Oil Price (WTI) on May 1, 2026?

Key producers project significant aggregate spare capacity by Q1 2026. The combined spare production capacity of Saudi Arabia, the United Arab Emirates, and Russia is projected to reach approximately 3.8 million barrels per day (bpd) by the first quarter of 2026 ^[1]. Saudi Arabia is anticipated to contribute about 2.5 million bpd to this total, with the UAE adding 0.8 million bpd, and Russia providing approximately 0.5 million bpd ^[1]. This substantial collective capacity represents a crucial element of the broader OPEC+ buffer, vital for maintaining stability in global oil markets ^[2].

OPEC+ members generally adhered to quotas throughout 2025 despite challenges. Throughout 2025, official statements from major OPEC+ members, including Saudi Arabia and Russia, consistently confirmed their commitment to market stability and necessary production adjustments ^[3]. Saudi Arabia was particularly recognized for its sustained leadership in stabilizing oil markets via production cuts ^[4]. The United Arab Emirates largely adhered to its agreed quotas during this period, even with aspirations to increase its production capacity; their potential exit from OPEC+ is projected for Q2 2026, ensuring their operation under quotas for 2025 ^[4]. Russia's adherence was less consistent, attributed to operational and sanctions-related difficulties, though its government officially reaffirmed its commitments ^[4]. Specific tanker tracking data regarding 2025 adherence was not detailed within the provided research.

Non-OPEC+ nations will drive most global liquid fuels supply growth. The U.S. Energy Information Administration (EIA) forecasts non-OPEC+ petroleum liquids production to increase by 1.7 million barrels per day (b/d) by year-end 2025 ^[1]. This expansion is anticipated to be the primary contributor to global supply growth, with these countries expected to account for approximately 90% of the total liquid fuels supply growth in 2025 ^[2].

Key projects like Guyana's Stabroek Block significantly boost non-OPEC+ supply. ExxonMobil's operations in the Stabroek Block offshore Guyana achieved a daily production milestone of 900,000 b/d by November 12, 2025 ^[3]. This impactful production from Guyana is a notable contribution to the broader non-OPEC+ supply expansion forecast for 2025.

Oil demand growth forecasts show differing trends for China and India. The International Energy Agency (IEA) has consistently lowered its 2025 oil demand growth forecast for China, decreasing from 340 thousand barrels per day (kb/d) in February 2026 ^[4] to 300 kb/d by April 2026 ^[1], with its 2026 projection standing at 280 kb/d ^[1]. In contrast, the IEA's 2025 India oil demand growth forecast saw a slight increase from 240 kb/d in February 2026 ^[4] to 250 kb/d by March 2026 ^[2], with a 2026 forecast of 260 kb/d ^[1]. The U.S. Energy Information Administration (EIA) also anticipates China's oil demand growth at 0.4 million barrels per day (mb/d) in 2025 and 0.3 mb/d in 2026, while projecting India's growth at 0.2 mb/d for both years, attributing this to sustained economic expansion ^[5].

Real-time data presents a nuanced picture for future oil consumption. Data on China's industrial output indicates growth of 4.5% year-on-year in March 2026 ^[6] and 6.1% in Q1 2026 ^[7], activity that typically supports oil demand. However, this potential boost is offset by the rapid adoption of electric vehicles (EVs), with sales penetration reaching approximately 35% of new car sales in China during Q1 2026 ^[3], demonstrating its global leadership in EV markets. India's EV market also expanded, with sales penetration climbing to 8% of total vehicle sales in Q1 2026 from 5% in 2025 ^[8], though its growth rate is slower compared to China ^[3]. These accelerating efficiency gains and EV penetration trends suggest a potential constraint on future oil demand growth in the transportation sectors of both nations ^[1].

The U.S. Department of Energy established clear SPR refilling targets. The Department of Energy (DOE) has outlined a strategy to repurchase oil for the Strategic Petroleum Reserve (SPR) at an approximate price of $72 per barrel, with a strict ceiling of $79 per barrel, prioritizing taxpayer value ^[1]. This replenishment initiative commenced with the delivery of 3 million barrels in January 2023 ^[1]. The DOE maintains a consistent, phased approach through monthly solicitations for crude oil, including a request for 1 million barrels for delivery in October 2025 ^[3].

SPR refilling faces significant future political and financial influences. Completing the refilling of the SPR is a substantial undertaking, estimated to cost around $20 billion and span several years ^[2]. While current research does not explicitly detail how SPR refilling policy would evolve under different U.S. presidential election outcomes, the pace and funding levels are highly susceptible to legislative priorities. For instance, a U.S. House budget bill proposed over $1.5 billion for the SPR in May 2025 ^[4], illustrating how future administrations and congressional compositions could impact political support and resource allocation.

Data limitations prevent calculating aggregate 2025 upstream capital expenditure for key oil companies. While ExxonMobil's planned total capital expenditure for 2025 is projected to be between $27 billion and $29 billion ^[1], and BP intends to allocate 75% of its group capital expenditure to upstream oil and gas ^[2], specific 2025 capital expenditure budgets for Chevron, Shell, and TotalEnergies, as well as BP's total group capital expenditure, are not available in the provided sources ^[3]. Due to these data gaps, a comprehensive aggregate upstream capital expenditure budget for the five largest international oil companies cannot be calculated.

IEA demand projections and required investment levels are unavailable in sources. The provided research output lacks any information regarding the International Energy Agency's (IEA) projected 2026 demand under its 'Stated Policies Scenario' (STEPS). Additionally, details on the investment levels required to meet that demand are also absent. Consequently, a comparison between any aggregated capital expenditure of the oil companies and the IEA's projected investment requirements cannot be made with the information provided.