Almost 1% of global CO2 comes from distillation to separate crude oil fractions at refineries. An alternative is to separate these fractions using precisely engineered polymer membranes, eliminating 50-80% of the costs and 97% of the CO2. We reviewed 1,000 patents, including a major breakthrough in 2020, which takes the technology to TRL5. Refinery membranes also comprise the bottom of the hydrogen cost curve. This 14-page note presents the opportunity and leading companies.
This data-file reviews over 1,000 patents to identify the technology leaders aiming to use membranes instead of other separation processes (e.g., distillation) within refineries.
Covered companies in the screen include Air Liquide, Air Products, Aramco, BASF, BP, Chevron, Dow, ExxonMobil, GE, Honeywell, IFP, MTR, Praxair, Shell, WR Grace and Zeon. A brief overview is prented for each company, along with a summary of their recent patent filings, and all the underlying details.
Operational data are also presented for two interesting cases: Exxon’s recent refinery membrane breakthrough (chart below) and Air Products’s PRISM membranes for hydrogen separation.
This data-file aggregates long-term historical prices of commodities going back to 1800, and running up until 1970, predominantly in the US, using academic records and census data.
Covered commodities include bricks, coal, copper, cotton, nails, rock oil, steel rails, sugar, turpentine, whale oil, wheat and wood. A combined profile of all of these commodities is aggregated in the index above.
In particular, we focus in upon the disruption of whale oil as a lighting fuel and the disruption of wood as a heating fuel, using granular data into pricing and demand. Our conclusions are presented in a research note linked here.
This model breaks down 2050 and 2100’s global energy market, based on a dozen core input assumptions.
You can ‘flex’ these assumptions, to see how it will affect future oil, coal and gas demand, as well as global carbon emissions.
Annual data are provided back to 1750 to contextualize the energy transition relative to prior transitions in history (chart below).
We are positive on renewables, but fossil fuels retain a central role, particularly natural gas, which could ‘treble’ in our base case.
A fully decarbonised energy market is possible by 2050, achieved via game-changing technologies that feature in our research.
Oil markets look primed for a new up-cycle by 2022, which could culminate in Brent surpassing $80/bbl. This is sufficient to unlock 20% IRRs on the next generation of offshore projects, and thus excite another cycle of offshore exploration and development. Beneficiaries include the technology leaders among offshore producers, subsea services, plus more operationally levered offshore oil services. The idea is laid out in our 17-page note.
This data-file compiles all of our insights into publicly listed companies and their edge in the energy transition: commercialising economic technologies that advance the world towards ‘net zero’ CO2 by 2050.
Each insight is a differentiated conclusion, derived from a specific piece of research, data-analysis or modelling on the TSE web portal; summarized alongside links to our work. Next, the data-file ranks each insight according to its economic implications, technical readiness, its ability to accelerate the energy transition and the edge it confers on the company in question.
Each company can then be assessed by adding up the number of differentiated insights that feature in our work, and the average ‘score’ of each insight. The file is intended as a summary of our differentiated views on each company.
The screen is updated monthly. At the latest update, in October-2020, it contains 180 differentiated views on 90 public companies.
This database tabulates almost 300 venture investments made by 9 of the leading Oil Majors, as the energy industry advances and transitions.
The largest portion of activity is now aimed at incubating New Energy technologies (c50% of the investments), as might be expected. Conversely, when we first created the data-file, in early-2019, the lion’s share of historical investments were in upstream technologies (c40% of the total). The investments are also highly digital (c40% of the total).
Four Oil Majors are incubating capabilities in new energies, as the energy system evolves. We are impressed by the opportunities they have accessed. Venturing is likely the right model to create most value in this fast-evolving space.
The full database shows which topic areas are most actively targeted by the Majors’ venturing, broken down across 25 sub-categories, including by company. We also chart which companies have gained stakes in the most interesting start-ups.
2022 oil markets now look 2Mbpd under-supplied, portending another industry up-cycle. 1.5bn bbls of excess inventories from the COVID crisis have likely been drained by early-2021, allowing OPEC to ramp back fully from production cuts by mid-2021. Yet this year’s disruption to shale and across the wider industry will drain a further 2.5bn bbls from inventories by mid-2023. It takes until 2024 for oil markets to re-balance. Inventories remain historically low until late in the decade.
This 4-page note makes the case for the next oil industry up-cycle, with a one-page summary of our thesis, plus three pages of charts covering market balances, demand, shale, other supply, inventories and our Monte Carlo analysis. The underlying models are available here for TSE clients.
Our oil price outlook is informed by a 45-line supply-demand model, running month-by-month out to 2025. This download contains both the model, and a 4-page summary of our outlook.
Oil prices could rebound sharply to the upside in the aftermath of the COVID crisis, as 7.5Mbpd of supply growth has been lost or deferred. The result is steep undersupply in 2021-23 and unprecedently low inventories across the mid-2020s; or in other words, the next industry up-cycle.
After ten years forecasting oil markets, our humble conclusion is that all oil models are wrong. Some are nevertheless useful. To be most useful, our model takes a Monte Carlo approach to the key uncertainties, to quantify the “risk” of positive and negative surprises (illustrative example below).
Please download the model to see, and to flex our input assumptions. Usually included with the download is a PDF summary of our latest oil price thesis, but our latest instalment has been superseded by our deep-dive note into the future of oil demand linked here.
The aim of this data-file is to tabulate and track technical papers into the impacts of deferring production at oil and gas fields. The impact depends on the reservoir type, but generally we expect shut-ins and deferrals during the 2020 COVID crisis will lower effective production capacity.
The Winners. Generally, super-giant Middle East carbonate reservoirs and recently completed shale wells may fare well after curtailments and deferals, with production rates coming back higher than before the shut-ins.
The Losers. Restoring production may be more challenging at highly mature, heavy and waxy fields, particularly those with high water cuts or in deep water: where shut in, these fields may never recover to previous levels, while ramping back can take several years in some past cases.