Offshore staff
OSLO, Norway – Even though 2020 was the year oil and gas producers reduced output to balance the pandemic-hit demand, Australasia’s production did not only stay resilient, but it also rose a little, according to Rystad Energy.
It estimates combined petroleum output across all products was 1.210 Bboe last year, little changed from 1.208 Bboe in 2019.
Within this, Australasia – Australia, New Zealand, Timor-Leste, and Papua New Guinea – produced an average 160,000 b/d of crude oil, an increase of about 3% from 2019. The largest contributor to crude oil production growth was Woodside’s Greater Enfield project, which is estimated to produce about 28,000 b/d. The region pumped condensate at an average rate of 265,000 b/d in 2020, down about 10% from 2019, while natural gas liquids (NGLs) increased roughly 10% to about 114,000 boe/d.
In terms of gas output, Rystad Energy estimates Australasian production averaged 16.6 bcf/d in 2020, relatively flat year-on-year. The top gas-producing project in the region was Chevron’s Gorgon with an estimated output of close to 2.1 bcf/d (LNG and domestic gas).
Capex excluding exploration fell to $6.5 billion in 2020, down 34% from $9.9 billion in 2019, according to the analyst. Before the pandemic struck, Rystad had expected $11.5 billion in non-exploration capex, which means the actual capex was 43% below its initial estimates. The decline was largely driven by spending cuts implemented by companies to weather the crash in benchmark commodity prices.
The industry’s bottom line decreased as expected. It estimates free cash flow from operations slipped by about 9% to $20.7 billion in 2020. On the exploration side, spending fell to a historic low of close to $930 million, a 53% decline compared to 2019, and the lowest level of exploration spending since 1994.
Post-tax impairments in Australasia are estimated to be more than $15 billion, with Shell taking the biggest impairment at $8.2 billion for the QCLNG and Prelude FLNG projects. Woodside announced $4.37 billion in post-tax impairments on its portfolio, followed by Total at $800 million for its Australian gas assets, Santos with $560 million, Origin Energy at $530 million, and Oil Search announcing $300 million in impairments relating to its assets in Papua New Guinea.
Upstream capital and operating expenditures have been sharply reduced alongside exploration budgets. Woodside, one of the largest producers in Australia, halved its total expenditure to about $2.4 billion in 2020, and other companies with a strong presence in Australia like Santos, Beach Energy, and Origin Energy also slashed their 2020 spending plans.
Projects that were to be sanctioned over the 2020-2022 period have been deferred due to the prevailing situation. The analyst expects these delays will reduce Australasia’s capex between 2020 and 2022 by about $5 billion.
New upstream oil and gas projects worth about $15 billion will be sanctioned in Australasia this year, according to Rystad Energy’s forecast, representing a huge boost compared to the $1.2 billion committed to new projects in 2020.
This jump in activity, however, is almost entirely dependent on the anticipated final investment decisions (FIDs) being taken for the Scarborough and Barossa LNG projects in Australia. Without these major FIDs, it anticipates new commitments this year of only $526 million in the region, representing a 57% drop from 2020 for major E&P companies. Virtually all sanctioning activity expected this year in the region will be in Australia.
The Scarborough/Pluto Train 2 project on the north coast of Western Australia, which operator Woodside is expected to formally sanction this year, dominates the list of FID candidates. The analyst estimates capex for Scarborough is $11.1 billion, which would represent 72% of all the potential investment commitments in the region for the full year. Meanwhile, the estimated capex associated with the other large Australian project likely to reach FID – Santos’ Barossa gas field development – is $3.7 billion.
The impact of project delays is most apparent in the analyst’s production forecasts for the 2024 to 2030 period. It now expects that Australian gas production in 2030 will be 101 MMboe lower than its previous forecast – a drop of about 9%. Overall, it continues to see a relatively balanced East Coast gas market, with potential for higher prices, and a shortfall in the West Coast gas market.
On a combined liquids and gas basis, the analyst now forecasts a 2030 production of 1.26 Bboe. This is 188 MMboe below its previous forecast – representing a 13% drop. As expected, the lower forecast is primarily the result of the deferrals in gas projects.
This year is set to be a busy one for Australian renewable energy players, with an expected 5.3 GW of utility PV, wind and battery projects expected to complete commissioning. Activity will be concentrated to the West Murray region for utility PV commissioning and western Victoria for wind.
New utility PV and wind construction is set to bounce back in 2021 from a four-year low in 2020. Rystad estimates the additions at 2.1 GW in utility PV projects, 2.8 GW of wind and 0.45 GW from batteries, however beyond 2021 appears challenging as grid capacity for new connections becomes limited.
When it comes to projects that break ground, the record for new construction starts in the utility PV sector was set in 2018, when 2.1 GW started construction. This year is set to challenge that record as several large-scale projects have secured power purchase agreements (PPAs) and are expected to begin construction in 2021.
Utility wind construction in Australia is also gearing up for a record year in 2021. About 2.9 GW of utility wind assets have currently signed PPAs but have yet to start construction.
02/09/2021
