Green deserts: a final frontier for forest carbon?

Forests can offset 15bn ton of CO2 per year from 3bn global acres. But is there potential to afforest any of the world’s 11bn acres of arid and semi-arid lands, by desalinating and distributing seawater? Our 18-page note answers this question. While the energy economics do not work in the most extreme deserts (e.g., the Sahara), $60-120/ton CO2 prices may be sufficient in semi-arid climates, while the best economics of all use waste water from oil and gas, such as in the Permian basin.

The opportunity and challenges for nature based solutions to climate change are outlined on pages 2-4, explaining the rationale for afforesting deserts.

Precedents for afforesting deserts, including detailed case studies from the Academic literature, are reviewed on pages 5-8.

Water requirements are quantified, based on data from 60 tree species and the forestry industry, on pages 9-10.

The energy economics of desalinating and piping water are presented on pages 11-12.

The challenges of afforestation in the most extreme desert environments are modelled on page 13, showing why it is almost impossible to grow forests in the Sahara. The CO2 costs of supplying sufficient water could exceed the CO2 absorbed by new trees.

Supplementing rainfall in marginal lands is a more compelling economic model (e.g., adding the equivalent of 100mm new rainfall to marginal lands with c300-400mm), as shown on page 14.

The best case we can find is to use Permian waste water. Costs of desalination could be lower than current costs of disposal, while Permian upstream operations on the reforested acreage could be made carbon neutral, per pages 16-17.

A short list of companies exposed to the theme is presented on page 18.

US shale: the quick and the dead?

It is no longer possible to compete in the US shale industry without leading digital technologies. This 10-page note outlines best practices, process by process, based on 500 patents and 650 technical papers. Chevron, Conoco and ExxonMobil lead our screens. We profile where they have an edge, to capture upside in the industry’s dislocation and recovery. Disconcertingly absent from the leader-board is EOG, whose long-revered technical edge may now have been eclipsed by others.

Qnergy: reliable remote power to mitigate methane?

This short note profiles Qnergy, the leading manufacturer of Stirling-design engines, which generate 1-10 kW of power, for remote areas, where a grid connection is not available. The units are particularly economical for mitigating methane emissions, with a potential abatement cost of $20/ton of CO2-equivalents avoided.

750,000 bleeding pneumatic devices around the oil and gas industry are the largest single source of methane leaks, with each medium-bleed device leaking an average of 1.5T of methane per year, comprising 35% of the oil and gas industry’s total emissions (chart below, data here).

We have screened the US onshore space, operator-by-operator, acreage position by position, to see who most urgently needs to replace bleeding pneumatics (chart below, data here, note here). But how will they be replaced?

The challenge is power. An 8-well pad will typically require 2kW of electricity, which is low because the pneumatic pressure of natural gas is used in control and actuation of valves. The power demands rise to 4kW if compressed air is used in lieu of methane. Compressed air is reliable, easy to retrofit and does not cause warming when it bleeds into the atmosphere. But a compressor is needed, and the compressor needs to be powered (below).

Qnergy’s Powergen product uses a Stirling engine to generate electricity from heat. It is fuel agnostic and can run on waste heat or in-basin gas.

The PowerGen product was launched in 2017 and its adoption has been growing at a 300% CAGR. The company now also manufactures and sells compressed air pneumatic devices, which will be powered by its Stirling engines. The 5,650 series generates 5.7kW of power from 1.4mcfd of gas inputs (implying c30% thermal efficiency).

NASA has accredited the design as the most reliable ever invented for a heat engine. One of the first units has now run for 24,000 hours without requiring maintenance (equivalent to driving a car to the moon and back 2x). Design life is estimated at over 60,000 hours (7-years). The engine runs between -40C in Alaska and 60C desert installations. Each unit is also remotely monitored, with live support, for preventative maintenance and to detect issues.

Total cost of ownership for Stirling’s Powergen is cited as the lowest cost power solution to replace bleeding pneumatic devices: costing $100k for Qnergy unit, $150k for a microturbine, $320k for a combination of renewable power and fuel cells, and c$380k for a thermo-electric alternative.

Emissions reductions from each Qnergy Powergen unit saves 325T of CO2e-emissions per annum, while powering each unit will emit 25T of CO2e, for a net saving of 300T/CO2e. At a total cost of $100k, this implies a CO2 abatement cost of $20/ton over a c15-year life of a Qnergy Powergen unit.

For our published screen of companies in methane mitigation, please see our data-file here.

For Qnergy’s latest presentation, see the video below, and please let us know if we can helpfully introduce you to the team at Qnergy.

Chevron: SuperMajor Shale in 2020?

SuperMajors’ shale developments are assumed to differ from E&Ps’ mainly in their scale and access to capital. Superior technologies are rarely discussed. But new evidence is emerging. This 11-page note assesses 40 of Chevron’s shale patents from 2019, showing a vast array of data-driven technologies, to optimize every aspect of unconventionals.

Page 2 explains how we assessed Chevron’s shale patents, to identify technologies that could support guidance for 900kboed of Permian production by 2023.

Page 3 sets out Chevron’s technologies for shale exploration and appraisal, based on recent seismic patents.

Page 4 sets out Chevron’s technologies for shale drilling, based on recent patents, many of which are co-filed with Halliburton, around a specific innovation.

Pages 5-8 set out Chevron’s technologies for shale completions, through an array of sophisticated, proprietary and increasingly digital technologies. These will not only help in the Permian, but also in de-risking international basins.

Page 8 sets out Chevron’s potential edge in completion fluids. We are particularly excited by the promising results from field-tests of anionic surfactants.

Page 9 sets out Chevron’s data-driven flowback practices, including productivity gains from field tests in the Vaca Muerta.

Pages 10-11 set out Chevron’s technologies for upgrading NGLs into gasoline-, jet- and diesel-range products, using industry-leading ionic liquid catalysts.

Page 11 concludes with implications for the broader shale industry.

Global gas: catch methane if you can?

Scaling up natural gas is among the largest decarbonisation opportunities on the planet. But this requires minimising methane leaks. Exciting new technologies are emerging. This 23-page note ranks producers, positions for new policies and advocates developing more LNG. To seize the opportunity, we also identify 23 early-stage companies and 10 public companies in methane mitigation. Global gas demand should treble by 2050 and will not be derailed by methane leaks.

Pages 2-4 explain why methane matters for climate and for the scale up of natural gas. If 3.5% of methane is leaked, then natural gas is, debatably, no greener than coal.

Pages 5-8 quantify methane emissions and leaks across the global gas industry, including a granular breakdown of the US supply-chain, based on asset-by-asset data.

Page 9-10 outlines the incumbent methods for mitigating methane, plus our screen of 34 companies which have filed 150 recent patents for improved technologies.

Pages 11-13 cover the best new developments in drones and robotics for detecting methane emissions at small scale, including three particularly exciting companies.

Pages 14-15 outline next generation satellite technologies, which will provide a step-change in pinpointing global methane leaks and repairing them more quickly.

Pages 16-20 covers the changes underway in the oilfield supply chain, to prevent fugitive methane emissions, highlighting interesting companies and innovations.

Page 20-21 screens methane emissions across the different Energy Majors, and resultant CO2-intensities for different gas plays.

Pages 22-23 advocate new LNG developments, particularly small-scale LNG, which may provide an effective, market-based framework to mitigate most methane.

Shale growth: what if the Permian went CO2-neutral?

Shale growth has been slowing due to fears over the energy transition, as Permian upstream CO2 emissions reached a new high in 2019. We have disaggregated the CO2 across 14 causes. It could be eliminated by improved technologies and operations, making Permian production carbon neutral: uplifting NPVs by c$4-7/boe, re-attracting a vast wave of capital and growth. This 26-page note identifies the best opportunities.

Pages 2-5 show how fears over the energy transition have slowed down shale growth in 2019.

Pages 6-10 disaggregate the CO2 intensity of the Permian, by source and by operator, based on over a dozen models we have constructed.

Pages 11-15 argue why increased LNG development is the single greatest operational opportunity to reduce Permian CO2 intensity.

Pages 16-18 summarise advances in methane mitigation technologies and their impacts.

Pages 19-23 outline and quantify the best opportunities to lower CO2 from digital initiatives, renewables, lifting and logistics.

Pages 24-25 quantifies the sequestration potential from CO2-EOR, which could offset the remaining CO2 left after all the other initiatives above.

Our conclusion is to identify three top initiatives that companies and investors should favor. Industry leading companies are also suggested based on the patents and technical literature we have reviewed.

New Diverter Regimes for Dendritic Frac Geometries?

The key challenge for the US shale industry is to continue improving productivity per well, as illustrated repeatedly in our research. Hence, this short note reviews an advance in fracturing fluids, which has been patented by BP. Diverter compositions are optimised across successive pressurization cycles, to create dendritic fracture geometries, which will enhance stimulated rock volumes.

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Patent Leaders in Energy

Technology leadership is crucial in energy. It drives costs, returns and future resiliency. Hence, we have reviewed 3,000 recent patent filings, across the 25 largest energy companies, in order to quantify our “Top Ten” patent leaders in energy.

This 34-page note ranks the industry’s “Top 10 technology-leaders”: in upstream, offshore, deep-water, shale, LNG, gas-marketing, downstream, chemicals, digital and renewables.

For each topic, we profile the leading company, its edge and the proximity of the competition.

Companies covered by the analysis include Aramco, BP, Chevron, Conoco, Devon, Eni, EOG, Equinor, ExxonMobil, Occidental, Petrobras, Repsol, Shell, Suncor and TOTAL.

Upstream technology leaders have been discussed in greater depth in our April-2020 update, linked here.

More information? Please do not hesitate to contact us, if you would like more information about accessing this document, or taking out a TSE subscription.

US Shale: No Country for Old Completion Designs

2019 has evoked resource fears in the shale industry. They are unfounded. Even as headline productivity weakened, underlying productivity continues improving at an exciting pace. These conclusions are substantiated by reviewing 350 technical papers, published by the shale industry in summer-2019. Major improvements are gathering momentum, in shale-EOR, machine learning techniques, digitalization and frac fluid chemistry.

Discussed companies include Apache, BP, Conoco, Chevron, Devon, ExxonMobil, Halliburton, Occidental, Pioneeer & Schlumberger.

Page 2 compares 2019’s shale performance to-date with our January forecasts, identifying that initial-month producutivity has been 20% weaker YoY.

Page 3-4 shows how continued productivity improvements matter, to unlock >20Mbpd of potential US shale output, plus $300bn of FCF by 2025 (at $50/bbl oil).

Pages 5-8 explain away the apparent degradation in resource productivity: it is a function of three alterations to completion designs.

Pages 9-12 outline 350 technical papers from the shale industry in summer-2019. They restore confidence: the industry is not facing systemic resource issues.

Page 12 covers 24 technical papers into “parent-child” issues. We were surprised by the number that were ‘negative’ versus the pragmatic solutions offered in others.

Page 13, 14 & 17 cover leading digitalization technologies: deployment of machine learning increased 5x YoY, while DAS/DTS increased 3x YoY in 2019.

Pages 14-16 cover the maturation of shale-EOR, which was the greatest YoY improvement, reaching 32 papers in 2019. The cutting-edge of EOR is exciting.

Page 18 outlines other technical highlights to drive future productivity higher.