Equinor starts production from Kristin South

 Equinor and its partners Petoro, Vår Energi, and TotalEnergies EP Norge started production from the first Lavrans well in the Kristin South area on 7 July.

The partnership submitted the plan for development and operation (PDO) of the Lavrans and Kristin Q discoveries as satellites to the Kristin field in 2021. This is the first phase of the Kristin South project. The PDO was approved by the authorities in 2022.

“The Kristin South project demonstrates our strategy to create value by developing existing infrastructure on the Norwegian Continental Shelf. Together with our partners and suppliers, we have developed the project and started the production from Lavrans in a safe and good way,” says Trond Bokn, senior vice president for project development in Equinor.

A new subsea template has been installed and tied into the Kristin platform, now processing oil and gas from the first well at the Lavrans field. The gas will be exported through the pipeline system to the European market, while the oil will be transported to the market by ship via the Åsgard C storage vessel.

Four additional wells are planned as part of the first phase of the Kristin South project, three at the Lavrans field and one in the Q-segment at the Kristin field. The latter will be drilled from an existing subsea template that has been tied back to the Kristin SEMI.

The expected production in phase one of the Kristin South project is in the PDO estimated at 6.2 GSm3 of gas and 1.9 MSm3 of oil (a total of 58.2 million barrels of oil equivalent).

“This is a key milestone in our plan to continue to develop new resources in a mature area in the Norwegian Sea. Tying in additional resources to our producing hubs is a cost-efficient way to add production and extend the lifespan of our fields in operation. This approach contributes to energy security and job creation in Norway,” says Grete B. Haaland, senior vice president for Exploration & Production North.

The CO2 intensity for extraction and production of Kristin South phase 1 is very low - less than 1 kg of CO2 per barrel of oil equivalent. The emissions will mainly be generated from the project’s drilling activities.

Norwegian suppliers have been awarded over 60% of the contract values in the development phase creating ripple effects along the coast. The project is estimated to have created 4,000 person-years across Norway, with 800 in the Mid-Norway region, over the 2020-2025 period.

Lavrans was discovered in 1995, while the Kristin field was put on stream in 2005. The technical lifetime of the Kristin platform is currently estimated to be 2043 with potential for further extensions.

Partners (Haltenbanken Vest Unit): Equinor Energy AS (54.82 %, operator), Petoro AS (22.52 %), Vår Energi ASA (16.66 %), TotalEnergies EP Norge AS (6 %).
Contracts:

• Aker Solutions/OneSubsea and subcontractors: Subsea production facilities
• TechnipFMC and subcontractors: Pipeline fabrication, pipelaying, and subsea installation
• Aibel and subcontractors: Engineering, procurement, construction, and installation for Kristin platform modification
• Transocean Spitsbergen: Rig contractor

Shell boosts LNG business with Manatee FID in Trinidad and Tobago

Shell Trinidad and Tobago Ltd. (Shell), a subsidiary of Shell plc, today announced that it has taken Final Investment Decision (FID) on the Manatee project, an undeveloped gas field in the East Coast Marine Area (ECMA) in Trinidad and Tobago.

Manatee will allow Shell to competitively grow its Integrated Gas business by building on development efforts in the ECMA, one of the country’s most prolific gas-producing areas. The ECMA is currently home to Shell’s largest gas-producing fields in the country including Dolphin, Starfish, Bounty and Endeavour.

The Manatee gas field will provide backfill for the country’s Atlantic LNG facility. Increasing utilization at existing LNG plants is an important lever to maximize potential from Shell’s existing assets.

“This project will help meet the increasing demand for natural gas globally while also addressing the energy needs of our customers domestically in Trinidad and Tobago,” said Zoë Yujnovich, Shell’s Integrated Gas and Upstream Director. “The investment bolsters our world-leading LNG portfolio in line with our commitment to invest in competitive projects that deliver more value with less emissions,” she added.

Shell plans to grow its LNG business by 20-30% by 2030, compared with 2022, and LNG liquefaction volumes are planned to grow by 25-30%, relative to 2022, as outlined at Shell’s Capital Markets Day in 2023.

Manatee is slated to start production in 2027. Once online, Manatee is expected to reach peak production of approximately 104,000 barrels of oil equivalent per day (boe/d) (604 MMscf/d).

Notes to editors

• Shell is the operator of Manatee with a 100% working interest under the sub-Block 6D Production Sharing Contract.
• The Loran-Manatee field was discovered in 1983 and subsequently appraised via four wells. Loran represents the portion of the field in Venezuelan waters and Manatee represents the portion of the field in Trinidad and Tobago waters.
• In 2007 the Government of Trinidad and Tobago (GORTT) and the Government of Venezuela (GOVEN) signed a Framework Treaty covering all cross-border fields and in 2010 signed a Unitization Agreement specifically covering Loran-Manatee.
• In 2019, GORTT and GOVEN terminated the Unitization Agreement and entered into another government-to-government agreement, allowing each country to independently develop its respective share of the Loran-Manatee field.
• The project will involve a Normally Unattended Installation platform located in the ECMA acreage with eight development wells via a 110 km 32” pipeline to the Shell-operated onshore Beachfield gas processing facility, for onward export to the Atlantic LNG facility, and to the National Gas Company of Trinidad and Tobago for the domestic gas market.
• Shell believes LNG will play a critical role in the energy transition, replacing coal in heavy industry. It also has a continued role in displacing coal in power generation, helping to reduce local air pollution and carbon emissions. LNG helps to provide the flexibility the power system needs, at a time when renewable generation is growing rapidly. Find out more in Shell’s Energy Transition Strategy 2024.
• Global demand for LNG is estimated to rise by more than 50% by 2040, as industrial coal-to-gas switching gathers pace in China, South Asian and South-east Asian countries. These countries are expected to use more LNG to support their economic growth, according to Shell’s LNG Outlook 2024.

Wood awarded concept study for Greater Sunrise Development

Wood, a global leader in consulting and engineering,has been selected as the lead specialist consultant for an independent study for the Sunrise Joint Venture’s (SJV) Greater Sunrise Development.

Wood will deliver a comprehensive concept study for the Greater Sunrise Development, considering engineering, technology, financing, commercial structures, fiscal, environmental, health & safety and socioeconomic drivers including local content. The study, on target for completion by no later than Q4 2024, will support the SJV to advance the development to the next stage.

Azad Hessamodini, President of Consulting at Wood, said: “This is an important concept study for the Greater Sunrise Development. We are delighted to support and deliver the work at pace to ensure the SJV has the impartial insights to advance this regionally significant project.”

SJV comprises TIMOR GAP (56.56%), Woodside Energy (33.44% and Operator) and Osaka Gas (10.00%). The development project is located between Timor-Leste and Australia’s Northern Territory and comprises the Sunrise and Troubadour gas and condensate fields.

Wood has completed over 100 LNG feasibility studies globally, providing technical consulting and advisory services at the earliest stages to support clients in making informed and independent decisions.

Wood teams up with Rosetti Marino to deliver FEED for North Sea platform

Wood has been selected by EPCI contractor Rosetti Marino to deliver a front-end engineering design (FEED) study for the INEOS Hejre development project in the Danish sector of the North Sea.

Wood has a proud heritage in offshore design, delivery and operations, having engineered over one million tons of topsides facilities globally including support for the majority of facilities in the North Sea. Building on that track record, Wood will deliver the engineering design for the facility as well as support Rosetti Marino to develop the execute phase tender for the project, providing a clear roadmap to project completion.

"Often the greatest success factor for new offshore projects comes down to the quality of execution, which is why we emphasise the importance of coupling innovative solutions with predictable delivery at Wood,” said Simon Harris, Senior Vice President of Oil & Gas and New Energies Europe at Wood.

“Combining Wood’s proven track-record in offshore engineering with Rosetti Marino’s topside EPCI expertise will deliver a fabrication and construction-ready design during the initial stages of the project, ensuring there are no surprises in later phases."

Together Wood and Rosetti Marino will provide INEOS with a cost effective and executable design to help the Hejre Development Project deliver planned first oil in 2027.

Hejre will provide critical energy supply to Europe upon completion. The project includes a greenfield topside installation and brownfield modifications and tie ins to the existing wellhead and processing platforms.

The Prax Group Signs An Agreement To Acquire TotalEnergies’ Upstream Assets In The West Of Shetland

The Prax Group announces the signing of an agreement to acquire TotalEnergies’ interests in the Greater Laggan Area fields and the onshore Shetland Gas Plant, as well as its interests in several nearby exploration licenses. The transaction is subject to approval from the relevant authorities.

The Greater Laggan Area fields include Laggan, Tormore, Glenlivet, Edradour and Glendronach, located around 140 kilometres west of the Shetland Islands. Current production (for FY 2023) for TotalEnergies’ interests is at about 7,500 barrels of oil equivalent per day, made up of around 90% of gas.

Having acquired Hurricane Energy last year – a UK-based oil and gas exploration and production company with a 100 per cent operated interest in the Lancaster offshore oil field in the West of Shetland basin – this is a major acquisition transaction for the Prax Group, to further develop its E&P portfolio. This acquisition would see TotalEnergies’ interests become integrated within the Prax Group’s existing businesses, as part of the Group’s larger, long-term strategy.

Sanjeev Kumar Soosaipillai, Chairman and CEO of the Prax Group, commented: “With a strong track record of integrating acquisitions and managing assets in the oil and gas value chain, the Prax Group is a long-standing and trusted partner of TotalEnergies. The announcement of the signing of this agreement is the culmination of many months of solid co-operation between our respective companies.

Our strong balance sheet has enabled the Group to execute its growth strategy having successfully completed two major acquisitions last year, and with two other transactions in the pipeline, I am delighted that the Prax Group is able to announce its proposed expansion in West of Shetland, as part of our long-term plan to strengthen our position across the whole oil and gas value chain.

Following a period of consolidation, we now have a clear path to achieve our vision and future-proof our company and are ready to continue implementing our strategy. The acquisition of TotalEnergies’ West of Shetland interests is the beginning of the next exciting chapter in our history.”

Discussing TotalEnergies’ reasoning behind the sale, Jean-Luc Guiziou, Senior Vice President Europe for Exploration & Production at TotalEnergies said: “This transaction is in line with TotalEnergies’ strategy to continuously adapt its portfolio by divesting mature non-core assets. TotalEnergies remains committed to the UK through both its upstream portfolio in the North Sea (Elgin-Franklin, Culzean and Alwyn fields) and its Integrated Power and Renewables portfolio.”

Technip Energies and KPSP sign a long-term services agreement with KPO for the development of the Karachaganak field in Kazakhstan

Technip Energies, through its joint-venture TKJV LLP with KPSP, announces the signing of a long-term services frame agreement with Karachaganak Petroleum Operating B.V. (KPO) for the development of the Karachaganak Field, located in northwest Kazakhstan near Aksai.

This five-year agreement covers a comprehensive range of services, from consulting and concept to detailed engineering, aimed at optimizing and expanding the existing facilities and infrastructure of one of the largest oil and gas condensate fields in the world. The project will be executed through TKJV LLP, Technip Energies’ locally incorporated joint venture established in 2019 to serve the Kazakh market by leveraging its engineering and technology capabilities.

Charles Cessot, SVP of T.EN X Consulting and Products, commented: "We are delighted to strengthen our relationship with KPO through this engagement. The trust placed in us for this project demonstrates our expertise and operational quality for many years in Kazakhstan. This project aligns perfectly with our ambition to provide cutting-edge and efficient consulting services.”

Nour Abou Jaoudé, CEO & Chairman of TKJV LLP, declared: “This is a collaboration for success. We are deeply honored and humbled by the trust that KPO's CEO, Mr. Marco Marsili, and H.E. the Minister of Energy of the Republic of Kazakhstan, Almassadam Satkaliyev, have bestowed upon us. We are fully committed to supporting the localization of complex engineering services as part of the country’s ambitious local content development plans and specially on such an important project for the Kazakh energy sector and economy.”

Aramco’s strategic gas expansion progresses with $25bn contract awards

Aramco, one of the world’s leading integrated energy and chemicals companies, has awarded contracts worth more than $25 billion to progress its strategic gas expansion, which targets sales gas production growth of more than 60% by 2030, compared to 2021 levels.

The contracts relate to phase two development of the vast Jafurah unconventional gas field, phase three expansion of Aramco’s Master Gas System, new gas rigs and ongoing capacity maintenance.

Amin H. Nasser, Aramco President & CEO, said: “These contract awards demonstrate our firm belief in the future of gas as an important energy source, as well as a vital feedstock for downstream industries. The scale of our ongoing investment at Jafurah and the expansion of our Master Gas System underscores our intention to further integrate and grow our gas business to meet anticipated rising demand. This complements the diversification of our portfolio, creates new employment opportunities, and supports the Kingdom’s transition towards a lower-emission power grid, in which gas and renewables gradually displace liquids-based power generation. To get where we are today, a lot of hard work, innovation and a strong ‘can do’ spirit has been demonstrated by teams across our vast network of suppliers and service providers, who have joined Aramco on this journey to build and expand our world-class energy infrastructure.”

Contract awards

The Company has awarded 16 contracts, worth a combined total of around $12.4 billion, for phase two development at Jafurah. The work will involve construction of gas compression facilities and associated pipelines, expansion of the Jafurah Gas Plant including construction of gas processing trains, and utilities, sulfur and export facilities. It will also involve construction of the Company’s new Riyas Natural Gas Liquids (NGL) fractionation facilities in Jubail — including NGL fractionation trains, and utilities, storage and export facilities — to process NGL received from Jafurah.

Another 15 lump sum turnkey contracts, worth a combined total of around $8.8 billion, have been awarded to commence the phase three expansion of the Master Gas System, which delivers natural gas to customers across the Kingdom of Saudi Arabia. The expansion, being conducted in collaboration with the Ministry of Energy, will increase the size of the network and raise its total capacity by an additional 3.15 billion standard cubic feet per day (bscfd) by 2028, through the installation of around 4,000km of pipelines and 17 new gas compression trains.

An additional 23 gas rig contracts worth $2.4bn have also been awarded, along with two directional drilling contracts worth $612 million. Meanwhile, 13 well tie-in contracts at Jafurah, worth a total of $1.63bn, have been awarded between December 2022 and May 2024.

Progress at Jafurah

The Jafurah unconventional gas field is estimated to contain 229 trillion standard cubic feet of raw gas and 75 billion Stock Tank Barrels of condensate. Phase one of the Jafurah development program, which commenced in November 2021, is progressing on schedule with initial start-up anticipated in the third quarter of 2025. Aramco expects total overall lifecycle investment at Jafurah to exceed $100 billion and production to reach a sustainable sales gas rate of two billion standard cubic feet per day by 2030, in addition to significant volumes of ethane, NGL and condensate.

Master Gas System expansion

Aramco’s Master Gas System is an extensive network of pipelines that connects Aramco’s key gas production and processing sites throughout the Kingdom of Saudi Arabia. Its expansion will increase access to domestic gas supplies for customers in the industrial, utility and other sectors — providing a lower greenhouse gas emission alternative to oil for power generation. From 1982, the network transported associated gas, also known as “waste gas” released during oil production, instead of being flared — illustrating Aramco’s innovation and early adoption of solutions that help mitigate emissions. This pioneering network, which now transports associated gas and sales gas, has helped Aramco achieve near-zero routine gas flaring and maintain a flare volume of less than 1% of total raw gas production since 2012, contributing to the Company having one of the lowest upstream carbon intensities in the industry.