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Rystad Energy

Rystad Energy

Rystad Energy is an independent energy consulting services and business intelligence provider offering global databases, strategic advisory and research products for energy companies and suppliers,…

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South America Is Rapidly Becoming A Global Leader In Offshore Oil

South America has made a cost-cutting leap since 2013, when it was the world’s most expensive region for deepwater oil and gas production costs. Average operational expenditure (opex) per barrel of oil equivalent has more than halved since then, from roughly $26 to $12.7 in 2020, a Rystad Energy report shows. The region also enjoyed the largest cost decline globally this year, in both absolute and percentage terms.

South America’s deepwater opex is driven mainly by Brazil, which accounted for roughly 99% of the continent’s brownfield costs from 2013 to 2020. Brazil’s state oil company Petrobras alone accounted for nearly 88% of South America’s deepwater opex. It therefore makes sense to focus the cost reductions on Brazil to get the greatest impact.

One of the factors that have helped Brazil save opex is Petrobras switching out its floating production, storage and offloading vessel (FPSO) fleet. When the state player initially began production on pre-salt basins it chose to rent most of its fleet, which led to a surge in its operational costs. In 2015–2016 the company started ordering more owned FPSOs.

Our numbers show that Petrobras increased its fleet of owned FPSOs by 16 whilst reducing the number of leased FPSOs by six from 2013 to 2020. Eight out of 10 fields in Brazil with start-up years from 2018 to 2020 have been developed via owned FPSOs while the two remaining fields use leased units, confirming the country’s shift from leased to owned vessels.

Spurred by the current Covid-19 market volatility and turmoil in the energy industry, Petrobras has also cut its employee count by roughly 22% this year by way of buyout programs. The company plans to achieve total cost cuts of around $2 billion in 2020 by lowering its overhead and relinquishing unnecessary office space.

Another important driver for the reduction in opex in South America is a 55.2% drop in the value of the Brazilian real (BRL) against the US dollar (USD) exchange rate since 2013. This has reduced opex per barrel as the costs are incurred in BRL but paid in USD. The depreciation in the real has therefore helped offset local price inflation pressures for general goods and services.

Petrobras has also increased its oil and gas production from 2013 to 2020, which has driven the opex per barrel down further thanks to economies of scale. Looking at this from a global and more generic perspective, already producing fields are generally more likely to have lower opex.

In addition to the factors mentioned above, the portfolio of producing fields in South America has been getting younger – and newer fields require much less maintenance than mature fields that generally have higher operational costs. More than 110 mature fields have been abandoned on the continent over the past eight years, with new fields now accounting for over half of the total production in South America compared to 17% from very mature fields. In general, the production share from fields that have passed half of their lifetime has decreased drastically in South America since 2013. It will be interesting to see the cost profiles of Brazil and Petrobras when decommissioning of older fields starts in a few years, given the country’s lack of experience in this area.

“Looking towards the future, we expect deepwater opex per barrel to stay relatively flat through 2020 to 2021. However, after 2021 we see lifting costs per production increasing by roughly $4 per boe, staying at that level through 2024 with an increase of approximately $1 in 2025,“ says Rystad Energy’s Vice President Energy Service Research Matthew Fitzsimmons.

The Covid-19 inflicted uncertainty means that service companies, operators and investors will continue to watch their budgets and stay clear of any non-profitable or high-risk projects in the months and years ahead. Due to the generally low and turbulent Brent spot price this year, investments and projects that do not meet the cost and risk criteria set forth by the companies are likely to be delayed.

Attaining the lowest possible cost per production will therefore be more vital than ever, despite the fact that cost reductions like the ones seen in 2014–2016 are unlikely as many of the possibilities have already been exhausted. Cost reduction strategies adopted by South America, and more specifically Brazil, could serve as a roadmap for other struggling regions and countries.


By Rystad Energy

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