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Inpex

INPEX Corporation is a multinational company headquartered in , specializing in the research, , development, , and sales of oil, , and related mineral resources. Formed in 2008 through the merger of INPEX, Teikoku Oil Co., Ltd., and INPEX Holdings—with precursors dating to 1966—INPEX operates as Japan's largest petroleum and firm, managing interests in over 20 countries including significant concessions in the oil fields and the operator of the LNG project in . The company employs approximately 3,679 people on a consolidated basis and pursues a dual strategy of ensuring stable supplies while advancing toward by 2050 through investments in carbon capture, renewables, and low-carbon fuels. Key achievements include the 2018 startup of the $37 billion LNG facility, capable of producing up to 9.3 million tonnes of LNG annually, marking INPEX's first operation of a world-scale LNG project as a lead operator. However, the project has faced operational challenges, including safety-related delays and electrical hazards identified in regulatory audits.

History

Formation and Merger

INPEX Corporation traces its origins to February 1966, when Offshore Petroleum Exploration Co., Ltd. was established as a entity focused on overseas development, initially in partnership with Indonesia's PERMINA (now ). This formation aligned with Japan's post-World War II efforts to secure through independent exploration abroad, operating initially as a semi-governmental initiative before evolving into a more commercial structure. The company underwent several name changes reflecting its expanding scope: in 1975, its shifted, followed by an official rename to Indonesia Petroleum, Ltd. in 1977, emphasizing its early focus on assets. By 2001, it adopted the name INPEX Corporation, consolidating its identity as Japan's primary overseas and gas explorer. Parallel to this, Teikoku Oil Co., Ltd., a key predecessor founded in 1941 as a semi-governmental unifier of domestic Japanese oil firms, was privatized in 1950 and grew into a significant player in both domestic and international operations. A pivotal integration occurred in April 2006, when INPEX Corporation and Teikoku Oil merged their management under INPEX Holdings, Inc., aiming to streamline operations and enhance competitiveness in global energy markets. This set the stage for the full merger on October 1, 2008, which combined INPEX Holdings, the former INPEX Corporation, and Teikoku Oil into the modern INPEX Corporation, creating Japan's largest oil and exploration and firm. The merger, backed by encouragement to bolster national energy security, relocated headquarters to , and positioned the entity to manage a portfolio exceeding 70 projects worldwide.

Key Milestones in Expansion

INPEX's expansion accelerated after the 2008 merger, with a focus on securing large-scale international oil and gas projects to diversify beyond domestic operations. In 2009, the company commenced oil production from the Frade Field in Brazil's Campos Basin and shipped the first LNG cargoes from Indonesia's Tangguh LNG Project, marking early post-merger advancements in South American and Southeast Asian production capabilities. These initiatives built on prior interests, enhancing INPEX's global portfolio amid rising demand for LNG. A pivotal milestone came in January 2012, when INPEX finalized the investment decision for the LNG Project in Australia's , where it holds a 66.2% operating stake; this $45 billion venture, involving subsea gas gathering and onshore processing, represented one of the world's largest LNG developments at the time. Later that year, in March, INPEX acquired a 17.5% interest in the FLNG Project offshore , further solidifying its presence in floating LNG technology and Australian waters. By 2014, INPEX extended its concession in Abu Dhabi's to 2041 and acquired a 5% stake in the onshore ADCO Concession, deepening long-term access to the UAE's prolific reserves where it has operated since 1973 via predecessor entities. Expansion into renewables and geothermal complemented hydrocarbon growth. In 2015, INPEX joined Indonesia's 110 MW Sarulla Geothermal Project and reached a final decision to expand the Tangguh LNG , targeting additional to meet Asian market needs. Production milestones followed, including the start of operations at Australia's LNG in July 2018, achieving 8.9 million tonnes per annum of LNG, and appointment as asset leader for Abu Dhabi's Lower Zakum Oil Field in April of that year. In 2021, INPEX entered Norway's Snorre oil field redevelopment and Indonesia's Muara Laboh Geothermal Project, extending its footprint into and additional low-carbon energy sources. Recent diversification included offshore wind acquisitions: in 2022, stakes in the ' Luchterduinen and Borssele III/IV projects, followed by the UK's Moray East in 2023, aligning with broader strategies while maintaining upstream oil and gas commitments. These moves, supported by project financing and partnerships, expanded INPEX's operations across 20 countries, emphasizing resilient supply chains.

Corporate Structure

Public Listing and Financial Performance

INPEX Corporation has been publicly traded on the Prime Market section of the since 2004, following its acquisition of Japan Oil Development Co., Ltd. (JODCO), with shares traded under the ticker symbol . The company maintains a market capitalization of approximately ¥2.91 trillion as of recent trading data, with shares comprising 1,259,136,067 common shares outstanding. It also trades as an (ADR) under the symbol IPXHY on over-the-counter markets. In fiscal year 2024, ending December 31, INPEX achieved revenue of ¥2.27 trillion, marking a 4.68% increase from ¥2.16 trillion in 2023, driven by higher production volumes and commodity prices in upstream operations. Net earnings for the year rose to ¥427.34 billion, reflecting improved operational efficiencies amid volatile energy markets. However, in the first half of 2025, revenue declined 11.9% year-over-year to ¥1.05 trillion, primarily due to lower oil and gas prices, with operating profit falling similarly to ¥616.8 billion. Despite the revenue drop, net profit for the half increased 5.1% to ¥223.5 billion, attributed to cost reductions, lower finance expenses, and tax benefits. The company's financial strategy emphasizes returns through and share buybacks; for instance, annual have been supported by a policy targeting progressive payouts, with recent quarterly contributing to a trailing twelve-month of ¥81.19. As of October 2025, share prices hovered around ¥2,849, reflecting resilience in sector valuations despite global commodity fluctuations. INPEX's remains robust, with total assets exceeding ¥10 trillion and a focus on debt management to fund capital-intensive projects like LNG developments.

Management and Workforce

INPEX Corporation's management is led by a that oversees strategic direction and operations, with a structure emphasizing efficient decision-making and supervision aligned with its mission as an integrated company. As of April 1, 2025, Takayuki Ueda serves as Representative Director, President, and CEO, having assumed the role on June 26, 2018, after prior positions within the company focused on projects. Hiroshi Fujii holds the position of Representative Director and Senior Vice President, contributing to executive oversight. The board includes additional directors and standing statutory auditors to ensure compliance and , supported by advisory bodies such as the INPEX Advisory Committee for sustainable growth. The company's workforce totals 3,679 employees on a consolidated basis as of December 31, 2024, reflecting a 4.19% increase from the prior year amid project expansions. Non-consolidated headcount stands at 889, primarily based in , with the broader group employing personnel across exploration, development, and administrative roles in over 20 countries. INPEX maintains a human resources strategy promoting , formalized in a DE&I Policy announced on February 14, 2025, which commits to non-discrimination based on , , , or other factors and prioritizes through targeted initiatives like career development programs. This approach addresses the multinational composition of its operations, though specific demographic breakdowns remain limited in public disclosures.

Exploration and Production Operations

Domestic Activities in

INPEX Corporation conducts exploration, development, and of and in primarily through its subsidiary INPEX JAPAN, LTD., which handles domestic and gas operations including , , and pipeline to the Kanto-Koshinetsu region. These activities contribute to 's limited domestic output, which accounts for less than 4% of national consumption, with the remainder imported as LNG. INPEX ranks as 's largest producer of and by volume. Onshore production centers on major fields in Niigata, , and Chiba prefectures. The Minami-Nagaoka Gas Field in , operated by INPEX, commenced commercial production in 1984 after completion of the Koshijihara Plant—one of Japan's largest gas processing facilities—and holds recoverable reserves of 3,788.76 million cubic meters, with peak output achieved in 2012 and over 92% of reserves recovered to date. This field supplies feedstock for initiatives like INPEX's blue hydrogen project in Niigata, where domestically sourced gas undergoes steam methane reforming with carbon capture. The Yabase Oil Field in represents one of Japan's largest conventional oil assets, with cumulative crude oil production totaling 5.87 million kiloliters as of December 31, 2023. In , the Gas Field supports co-production of iodine, a extracted from , contributing to regional output that accounts for approximately 80% of Japan's total iodine production. Offshore efforts include geophysical and evaluation since the early in areas off Shimane and Fukuoka prefectures, supported by equity financing from JOGMEC. INPEX initiated exploratory gas off from to July 2022, targeting reservoirs near a 2016 discovery site to assess commercial viability. These activities reflect ongoing attempts to expand domestic reserves amid declining mature field outputs.

Ichthys LNG Project

The LNG Project is a major (LNG) development located in the Browse Basin offshore , approximately 200 kilometers from , where onshore processing facilities are situated. Operated by INPEX Corporation as the majority partner, the project involves the extraction and processing of gas from the Field, discovered in 2000, with estimated reserves exceeding 3 trillion cubic feet of gas and significant . Ownership is held primarily by INPEX at 67.82% following its acquisition of Gas's stake in January 2024, alongside (26%), Japanese gas buyers (5.13%), and (2.62%). Final investment decision was reached in 2012, marking the start of construction for subsea infrastructure, a central processing facility (CPF) semi-submersible platform, a floating production storage and offloading (FPSO) vessel named Ichthys Venturer with 1.12 million barrels of condensate storage capacity, and onshore LNG trains at Bladin Point. Key milestones included completion of offshore flowlines in February 2016 and reaching the project halfway mark in June 2014, though the timeline faced delays from initial targets, pushing first gas to July 2018 and the inaugural LNG shipment to October 2018, with financial completion achieved in December 2019 after approximately 14 months of production ramp-up. The project overcame logistical complexities, including extensive dredging in Darwin Harbor to accommodate large LNG carriers, which posed environmental challenges managed through mitigation measures. The facility comprises two LNG trains with a increased from an original 8.4 million tonnes per annum () to 8.9 in 2015, and further enhanced through debottlenecking to target 9.3 by 2024, alongside peak outputs of 1.65 of (LPG) and 100,000 barrels per day of . In 2023, the project achieved a production record, confirming the viability of the expanded LNG , with INPEX planning 116 LNG cargoes in 2025 despite scheduled shutdowns from August to for both onshore and components to ensure long-term stability. Operations emphasize safe, stable supply to markets, particularly , contributing significantly to INPEX's upstream earnings, as evidenced by upward revisions to annual profit forecasts in August 2025 driven by strong Ichthys output. Challenges have included initial delays due to and issues, as well as recent over emissions ; in September 2025, INPEX identified errors at the onshore , prompting recalculation and an regulatory launched in October 2025 into potential under-reporting. Despite these, the project maintains a framework for sustained output enhancement, with INPEX exploring upstream acquisitions to support further expansion.

Abadi LNG Project

The Abadi LNG Project is a (LNG) development led by INPEX in the Masela Block, located in the offshore eastern , approximately 2,600 km east of . The project centers on the Abadi Gas Field, with plans for an onshore LNG facility in South Maluku Province to process gas from subsea infrastructure. INPEX Masela Ltd., a of INPEX , serves as with a 65% participating interest, alongside partners PT Hulu Energi (20%) and Petronas Masela Sdn. Bhd. (15%), who joined in 2023 following contract adjustments. Development of the project has progressed through multiple phases, including a revised Plan of Development (POD) submitted by INPEX in April 2023 and approved by Indonesian authorities in December 2023, incorporating cost optimizations and measures to enhance project viability and reduce emissions. and design (FEED) for the onshore LNG plant and related facilities commenced in August 2025, with contracts awarded to engineering firms including , KBR, Worley, , and JGC for scopes such as LNG processing, subsea systems, and CCS integration. The overall project investment is estimated at around $20 billion, targeting tenders in 2026 and first LNG production in 2029. Upon completion, the facility is projected to produce 9.5 million tonnes per annum () of LNG, equivalent to over 10% of Japan's annual LNG imports, alongside 150 million standard cubic feet per day of for Indonesia's domestic market to support . efforts since 2020 have secured non-binding memoranda of understanding (MOUs) and letters of intent (LOIs) with buyers primarily in , emphasizing the project's role in regional supply stability. Recent advancements include completion of a CCS by Indonesia's SKK in October 2025, aligning with efforts to integrate lower-carbon technologies, while Indonesian officials have urged acceleration to meet timelines. The project is positioned to bolster INPEX's global output toward 800,000 barrels of oil equivalent per day, contributing to energy needs in , , and broader amid ongoing negotiations on fiscal terms and potential stake adjustments.

Eurasia Region Operations

INPEX maintains significant upstream operations in the Eurasia region, primarily through participating interests in major oil fields in and . These assets contribute to the company's global production portfolio, with a focus on crude oil extraction from the basin. Operations emphasize long-term production sharing agreements (PSAs) amid geopolitical and logistical challenges, including efforts to diversify export routes away from Russian pipelines following regional tensions. In Azerbaijan, INPEX holds a 9.31% participating interest in the Azeri-Chirag-Gunashli (ACG) oil fields via its subsidiary INPEX Southwest Caspian Sea, Ltd., acquired in April 2003. Operated by BP, the fields are located approximately 120 km east of Baku in the Caspian Sea and have been in production since 1997, with cumulative output reaching 4 billion barrels by September 2021. Current production capacity stands at around 350,000 barrels per day across platforms including Chirag, Central Azeri, West Azeri, East Azeri, Deepwater Gunashli, and West Chirag. The Azeri Central East (ACE) project, sanctioned in April 2019, commenced production in April 2024, enhancing reserves recovery. The PSA, originally signed in 1994, was extended in 2017 and runs until 2049, supporting stable output despite periodic negotiations on equity adjustments. INPEX also participates in the Baku-Tbilisi-Ceyhan (BTC) pipeline, which transports ACG crude over 1,770 km to Turkey's Mediterranean coast, facilitating exports to global markets. In , INPEX's primary asset is a 7.56% stake in the Offshore North Caspian Sea Contract Area, including the Kashagan oil field, acquired in September 1998 through INPEX North Caspian Sea, Ltd. Operated by the (NCOC), Kashagan lies in shallow waters (3-4 meters depth) 75 km southeast of and ranks among the world's largest discoveries, with first oil in October 2016 after overcoming technical hurdles like high-pressure reservoirs and content. has reached approximately 430,000 barrels per day, with a target of 450,000 barrels per day; cumulative output hit 1 billion barrels by July 2025. The PSA expires in 2031 but can extend to 2041. Recent developments include export diversification: in March 2023, INPEX shipped Kashagan crude from port to , bypassing Russian routes, followed by a test batch via the BTC pipeline and initial deliveries through the to in June 2024, totaling around 20,000 tons. These moves address sanctions and infrastructure constraints, enhancing access to European markets. INPEX's Eurasia activities have historically included exploratory interests in Russia's Far East and Siberian blocks, such as the Zapadno-Yaraktinsky and Bolshetirsky areas acquired in 2013, but these were minor and largely divested by 2024 amid geopolitical shifts, with stakes sold to domestic partners like . The region remains focused on maturation rather than expansion into higher-risk ventures.

Other International Ventures

INPEX Corporation maintains significant exploration and production interests in the , particularly in , where it has operated since acquiring Japan Oil Development Company Limited (JODCO) in 1973. The company's subsidiary, JODCO, participates in the Abu Dhabi Offshore Oil Fields, encompassing four major concessions: Upper Zakum, Umm Al Anbar, , and . Upper Zakum ranks among the world's largest oil fields, with INPEX holding a 12% interest in its development, contributing to daily production exceeding 1 million barrels of oil equivalent through advanced water injection and drilling technologies. In the field, INPEX commenced oil production in phases starting around 2014, utilizing tie-ins to nearby facilities like Abu Al Bukhoosh and Umm Al Lul, achieving initial outputs of approximately 65,000 barrels per day. Onshore operations include a 5% participating interest in the expansive Onshore Concession, secured in April 2015, which encompasses vast crude reserves across multiple fields operated primarily by (ADNOC). This concession supports steady contributions to INPEX's portfolio, with the company focusing on efficiency enhancements amid UAE's push for increased output. In June 2025, INPEX's subsidiary JODCO Exploration Limited received a production concession for Onshore Block 4, located on 's central coast, granting a 40% working interest alongside ADNOC's 60%. Exploration began in May 2021, confirming multiple reservoirs of conventional , , and gas, marking a shift from appraisal to development in this block appraised since 2019. INPEX views as a core growth area, planning increases across its onshore and assets to bolster reserves and cash flow. Beyond the , INPEX has scaled back traditional hydrocarbon ventures in and the . The company divested all interests in offshore blocks in the of Congo by October 2021, ending operations that dated back to 1970 with cumulative discoveries of multiple fields. Similarly, in January 2022, INPEX sold its stakes in Angola's Block 14 in partnership with , aligning with a strategic exit from African upstream activities announced in 2022 to reallocate resources toward higher-priority regions. In the , remains minimal following prior withdrawals from South American assets, though INPEX pursues emerging low-carbon initiatives, such as a 2023 collaboration on the Hydrogen City project in for and ammonia production and export. These moves reflect a emphasizing stable, high-yield assets like those in the UAE over dispersed, lower-return international pursuits.

Sustainability and Environmental Record

Achievements in Resource Management and Low-Carbon Initiatives

INPEX has implemented measures to minimize flaring and fuel gas emissions in its production operations, contributing to more efficient resource utilization and reduced waste in hydrocarbon extraction. The company integrates health, safety, and environment (HSE) management across its operations to sustain resource extraction while aiming to enhance long-term corporate value as a energy supplier. In recognition of these efforts, INPEX received acknowledgment as an Environmentally Sustainable Company in the 6th ESG Finance Awards Japan by the Ministry of Economy, Trade and Industry in March 2025, based on disclosures of environmental performance metrics. On low-carbon fronts, INPEX achieved a net carbon intensity reduction of at least 30% and brought it to 4.1 kg per barrel of oil equivalent (boe) or lower by 2024, aligning with internal targets for emissions efficiency in upstream activities. The company committed to net-zero scope 1 and 2 emissions by 2050, emphasizing pragmatic transitions via natural gas expansion and carbon management technologies as outlined in its 2021 strategy update. In carbon capture and storage (CCS), INPEX advanced the Bonaparte CCS project offshore Australia, securing Major Project Status from the Australian government in July 2025 and initiating pre-front-end engineering and design (pre-FEED) in April 2025 to enable CO2 injection into depleted gas reservoirs for emissions mitigation in hard-to-abate sectors. Collaborative CCS value chain studies with partners like Chubu Electric Power, expanded in 2025, assess CO2 transport from Japan to Australian storage sites, including feasibility of shipping and pipeline options. INPEX progressed blue hydrogen production in , , starting commissioning in June 2025 for a facility integrating and output with to capture CO2 during natural gas reforming, targeting operations by 2030 to support domestic clean energy supply. In renewables, the company invested up to A$1.25 billion by 2030 in projects, including and wind to reach 2-4 gigawatts , facilitating production and local support under its INPEX Vision 2035 framework for diversified low-carbon revenue. These initiatives collectively aim to cut group-wide emissions by 8.2 million tonnes per annum through , , and renewables integration.

Criticisms, Controversies, and Regulatory Challenges

In October 2025, the in launched an investigation into INPEX's LNG project after the company admitted to errors in under-reporting certain emissions, prompting a recalculation of data and scrutiny by environmental regulators. The disclosure involved inaccuracies in monitoring volatile organic compounds (VOCs) and other pollutants from the facility near , raising concerns over compliance with air quality standards despite INPEX's prior claims of no discernible impacts. Earlier operational challenges at included exceeding permitted carbon emissions by approximately 10% in 2020, equivalent to the annual output offset by 1.7 million solar panels, as reported by environmental analyses of flaring and venting practices. Safety audits have also highlighted deficiencies, such as in 2018 when regulators identified electrical equipment issues in hazardous zones on the offshore platform, with over half of inspected items non-compliant, necessitating remediation to prevent potential environmental releases from fires or explosions. For the Abadi LNG project in , regulatory hurdles have delayed progress, including mandates to relocate onshore processing facilities and integrate (CCS), complicating INPEX's plans to neutralize project-related CO2 emissions and extending timelines beyond initial targets. These requirements, driven by environmental policies, have contributed to cost escalations and a postponed final decision to , amid broader challenges in securing approvals for high-risk offshore developments. INPEX has faced criticism from advocacy groups over potential involvement in projects like LNG, where investments could exacerbate impacts and economic for stakeholders, though the company has not confirmed participation. Domestically in , while no major incidents have been documented, INPEX acknowledges of and from activities, with ongoing regulatory pressures to mitigate under stringent national environmental laws.

Strategic Outlook

Recent Developments and Partnerships

In February 2025, INPEX unveiled its "INPEX Vision 2035," a long-term strategic framework emphasizing stable energy supply, carbon neutrality goals, and diversification into low-carbon technologies such as (CCS), , and ammonia, while maintaining core hydrocarbon operations. In May 2025, INPEX partnered with Corporation and Kanto Natural Gas Development Co., Ltd. to secure consignment contracts for CCS demonstration projects in , aimed at advancing commercial-scale sequestration technologies. On June 3, 2025, INPEX and its partners achieved final investment decision (FID) on the electrification of the Sangachal terminal in , replacing gas turbines with grid electricity to reduce emissions from Shah Deniz gas processing operations in which INPEX holds a stake. In January 2025, INPEX joined the International e-Methane Alliance, committing to collaborative efforts for synthetic production using , as part of broader decarbonization initiatives. Earlier, in December 2024, INPEX participated in a project in via its subsidiary INPEX Idemitsu Norge AS, focusing on storage in the northern to support emissions reductions from regional oil and gas activities. Building on prior efforts, INPEX signed a (MOU) with Indonesia's in July 2023 to explore joint opportunities in upstream oil and gas, LNG, and emerging low-carbon sectors like and , enhancing bilateral cooperation. In 2023, INPEX joined the Oil and Gas Methane Partnership 2.0 (OGMP 2.0), a UN-supported initiative to cut through improved measurement and mitigation in operations worldwide. These moves reflect INPEX's strategy to balance traditional resource development with partnerships advancing technologies.

Future Projects and Energy Transition Strategies

INPEX's future projects emphasize expansion in (LNG) production to support stable energy supply, with the Abadi LNG project in positioned as a cornerstone. This onshore LNG facility, operated by INPEX with a 65% stake alongside , is designed to produce 9.5 million tonnes per annum () of LNG, supplemented by 150 million standard cubic feet per day of domestic sales. and (FEED) contracts for the project were awarded in August 2025, advancing toward a final decision expected in the coming years. In , INPEX is accelerating the Cash-Maple gas field development offshore , evaluating export pipeline routes to integrate with the existing LNG infrastructure, which maintains a capacity of 9.3 . Complementing these hydrocarbon developments, INPEX plans substantial capital allocation for growth, committing over ¥1,800 billion from 2025 to 2027 toward upstream investments, including LNG and associated infrastructure. A September 2025 strategic agreement with the in underscores commitments to around , incorporating environmental safeguards and community benefits aligned with long-term operations. INPEX's energy transition strategies, outlined in the February 2025 INPEX Vision 2035, prioritize a "responsible energy transition" by expanding as a bridge fuel while developing low-carbon technologies to achieve by 2050. The company targets a 60% reduction in net carbon intensity through production optimization and plans to establish five net zero businesses: and , carbon capture, utilization, and storage (CCUS), , power generation, and metal resource supply. CCUS initiatives focus on injecting captured CO2 into depleted reservoirs, with pilot projects underway to scale for broader application. and ammonia efforts aim to create new revenue streams, leveraging INPEX's gas expertise for decarbonized fuels. This approach balances continued oil and gas operations—projected to form the core of revenue through 2035—with incremental low-carbon investments, reflecting pragmatic adaptation to global demand for reliable energy amid geopolitical risks. INPEX's strategy avoids abrupt divestment from hydrocarbons, instead integrating CCUS and to mitigate emissions from existing assets like and Abadi.

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