: CEO, TSX: CNU) today announced that the Huizhou 32-5 Oilfield Comprehensive Adjustment/Huizhou 5-33 Oilfield Joint Development Project has commenced production. The Huizhou 32-5 Oilfield Comprehensive Adjustment/Huizhou 33-1 Oilfield Joint Development Project is located in the south-central part of the eastern part of the South China Sea, about 170 kilometers away from Hong Kong, and the water depth in the sea area is about 115 meters. The project will build a new drilling and production platform and rely on the existing facilities of Huizhou 25-8 oilfield for development. There is currently one well in production, and it is expected to achieve peak production of 1,2020 barrels of crude oil per day in 19. CNOOC Limited has a 32% interest in the Huizhou 5-33 Oilfield Comprehensive Adjustment/Huizhou 1-100 Oilfield Joint Development Project and acts as the operator.

2018-04-29 Huizhou 32-5 Jacket and Piles Fabrication Project Completed CSE completed fabricating jackets and piles in only 8 months, which successfully left the port on April 28, 2018. The weights of jackets and piles were 6,971 tons and 4,897 tons respectively.

May 26, 2009  ConocoPhillips China Inc (COPC), a subsidiary of ConocoPhillips [NYSE: COP] announced first production from Hai Yang Shi You 117 -China's largest Floating, Production, Storage and Offloading (FPSO) vessel at the Penglai 19-3 Oilfield which is under joint development by COPC and CNOOC Ltd.  "This is a significant milestone for both ConocoPhillips and our co-venturer, CNOOC Ltd., towards the full production from this large oil field," said Georg Storaker, president of ConocoPhillips China. "This achievement demonstrates cooperation between CNOOC Ltd. and ConocoPhillips in developing energy resources offshore China."  Also called Bo Hai Peng Bo, the FPSO is among the largest of such vessels built anywhere in the world with its hull's dimension of 323m x 63m x 32.5m. The FPSO's design processing capacity is 190,000 barrels oil per day (BOPD) and design storage capacity is two million barrels (MM BBL).  Located in Block 11-05 in China's Bo

5th May 2020 CNOOC Limited (the "Company", SEHK: 22, NYSE: CEO, TSX: CNU) today announced that the Penglai 19-3 Adjustment/Penglai 4-19 Phase II Development Project has commenced production. Penglai 19-3/19-9 oilfield is located in the Bohai Sea, with an average water depth of about 28 meters. The project will build a new wellhead platform and plan to put into operation 47 wells, including 30 production wells, 16 water injection wells, and 1 development and evaluation well. The new wellhead platform will utilize the processing capacity of the existing facilities in the Penglai 19-3 oilfield. The project is expected to achieve peak crude oil production of approximately 2022,15 barrels per day in 681. CNOOC Limited has a 19% interest in the Penglai 3-4 Oilfield Area 19 Adjustment/Penglai 9-51 Oilfield Phase II Development Project and acts as the operator. Partner ConocoPhillips China owns the remaining 49% interest.

8th August 2017 CNOOC Limited (the "Company", SEHK: 8, NYSE: CEO, TSX: CNU) today announced that the Hangingstone Project in Canada has commenced production. Located in Alberta, Canada, the project consists of a steam generator, well site equipment, 32 well pairs, and water treatment and asphalt pipelines. The project is expected to reach peak production of 2018,2 barrels of bitumen per day in <>. The Company's wholly-owned subsidiary, Nexen Energy ULC, has a 25% interest in the Hangingstone Project, and Japan Canada Oil Sands Limited (JACOS) has a 75% interest in the Project and acts as the operator.

December 2017, 12 CNOOC Limited (the "Company", SEHK: 8, NYSE: CEO, TSX: CNU) announced that it has recently acquired a new discovery of Bozhong 00883-19 in a medium-sized natural gas field in the Bohai Sea. The Bozhong 19-6 trap is located in the southwest of the Bozhong Sag in the south-central part of the Bohai Sea, with an average water depth of about 22 meters. Bozhong 19-6-1 discovered that the well encountered a total of about 25 meters of oil layer and 348 meters of gas layer, and completed drilling to a depth of 4,180 meters. Evaluated wells have tested an average of about 1000,6 barrels of oil per day and about 4.<> million cubic feet of gas per day. Mr. Xie Yuhong, Executive Vice President and General Manager of the Exploration Department of the Company, said, "The new discovery of the Bozhong 19-6 natural gas field reveals the huge exploration prospects of the buried hill natural gas field in the Bohai Bay area, and lays a solid foundation for the suppl

August 9, 2023 Saipem has been awarded a new contract by Mellitah Oil & Gas B.V. Libyan Branch, a consortium formed by National Oil Corporation of Libya and Eni North Africa, for the development of the Bouri Gas Utilisation Project (BGUP) , worth approximately 1 billion USD. Saipem will undertake revamping of the platforms and of the facilities of the Bouri gas field, which lies in water depths between 145 m and 183 m, offshore the Libyan coast. The contract entails the engineering, procurement, construction, installation and commissioning (EPCIC) of an approximately 5,000-ton Gas Recovery Module (GRM), onto the existing DP4 offshore facility, together with the laying of 28 km of pipelines connecting the DP3, DP4 and Sabratha platforms. The main lifting operations will be executed by the semi-submersible crane vessel Saipem 7000. With this award, Saipem confirms its commitment and competitive positioning offshore Libya. The completion of the project will make an important contribut

November 14th, 2019 Saipem has been awarded a subsea contract by ExxonMobil subsidiary Esso Exploration and Production Guyana Limited (“EEPGL”) for the proposed Payara development project located in the Stabroek block offshore Guyana at a water depth of around 2000 metres. The contract scope includes Subsea Structures, Risers and Flowlines. Saipem was awarded earlier subsea contracts for the first two phases of the Liza development in Guyana by EEPGL in 2017 and in 2018, respectively. Subject to government approvals, project sanction by EEPGL and its partners HESS Guyana Exploration Ltd and CNOOC Nexen Petroleum Guyana Ltd and an authorization to proceed with the final phase, Saipem will perform the detailed Engineering, Procurement, Construction and Installation (EPCI) of a large subsea production facility. This facility will include approximately 130 km of flowlines, rigid risers, associated terminations and jumpers together with the installation of manifolds, flexible risers, dynam

October 01, 2020 TechnipFMC  has been awarded a large contract by Exxon Mobil Corporation (NYSE:XOM) subsidiary Esso Exploration and Production Guyana Limited for the subsea system for the proposed Payara project . TechnipFMC will manufacture and deliver the subsea production system, including 41 enhanced vertical deep water trees and associated tooling, six flexible risers and ten manifolds along with associated controls and tie-in equipment. Arnaud Pieton, President Subsea stated: “We are delighted to take the next step in the partnership established with ExxonMobil and the country of Guyana for their subsea developments. As a continuation from Liza phase 1 and 2, this award is a tribute to the value created through this partnership and will also lead to growing further TechnipFMC’s local presence in Guyana. We continue to develop and deliver the most advanced proven subsea technologies enabling these developments with the schedule certainty required for the Payara Project first oil

14 Nov 2017 Following SBM Offshore’s completion of the Front End Engineering and Design (FEED) and a final investment decision on the Liza Phase 1 Development project by ExxonMobil in June 2017, SBM is delighted to announce the next step in its scope for the floating production, storage and offloading vessel (FPSO). The arrival of the tanker, ultimately destined for the Liza Phase 1 project in Guyana, marks the start of the FPSO conversion phase. To meet the project’s requirements, the conversion includes upgrade work on the hull and integration of topsides, which is being undertaken in Singapore at Keppel’s shipyard. “With the arrival of the tanker we now begin in earnest the construction phase of the journey that SBM Offshore is on. We will leverage our in-depth experience with over 34 FPSO projects to date. Our objective is to safely deliver the Liza FPSO in partnership with our client and the experienced team at Keppel by working together as one team. SBM is proud to play its part

22 Jul 2019 The Liza Destiny FPSO is currently sailing to Guyana, having recently departed from Keppel shipyard in Singapore. This key milestone follows a record turnaround time of just over 20 months for its construction phase by SBM Offshore – including module construction at nearby Dyna-Mac yard. “The safe and on-time departure of Liza Destiny represents a great achievement for the project team. This first vessel constructed for Guyana has benefitted from the team’s vast experience and expertise for the execution of such large capacity FPSOs, as well as the added value of our sub-contractors. We wish her and her crew a safe voyage,” says Severine Baudic, Managing Director Floating Production Solutions. Following the successful EPC phase, the project team handed over to SBM Offshore’s Operations team. “We are happy to welcome Liza Destiny FPSO into SBM Offshore’s fleet. We know her well, having been involved from the initial phases of her design and construction, ensuring that the F

Dec 23 2019 SBM Offshore is pleased to announce that FPSO Liza Destiny has produced first oil as of December 20, 2019 and is formally on hire. The FPSO is installed at the Liza field , which is located circa 200 kilometers offshore Guyana in the Stabroek block. ExxonMobil affiliate Esso Exploration and Production Guyana Limited is operator and holds 45 percent interest in the Stabroek Block. Hess Guyana Exploration Ltd. holds 30 percent interest and CNOOC Petroleum Guyana Limited, a wholly-owned subsidiary of CNOOC Limited, holds 25 percent interest. Bruno Chabas, CEO of SBM Offshore, commented: “We are proud of FPSO Liza Destiny reaching first oil for our client and the people of Guyana. The vessel is producing the first oil in Guyana’s history. Our teams have done an excellent job by completing the project well in line with our client’s schedule. The delivery time from the engineering study phase until first oil, three years, is impressive and a clear testimony of our capabilities a

27 Sep 2019 SBM Offshore kicked off its scope for the construction phase of Liza Unity following FID* by ExxonMobil in May 2019. She will be the second FPSO for our client’s Liza project in Guyana. The Liza Unity FPSO design is based on the industry leading Fast4Ward® program with a new build, multi-purpose hull combined with several standardized topsides modules. Leveraging SBM Offshore’s Fast4Ward program with the experience gained on Liza Destiny has allowed the FPSO project teams to fast-track the Liza Unity. The SBM Offshore teams working on Liza Unity have been able to leverage the valuable experience built up on the Liza Destiny project, as many of the team members were transferred from the Destiny to the Unity project. This experience, in combination with a close working relationship with our client, sub-contractors and suppliers and a firm commitment to safety and quality has played a key role in the success of the project to date across all phases from engineering, procureme