Greater decarbonization at a lower cost is achievable by burying biomass (such as corn or sugarcane) rather than converting it into bio-ethanol.
This model captures the economics. Detailed costs are estimated for biomass burial and to compare the relative CO2 footprints of the two options.
Three individual tabs illustrate margins, NPVs and IRRs for sugar-cane to bio-ethanol economics, buried sugarcane, and buried napier grass.
This data-file estimates the CO2 intensity of drilling oil wells, in our usual units of kg/boe. The calculations are conducted bottom-up, based on fuel consumption at onshore, offshore and deep-water rigs; plus drilling days and typical resource volumes per well.
Drilling wells is not the largest portion of the oil industry’s total CO2 intensity. Nevertheless there is a 50x spread between the best and worst barrels, which is wider than other categories we have screened.
Prolific fields will have the lowest drilling-CO2 intensities, particularly where they are onshore (e.g., Saudi Arabia). Infill wells at mature deepwater fields may have the highest drilling-CO2.
This data-file quantifies the costs and CO2 emissions associated with different oilfield development concepts’ construction materials.
We have tabulated c25 projects, breaking down the total tonnage of steel and concrete used in their topsides, jackets, hulls, wells, SURF and pipelines. Included are the world’s largest FPSOs, platforms and floating structures; as well as new resources in shale, deepwater-GoM, Guyana, pre-salt Brazil and offshore Norway.
Infill wells, tiebacks and FPSOs make the most efficient use of construction materials per barrel of production. Fixed leg platforms are higher, then gravity based structures, then FLNG, and finally offshore wind (by a factor of 30x).
This database covers all 14 subsea separation projects across the history of the oil industry, going back to the “dawn of subsea” in 1969.
For each example, we tabulate the asset, region, operator, water depth, process technology, Service company, start-up year, power rating, oil capacity, gas capacity, water capacity and some notes.
What is interesting about the data is how elusive the technology’s ascent has been. Two of our projects were cancelled. The largest were 2.3MW. Subsea Boosting and Compression has been 4x more prevalent (chart below).
This matters for the Mero pre-salt field where an unprecedented, giant, 6MW subsea-separation project is being pioneered, to handle high gas and CO2 cuts.
This data-file tracks the construction progress of 30 FPSOs that are being deployed in the Brazilian pre-salt oil province. In each case, we quantify the vessel’s oil and gas handling capacity, development timing and recent news.
We also compare the FPSOs’ gas-handling capacity with regional pipeline capacity. There will only be room to monetize one-third of the pre-salt’s produced gas volumes by the mid-2020s. The rest must be re-injected (chart below).
We have modeled the economics of the Mero oilfield (formerly known as Libra), using public disclosures and our own estimates.
Our model spans >250 lines of inputs and outputs, so you can flex key assumptions, such as oil prices, gas prices, production profiles and costs.
In particular, we have tested the impact of different gas bottleneck scenarios on the field’s ultimate value.
Technology leadership determines offshore capex. Specifically, this data-file measures a -88% correlation coefficient between different Major’s offshore patent filings in 2018 and their projects’ capex costs.
The details: We have tabulated the number of Offshore Patents filed in 2018, across 25 leading Majors, from our sample of 3,000 patents. We have also tabulated a dozen, recent, offshore greenfields operated by these companies, which were sanctioned in 2017-19. Investments from Aramco, BP, Equinor, Exxon, Petrobras, TOTAL and Shell are included.
The lowest-cost projects are not “easy oil”. The most economical project in the entire sample, at $17M/kboed, has a complex gas cap with a risk of asphaltene precipitation. Also in the ‘Top 5’ are an Arctic greenfield, an ultra-deepwater carbonate with unusually high-CO2 and an ultra-high pressure deep-water field. Economical development depends on leading technology.
To see the projects included in the analysis, please download the data-file…
The CO2 content of gas fields is going to matter increasingly, for future gas development decisions: CO2 must be lowered to 50ppm before gas can be liquefied, adding cost. Moreover, it is no longer acceptable to vent the separated CO2 into the atmosphere.
Large, low-CO2 resources like the Permian, Marcellus and Mozambique are well-positioned to dominate future LNG growth.
This data-file tabulates 30 major gas resources around the world, their volumes, their CO2 content and how the CO2 is handled.