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Multi-layer commingling production capacity prediction method based on shaft multi-permeability coupling

A productivity prediction and multi-layer commingled production technology, applied in the field of oil and gas exploration, can solve the problems of reservoir permeability considerations and low accuracy of productivity prediction models, and achieve the effect of productivity prediction

Pending Publication Date: 2022-06-17
中海石油(中国)有限公司海南分公司 +1
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  • Application Information

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Problems solved by technology

Although it comprehensively considers the rock fracture mechanics of the reservoir, the flow characteristics of crude oil and the scale of geological reserves to predict the production capacity, it does not consider the permeability of different scales of the reservoir, making the overall production capacity Predictive models are not accurate enough

Method used

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  • Multi-layer commingling production capacity prediction method based on shaft multi-permeability coupling
  • Multi-layer commingling production capacity prediction method based on shaft multi-permeability coupling
  • Multi-layer commingling production capacity prediction method based on shaft multi-permeability coupling

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no. 1 example

[0066] like Figure 1 to Figure 3 Shown is a first embodiment of a multi-layer commingled production productivity prediction method based on wellbore multi-permeability coupling, comprising the following steps:

[0067] S1: acquiring logging data of wells in the target area, the logging data includes one or more of core test analysis data, wireline formation test data, and DST test data, as well as conventional logging data;

[0068] S2: Determine whether the target logging has cable formation test data, and if so, perform mobility transformation on the pressure pre-test data in the cable formation test data to obtain the pressure pre-test permeability, and perform the cable pumping test in the cable formation test data. Carry out the pumping pressure data interpretation to obtain the permeability of the pumping test well, and use the conventional logging data to couple the permeability of the pressure pre-test permeability and the permeability of the pumping test well to obta...

Embodiment 2

[0112] The only difference between this embodiment and Embodiment 1 is that when there is only conventional logging data, in step S2 in this embodiment, the permeability in the conventional logging data combined with the absolute permeability in the core test analysis data is used to conduct permeation. rate coupling, the continuous effective permeability profile is obtained as follows:

[0113] Select the absolute permeability of nuclear magnetic logging or flow unit subdivision or porosity-permeability correlation method, refer to the DST well test to explain the permeability and the relative permeability law of the core test area, and establish the relationship between the logging permeability and the oil phase relative permeability according to the flow unit. Fit the relational model and correct the permeability explained by the flow unit to obtain a continuous continuous effective permeability profile.

Embodiment 3

[0115] The only difference between this embodiment and Embodiment 1 or Embodiment 2 is that in this embodiment, the well logging is qualitatively analyzed according to the logging curve. When it is weak, in this embodiment, based on conventional logging data, the vertical heterogeneity is finely described and sub-layers are divided, and the permeability upscaling normalization for the continuous effective permeability profile specifically includes the following steps:

[0116] S321: Log the target well, find out all target oil layers, record the layer thickness of each target oil layer, and use conventional logging ELAN interpretation for each target oil layer to obtain the initial value of static permeability for reference;

[0117] S322: Based on the thickness-weighted arithmetic mean method, the thickness, piezometric fluidity and absolute permeability are scaled up to obtain the large-scale dynamic oil phase effective permeability.

[0118] In this embodiment, the producti...

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Abstract

The invention belongs to the technical field of petroleum and natural gas exploration, and particularly relates to a shaft multi-permeability coupling multilayer commingling production capacity prediction method which comprises the following steps: when cable formation test data exist, carrying out fluidity conversion on pressure pre-test data in the cable formation test data to obtain pressure pre-test permeability; carrying out pumping pressure data interpretation on cable pumping test data in the cable formation test data to obtain pumping well test permeability, and carrying out permeability coupling on the pressure pre-test permeability and the pumping well test permeability by utilizing conventional logging data to obtain a continuous effective permeability profile; if only the conventional logging information exists, permeability coupling is carried out according to the conventional logging information, and a continuous effective permeability profile is obtained; permeability upscaling normalization is carried out on the continuous effective permeability profile and conventional logging information, and large-scale dynamic effective permeability is obtained; and carrying out productivity prediction on the target layer section based on the large-scale dynamic oil phase permeability, the layer thickness of the target oil layer and the fluid viscosity.

Description

technical field [0001] The invention belongs to the technical field of oil and natural gas exploration, and more particularly relates to a multi-layer commingled production productivity prediction method based on the coupling of multi-permeability of the wellbore. Background technique [0002] Offshore low-permeability oil and gas fields have high development costs and high technical and economic risks. Accurate reservoir permeability evaluation and productivity prediction are of great significance for well completion design, scheme and production optimization. However, low-permeability reservoirs have strong heterogeneity, complex and variable pore structure, and complex electrical characteristics. The static permeability evaluation method and process based on conventional logging are difficult to accurately describe permeability, and it is difficult to directly predict single-well productivity. . In addition, offshore DST testing and completion testing operations are more...

Claims

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Application Information

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Patent Type & Authority Applications(China)
IPC IPC(8): E21B47/00E21B49/00
CPCE21B47/00E21B49/00
Inventor 杨冬汤翟张恒荣胡向阳吴一雄袁伟谭伟刘土亮杨毅骆玉虎
Owner 中海石油(中国)有限公司海南分公司
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