This data-file calculates the CO2 intensity of oilfield supply chains, across ten different resources, as materials are transported to drilling rigs, frac crews, production platforms and well pads.
Different resources can be ranked on this measure of supply chain CO2-intensity: such as the Permian, the Gulf of Mexico, offshore Norway, Guyana, pre-salt Brazil and Middle East onshore production (chart above).
Underlying the calculations are modeling assumptions, for both onshore and offshore operations, each based on c15 input variables. You can change the inputs to run your own scenarios, or test the most effective ways to lower supply-chain CO2.
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 fieldswill 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 emissionsassociated 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 download is a full economic modelfor the development of Exxon, Hess and CNOOC-Nexen’s Stabroek block in Guyana.
The output is our base case expectation for the block’s ultimate value, resources, production volumes, cash flows, capex and per-barrel economics.
Sensitivities can modeledas a function of oil prices, WACCs, resource volumes and other costs.
Exploration resultsto-date are also tabulated in the ‘E&A’ tab, underpinning our resource estimates.
After the COVID crisis, our NAV estimate has arguably increased by c9%, despite oil crashing in 2020 and a 1-year delay to FPSOs 4&5.
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