The EIA released its Annual Energy Outlook
Here's 15 forecasts that went right and wrong over the past decade - a thread #oott#oil#natgas#renewables
Oil Demand: In 2011, oil demand was forecast to be 19.1 Mbbls/d by 2022 (actual: 17.7 Mbbls/d)
Part of the energy revisions reflect changes to U.S. population growth (which has been revised down 6% since the 2018 - the first year with forecasts out to 2050). By 2050, U.S. population is expected now at 370 mln vs. 395 mln people previously.
U.S. Crude Supply: In 2011, oil production was forecast to be 3.8 Mbbls/d by 2022 (actual: 9.6 Mbbls/d).
2050 production forecast has been revised 5% higher y/y to 11.2 Mbbls/d. But overall, for the next ~30 years, the EIA expects production to remain mostly flat #permian#bakken
WTI Spot Price: In 2011, oil prices were forecast to be $112/bbl by 2022 (actual: $95/bbl). By 2050, oil price expectations have been revised higher by +12% to $98/bbl (vs. last year’s forecast) #WTI#brent#opec
Natural Gas (NYMEX) Prices: In 2011, natural gas prices were forecast to be $5.40/mcf by 2022 (actual: $6.50/mcf). For 2050, natgas prices have been revised higher by +5% y/y but still lower than many prior year forecasts – despite the volatility we saw in 2022
In 2011, electricity was forecast to be $8.85/kWh by 2022 (actual: $12.25/kWh). Compared to last year’s outlook, 2050 price forecast has been revised +8% to $11.00/kWh #energy#EnergyBills
In 2011, share of electric vehicle sales were expected to be 26% by 2022 (actual: 15%)
By 2050, share of EV sales have been revised up by 20% y/y (i.e., EV’s are now expected to be 30% of all new vehicle sales (vs. 25% last year) #energytransition
In 2011, natural gas supply was forecast to be 64 bcf/d by 2022 (actual: 100 bcf/d).
The 2050 natural gas supply forecast has been revised -1% y/y (to 115 bcf/d). The trend has been moving lower over the last few years and down from a high forecast done in 2020 at 123 bcf/d
In 2011, natural gas demand was forecast to be 68 bcf/d by 2022 (actual: 88 bcf/d).
For 2050, natural gas demand has been revised lower by 12% y/y to 82 bcf/d. This is a considerable drop from prior years with more renewable energy expected
In 2011, the U.S. expected to be exporting ~5 bcf/d of gas by 2022 (actual: 18.9 bcf/d).
For 2050, net exports have been revised up +47% y/y (to be 37 bcf/d).
In 2011, solar/ wind was expected to supply 2.4% of energy by 2022 (actual: 5.6%).
By 2050, solar/wind mix has now been revised +146% since 2018 (from 9.5% energy share to 23.3% with the most recent forecast). #solarenergy#renewables#WindEnergy
Net Summer Capacity for both solar and wind energy was revised up meaningfully y/y #energy
Once again however, planned coal and nuclear plant retirements keep getting pushed out as demand for energy continues
In 2011, household energy use was expected at 25 Mwh by 2022 (actual 27 MwH).
By 2050, individual household energy use has been revised -3% y/y to 22.5 Mwh. Expected efficiencies are offset by more households with Air conditioning, deep freezers and clothes dryers, etc
In 2011, CO2 emissions/capita were expected to be 16.8 MMmt (actual: 14.6 MMmt).
CO2/capita has now been revised down-20% (since 2018 forecasts) and is expected to be 10.6 MMmtCO2/capita by 2050
The risk factor with energy investments continues to drop. The combined loan book by Canada's 6 big banks shows a 92% decrease in impaired loans to Oil & Gas (to $230 mln). What are the additional implications? -a thread #oott#energy#oilandgas
The banks comfort in the Oil & Gas sector plays a major role in capital spending plans (and ability for M&A). Despite loan impairments down, the banks have still reduced their overall lending to Oil & Gas by 54% since 1Q20 to $27 bln.
On a relative basis, Oil & Gas is now only 1.8% of the CDN bank wholesale loan business. As ancillary fees decline, so to has desire to lend, especially to smaller-cap E&Ps. The result is less sector growth, less 'farm-teams' for the majors, less exploration, etc
These are the EIA's key forecast revisions impacting natural gas markets. Although many of the adjustments are small, it shows the directional bias within their models. Overall, negative revisions for production; upward revisions in consumption for 2024, as NYMEX prices come down
LNG volumes are taking longer to pick-up in early 2023 but ultimately are still expected to grow to 13.5 bcf/d by YE 2024 #LNG#Natgas
Natural gas consumption doesn't quite reach levels seen last year (in both winter and summer months). This is typically the result of weather; with current demand being revised down slightly from last month
EIA came out with their Short Term Energy Outlook
- These are the largest revisions in key data points impacting oil markets today. Although many of the adjustments are small, it shows the directional bias the EIA sees with its forecast models - a thread #oott#oilandgas#WTI
With China showing more signs of opening, oil demand was revised up 1% (160 mb/d). Is there more oil demand revisions to come? Possibly. Expected crude demand in 2023 is still only up 5% to 15.8 mln b/d (from 14.4 mln b/d in 2020) #oott
U.S. oil production in 2024 was lowered 1.4% (150 mb/d) - with much of this oil supply decline near the back-end of the year. As earning season progresses (and capex budgets are revised), we may see more estimate revisions to come #crude#permian#eagleford#midland#bakken
NYMEX natural gas prices have recently slumped, but could this reverse? The U.S. has relied on ~5.5 bcf/d of 'cheap' Canadian natgas imports but that may soon end
With W. CDN natgas storage at record lows now (only 64% full), the AECO / NYMEX diff is nearly gone.
A thread:
2/ AECO prices are now C$6.85/mcf (to incentivize natural gas to stay in Canada). Previously, when W. CDN storage levels were this low (2019), we saw very little CDN natural gas exports. We likely begin to see a drop in exports, that should be bullish for NYMEX natgas pricing
3/ Despite CDN natural gas production at record levels (16.8 bcf/d and ~1 bcf/d higher than last year), summer maintenance issues and other factors have yet to contribute to higher CDN natgas storage levels #AECO#LNG#energy
Thread: Why has Oil & Gas been so volatile? Since 2018, the majority of all CDN E&P buying has come from high-turnover funds. Thus any WTI weakness had them rushing to the exits. Encouragingly, low-turnover funds have become the main buyer in 3Q
More energy inst. buying trends:
2/ As CDN Oil & Gas names hinted at bigger dividends & more growth post Q2 earnings, we saw these 'style' of funds be the dominant buyer in Q3. This theme likely continues as balance sheets allow for more ‘shareholder friendly’ items and growth into 2023 #WTI
3/ Importantly, some of the largest global funds are now picking up CDN Oil & Gas names. Given their AUM size, it can take multiple quarters to establish a position, suggesting there is more large block buying to come in future quarters #energy#CrudeOil#OOTT
Thread – The unemployment rate within CDN Oil & Gas continues to drop, now at 2.5% (w/ Alberta even lower at 1.8%). This budget season, even if mgmt teams wanted to spend more, finding technical staff is increasingly more difficult, likely capping any large capex plans #yyc#yeg
/2 There’s been quite the hiring spree over the last couple years, with jobs in the Exploration & Production group rising ~20% since Jan 2020. That said, levels have plateaued now, even while WTI oil and NYMEX natgas prices have increased, showing the difficulty in hiring #oott
/3 The issue is a declining E&P labour force, now down 6% from recent highs, (at 104k vs. 111k last June) and more meaningfully below 2016 levels. Finding qualified geologists / engineers is becoming increasingly challenging