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US 11,692,439 B2Granted
Systems and methods for estimating pore pressure at source rocks
AssigneeSaudi Arabian Oil Company
InventorAngelica Maria Rios Alvarez
Life of this patent
Estimating the term…
Abstract
Systems and methods to estimate a pore pressure of source rock include a pore pressure estimation processor, an executable, or both, and are operable to (i) calculate an estimate pore pressure based on overburden gradient data, a compaction velocity profile, hydrocarbon maturity, and an unloading velocity profile, (ii) determine a total organic content (TOC) estimate of the source rock based on a bulk density at a vertical depth measured using the density logging tool, (iii) determine a correction factor based on (a) the TOC estimate and (b) vitrinite ratio Ro data, and (iv) update the estimated pore pressure in real-time based on the correction factor.
Claims19
A pore pressure estimation system comprising:
- a density logging tool configured to measure a bulk density of source rock at a vertical depth, wherein the density logging tool comprises a gamma ray source transmitting gamma rays into the source rocks-, and a detector configured to generate a density detection signal from a portion of the gamma rays that are scattered by the source rock, wherein a pore pressure estimation processor is operable to determine a total organic content (TOC) estimate of the source rock based on density detection signals;
- a model module comprising a regional model for a region of source rock and a source rock model for source rock of a well bore, the source rock model of the model module comprising vitrinite ratio Ro data for the source rock defining hydrocarbon maturity in the source rock, the regional model of the model module comprising regional data associated with the region of the source rock, the regional data comprising overburden gradient data defining overburden stress of the source rock in the region, a compaction velocity profile of the source rock in the region as a function of effective stress, and an unloading velocity profile of the source rock as a function of effective stress including pore overpressure and hydrocarbon maturity;
- the pore pressure estimation processor communicably coupled to the density logging tool and the model module, and being operable to calculate an estimated pore pressure based on the overburden gradient data, the compaction velocity profile, the hydrocarbon maturity, and the unloading velocity profile, determine the TOC estimate of the source rock based on the bulk density at the vertical depth using the density logging tool, determine a correction factor based on (i) the TOC estimate and (ii) the vitrinite ratio Ro data, and update the estimated pore pressure in real-time based on the correction factor.
A pore pressure estimation system comprising:
- a density logging tool disposed in a well bore and is configured to measure a bulk density of source rock at a vertical depth, wherein the density logging tool comprises a gamma ray source transmitting gamma rays into the source rocks-, and a detector configured to generate a density detection signal from a portion of the gamma rays that are scattered by the source rock, wherein a pore pressure estimation processor is operable to determine a total organic content (TOC) estimate of the source rock based on density detection signals;
- a model module comprising a regional model for a region of source rock and a source rock model for source rock of a well bore, the source rock model of the model module comprising vitrinite ratio Ro data for the source rock defining hydrocarbon maturity in the source rock, the regional model of the model module comprising regional data associated with the region of the source rock, the regional data comprising overburden gradient data defining overburden stress of the source rock in the region, a compaction velocity profile of the source rock in the region as a function of effective stress, and an unloading velocity profile of the source rock as a function of effective stress including pore overpressure and hydrocarbon maturity;
- and
- the pore pressure estimation processor communicably coupled to the density logging tool and the model module, being operable to calculate an estimated pore pressure based on the overburden gradient data, the compaction velocity profile, the hydrocarbon maturity and the unloading velocity profile, determine the TOC estimate of the source rock based on the bulk density at the vertical depth using the density logging tool, determine a correction factor based on (i) the TOC estimate and (ii) the vitrinite ratio Ro data, and update the estimated pore pressure in real-time based on the correction factor such that the correction factor is added to the estimated pore pressure calculated based on the overburden gradient data, the compaction velocity profile, the hydrocarbon maturity, and the unloading velocity profile.
1 more element
A method comprising:
- calculating, via a pore pressure estimation processor, an estimated pore pressure based on regional data of a regional model for a region of source rock of a well bore, the regional data of the regional model comprising overburden gradient data defining overburden stress of the source rock in the region, a compaction velocity profile of the source rock in the region as a function of effective stress, and an unloading velocity profile of the source rock as a function of effective stress and hydrocarbon maturity;
- determining a total organic content (TOC) estimate of the source rock based on a bulk density at a vertical depth, wherein the bulk density at the vertical depth is estimated using a density logging tool that is configured to estimate the bulk density at the vertical depth, wherein the density logging tool comprises a gamma ray source transmitting gamma rays into the source rock, and a detector configured to generate a density detection signal from a portion of the gamma rays that are scattered by the source rock, wherein the pore pressure estimation processor is operable to determine the TOC estimate of the source rock based on density detection signals;
- determining a correction factor based on (i) the TOC estimate and (ii) vitrinite ratio R0 data for the source rock defining hydrocarbon maturity in the source rock;
- and
- updating, via the pore pressure estimation processor, the estimated pore pressure in real-time based on the correction factor.
2 more elements
Dependencies are inferred from the claim text.