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A process and technology of compound acid, which is applied in the direction of drilling composition, production fluid, wellbore/well parts, etc., can solve the problems of inconspicuous effect and short validity period, and achieve the elimination of inorganic pollution, long validity period, and improvement of effective penetration rate effect
Active Publication Date: 2008-10-15
DAQING HUILIAN TECH DEV
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The commonly used plugging removal method is acidification plugging r
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Embodiment 1
[0036] Embodiment 1. Simulating the actual formation temperature and pressure, passing the compound acid and the active agent successively through the natural core to carry out the plugging removal flow simulation test of the core, and judging the effect of plugging removal by the change of standard brine permeability before and after the injection of the compound plugging removal fluid.
[0037] η=(Kw-Kw 0 ) / Kw×100%
[0038] In the formula, η-permeability increase rate, %
[0039] k 0 - Annotate the initial hydraulic permeability of the core before liquid plugging, ×10 -3 μm 2 ;
[0040] Kw-the hydraulic permeability of the core after annotating liquid plugging, ×10 -3 μm 2 .
[0041] Core physical simulation experiment data Table 3
[0042]
[0043] The average increase rate of core permeability is 100.81%.
Embodiment 2
[0044] Example 2. Field test of tertiary infill wells in the west block of South 6 District:
[0045] 1. Geological characteristics of test wells and analysis of reasons for poor water absorption conditions
[0046] According to the actual injection status of the test well, through the analysis of the reservoir minerals and fluid physical properties in the tertiary infill well area of the west block of South 6 Block, combined with the logging results of the water absorption profile of the test well, the main reasons for the poor water absorption are as follows:
[0047] (1) The reservoir has poor homogeneity, uneven water absorption, serious conflicts between layers, and some layers do not absorb water;
[0048](2) The reservoir is a thin and dirty oil layer with poor fluidity, weak water absorption capacity, medium velocity sensitivity, medium strong water sensitivity, medium strong salt sensitivity, medium strong acid sensitivity, and medium strong alkali sensitivity. Conv...
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Abstract
The invention relates to a HAS composite plug removal process, comprising two parts that: firstly, compound acid is injected into a wellhead of a water injection well by adopting a high pressure pump; secondly, after the interval between 5 to 24 hours, an active agent is injected in by using a high concentration slug or an instillation device, wherein the compound acid is formed by the following composition in percentage by weight: 10 to12 percent of hydrochloric acid, 1 to 2 percent of hydrofluoric acid, 8 to 10 percent of fluoboric acid, 2 percent of glacial acetic acid, 2.0 percent of corrosion inhibitor, 0.1 to 0.2 percent of citric acid, 4.0 to 6.0 percent of isobutanol and 68 to 72 percent of water; the active agent is formed by the following composition in percentage by weight: 0.1 to 0.2 percent of negative nonionic surfactant, 0.3 to 0.5 percent of sodium chloride, the balance being water; the corrosion inhibitor is formed by compositely preparing hexamethylene tetramine and formaldehyde in the proportion of 1 to 1; the negative nonionic surfactant is formed by compositely preparing petroleum benzene sulfonic acid sodium salt and fatty acid alkanolamide in the proportion of 1 to 1. The composite plug removal agent has the effect in the comprehensive plug removal for near bore zones and the deep parts of oil layers, which is long in valid period and obvious in plug removal effect.
Description
Technical field: [0001] The invention relates to a blocking removal technology for water injection wells in the field of oil production, in particular to an HSA composite blocking removal technology. Background technique: [0002] In low-permeability oilfields, the reservoirs are poorly developed, the pore radius of the reservoirs becomes significantly smaller, the clay content and shale content increase significantly, and the median grain size decreases significantly. Slight clogging of this type of oil layer during water injection development can cause injection pressure to rise, making injection difficult. At the same time, the characteristics of small pores, enhanced pore-throat effect, and high specific surface directly have a significant impact on fluid flow, and the lower the permeability, the stronger the impact. As the injected water continues to advance, the seepage resistance increases rapidly, the injection pressure rises rapidly, and the water injection volume ...
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