A neutron logging method and system for coupled formation density and porosity measurements

By using high-energy neutron source logging methods, combined with iterative calculations of thermal neutron count ratio and inelastic gamma count ratio, the problems of large size, high complexity, and radiation hazards of traditional logging instruments have been solved, achieving high-precision and efficient formation density and porosity measurement.

CN115755205BActive Publication Date: 2026-05-29ZHONGKE CHAOAN TECH CO LTD
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Patent Information

Authority / Receiving Office
CN · China
Patent Type
Patents(China)
Current Assignee / Owner
ZHONGKE CHAOAN TECH CO LTD
Filing Date
2022-10-14
Publication Date
2026-05-29

AI Technical Summary

Technical Problem

Traditional formation density and porosity measurement instruments are large, complex to operate, costly, and pose significant radiation hazards. Existing dual-function logging methods are greatly affected by lithology, have complex data processing, and are slow in logging speed.

Method used

The high-energy neutron source logging method is adopted. By establishing a model of formation porosity and thermal neutron count ratio and non-elastic gamma count ratio, the formation density and porosity are calculated iteratively. The thermal neutron count ratio is used to replace the captured gamma rays, which reduces the influence of lithology and simplifies the instrument design.

Benefits of technology

It improves logging accuracy and efficiency, reduces instrument complexity and data processing difficulty, reduces radiation hazards, and simplifies operation procedures.

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Abstract

The present application belongs to the technical field of well logging, and particularly relates to a neutron logging method and system for coupling measurement of formation density and porosity, which comprises the following steps: bringing a preset formation density and a thermal neutron count ratio of a target formation of a well to be measured into a formation porosity model to obtain a first formation porosity of the target formation of the well to be measured; bringing the first formation porosity and an inelastic gamma count ratio of the target formation of the well to be measured into a formation density model to obtain a first formation density of the target formation of the well to be measured; iteratively using the models to obtain the first formation density and the first formation porosity until a preset condition is met; determining the first formation porosity meeting the preset condition as the formation porosity of the target formation of the well to be measured, and determining the first formation density meeting the preset condition as the formation density of the target formation of the well to be measured. The present application has high measurement precision and high well logging efficiency.
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