Low oil prices could play pivotal role in boosting decommissioning spending, Rystad says

Energy companies have been slashing exploration and production budgets since the Covid-19 pandemic took hold and sent oil prices tumbling, but, with few profitable investment alternatives, operators are now likely to increase spending in decommissioning work, according to energy intelligence firm Rystad Energy.

Rystad Energy estimates the total value of the global pool of decommissioning projects that will accumulate through 2024 could reach $42 billion.

With an average asset age of 25 years, the Northwest European decommissioning market could grow 20 per cent in annual commitments through 2022 if the current low oil prices don’t show signs of substantial recovery soon.

In addition to a rapidly maturing asset base and low oil prices that erode commercial viability and potential life extensions, the North Sea decommissioning market will also be helped by favourable service contract prices.

Only about 15 per cent of North Sea assets have been decommissioned to date, but in the coming five years Rystad expects an average of 23 assets to cease production annually. The UK is poised to lead the way with nearly 80 per cent of total estimated expenditure on Northwest European decommissioning in the next five years, followed by Norway with 14 per cent and Denmark with 4 per cent.

The pool of removal projects in the region for that period is estimated at about $17 billion. By comparison, decommissioning costs in the US for the same period are estimated at $5.7 billion.

“A protracted low price environment can potentially motivate operators to leverage low contract prices and commit to their asset retirement obligations, thus spurring decommissioning activity in the Northwest Europe region. This will also provide welcome opportunities for contractors in an otherwise gloomy oilfield services market”, said Sumit Yadev, energy service analyst at Rystad Energy.

The high market share of the UK can be largely attributed to its rapidly maturing production levels, as almost 80 per cent of the country’s oil and gas assets have produced more than 75 per cent of their available resources.

Additionally, lacklustre exploration results, growing regulatory stringency and a prolonged low oil price environment may lead operators to fulfil their asset retirement obligations in the absence of any lucrative competing investments.

Some of the leading assets that will drive the decommissioning market in the region include the Brent, Ninian, and Thistle fields in the UK and Gyda in Norway. Shell’s Brent project would emerge as the single largest asset ever decommissioned globally, representing an outlay of nearly $3 billion alone over the coming decade. Ninian and Gyda would collectively present contracting opportunities worth nearly $2 billion.

The increased spending on decommissioning may limit the room for operators to invest in other segments such as exploration, development and enhanced oil recovery projects. Leading players such as Shell, Total, Repsol and Premier Oil are expected to assign 10 per cent or more of their North Sea spending in the next five years to decommissioning activities.

Plugging and abandonment (P&A) of wells is expected to make up about 45 per cent of decommissioning costs for the period, followed by platform removals, which account for nearly 20 per cent of the total costs. Platform wells are set to be the dominant segment for well P&A activity, making up about 65 per cent of the total wells to be abandoned, while the rest are subsea wells.

However, in terms of costs, subsea wells will take the lead as they cost on average $11 million each to abandon, compared with $5 million for an average platform well.

According to Rystad, low oil prices could play a pivotal role in boosting decommissioning spending in the UK if they persist beyond the end of this year. Nearly 10 per cent of all UK offshore assets have lifting costs above $25 per barrel, which will hamper their life extension prospects and make decommissioning a better financial option if low prices persist.

Operators implemented strong cost optimization measures after the oil price crash of 2014 and therefore have little room for further cost and efficiency gains now, which may also expedite decommissioning spending.

Overall, more than 2,500 oil and gas wells are expected to be decommissioned across the North Sea in the coming decade, of which 1,500 are in the UK. The UKCS will also witness the removal of nearly 300,000 tonnes of topsides in the next five years, with nearly 50 topsides set to be decommissioned, representing an average topside removal cost of $5,300 per tonne.

Additionally, almost 100,000 tonnes of substructures are expected to be removed in UK waters. In line with the broader North Sea trends, platform wells are expected to account for the bulk of the well P&A activity with nearly 70 per cent.

“While decommissioning is becoming a pressing concern for North Sea operators, the prevailing low-price environment presents an opportunity for driving down costs. For instance, after the oil price slump of 2014, rig and vessel rates declined by 30 per cent to 40 per cent. We expect rig and vessel rates to exhibit a downward trend this time as well, with declines likely lasting until 2022”, Yadev concluded.

Photo by SP Mac – shared with permission of the photographer