WO2020248740A1 - 一种整体调堵边底水稠油油藏水侵和汽窜的方法 - Google Patents

一种整体调堵边底水稠油油藏水侵和汽窜的方法 Download PDF

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WO2020248740A1
WO2020248740A1 PCT/CN2020/088123 CN2020088123W WO2020248740A1 WO 2020248740 A1 WO2020248740 A1 WO 2020248740A1 CN 2020088123 W CN2020088123 W CN 2020088123W WO 2020248740 A1 WO2020248740 A1 WO 2020248740A1
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steam
water
well
injected
volume
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PCT/CN2020/088123
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English (en)
French (fr)
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鹿腾
李兆敏
李宾飞
李松岩
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中国石油大学(华东)
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Priority to US17/596,156 priority Critical patent/US11719081B2/en
Publication of WO2020248740A1 publication Critical patent/WO2020248740A1/zh

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium

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  • the invention belongs to the technical field of oil and gas field development, and specifically relates to a method for integrally regulating and plugging the water invasion and steam channeling of a heavy oil reservoir with edge and bottom water.
  • Heavy oil refers to crude oil with a crude oil viscosity greater than 50 mPa ⁇ s under oil layer conditions or a degassed crude oil viscosity greater than 100 mPa ⁇ s at oil layer temperature and a relative density greater than 0.92.
  • the predicted resource of heavy oil in China is about 198 ⁇ 10 8 t.
  • steam huff and puff production accounts for more than 70% of heavy oil production.
  • the formation energy in the heavy oil reservoir gradually decreases, and there is no external energy supplement.
  • the bottom of the huff and puff well will produce a pressure deficit, and the edge and bottom water will invade the inside of the oil layer under the action of the pressure difference, which will cause water flooding in the oil layer, and the water cut will rise rapidly, which will affect the development effect.
  • steam channeling between huff and puff wells will also affect the steam huff and puff development effect. Therefore, after multiple rounds of steam huff and puff in heavy oil reservoirs with edge and bottom water, water invasion and steam channeling are serious, and the steam huff and puff effect becomes poor.
  • the purpose of the present invention is to provide a method for integrally plugging the water invasion and steam channeling of heavy oil reservoirs with edge and bottom water in view of the above existing problems.
  • This method adopts integral plugging control technology, and injects high-strength nitrogen foam system and nitrogen foam system respectively through well rows at different positions in the reservoir. Effective sealing walls are formed at different positions from the edge and bottom water to slow down water invasion and steam channeling. .
  • the technical scheme of the present invention is: a method for integrally adjusting and plugging the water invasion and steam channeling of heavy oil reservoirs with edge and bottom water, including the following steps:
  • Reservoir selection Applicable reservoirs are coarsely screened according to the following conditions: the reservoir is a heavy oil reservoir with edge and bottom water, the viscosity of ground degassed crude oil at 50°C is ⁇ 100000mPa ⁇ s, and the reservoir depth is ⁇ 1000m, which is effective The thickness is greater than 5m, the initial oil saturation is greater than 0.5, the permeability is greater than 200mD, and the ratio of water volume to oil layer volume is less than 500;
  • Huff and puff wells drill huff and puff wells in the reservoir according to the arrangement of wells; huff and puff wells are vertical wells or horizontal wells; the number of well rows is determined according to the area of the reservoir, and at least three rows of huff and puff wells are set in the oil layer, two adjacent to each other.
  • the spacing between the well rows is 100-150m, and the spacing between two adjacent huff and puff wells in each well row is 100-150m; the well row near the water body is the first-line well row, and then the second-line well row and the third-line well row in sequence.
  • the distance between the first line of well rows and the water body is greater than 150m;
  • the volume ratio of the output fluid volume of the first-line well to the equivalent volume of injected steam cold water is less than 5; the volume ratio of the output fluid volume of the second line well to the equivalent volume of injected steam cold water is less than 10;
  • the ratio of the volume of produced fluid from the third-line well discharge to the equivalent volume of injected steam and cold water is less than 20; the throughput parameters of the next cycle are the same as those of the first cycle;
  • high-strength nitrogen foam system is injected into the first-line well during steam injection stage, and the first-line well row reduces the periodic steam injection volume to 800-1000t. Nitrogen is injected along with the steam in the whole process. The injection volume is based on the downhole The gas-liquid ratio of the formed foam is calculated as 2:1; then the oil is produced after simmering the well for 3 to 5 days;
  • the nitrogen foam system is injected into the second-line well at the same time as the steam is injected, and the concentration of foaming agent is 0.5%; the second-line well's steam injection volume is 1500 ⁇ 1800t, and nitrogen is injected along with the steam.
  • the nitrogen injection volume is based on the foam gas-liquid ratio formed downhole It is calculated as 3:1; after the steam injection is finished, increase the simmering time to 5-6 days, and then open the well for production;
  • the nitrogen foam system is injected into the third-line well at the same time as the steam is discharged, and the concentration of foaming agent is 0.5%; the third-line well’s steam injection volume is 1500 ⁇ 2500t, and nitrogen is injected along with the steam in the whole process.
  • the nitrogen injection volume is based on the foam gas-liquid ratio formed downhole It is calculated as 4:1; after the steam injection, increase the simmering time to 6-8 days, and then start the well for production.
  • the high-strength nitrogen foam system selects a solid-phase particle reinforced foam system or a high-temperature resistant gel foam system.
  • the concentration of solid-phase particles is 0.5-1%, and the concentration of foaming agent is 0.5%.
  • the solid particles in the solid particle reinforced foam system are fly ash, clay particles or nano particles.
  • the high temperature resistant gel foam system includes a high temperature resistant gel plugging agent first injected into the formation and a nitrogen foam injected simultaneously during steam huff and puff.
  • the high temperature resistant gel blocking agent is selected from tannin extract or temperature sensitive gel.
  • the injection volume of the high temperature resistant gel plugging agent is 30-50t.
  • the foaming agent concentration in the high temperature resistant gel foam system is 0.5%.
  • the present invention provides a method for integrally adjusting and blocking the water invasion and steam channeling of heavy oil reservoirs with edge and bottom water. With the increase of throughput rounds, the formation pressure gradually decreases, and water invasion and steam will occur.
  • This method adopts the overall plugging control technology, and the high-strength nitrogen foam system and the nitrogen foam system are respectively injected through the well rows at different positions in the reservoir. An effective sealing wall is formed at different positions from the edge and bottom water to slow down water invasion.
  • Steam channeling reduces the water content by 10-15% and the oil-steam ratio increases by 0.2-0.5%, thereby improving the overall development effect of multiple rounds of steam stimulation for heavy oil reservoirs with edge and bottom water.
  • At least 3 rows of huff and puff wells are arranged in the oil layer, and the distance of the wells is designed.
  • the distance between the first line of wells and the water body is greater than 150m. If the distance is less than 150m, the steam huff and puff development of the first line of wells is very It is easy to communicate with the edge and bottom water, causing rapid intrusion of water bodies and affecting development effects.
  • the distance between two adjacent rows of wells is 100-150m, and the distance between two adjacent huff and puff wells in each row is 100-150m.
  • the three types of well rows have different distances from the edge and bottom water, and different types of technologies can be developed in sequence to achieve the effect of mitigating water invasion and steam channeling.
  • the relationship between the amount of steam injected and the amount of liquid produced by the huff and puff well and the injected steam and cold water is also designed.
  • the first-line well row is close to the water body, and the injected steam volume is too large to connect the water body, and the second-line well row and the third line
  • the well row gradually becomes farther from the water body, and the steam injection volume gradually increases.
  • the ratio of the output fluid volume of the first-line well row to the equivalent volume of injected steam and cold water should be less than 5, otherwise, if the production time of the first-line well row is long and the output fluid volume is too large, it will cause the water body to invade quickly;
  • the equivalent volume ratio of injected steam and cold water should be less than 10, otherwise if the production time of the second-line well row is long and the produced liquid volume is too large, it will also cause rapid water intrusion.
  • the ratio of the volume of fluid produced by the third-line well row to the equivalent volume of injected steam and cold water should be less than 20. Otherwise, if the production time of the third-line well row is long and the produced fluid volume is too large, it will also cause the water body to invade quickly. The cycle is consistent.
  • Fig. 1 is a schematic diagram of the arrangement of throughput wells in a specific embodiment of the present invention.
  • Fig. 2 is a schematic diagram of water invasion and steam channeling in a specific embodiment of the present invention.
  • Figure 3 is a schematic diagram of overall plugging adjustment in a specific embodiment of the present invention.
  • the method for integrally regulating and plugging the water invasion and steam channeling of heavy oil reservoirs with edge and bottom water includes the following steps:
  • a block is a heavy oil reservoir with edge and bottom water, with an oil-bearing area of 6.0km 2 , a surface degassed crude oil viscosity of 3,983mPa ⁇ s at 50°C, a buried depth of 940m, an effective thickness of 7m, and initial oil saturation Degree 0.65, permeability 2520mD, ratio of water volume to oil layer volume 350;
  • Huff and puff wells drill huff and puff wells in the reservoir according to the arrangement of wells; huff and puff wells are horizontal wells; the number of well rows is determined according to the area of the reservoir, and three rows of huff and puff wells are set in the oil layer, as shown in Figure 1.
  • the well row closest to the water body is the first-line well row (#1, #2, #3), the well row slightly farther from the water body is the second-line well row (#4, #5, #6), and the well row farthest from the water body It is a three-line well row (#7, #8, #9), in which the distance between the first-line well row and the water body is 200m; the distance between two adjacent rows of well rows is 150m, and the distance between two adjacent wells in each row It is 150m.
  • the well is shut in when the ratio of the volume of produced fluid discharged from the third-line well to the equivalent volume of injected steam cold water is 15, that is, the volume of produced fluid discharged from the third-line well is 30,000 m 3 , and then the next cycle of steam huff and puff is performed, and the cycle parameters are consistent with the first cycle.
  • the oil production volume is less than 1 ton/day, the well is shut in, and then the next cycle of steam huff and puff is performed, and the huff and puff parameters of the next cycle are consistent with the first cycle.
  • the third-line well row (#7, #8, #9) farthest from the edge and bottom water is due to the distance from the water body. Therefore, the water cut rises slowly, but because there is no water energy supplement, the bottom hole pressure of the third-line well row drops faster.
  • the steam injected from the third-line well row is prone to steam channeling, #8 well Steam channeling occurred in wells #7 and #9, and the injected steam flowed through the formation in a large amount, which affected the development effect. Therefore, water invasion and steam channeling would greatly affect the multi-round steam stimulation development of edge-bottom water reservoirs.
  • the method adopts overall plugging adjustment technology, and the specific operations are as follows:
  • the water cut has risen from 35% to 92% at the beginning.
  • the water body has completely invaded the first-line well, and the first-line well row has steam injection in the third cycle.
  • the high temperature resistant gel foam system is simultaneously injected in the steam stage, and the high temperature resistant gel foam system includes the high temperature resistant gel plugging agent injected into the formation first and the nitrogen foam injected simultaneously during steam stimulation. Tannin extract is selected as the high temperature resistant gel blocking agent.
  • the injection volume of the high temperature resistant gel plugging agent is 30t, and then the nitrogen foam is injected while the steam is injected, and the concentration of the foaming agent is 0.5%.
  • the first-line well row reduces the periodic steam injection volume to 800t, and the nitrogen is injected along with the steam.
  • the injection volume is calculated based on the foam gas-liquid ratio of 2:1 formed downhole.
  • the calculated nitrogen injection volume is 96000m 3 ; then the well is simmered for 5 days and then oil is produced;
  • the well is shut in when the ratio of the volume of fluid produced from the well discharge to the equivalent volume of injected steam and cold water is 5, that is, the fluid volume of the first-line well is 4000m 3 .
  • the injected high-strength nitrogen foam system will form a high-strength blocking wall in the first-line well row.
  • the high-strength blocking wall will significantly slow down the intrusion rate of the water body.
  • reducing the amount of steam injection can prevent the steam from reconnecting with the bottom water to form a water intrusion channel ,As shown in Figure 3.
  • the nitrogen foam system is injected at the same time as the steam injection, and the concentration of foaming agent is 0.5%; the second-line well exhaust steam injection volume is 1600t, and nitrogen is injected with steam throughout the entire process.
  • the nitrogen injection volume is based on the foam gas liquid formed downhole When the ratio is 3:1, the nitrogen injection volume is 288000m 3 .
  • the increase in the amount of nitrogen injected can play the role of formation energy and delay the intrusion of side and bottom water; after the steam injection, increase the simmering time to 6 days. Extending the simmering time is conducive to the migration of nitrogen to the deep part of the formation and increases the elastic displacement of nitrogen. Oil energy.
  • the well was opened for production; the second-line well produced liquid volume to the injected steam and cold water equivalent volume ratio was 8 when the well was shut down, that is, the second-line well produced 12800m 3 of liquid.
  • the injected nitrogen foam will form a low-strength blocking wall in the second-line well row, and the low-strength blocking wall will further slow down the water invasion rate, as shown in Figure 3.
  • the third-line well row (#7, #8, #9) is far away from the edge and bottom water, and the impact of water intrusion is small, and the water cut is less than 60%.
  • the third-line well is easy to generate steam due to the rapid drop in formation pressure. Channeling.
  • the nitrogen foam system is injected at the same time of steam injection, and the concentration of foaming agent is 0.5%; the steam injection volume of the third-line well is 2500t, and the nitrogen is injected along with the steam.
  • the nitrogen injection volume is calculated based on the foam gas-liquid ratio of 4:1 formed downhole.
  • the nitrogen injection volume is 600,000 m 3 ; after the steam injection is completed, increase the simmering time to 8 days.
  • Extending the simmering time is conducive to the migration of nitrogen to the deep part of the formation, and then the well is opened for production.
  • the well is shut in, that is, the output fluid volume of the third-line well is 25,000 m 3 .
  • the average daily oil production increased by 27t/d
  • the average water cut decreased by 10.2%
  • the periodic oil-steam ratio increased by 0.08, achieving a good effect of controlling water invasion and steam channeling.
  • the formation pressure gradually decreases, water invasion and steam channeling occur, and the high-pressure edge and bottom water body will intrude into the oil layer, and the first-line well row (#1, #2, #3) closest to the water body will be injected
  • the steam easily communicates with the edge and bottom water to form a water invasion channel, which will cause the water cut of the first-line well to rise rapidly.
  • the average water cut increased from 35% to 92% at the initial stage.
  • the water has completely penetrated into the first-line well, and the second-line well row (#4, #5, #6) After 2 cycles of throughput, the average water cut increased from 21% to 75% at the initial stage, and the second-line well row has also been affected by the intrusion of side and bottom water.
  • the other steps are the same as the embodiment. The difference is that this comparative example adopts local plugging adjustment for the wells with serious water invasion and steam channeling in the block. The details are as follows: the water cut of #2 well in the first-line well row is as high as 94%.

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Abstract

公开了一种整体调堵边底水稠油油藏水侵和汽窜的方法。该整体调堵边底水稠油油藏水侵和汽窜的方法包括以下步骤：(1)选择油藏；(2)布吞吐井；(3)蒸汽吞吐开发；(4)整体调堵。该方法采取整体调堵技术，通过油藏内不同位置处的井排分别注入高强度氮气泡沫体系，在距离边底水不同位置均形成有效封堵墙，减缓水侵和汽窜。

Description

一种整体调堵边底水稠油油藏水侵和汽窜的方法 技术领域
本发明属于油气田开发的技术领域，具体的涉及一种整体调堵边底水稠油油藏水侵和汽窜的方法。
背景技术
稠油是指油层条件下原油粘度大于50mPa·s或在油层温度下脱气原油粘度大于100mPa·s，相对密度大于0.92的原油。中国稠油预测资源量约198×10 8t。随着常规稀油油藏勘探开发难度的增大，进一步提高稠油产量是维持我国产油量稳定，维护国家能源安全的重要保障。
目前蒸汽吞吐产量占稠油产量70％以上，但是对于含有边底水的稠油油藏，随着蒸汽吞吐轮次的增加，稠油油藏内地层能量逐渐下降，在没有外来能量补充的情况下，吞吐井井底会产生压力亏空，边底水在压差作用下侵入油层内部，从而造成油层内水淹，含水率迅速上升，影响开发效果；同时在油层内部，随着吞吐轮次的增加，吞吐井之间产生蒸汽窜流通道，也会影响蒸汽吞吐开发效果。因此边底水稠油油藏多轮次蒸汽吞吐后，水侵和汽窜严重，蒸汽吞吐效果变差。
发明内容
本发明的目的在于针对上述存在的问题而提供一种整体调堵边底水稠油油藏水侵和汽窜的方法。该方法采取整体调堵技术，通过油藏内不同位置处的井排分别注入高强度氮气泡沫体系和氮气泡沫体系，在距离边底水不同位置均形成有效封堵墙，减缓水侵和汽窜。
本发明的技术方案为：一种整体调堵边底水稠油油藏水侵和汽窜的方法，包括以下步骤：
(1)选择油藏：按照以下条件进行粗筛选适用的油藏：油藏为边底水稠油油藏，50℃下地面脱气原油粘度＜100000mPa·s，油藏埋深＜1000m，有效厚度大于5m，初始含油饱和 度＞0.5，渗透率＞200mD，水体体积与油层体积比小于500；
(2)布吞吐井：按照排状布井方式在油层内钻吞吐井；吞吐井为直井或水平井；根据油藏面积确定井排数目，油层内至少设置3列吞吐井排，相邻两列井排的间距为100～150m，每列井排内相邻两个吞吐井的间距为100～150m；靠近水体的一列井排为一线井排，然后依次为二线井排、三线井排，以此类推，其中一线井排与水体的距离大于150m；
(3)蒸汽吞吐开发：首先开始第一周期蒸汽吞吐，其中一线井排注入蒸汽量为1000～1200t，二线井排注入蒸汽量为1500～1800t，三线井排注入蒸汽量为2000～2200t；蒸汽注入后，焖井3～5天，焖井结束后开井生产，一线井排产出液量与注入蒸汽冷水当量体积比小于5；二线井排产出液量与注入蒸汽冷水当量体积比小于10；三线井排产出液量与注入蒸汽冷水当量体积比小于20；下一周期的吞吐参数与第一周期一致；
(4)整体调堵：随着吞吐轮次的增加，地层压力逐渐降低，发生水侵与汽窜，采取氮气泡沫整体调堵技术，具体操作如下：
①在一线井排含水率超过90％后，对一线井排注蒸汽阶段同时注入高强度氮气泡沫体系，一线井排降低周期蒸汽注入量至800～1000t，氮气随蒸汽全程注入，注入量根据井下形成的泡沫气液比为2:1计算；然后焖井3～5天后采油；
②二线井排注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；二线井排蒸汽注入量为1500～1800t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为3:1计算；注蒸汽结束后，提高焖井时间至5～6天，然后开井生产；
③三线井排注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；三线井排蒸汽注入量为1500～2500t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为4:1计算；注蒸汽结束后，提高焖井时间至6～8天，然后开井生产。
所述步骤(4)中高强度氮气泡沫体系选用固相颗粒强化泡沫体系或耐高温凝胶泡沫体系。
所述固相颗粒强化泡沫体系中固相颗粒浓度为0.5～1％，起泡剂浓度为0.5％。
所述固相颗粒强化泡沫体系中固相颗粒选用粉煤灰、粘土颗粒或纳米颗粒。
所述耐高温凝胶泡沫体系包括先向地层内注入的耐高温凝胶堵剂和蒸汽吞吐时同时注入的氮气泡沫。
所述耐高温凝胶堵剂选用栲胶或温敏凝胶。
所述耐高温凝胶堵剂的注入量为30～50t。
所述耐高温凝胶泡沫体系中起泡剂浓度为0.5％。
本发明的有益效果为：本发明提供了一种整体调堵边底水稠油油藏水侵和汽窜的方法，随着吞吐轮次的增加，地层压力逐渐降低，会发生水侵与汽窜，该方法采取整体调堵技术，通过油藏内不同位置处的井排分别注入高强度氮气泡沫体系和氮气泡沫体系，在距离边底水不同位置均形成有效封堵墙，减缓水侵和汽窜，使得含水率降低10～15％，油汽比增加0.2～0.5％，从而整体性地改善边底水稠油油藏多轮次蒸汽吞吐的开发效果。
为了实现整体调堵，在油层内至少布置3列吞吐井排，并对井排的距离进行了设计，其中一线井排与水体的距离大于150m，如果距离小于150m，一线井排蒸汽吞吐开发很容易与边底水沟通，造成水体的迅速侵入，影响开发效果。相邻两列井排的间距为100～150m，每列井排内相邻两个吞吐井的间距为100～150m。三种类型井排距离边底水的距离不同，可以依次开展不同类型的技术，从而达到缓解水侵和汽窜的作用。
所述方法中对于注入的蒸汽量以及吞吐井产出液量与注入蒸汽冷水之间的关系也进行了设计，一线井排距离水体较近，注入蒸汽量过大会连通水体，二线井排和三线井排距离水 体逐渐变远，蒸汽注入量逐渐增大。一线井排产出液量与注入蒸汽冷水当量体积比要小于5，否则如果一线井排的生产时间长，产出液量太大的话，会造成水体快速侵入；二线井排产出液量与注入蒸汽冷水当量体积比要小于10，否则如果二线井排的生产时间长，产出液量太大的话，也会造成水体快速侵入。三线井排产出液量与注入蒸汽冷水当量体积比要小于20，否则如果三线井排的生产时间长，产出液量太大的话，也会造成水体快速侵入，下周期吞吐参数与第一周期一致。
附图说明
图1为本发明具体实施方式中吞吐井的排布示意图。
图2为本发明具体实施方式中产生水侵与汽窜的示意图。
图3为本发明具体实施方式中整体调堵的示意图。
具体实施方式
下面通过实施例对本发明进行详细说明。
实施例1
所述整体调堵边底水稠油油藏水侵和汽窜的方法，包括以下步骤：
(1)选择油藏：某区块为边底水稠油油藏，含油面积6.0km 2，50℃下地面脱气原油粘度3983mPa·s，油藏埋深940m，有效厚度7m，初始含油饱和度0.65，渗透率2520mD，水体体积与油层体积比350；
(2)布吞吐井：按照排状布井方式在油层内钻吞吐井；吞吐井为水平井；根据油藏面积确定井排数目，油层内设置3列吞吐井排，如图1所示，距离水体最近的井排为一线井排(#1、#2、#3)，距离水体稍远的井排为二线井排(#4、#5、#6)，距离水体最远的井排为三线井排(#7、#8、#9)，其中一线井排与水体的距离为200m；相邻两列井排的间距为150m，每列井排内相邻两个吞吐井的间距为150m。
(3)蒸汽吞吐开发：首先开始第一周期蒸汽吞吐，其中一线井排注入蒸汽量为1200t，二线井排注入蒸汽量为1800t，三线井排注入蒸汽量为2000t；蒸汽注入后，焖井3天，焖井结束后开井生产，一线井排产出液量与注入蒸汽冷水当量体积比为4.5时关井，即一线井 排产出液量为5400m 3；二线井排产出液量与注入蒸汽冷水当量体积比为8时关井，即二线井排产出液量为14400m 3。三线井排产出液量与注入蒸汽冷水当量体积比为15时关井，即三线井排产出液量为30000m 3，然后进行下一周期蒸汽吞吐，周期吞吐参数与第一周期一致。当采油油量低于1吨/天后关井，然后进行下一周期蒸汽吞吐，下一周期的吞吐参数与第一周期一致。
(4)整体调堵：如图2所示，随着吞吐轮次的增加，地层压力逐渐降低，发生水侵与汽窜，高压的边底水体便会侵入到油层内部，距离水体最近的一线井排(#1、#2、#3)注入的蒸汽很容易与边底水连通形成水侵通道，这会导致一线井含水率迅速上升。距离边底水距离次之的二线井排(#4、#5、#6)也会受到水体侵入的影响，表现出含水率的提高。在边底水的能量补充下，一线井排和二线井排的地层压力并没有明显降低，离边底水最远的三线井排(#7、#8、#9)，由于距离水体较远，因此含水率上升较慢，但由于没有水体能量的补充，三线井排井底压力下降较快，加之地层非均质性的影响，三线井排注入的蒸汽很容易产生汽窜，#8井与#7、#9井都产生了汽窜，注入蒸汽在地层内大量窜流，影响开发效果，因此水侵和汽窜会极大地影响边底水油藏多轮次蒸汽吞吐开发。
所述方法采取整体调堵技术，具体操作如下：
①在一线井排(#1、#2、#3)吞吐2周期后，含水率由初期的35％上升至92％，此时水体已经完全侵入一线井内，一线井排第3周期蒸汽吞吐注蒸汽阶段同时注入耐高温凝胶泡沫体系，所述耐高温凝胶泡沫体系包括先向地层内注入的耐高温凝胶堵剂和蒸汽吞吐时同时注入的氮气泡沫。所述耐高温凝胶堵剂选用栲胶。耐高温凝胶堵剂的注入量为30t，然后注蒸汽的同时注入氮气泡沫，起泡剂的浓度为0.5％。一线井排降低周期蒸汽注入量至800t，氮气随蒸汽全程注入，注入量根据井下形成的泡沫气液比为2:1计算，计算得到氮气注入量为96000m 3；然后焖井5天后采油；一线井排产出液量与注入蒸汽冷水当量体积比为5时关井，即一线井产出液量为4000m 3。注入的高强度氮气泡沫体系会在一线井排内形成高强度封堵墙，高强度封堵墙会明显减缓水体侵入速度，同时减少蒸汽注入量可以防止蒸汽与边底水再次连通形成水侵通道，如图3所示。
②二线井排(#4、#5、#6)吞吐2周期后，含水率由初期21％上升至75％，二线井排也 已受到边底水侵入的影响。二线井排第3周期在注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；二线井排蒸汽注入量为1600t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为3:1计算，氮气注入量为288000m 3。氮气注入量提高，可以起到地层能量，延缓边底水侵入的作用；注蒸汽结束后，提高焖井时间至6天，延长焖井时间有利于氮气向地层深部的运移，增加氮气弹性驱油能量。然后开井生产；二线井产出液量与注入蒸汽冷水当量体积比为8时关井，即二线井产出液量为12800m 3。注入的氮气泡沫会在二线井排内形成低强度封堵墙，低强度封堵墙会进一步减缓水体侵入速度，如图3所示。
③三线井排(#7、#8、#9)由于距离边底水较远，水侵影响较小，含水率低于60％，但是三线井由于地层压力下降较快，很容易产生蒸汽汽窜。注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；三线井排蒸汽注入量为2500t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为4:1计算，氮气注入量为600000m 3；注蒸汽结束后，提高焖井时间至8天，延长焖井时间有利于氮气向地层深部的运移，然后开井生产。三线井产出液量与注入蒸汽冷水当量体积比为10时关井，即三线井产出液量为25000m 3。
通过整体调堵技术，平均日产油上升27t/d，平均含水率下降10.2％，周期油汽比上升0.08，取得了很好的控制水侵和汽窜效果。
对比例1
随着吞吐轮次的增加，地层压力逐渐降低，发生水侵与汽窜，高压的边底水体便会侵入到油层内部，距离水体最近的一线井排(#1、#2、#3)注入的蒸汽很容易与边底水连通形成水侵通道，这会导致一线井含水率迅速上升。一线井排(#1、#2、#3)吞吐2周期后，平均含水率由初期的35％上升至92％，此时水体已经完全侵入一线井内，二线井排(#4、#5、#6) 吞吐2周期后，平均含水率由初期21％上升至75％，二线井排也已受到边底水侵入的影响。其他步骤与实施例相同，不同的是该对比例采用对该区块水侵和汽窜严重的井实施局部调堵，具体如下：一线井排中的#2井含水率高达94％，对该井实施了氮气泡沫调堵，氮气注入量为50000m 3，蒸汽注入量为1200t，焖井3天。但是生产后，该井含水率仍然达到92％，含水率没有降低，说明如果无法根据油藏内不同位置处的井排具体情况进行统筹布局、设定条件整体调堵，仅依靠氮气泡沫局部调堵，则无法在距离边底水不同位置均形成有效封堵墙，从而无法有效控制边底水侵入。

Claims (8)

  1. 一种整体调堵边底水稠油油藏水侵和汽窜的方法，包括以下步骤：
    (1)选择油藏：按照以下条件进行粗筛选适用的油藏：油藏为边底水稠油油藏，50℃下地面脱气原油粘度＜100000mPa·s，油藏埋深＜1000m，有效厚度大于5m，初始含油饱和度＞0.5，渗透率＞200mD，水体体积与油层体积比小于500；
    (2)布吞吐井：按照排状布井方式在油层内钻吞吐井；吞吐井为直井或水平井；根据油藏面积确定井排数目，油层内至少设置3列吞吐井排，相邻两列井排的间距为100～150m，每列井排内相邻两个吞吐井的间距为100～150m；靠近水体的一列井排为一线井排，然后依次为二线井排、三线井排，以此类推，其中一线井排与水体的距离大于150m；
    (3)蒸汽吞吐开发：首先开始第一周期蒸汽吞吐，其中一线井排注入蒸汽量为1000～1200t，二线井排注入蒸汽量为1500～1800t，三线井排注入蒸汽量为2000～2200t；蒸汽注入后，焖井3～5天，焖井结束后开井生产；一线井排产出液量与注入蒸汽冷水当量体积比小于5；二线井排产出液量与注入蒸汽冷水当量体积比小于10；三线井排产出液量与注入蒸汽冷水当量体积比小于20；下一周期的吞吐参数与第一周期一致；
    (4)整体调堵：随着吞吐轮次的增加，地层压力逐渐降低，发生水侵与汽窜，采取整体调堵技术，具体操作如下：
    ①在一线井排含水率超过90％后，对一线井排注蒸汽阶段同时注入高强度氮气泡沫体系，一线井排降低周期蒸汽注入量至800～1000t，氮气随蒸汽全程注入，注入量根据井下形成的泡沫气液比为2:1计算；然后焖井3～5天后采油；
    ②二线井排注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；二线井排蒸汽注入量为1500～1800t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为3:1计算；注蒸汽结束后，提高焖井时间至5～6天，然后开井生产；
    ③三线井排注蒸汽的同时注入氮气泡沫体系，起泡剂的浓度为0.5％；三线井排蒸汽注入量为1500～2500t，氮气随蒸汽全程注入，氮气注入量根据井下形成的泡沫气液比为4:1计算；注蒸汽结束后，提高焖井时间至6～8天，然后开井生产。
  2. 根据权利要求1所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述步骤(4)中高强度氮气泡沫体系选用固相颗粒强化泡沫体系或耐高温凝胶泡沫体系。
  3. 根据权利要求2所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述固相颗粒强化泡沫体系中固相颗粒浓度为0.5～1％，起泡剂浓度为0.5％。
  4. 根据权利要求3所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述固相颗粒强化泡沫体系中固相颗粒选用粉煤灰、粘土颗粒或纳米颗粒。
  5. 根据权利要求2所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述耐高温凝胶泡沫体系包括先向地层内注入的耐高温凝胶堵剂和蒸汽吞吐时同时注入的氮气泡沫。
  6. 根据权利要求5所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述耐高温凝胶堵剂选用栲胶或温敏凝胶。
  7. 根据权利要求5所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述耐高温凝胶堵剂的注入量为30～50t。
  8. 根据权利要求5所述整体调堵边底水稠油油藏水侵和汽窜的方法，其特征在于，所述耐高温凝胶泡沫体系中起泡剂浓度为0.5％。
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