Core Viewpoint - Occidental Petroleum is positioned as a potential long-term investment opportunity, supported by its vast resources, commitment to carbon capture technology, and growth in its chemicals business [2][3][10]. Group 1: Investment Positioning - Occidental Petroleum is one of Berkshire Hathaway's top holdings, with nearly 265 million shares owned, representing 28.2% of its outstanding shares, valued at $10.5 billion [3]. - Warren Buffett views Occidental as a "forever holding," similar to Coca-Cola and American Express, indicating strong confidence in its long-term potential [3]. Group 2: Growth Catalysts - The company possesses extensive low-cost oil and gas resources across 9.3 million net acres in key regions, which should support production growth for years [4]. - Occidental is investing heavily in carbon capture and sequestration (CCS), aiming to build the world's largest direct air capture facility, with the potential for a $3 trillion to $5 trillion global industry [6][7]. - The chemicals business, OxyChem, is projected to add approximately $325 million in annualized earnings by 2026, driven by increasing global demand for petrochemicals [8]. Group 3: Future Outlook - The combination of vast oil and gas resources, leadership in CCS, and a strong management team under CEO Vicki Hollub positions Occidental for significant shareholder value growth [11]. - While there are uncertainties regarding the future of oil and gas and the unproven nature of CCS technology, the company has multiple avenues for growth that could yield substantial returns [10].

Core Viewpoint - ANGKOR RESOURCES CORP. is advancing its oil and gas exploration efforts in Cambodia through its subsidiary EnerCam Resources Co. Ltd., with a focus on Block VIII, where a 350-kilometer 2-D seismic line program has been established to identify drilling targets and enhance exploration activities [1][2][3]. Group 1: Exploration Activities - The technical team has identified six potential sedimentary sub basins of interest within Block VIII, with four located in the central west and two in the east [2]. - Initial seismic survey targets are concentrated in the western half of the Permit Block, specifically in the South Cardamom, Central Bokor, South Bokor, and North Phu Quoc sedimentary sub basins [3]. - The eastern side of Block VIII features two shallower sedimentary basins, North Kampot and South Kampot, which have known oil seeps of interest [4]. Group 2: Seismic Program and Methodology - The seismic program is expected to be conducted using accelerated weight drop (AWD) seismic technology, particularly suited for the shallower targets identified [4]. - The results from the 2-D seismic survey will be processed and interpreted during the rainy season, guiding subsequent exploration steps [11]. Group 3: Regional Context and Comparisons - The oil seeps found in Block VIII are similar to those in the Phitsanulok Basin of northwestern Thailand, which hosts the Sirikit oilfield, the largest onshore oilfield in Thailand with an initial estimate of 800 million barrels of oil [5]. - The Sirikit oilfield's recoverable estimates include 148 million barrels of oil and 250 billion cubic feet of associated gas, although these figures do not directly indicate the resource potential of Block VIII [5]. Group 4: Environmental Considerations - The seismic lines will be adjusted to remain within Permit boundaries, avoiding any encroachment into Protected Park areas or special Ecological Reserve lands [8].

Financial Data and Key Metrics Changes - The company reported a net loss of $57 million in Q4 2024, primarily due to net derivative losses of $58 million, resulting in a negative $0.68 per diluted share [46] - Adjusted net income for Q4 2024 was approximately $1 million, or a positive $0.01 per diluted share, after adjusting for unrealized derivative losses and other non-recurring items [47] - For the full year 2024, the company generated positive adjusted free cash flow of $92 million, with an overall adjusted free cash flow margin of 15% [45] Business Line Data and Key Metrics Changes - The upstream business produced 774 million cubic feet equivalent per day in Q4 2024, exceeding the midpoint of guidance by 5% [20] - The average annual daily production for 2024 was 788 million cubic feet equivalent per day [22] - The Power JV's implied share of net loss during Q4 was about $17 million, with adjusted EBITDA of $0.5 million [38] Market Data and Key Metrics Changes - The average capacity factor for the Temple plants during Q4 was 38%, with total generation of 1,200 gigawatt hours [37] - Power prices averaged $36.90 per megawatt hour in Q4, with average natural gas costs of $2.50 per MMBtu, resulting in an average spark spread of $19.37 per megawatt hour [37] - ERCOT's long-term load forecast estimates overall demand could reach 150 gigawatts by 2030, nearly doubling the 2023 peak load of 85 gigawatts [10] Company Strategy and Development Direction - The company aims to redefine the concept of an energy company by combining traditional and new energy approaches, focusing on integrated energy solutions [8] - The Power business is expected to grow through increased utilization of existing assets and potential M&A opportunities [12] - The company is actively pursuing additional combined cycle units to address projected demand growth and baseload supply mismatch [13] Management Comments on Operating Environment and Future Outlook - Management expressed optimism about the long-term demand growth in ERCOT, despite short-term price moderation due to benign weather and renewable additions [11] - The company remains committed to capital discipline and systematic investment in response to market conditions [41] - Management highlighted the importance of carbon capture in decarbonizing the global economy and expressed confidence in the CCUS business growth [14][16] Other Important Information - The company plans to increase total capital expenditures for 2025 to between $320 million and $380 million, with approximately $220 million allocated for development [43] - The company is in exclusive negotiations with a global energy transition investor for a joint venture in the carbon capture business, with a timeline to finalize agreements within 90 to 120 days [16] Q&A Session Summary Question: How much capacity would the company be comfortable dedicating to a PPA? - Management indicated that they would be comfortable dedicating up to 750 megawatts of capacity for a PPA, maintaining redundancy for maintenance [59] Question: What is the latest on discussions regarding PPAs and new plants? - Management confirmed active discussions for existing plants and is also exploring agreements for new plants, indicating a strong market position [61] Question: What is the expected CCUS capital spending? - Approximately $90 million of the $130 million guidance for CCUS and other is expected to be spent on CCUS projects, with no assumption of a joint venture at this time [69][71] Question: What is the outlook for production taxes? - Management clarified that lower production taxes were due to timing impacts related to ad valorem taxes, which are expected to normalize [75][77] Question: What factors drove the strong upstream performance? - The strong performance was attributed to new well development exceeding forecasts and effective base decline management [105] Question: What is the company's strategy regarding potential joint ventures for carbon capture? - Management expressed optimism about securing a joint venture partner, emphasizing bipartisan support for carbon capture initiatives [115]