Thank you very much, my fellow Americans. Good evening. Let me begin by congratulating the team at NASA and our brave astronauts on the successful launch of Artemis 2.It was quite something. It will be traveling further than any manned rocket has ever flown and will very substantially pass the moon, go around it, and come back home from a distance that has never been done before. It's amazing.They are on the way. And God bless them. These are brave people.We want to God bless those four unbelievable astrona ...

Core Insights - New Zealand Energy Corp. (NZEC) has successfully resumed production at the Waihapa H1 well in Taranaki, New Zealand, following workover activities in collaboration with L&M Energy Ltd. and Monumental Energy Corp. [1][5] Production Details - The workover targeted bypass pay within the Mount Messenger formation, similar to the recently perforated Ngaere-1 well, with seven six-meter perforated intervals that encountered high-pressure oil flow [2] - Initial stabilized oil and gas flow rates from the Waihapa H1 well are approximately 553 barrels per day over a 24-hour period after six days of production and well clean-up [3] - Oil is being transported to the nearby Waihapa production facility for processing and sale, with associated natural gas also being processed for the local market [2][4] Market Context - The Mount Messenger formation is a proven producing zone, with the adjacent Cheal oil field having produced around 12 million barrels of oil [4] - Current natural gas prices in New Zealand range from approximately USD$10 to USD$15 per MCF, positioning it as one of the highest gas price environments globally [4] Company Strategy - The CEO of NZEC emphasized the importance of optimizing existing infrastructure and previously identified bypass pay zones, indicating a focus on enhancing production across the Waihapa and surrounding fields [5] - NZEC is actively evaluating additional workover and production optimization opportunities within its Taranaki Basin assets [5][6]

Core Insights - Venezuela has formalized strategic agreements with Repsol to enhance gas production and facilitate future exports at the Cardon IV block, which is jointly operated with Eni [1][3] - The Cardon IV concession includes the Perla field, one of the largest offshore gas reserves in Latin America, currently producing 580 million cubic feet per day [2] - The Venezuelan administration is committed to fostering partnerships with international investors in the oil and gas sectors, emphasizing collaboration with European companies [3] Industry Context - Venezuela, despite its significant oil reserves, is facing challenges with deteriorating energy infrastructure, impacting its position in global natural gas markets [5] - The U.S. has relaxed sanctions on Venezuela's energy industry, allowing global companies to engage in oil and gas projects, which may lead to increased production [4] - A report suggests that a rise in Venezuelan oil production could challenge Brazil's ambitions to become the world's fifth-largest crude producer by 2030 [6] - Increased output from Venezuela could put downward pressure on the global oil market, which is already facing weak prices and demand [7]

Core Insights - Harbour Energy reported an adjusted profit after tax of $603 million for the full year 2025, marking a 63% increase from $370 million in 2024 [1] - The company's revenue and other income surged by 66% to $10.3 billion in 2025, up from $6.2 billion in 2024 [1] - Earnings before interest, tax, depreciation, amortisation, and exploration (EBITDAX) climbed to $7.1 billion in 2025, a 76% rise from $4.02 billion the previous year [1] Financial Performance - Adjusted EBITDAX reached $7.2 billion, reflecting a 74% increase from $4.14 billion [2] - Despite positive metrics, the company reported a loss after tax of $182 million, impacted by a 106% effective tax rate and a deferred tax charge of $300 million due to changes in the UK fiscal regime [2] - Unit operating costs were reduced by 22%, down to $12.8 per barrel of oil equivalent (boe) from $16.5/boe the previous year [3] Operational Highlights - Harbour Energy achieved production of 474,000 barrels of oil equivalent per day (boepd), an 84% increase from 258,000 boepd in the previous year [2] - The company brought new wells and projects online across the UK, Norway, Argentina, and Egypt, with exploration successes in Egypt and Norway [3] Strategic Developments - Harbour Energy was appointed as the operator of Mexico's Zama oilfield, with gross recoverable reserves of 750 million barrels of oil equivalent, and initiated a capital-efficient phased development plan [4] - Construction has begun on the six million tonnes per annum Southern Energy LNG project in Argentina, where the company holds a 15% stake, with operations expected to start by the end of 2027 [4] - The company announced its exit from Vietnam and plans to divest $215 million in Indonesia, with transactions expected to complete by mid-2026 [5] Acquisitions and Future Outlook - Harbour Energy completed the acquisition of LLOG for $3.2 billion, securing a fully operated oil-weighted portfolio with significant growth potential in the deep-water US Gulf [6] - The company announced a $170 million acquisition of Waldorf in the UK, expected to unlock financial synergies valued at approximately $900 million upon completion by mid-2026 [5] - Looking ahead to 2026 and beyond, production levels are anticipated to be between 475,000 and 500,000 boepd, with unit operating costs around $14.5/boe [6]

Nigeria’s government will channel more of the proceeds from its oil and gas production directly into a central account, a move aimed at boosting state finances https://t.co/TvgSwAnsEZ ...

Core Viewpoint - Trio Petroleum Corp has successfully transitioned its Alberta heavy-oil asset into active production operations following the completion of all necessary regulatory approvals and license transfers [2][9]. Operational Update - As of January 30, 2026, Trio Canada has completed all required approvals from the Alberta Energy Regulator, allowing the asset to move from acquisition to active field operations [2]. - Surface lease agreements for initial producing well locations are expected to be executed by the end of the week, enabling the commencement of production operations [3]. Initial Production and Operational Plan - The company plans to place two wells into production within 7 to 10 days, anticipating a combined output of approximately 30 to 40 barrels of oil per day as production is established [4]. - Additional perforation operations are planned to access new zones within existing wellbores, aimed at enhancing production rates and improving long-term recovery [5]. Additional Wells and Near-Term Upside - Two additional wells are included in the near-term development plan, with a target to bring them into production by March 31, 2026, subject to surface access and operational sequencing [6]. Strategic Significance - The Alberta asset marks Trio's first producing platform in a well-established heavy-oil region, providing immediate production and existing infrastructure, which is seen as a foundation for future growth in Alberta [8]. Management Commentary - The CEO emphasized the importance of this milestone, highlighting the company's ability to convert acquisitions into near-term production and cash flow, positioning for continued growth in Western Canada [9].

Core Viewpoint - Santos anticipates increased production in 2026, driven by the Barossa gas project and the Pikka oil development, despite previous delays in the Darwin LNG plant [1][2] Production and Operational Updates - The first cargo from the Darwin LNG plant is being loaded onto the LNG tanker Kool Blizzard, destined for Sakai, Japan, following successful drilling in the Barossa gas field [2] - Production from Barossa gas and Pikka is expected to increase by up to 30% in 2026 [2] - Pikka phase one is nearing mechanical completion, with first oil expected in Q1 2026 [2] Financial Performance - For Q4 2025, total sales revenue was A$1.23 billion, a decrease of 12.1% from A$1.4 billion in Q4 2024 [3] - Free cash flow from operations in Q4 was approximately A$380 million, up 30% from the prior quarter, totaling around A$1.8 billion for the full year [3][6] - Quarterly production rose 5% to 22.3 million barrels of oil equivalent (mboe), with full-year production at 87.7 mboe [3] Sales Volume and Revenue Breakdown - Sales volumes increased 15% quarter-on-quarter to 24.8 mboe in Q4, with total sales volumes for the year reaching 93.5 mboe [4] - LNG sales revenue in Q4 was A$780 million, down 9.1% year-on-year, while domestic sales gas revenue increased by 5.9% to A$268 million [4] - Crude oil revenue fell 61.8% to A$66 million, and condensate revenue decreased by 1.9% to A$101 million, while liquefied petroleum gas revenue rose by 7.7% to A$14 million [4] Operational Highlights - Production commenced at the Hides F2 well in Papua New Guinea at an average rate of 60 million standard cubic feet per day [5] - Domestic gas production in Western Australia increased by around 19% due to project initiatives [5] - The company secured a mid-term LNG supply contract and is preparing for the Beetaloo Basin appraisal programme planned for Q3 2026 [5]

Group 1: Rig Count and Production Data - The total number of active drilling rigs in the US increased by 5 to reach 554, which is down 29 from the same time last year [1] - Active oil rigs rose by 2 to 419, reflecting a year-over-year decline of 60 rigs; gas rigs also increased by 2 to 127, which is 28 more than last year [2] - The active drilling rigs in the Permian Basin rose by 1 to 254, which is 49 rigs lower than the previous year [3] Group 2: Production Trends - Weekly US crude oil production slightly dipped to an average of 13.834 million barrels per day, just 28,000 barrels per day below the all-time high [2] - Primary Vision's Frac Spread Count increased by 2 to 175, ending a three-week decline, but is down from 201 at the beginning of the year [3] Group 3: Market Prices - WTI benchmark crude oil was trading down by $1.11 per barrel at $57.89, and Brent benchmark was down $1.01 per barrel at $62.37, reflecting a decrease of approximately $2 per barrel week over week [4]

Core Viewpoint - Petrobras, the Brazilian state-run oil company, may initiate oil and gas production in the Foz do Amazonas basin within seven years, contingent on the confirmation of large reserves [1] Company Summary - The Chief Executive of Petrobras, Magda Chambriard, indicated the potential timeline for production commencement, highlighting the importance of confirming substantial reserves in the region [1] Industry Summary - The Foz do Amazonas basin represents a significant opportunity for oil and gas production, which could enhance Brazil's energy sector and contribute to the country's economic growth if reserves are validated [1]

Core Insights - Gran Tierra Energy reported record production of 47,196 barrels of oil equivalent per day in Q2 2025, driven by an expanded Canadian portfolio [1][5] - Despite operational growth, revenue declined by 8% year over year to $152 million due to weaker commodity prices, resulting in a net loss of $13 million compared to a profit of $36 million in Q2 2024 [1][2] Financial Performance - Net income decreased significantly to $(13 million) from $36 million, marking a 136.1% decline [2] - Revenue fell to $152 million from $165 million, an 8.4% decrease [2] - Adjusted EBITDA dropped 25.2% to $77 million [2] - Funds flow from operations increased by 17.4% to $54 million [2] - Free cash flow turned positive at $2.7 million, improving from $(15.1 million) [2] Production and Operational Highlights - Average daily production increased by 43.9% year over year, reaching 47,196 boe/d [2] - The Canadian segment contributed 17,496 boe/d, with new wells exceeding expectations despite lower realized prices [6] - Colombia's Acordionero field benefited from waterflood optimization, enhancing oil recovery [5][14] Cost Management and Efficiency - Operating costs per barrel improved to $13.42, the lowest since Q1 2022 [7] - Drilling costs in the Colombian Cohembi field decreased by 47% compared to previous operators [7] - Operating netback fell to $21.39, significantly lower than $38.80 in Q2 2024 due to lower sales prices and the inclusion of Canadian volumes [11] Strategic Developments - The company entered a binding agreement to exit the UK North Sea, expected to close in Q3 2025 [8] - A $14 million gain from hedging activities helped mitigate the impact of lower oil prices [8][10] - A $200 million prepayment facility was signed to enhance liquidity and balance sheet flexibility [9][12] Regional Performance - Colombia remained the core revenue source, with the Acordionero field averaging around 14,200 barrels per day [14] - Ecuador's operations showed positive results from successful drilling in the Iguana Block [15] - Canadian operations, while adding scale, realized lower prices and margins compared to South America [15] Management Outlook - No updated financial guidance was provided, but prior expectations for FY2025 production were set at 47,000 to 53,000 boe/d [17] - Investors are advised to monitor realized oil pricing and the integration of Canadian assets for future performance [18]