相渗透率改善剂驱油效果的实验研究
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摘要
聚合物驱时驱油效率的提高是不增加宏观压力梯度的微观力引起的,驱替液的弹性会改变孔隙中的微观流线,从而增加作用于残余油团突出部位的微观作用力,使突出部位移动,从而增加了聚合物驱的驱油效率。
微观力具有以下特点。粘弹性流体可以产生比牛顿流体更大的微观力,只要有少部分突出部位被微观力推动就可能可观地提高采收率,即使微观力比宏观压力梯度小也可能使残余油团移动,由流线改变而产生的微观力不影响宏观压力梯度,宏观力不变条件下,微观力可以变化,粘弹性流体驱时,微观力为独立变量
表征流体弹性的参数,如第一法向应力差、松弛时间、德博拉数、威森博格数等等,用不同的参数表征的效果不同。在简化的二维非等径孔隙模型中,粘弹性流体流线的变化程度是由威森博格数(We)决定的,We越大,粘弹性流体流线改变的幅度越大,“可变直径活塞效应”应该更加显著,使黏弹性流体的驱油效率更大。因此在本实验中,采用威森博格数We定量表征影响驱油效率的聚合物溶液黏弹性的大小。威森博格数越大,聚合物溶液的黏弹性越大,驱油效率也增加。
通过水溶性的醋酸铬-HPAM凝胶在亲水岩心和亲油岩心中的驱替过程,观察不同大小的孔隙中流体饱和度的变化规律,并对不同孔隙中油、水的驱替进行分析,从而得到亲水岩心和亲油岩心在宏观状态下,在不同驱替过程中的驱替结果的机理认识。
在凝胶驱前的油水驱过程中,含水饱和度改变对于贝雷砂岩的孔隙大小是不敏感的,在较小的聚乙烯孔隙中,油大部分是不可移动的;在凝胶驱后的油和水驱,油的注入减少了贝雷砂岩中的凝胶的体积,贝雷砂岩中的残余水饱和度在凝胶驱后比之前高,在后续的水驱过程中,油被圈闭在贝雷砂岩中,在聚乙烯岩心中,在后续水驱中没有圈闭额外的油。胶凝液的注入使两种多孔介质中的油发生流动,即使在胶凝液驱替的过程中压力梯度比在前面的驱替过程中的压力梯度要小。
在贝雷砂岩或者是聚乙烯岩心中,在凝胶驱后立刻产生了水相流动的极高阻力(Frrw>10000),推测起来是因为不可渗透凝胶占据了几乎所有的亲水孔隙空间。在贝雷砂岩凝胶驱后的油的流动过程中,许多凝胶被破坏了或者是体积减少,因此导致了相对高的油相渗透率(Frro=15)。
为了筛选适合现场岩心的RPM,通过对不同浓度、注入量、注入压力驱油效果比较,结果注入浓度为1000mg/l、注入量为0.4PV改善剂,注入压力为0.3MPa的采收率和累积产油量提高幅度最大,最终采收率最高。在水驱基础上,在该条件下注入改善剂:非均质岩心注入改善剂驱油效果明显好于均质岩心。改善剂驱油中压力变化、流出水中善剂浓度,可增加改善剂的流动性。
本研究中利用不同聚合物质量浓度的RPM,在不同润湿性的岩心上,在水驱使产出液含水达到98%以后,又进行了以延迟交联的胶凝液模拟的聚合物驱,注入胶凝液的过程在产出液含油少于2%后停止,然后等待胶凝液胶凝后,进行凝胶驱的后续水驱,结果如下:
亲水岩心的水驱阶段采收率比亲油岩心的高,这是因为亲油岩心中小的孔隙中的油没有受到影响,而亲水岩心中无论大小孔隙中都有水进入驱替孔隙中的油。
在亲油岩心中,由于不同聚含量的RPM黏弹性的不同,随着威森伯格数的增加,其聚驱的采收率随聚含量增加而增加,最低含水率也随之发生变化;后续的凝胶驱由于受到前期聚驱采出程度的影响,随着RPM聚含量增加,采收率增大后减小。累积产油量的变化趋势与采收率变化相近;
在亲水岩心中,在不同聚含量条件下,聚驱采收率效果与亲油岩心中的一致,而凝胶驱采收率比较低,这是由于注入的凝胶圈闭了大量的残余油。累积产油量变化趋势与采收率变化相近;
通过注入RPM前后渗透率以及相对渗透率曲线的变化,我们看到了实验中所采用的RPM的DPR效果。这是因为在油注入过程中打开了一条流动通道,是通过凝胶的脱水打开的。在后续的注入水的过程中,在凝胶重新水化的过程中,通道可能会部分关闭。
The increase in displacement efficiency of polymer flooding can only be caused by micro forces which do not increase the macro pressure gradient, the elasticity of driving fluid can change the microflow lines in porous media, the increase the micro force which acting on the protruding part of residual oil blob and mobilize the protruding part, so the displacement efficiency of polymer flooding increase.
Micro forces have the following characteristics. Viscoelastic fluid can produce more micro forces than the Newtonian fluid, it can largely increase the displacement efficiency of polymer flooding that the micro forces mobilize the small protruding part. Even if the micro forces is smaller the macro pressure gradient, it can move the residual oil blob,the micro forces that are created by the change in flow lines can’t impact macro pressure gradient; it can change but macro forces don’t change, and it is independent variable in viscoelastic fluid flooding.
The parameters characterizing fluid elastic are First normal stress difference, Relaxation time,Deborah number,Storage module, and Weissenberg number, and different parameters have different effects. In the simplified two-dimensional model of the non-equant diameter pore, the degree of change in flow lines for viscoelastic fluid is determined by weissenberg number, weissenberg number is larger and the range of degree is biger, and the piston effect of variable diameter is more significant, and it has larger displacement efficiency of viscoelastic fluid. Then in this research, it is quantitatively characterized the size of the viscoelastic polymer solution that impact on oil displacement efficiency by Weissenberg number. weissenberg number is larger, the viscoelastic polymer solution is bigger, and displacement efficiency increase.
By the placement of water-soluble Cr(Ⅲ)-acetate-HPAM gel in water-wet and oil-wet cores, we research variation of fluid saturation in different size pores, and analyze the oil and water flooding in defferent pores, then recognize the flooding mechanism of water-wet and oil wet cores that is in macroscopic state in different flooding course.
During water and oil flooding before gel placement, pores of all size rages in Berea experienced significant gains in water saturation, in contrast in polyethylene, oil was largely immobile in smaller pores; During oil flow after gel placement in Berea, much of the gel was destroyed or experienced a reduction in volume, Swr after gel placement is higher than that before gel placement, oil was traped in Berea in follow-up water flooding, and in polyethylene. extra oil wasn’t traped in follow-up water flooding. Injection of gelant mobilized oil in both porous media even though the pressure gradients during gelant placement were less than those during previous floods.
In Berea or polyethylene, immediately after gel placement,an extremely high resistance to water flow occurs, presumably because impermeable gel occupies nearly all of the aqueous pore space. During oil fow after gel placement in Berea, much of the gel was destroyed or experienced a reduction in volume, thus leading to a relatively high permeability to oil. In order to select suitable RPM for-on site core, efficiency that is in different polymer concentration, injection volume, injection pressure was contrasted, the result was that the displacement efficiency and cumulative oil production were largest margin of increase while polymer concentration was 1000mg/l, injection volume was 0.4PV, injection pressure was 0.3MPa. On the basis of water flooding, RPM was injected In the above conditions. Displacement effeciency was better in heterogeneous cores than in homogeneous cores. The result of pressure change in RPM flooding and HPAM and Cr concentration in effluent demonstrated that the RPM is illiquid, but if polymer concentration is lower, the RPM fluidity will increase.
This research adopted the RPM of different concentration, carried out polymer displacement that was simulated by delayed crosslined gelation in defferent wettability cores after the effluent in water flooding contained more than 98% water and the experiment was stopped. Injecting gelation process was stopped when the effluent contained less than 2% oil, and after the gel formed, follow-up water flooding carried on. The result is below.
The efficiency of water flooding in water-wet cores was higher than that in oil-wet cores, the cause was that the oil in the smallest cores wasn’t affected in oil-wet cores, in contrast, water entered all size cores and placed the oil out in water-wet cores.
In oil-wet cores, because of the different viscoelasticity of RPM in different polymer concentration, with the increase of Weissenberg number, efficiency of polymer placement increased and the lowest water content changed; follow-up gel flooding were affected by the recovery level of early polymer flooding and the recovery inceased then reduced with the increase of of polymer concentration of RPM. Cumulative oil production had the similar trend as recovery.
In water-wet cores, polymer recovery trends were same as that in oil-wet cores for different polymer concentration, in contrast, gel recovery were smaller because the gel traped large volume residual oil. Variation trend of cumulative oil production were similar as that of recovery.
Due to permeability change before and after gelation injection, and relative permeability curve change, DPR effect of RPM were indicated. The cause was that flow lines were opened during oil injection by gel dehydrating. During follow-up water injection, gel re-hydrated and the open lines closed.
微观力具有以下特点。粘弹性流体可以产生比牛顿流体更大的微观力,只要有少部分突出部位被微观力推动就可能可观地提高采收率,即使微观力比宏观压力梯度小也可能使残余油团移动,由流线改变而产生的微观力不影响宏观压力梯度,宏观力不变条件下,微观力可以变化,粘弹性流体驱时,微观力为独立变量
表征流体弹性的参数,如第一法向应力差、松弛时间、德博拉数、威森博格数等等,用不同的参数表征的效果不同。在简化的二维非等径孔隙模型中,粘弹性流体流线的变化程度是由威森博格数(We)决定的,We越大,粘弹性流体流线改变的幅度越大,“可变直径活塞效应”应该更加显著,使黏弹性流体的驱油效率更大。因此在本实验中,采用威森博格数We定量表征影响驱油效率的聚合物溶液黏弹性的大小。威森博格数越大,聚合物溶液的黏弹性越大,驱油效率也增加。
通过水溶性的醋酸铬-HPAM凝胶在亲水岩心和亲油岩心中的驱替过程,观察不同大小的孔隙中流体饱和度的变化规律,并对不同孔隙中油、水的驱替进行分析,从而得到亲水岩心和亲油岩心在宏观状态下,在不同驱替过程中的驱替结果的机理认识。
在凝胶驱前的油水驱过程中,含水饱和度改变对于贝雷砂岩的孔隙大小是不敏感的,在较小的聚乙烯孔隙中,油大部分是不可移动的;在凝胶驱后的油和水驱,油的注入减少了贝雷砂岩中的凝胶的体积,贝雷砂岩中的残余水饱和度在凝胶驱后比之前高,在后续的水驱过程中,油被圈闭在贝雷砂岩中,在聚乙烯岩心中,在后续水驱中没有圈闭额外的油。胶凝液的注入使两种多孔介质中的油发生流动,即使在胶凝液驱替的过程中压力梯度比在前面的驱替过程中的压力梯度要小。
在贝雷砂岩或者是聚乙烯岩心中,在凝胶驱后立刻产生了水相流动的极高阻力(Frrw>10000),推测起来是因为不可渗透凝胶占据了几乎所有的亲水孔隙空间。在贝雷砂岩凝胶驱后的油的流动过程中,许多凝胶被破坏了或者是体积减少,因此导致了相对高的油相渗透率(Frro=15)。
为了筛选适合现场岩心的RPM,通过对不同浓度、注入量、注入压力驱油效果比较,结果注入浓度为1000mg/l、注入量为0.4PV改善剂,注入压力为0.3MPa的采收率和累积产油量提高幅度最大,最终采收率最高。在水驱基础上,在该条件下注入改善剂:非均质岩心注入改善剂驱油效果明显好于均质岩心。改善剂驱油中压力变化、流出水中善剂浓度,可增加改善剂的流动性。
本研究中利用不同聚合物质量浓度的RPM,在不同润湿性的岩心上,在水驱使产出液含水达到98%以后,又进行了以延迟交联的胶凝液模拟的聚合物驱,注入胶凝液的过程在产出液含油少于2%后停止,然后等待胶凝液胶凝后,进行凝胶驱的后续水驱,结果如下:
亲水岩心的水驱阶段采收率比亲油岩心的高,这是因为亲油岩心中小的孔隙中的油没有受到影响,而亲水岩心中无论大小孔隙中都有水进入驱替孔隙中的油。
在亲油岩心中,由于不同聚含量的RPM黏弹性的不同,随着威森伯格数的增加,其聚驱的采收率随聚含量增加而增加,最低含水率也随之发生变化;后续的凝胶驱由于受到前期聚驱采出程度的影响,随着RPM聚含量增加,采收率增大后减小。累积产油量的变化趋势与采收率变化相近;
在亲水岩心中,在不同聚含量条件下,聚驱采收率效果与亲油岩心中的一致,而凝胶驱采收率比较低,这是由于注入的凝胶圈闭了大量的残余油。累积产油量变化趋势与采收率变化相近;
通过注入RPM前后渗透率以及相对渗透率曲线的变化,我们看到了实验中所采用的RPM的DPR效果。这是因为在油注入过程中打开了一条流动通道,是通过凝胶的脱水打开的。在后续的注入水的过程中,在凝胶重新水化的过程中,通道可能会部分关闭。
The increase in displacement efficiency of polymer flooding can only be caused by micro forces which do not increase the macro pressure gradient, the elasticity of driving fluid can change the microflow lines in porous media, the increase the micro force which acting on the protruding part of residual oil blob and mobilize the protruding part, so the displacement efficiency of polymer flooding increase.
Micro forces have the following characteristics. Viscoelastic fluid can produce more micro forces than the Newtonian fluid, it can largely increase the displacement efficiency of polymer flooding that the micro forces mobilize the small protruding part. Even if the micro forces is smaller the macro pressure gradient, it can move the residual oil blob,the micro forces that are created by the change in flow lines can’t impact macro pressure gradient; it can change but macro forces don’t change, and it is independent variable in viscoelastic fluid flooding.
The parameters characterizing fluid elastic are First normal stress difference, Relaxation time,Deborah number,Storage module, and Weissenberg number, and different parameters have different effects. In the simplified two-dimensional model of the non-equant diameter pore, the degree of change in flow lines for viscoelastic fluid is determined by weissenberg number, weissenberg number is larger and the range of degree is biger, and the piston effect of variable diameter is more significant, and it has larger displacement efficiency of viscoelastic fluid. Then in this research, it is quantitatively characterized the size of the viscoelastic polymer solution that impact on oil displacement efficiency by Weissenberg number. weissenberg number is larger, the viscoelastic polymer solution is bigger, and displacement efficiency increase.
By the placement of water-soluble Cr(Ⅲ)-acetate-HPAM gel in water-wet and oil-wet cores, we research variation of fluid saturation in different size pores, and analyze the oil and water flooding in defferent pores, then recognize the flooding mechanism of water-wet and oil wet cores that is in macroscopic state in different flooding course.
During water and oil flooding before gel placement, pores of all size rages in Berea experienced significant gains in water saturation, in contrast in polyethylene, oil was largely immobile in smaller pores; During oil flow after gel placement in Berea, much of the gel was destroyed or experienced a reduction in volume, Swr after gel placement is higher than that before gel placement, oil was traped in Berea in follow-up water flooding, and in polyethylene. extra oil wasn’t traped in follow-up water flooding. Injection of gelant mobilized oil in both porous media even though the pressure gradients during gelant placement were less than those during previous floods.
In Berea or polyethylene, immediately after gel placement,an extremely high resistance to water flow occurs, presumably because impermeable gel occupies nearly all of the aqueous pore space. During oil fow after gel placement in Berea, much of the gel was destroyed or experienced a reduction in volume, thus leading to a relatively high permeability to oil. In order to select suitable RPM for-on site core, efficiency that is in different polymer concentration, injection volume, injection pressure was contrasted, the result was that the displacement efficiency and cumulative oil production were largest margin of increase while polymer concentration was 1000mg/l, injection volume was 0.4PV, injection pressure was 0.3MPa. On the basis of water flooding, RPM was injected In the above conditions. Displacement effeciency was better in heterogeneous cores than in homogeneous cores. The result of pressure change in RPM flooding and HPAM and Cr concentration in effluent demonstrated that the RPM is illiquid, but if polymer concentration is lower, the RPM fluidity will increase.
This research adopted the RPM of different concentration, carried out polymer displacement that was simulated by delayed crosslined gelation in defferent wettability cores after the effluent in water flooding contained more than 98% water and the experiment was stopped. Injecting gelation process was stopped when the effluent contained less than 2% oil, and after the gel formed, follow-up water flooding carried on. The result is below.
The efficiency of water flooding in water-wet cores was higher than that in oil-wet cores, the cause was that the oil in the smallest cores wasn’t affected in oil-wet cores, in contrast, water entered all size cores and placed the oil out in water-wet cores.
In oil-wet cores, because of the different viscoelasticity of RPM in different polymer concentration, with the increase of Weissenberg number, efficiency of polymer placement increased and the lowest water content changed; follow-up gel flooding were affected by the recovery level of early polymer flooding and the recovery inceased then reduced with the increase of of polymer concentration of RPM. Cumulative oil production had the similar trend as recovery.
In water-wet cores, polymer recovery trends were same as that in oil-wet cores for different polymer concentration, in contrast, gel recovery were smaller because the gel traped large volume residual oil. Variation trend of cumulative oil production were similar as that of recovery.
Due to permeability change before and after gelation injection, and relative permeability curve change, DPR effect of RPM were indicated. The cause was that flow lines were opened during oil injection by gel dehydrating. During follow-up water injection, gel re-hydrated and the open lines closed.
引文
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