International Upstream: Deepwater and Pre-Salt

Introduction

While the previous articles in this section have focused primarily on US onshore shale production (which dominates US energy banking activity), a significant portion of global upstream investment occurs in international deepwater and offshore environments that operate under fundamentally different economic, technical, and political frameworks. Deepwater projects involve capital commitments of $5-30+ billion, development timelines of 5-10 years from discovery to first production, and complex joint venture structures among multiple IOCs and NOCs. These characteristics make international upstream deals analytically and structurally distinct from the Permian Basin A&D transactions and corporate mergers that dominate US energy banking.

For energy bankers, international upstream exposure comes through several channels: advising IOCs on cross-border acquisitions, advising NOCs on asset sales and capital markets transactions, structuring project finance for deepwater developments, and evaluating the international components of IOC sum-of-the-parts valuations. London-based energy banking teams handle much of this work, though Houston-based bulge brackets also participate in global mandates.

Guyana's offshore Stabroek Block has emerged as the most significant upstream development story of the 2020s. Production increased roughly ten-fold from 2020 to 2025, averaging over 750,000 barrels per day by October 2025, making Guyana one of the world's fastest-growing oil producers despite having no prior hydrocarbon production history before 2019.

The Stabroek Block is operated by ExxonMobil (45% interest) in partnership with Hess Corporation (30%, now part of Chevron following the $53 billion merger) and CNOOC (25%). The consortium has committed over $60 billion in total investment across seven approved development projects, each centered on a Floating Production, Storage, and Offloading (FPSO) vessel. The Uaru and Whiptail developments are expected to begin production in 2026 and 2027, each adding approximately 250,000 barrels per day. Total Stabroek production could reach 1.7 million barrels per day by 2030.

FPSO (Floating Production, Storage, and Offloading Vessel)

A vessel used for deepwater oil production that receives hydrocarbons from subsea wells, processes them onboard, stores the crude oil, and periodically offloads it to tankers for transport to market. FPSOs are the standard development concept for deepwater fields that are too far from shore for pipeline export. Each Stabroek Block FPSO costs approximately $6-10 billion including subsea infrastructure and has a production capacity of 220,000-250,000 barrels per day. The capital commitment required for each FPSO development is orders of magnitude larger than a horizontal shale well ($7-9 million), which is why deepwater projects are undertaken only by the largest IOCs and NOCs.

Why Guyana matters for energy banking: The Chevron/Hess $53 billion merger was substantially driven by Hess's 30% Stabroek interest, demonstrating how a single world-class deepwater asset can anchor a corporate acquisition valued in the tens of billions. The ExxonMobil/Hess arbitration dispute over preemptive rights in the Stabroek joint operating agreement highlighted the legal complexity of international JV structures. Guyana's favorable fiscal terms (relatively low government take compared to other deepwater provinces) and the exceptional reservoir quality (light, sweet crude with high flow rates) make Stabroek one of the most valuable upstream assets in the world.

Brazil is the largest non-OPEC deepwater producer, with approximately 77% of national production coming from pre-salt fields in 2025. The pre-salt formations lie beneath a thick layer of salt at water depths of 2,000-3,000 meters off the coast of southeast Brazil. Despite the technical challenges of drilling through the salt layer, the pre-salt reservoirs produce light, sweet crude with exceptional flow rates and long-life production profiles that generate strong economics.

Petrobras (Petroleo Brasileiro S.A.) is the dominant operator, with plans to invest $77 billion in E&P activities through its 2025-2029 strategic plan. The Buzios field achieved a record 800,000 barrels per day in February 2025, making it one of the most productive single fields in the world. Other major pre-salt fields include Tupi (Lula), Sapinhoa, and Mero, each producing several hundred thousand barrels per day.

Understanding the pre-salt formations that drive Brazil's production requires appreciating the unique geological challenge these reservoirs present.

Pre-Salt Formation

A geological formation located beneath a thick layer of salt at great depth beneath the ocean floor. Brazil's pre-salt fields lie at water depths of 2,000-3,000 meters, with the productive reservoir located beneath 2,000-3,000 meters of sediment and a 2,000-meter salt layer. Despite the extreme depth and drilling complexity, pre-salt reservoirs produce light, sweet crude with exceptional flow rates (often exceeding 20,000 barrels per day per well), making them among the most productive offshore reservoirs in the world. The term "pre-salt" refers to the geological position of the reservoir beneath (pre-dating) the salt layer.

Banking relevance: Petrobras periodically divests non-core assets (both upstream and downstream), creating sell-side advisory mandates for international energy banks. Brazil's pre-salt auction rounds invite IOCs and independents to bid for exploration blocks, generating acquisition advisory and partnership structuring work. International banks (JPMorgan, Citi, Goldman, Rothschild, Lazard) maintain Brazil-focused energy banking teams that cover Petrobras and the international operators (Shell, TotalEnergies, Equinor, Repsol) active in Brazilian deepwater.

The North Sea (UK Continental Shelf and Norwegian Continental Shelf) is the most mature major offshore basin in the world, with over 50 years of production history. While production has been declining for decades, the basin remains strategically important for energy banking because of its active M&A market (driven by portfolio optimization and the energy transition), decommissioning liabilities (creating complex transaction dynamics), and the presence of Equinor (Norway's partially state-owned oil company) as a major operator and acquirer.

UK North Sea has been particularly active in M&A as fiscal uncertainty (the UK's Energy Profits Levy) and net-zero commitments have pushed some operators to divest assets. Companies like Harbour Energy, Ithaca Energy, and various PE-backed operators have been both acquirers and sellers, creating consistent advisory deal flow for London-based energy banking teams.

Norwegian Continental Shelf benefits from a more stable fiscal regime and Equinor's continued investment in existing field extensions and new developments (including the Johan Sverdrup giant field). Norway's approach to managing its petroleum wealth (through the Government Pension Fund Global, the world's largest sovereign wealth fund at approximately $1.9 trillion) provides a case study in how resource revenues can be invested for long-term national benefit.

These structural differences translate directly into how international assets are valued and what risks must be factored into deal analysis.