CN114458275A - Multilayer small sand body comprehensive fracturing method for underwater diversion river sediment microphase - Google Patents
Multilayer small sand body comprehensive fracturing method for underwater diversion river sediment microphase Download PDFInfo
- Publication number
- CN114458275A CN114458275A CN202111656851.8A CN202111656851A CN114458275A CN 114458275 A CN114458275 A CN 114458275A CN 202111656851 A CN202111656851 A CN 202111656851A CN 114458275 A CN114458275 A CN 114458275A
- Authority
- CN
- China
- Prior art keywords
- sand
- carrying
- fracturing
- fluid
- liquid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 239000004576 sand Substances 0.000 title claims abstract description 106
- 238000000034 method Methods 0.000 title claims abstract description 30
- 239000013049 sediment Substances 0.000 title description 2
- 239000012530 fluid Substances 0.000 claims abstract description 106
- 238000010276 construction Methods 0.000 claims abstract description 52
- 230000008859 change Effects 0.000 claims abstract description 3
- 239000007788 liquid Substances 0.000 claims description 118
- 238000004132 cross linking Methods 0.000 claims description 98
- 238000005086 pumping Methods 0.000 claims description 59
- 239000000243 solution Substances 0.000 claims description 34
- 238000002347 injection Methods 0.000 claims description 25
- 239000007924 injection Substances 0.000 claims description 25
- 239000003795 chemical substances by application Substances 0.000 claims description 23
- 239000003292 glue Substances 0.000 claims description 19
- 239000000835 fiber Substances 0.000 claims description 15
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 10
- 239000002245 particle Substances 0.000 claims description 6
- 239000002253 acid Substances 0.000 claims description 4
- 229920000426 Microplastic Polymers 0.000 claims description 2
- 230000000694 effects Effects 0.000 abstract description 10
- 238000004519 manufacturing process Methods 0.000 abstract description 6
- 230000000704 physical effect Effects 0.000 abstract description 6
- 239000010410 layer Substances 0.000 description 48
- 239000007789 gas Substances 0.000 description 29
- 239000011435 rock Substances 0.000 description 14
- 230000035699 permeability Effects 0.000 description 11
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 10
- 239000003431 cross linking reagent Substances 0.000 description 5
- 230000008021 deposition Effects 0.000 description 5
- 238000010586 diagram Methods 0.000 description 5
- 239000003345 natural gas Substances 0.000 description 5
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 4
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 4
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 4
- 239000000654 additive Substances 0.000 description 4
- 230000000996 additive effect Effects 0.000 description 4
- 238000004088 simulation Methods 0.000 description 4
- 239000003381 stabilizer Substances 0.000 description 4
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 230000002035 prolonged effect Effects 0.000 description 3
- 230000009466 transformation Effects 0.000 description 3
- 238000010306 acid treatment Methods 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000003638 chemical reducing agent Substances 0.000 description 2
- 239000004927 clay Substances 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 239000003112 inhibitor Substances 0.000 description 2
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 229910052742 iron Inorganic materials 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000001103 potassium chloride Substances 0.000 description 2
- 235000011164 potassium chloride Nutrition 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 239000002994 raw material Substances 0.000 description 2
- 239000002904 solvent Substances 0.000 description 2
- 230000001131 transforming effect Effects 0.000 description 2
- 238000005299 abrasion Methods 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 230000018109 developmental process Effects 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000001125 extrusion Methods 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- 229920013818 hydroxypropyl guar gum Polymers 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- WSFSSNUMVMOOMR-NJFSPNSNSA-N methanone Chemical compound O=[14CH2] WSFSSNUMVMOOMR-NJFSPNSNSA-N 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 238000002407 reforming Methods 0.000 description 1
- 238000004062 sedimentation Methods 0.000 description 1
- 239000002356 single layer Substances 0.000 description 1
- 238000002791 soaking Methods 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 230000008093 supporting effect Effects 0.000 description 1
- 238000011426 transformation method Methods 0.000 description 1
Images
Classifications
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/001—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells specially adapted for underwater installations
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Revetment (AREA)
Abstract
The invention belongs to the field of oil and gas reservoir exploitation, and particularly relates to a multi-layer small sand body comprehensive fracturing method for underwater diversion riverway sedimentary microfacies. The method comprises the following steps: aiming at a sedimentary microfacies underwater diversion river channel, a longitudinal upper target layer is a small sand compact gas reservoir with more than two layers, first fracturing construction is firstly carried out according to the position of a sand body of the target layer to change the heterogeneous difference between the target layers, then at least one fracturing construction is carried out, and fracturing reconstruction is carried out on each target layer. The small sand compact gas reservoir of the underwater diversion riverway sedimentary microfacies has the characteristics of multiple layers, compact lithology and poor physical property, and conventional fracturing is easy to cause fracturing fluid to only enter a unconsolidated stratum, thereby causing the under-reconstruction of a small sand layer. According to the method, heterogeneous differences among the target layers are changed through at least two times of fracturing reconstruction according to the positions of sand bodies of the target layers, so that the fracturing effect of each target layer is improved, and the gas production degree of the oil reservoirs is improved.
Description
Technical Field
The invention belongs to the field of oil and gas reservoir exploitation, and particularly relates to a multi-layer small sand body comprehensive fracturing method for underwater diversion riverway sedimentary microfacies.
Background
The Henan oil field has abundant natural gas resources, but the natural gas reservoir has the characteristics of low permeability, early water breakthrough period of a gas well, low yield after perforation and the like, so that the effective development of the oil reservoir is severely restricted. Geological reserve of natural gas of condensed gas reservoir of deep system of Anhui oil field 5.67X 108m3In the rural area of the ann canopy in the county of Tongbai, Henan province, the geological reserve of condensate oil is 11.7 multiplied by 104t, belonging to small condensate gas reservoirs.
The reservoir is obviously controlled by the fracture of the basin edge, and the characteristics of multi-source gathering, short-distance transportation, rapid sedimentation and vertical superposition of multiple sets of reservoirs are formed. The gas reservoir has four low characteristics of low permeability, low pressure, low abundance and low yield, and a gas well has no natural productivity and can obtain economic yield only by fracturing modification. Meanwhile, as a plurality of sets of single sand bodies develop in the same layer, the physical property and the gas content of each sand body are different greatly, and stronger heterogeneity is shown. Even the same dense sand body may form a plurality of gas reservoirs due to the heterogeneity of permeability. Overall, the reservoir exhibits the characteristics of a small sand compact gas reservoir.
The small sand compact gas reservoir has the following characteristics: the buried depth of the target layer is 3000-4000m, and the target layer is a sandstone gas-bearing layer. Reservoir temperature 130-. In the longitudinal direction, the number of reservoir layers is large, the thickness is large, the lithology is compact, and the physical property is poor. On a plane, the oil-gas containing area is less than 0.5km2. Natural gas reserve less than 0.4×108m3Condensate oil reserve less than 0.4X 104t。
The characteristics lead to that the traditional general fracturing transformation method can lead the fracturing fluid to preferentially enter the sand body with good physical property, the fracturing fluid entering the small sand compact gas reservoir is less, the fracturing effect is poor, and further the gas production degree of the gas reservoir is influenced.
Disclosure of Invention
The invention aims to provide a multi-layer small sand comprehensive fracturing method for sedimentary microfacies of an underwater diversion river channel, and solves the problem of poor fracturing effect of small sand compact gas reservoir yield.
In order to achieve the above purpose, the technical scheme adopted by the invention is as follows:
a multi-layer small sand body comprehensive fracturing method for sedimentary microfacies of an underwater shunt river comprises the following steps: aiming at a sedimentary microfacies underwater diversion river channel, a longitudinal upper target layer is a small sand compact gas reservoir with more than two layers, first fracturing construction is firstly carried out according to the position of a sand body of the target layer to change the heterogeneous difference between the target layers, then at least one fracturing construction is carried out, and fracturing reconstruction is carried out on each target layer.
The small sand compact gas reservoir of the underwater diversion riverway sedimentary microfacies has the characteristics of multiple layers, compact lithology and poor physical property, and conventional fracturing is easy to cause fracturing fluid to only enter a unconsolidated stratum, thereby causing the under-reconstruction of a small sand layer. According to the method, heterogeneous differences among the target layers are changed through at least two times of fracturing reconstruction according to the positions of sand bodies of the target layers, so that the fracturing effect of each target layer is improved, and the gas production degree of the oil reservoirs is improved.
Preferably, the target layer is on a different sand body; the first fracturing construction comprises acid liquor treatment, preposed liquid pumping and sand-carrying liquid pumping in sequence; the changing of the heterogeneous difference among the target layers comprises pumping plugging liquid to plug the pressed layer; the at least one fracturing construction comprises a second fracturing construction, a pumping plugging liquid and a third fracturing construction in sequence; the second fracturing construction comprises the steps of sequentially pumping a pad fluid and a sand carrying fluid; and the third fracturing construction comprises the steps of sequentially pumping the pad fluid and the sand carrying fluid. Aiming at the condition that the target layer is positioned on different sand bodies, the fracturing fluid can enter other perforated sand layers through multiple fracturing combined plugging technology, so that uniform transformation is realized.
Preferably, the sand-carrying fluid pumping stage in the first fracturing construction, the second fracturing construction and the third fracturing construction comprises the steps of pumping 8-10 combined cross-linking fluid-slickwater combination in sequence and pumping the tail end sand-carrying cross-linking fluid; the cross-linking liquid-slickwater combination comprises a sand-carrying cross-linking liquid and slickwater which are injected in sequence, wherein the volume ratio of the sand-carrying cross-linking liquid to the slickwater is 1: 1-2; the sand-carrying cross-linking liquid and the tail-end sand-carrying cross-linking liquid are both composed of cross-linking liquid, propping agent and fiber for fracturing. The cross-linking liquid-slickwater combination is used in the sand carrying liquid stage, the pulse sand adding characteristic is achieved, the fracturing fibers can wind loose sand grains into sand clusters, the sand clusters are extruded by compact rocks with high elastic modulus and low Poisson ratio, the damage degree of single sand grains is reduced, a gas flow channel can be established at the bottom of a well, high flow conductivity is achieved, and the gas production time is prolonged.
More preferably, in the 8-10 combined cross-linking liquid-slickwater combined sand-carrying cross-linking liquid and the tail end sand-carrying cross-linking liquid, the sand-liquid ratio is 5-40%, and the sand-liquid ratio is sequentially increased according to the pumping sequence; the addition amount of the fiber for fracturing is 0.35 to 2.8Kg/m3The addition of the fibers for fracturing is increased in sequence according to the pump injection sequence. By adopting the mode, effective support can be formed at the position close to the well casing, and the fracturing effect can be better maintained.
Preferably, the pre-liquid pumping in the first fracturing construction, the second fracturing construction and the third fracturing construction comprises sequentially pumping slickwater, sand-carrying slickwater and cross-linking liquid, wherein the volume ratio of the slickwater to the sand-carrying slickwater to the cross-linking liquid is (10-12) to (8-12); the sand-carrying slickwater consists of slickwater and a propping agent. By adopting the pre-liquid mode, sandstone with more areas can be crushed due to low friction of slickwater, and the effect of forming dendritic seams is achieved.
Further preferably, the sand-liquid ratio of the sand-carrying slickwater is 3%.
Preferably, the plugging fluid consists of slippery water and plastic pellets. By adopting the plugging mode, the cost is low, and the plugging effect is good.
Preferably, the destination layer is on the same sand body; the first fracturing construction comprises sequentially pumping and injecting a pad fluid, a sand carrying fluid and a displacing fluid; the step of changing the heterogeneous difference among the target layers comprises stopping the pump for 60-90 min; and then carrying out second fracturing construction, wherein the second fracturing construction comprises sequentially pumping and injecting the pad fluid, the sand carrying fluid and the displacing fluid. Under this kind of condition, there is the multilayer perforation section in the same layer of sand body, and the perforation section is relatively close apart, and owing to the deposit characteristics of reposition of redundant personnel river course microphase under water, there is great difference in the rerum natura of each perforation section still, through twice fracturing process the last time, can effectively realize the even transformation of each perforation section.
Preferably, in the first fracturing construction, the pump injection pad fluid comprises a pump injection cross-linking fluid, a sand-carrying base glue fluid, a first sand-carrying cross-linking fluid, a second sand-carrying cross-linking fluid and a cross-linking fluid in sequence; the sand-carrying primary glue solution consists of a primary glue solution and a propping agent; the sand-carrying cross-linking liquid consists of cross-linking liquid and propping agent; the sand-liquid ratio of the sand-carrying raw glue solution, the first sand-carrying cross-linking liquid and the second sand-carrying cross-linking liquid is gradually increased; the pump injection sand-carrying liquid comprises 6-7 groups of pump injection sand-carrying cross-linking liquid, the sand-liquid ratio is 12-40%, and the sand-liquid ratio is gradually increased according to the pump injection sequence; the particle sizes of the propping agents in the sand-carrying raw glue solution, the sand-carrying cross-linking solution in the pad fluid stage and the sand-carrying cross-linking solution in the sand-carrying fluid stage are sequentially increased and are 70/140 meshes, 40/70 meshes and 20/40 meshes respectively;
in the second fracturing construction, the pump injection pad fluid comprises pump injection raw glue solution, sand-carrying cross-linking liquid and cross-linking liquid in sequence; the pump injection sand-carrying liquid comprises 6-7 groups of pump injection sand-carrying cross-linking liquid, the sand-liquid ratio is 10-40%, and the sand-liquid ratio is gradually increased according to the pump injection sequence; the particle sizes of the proppant in the sand-carrying cross-linking liquid in the pad fluid stage and the sand-carrying cross-linking liquid in the sand-carrying fluid stage are sequentially increased and are 40/70 meshes and 20/40 meshes respectively. By adopting the pumping injection mode, more proppants can be injected into the stratum, and the fracturing and supporting effects on the sandstone gas reservoir are good.
In order to further optimize the injection effect of the proppant, the construction discharge volumes of the pad fluid stage and the sand carrying fluid stage in the first fracturing construction and the second fracturing construction are more preferably gradually selectedGradually increasing; the construction discharge capacity of the pad fluid stage is 4.0-4.5 m3Min, sand carrying discharge capacity of 5m at sand carrying liquid stage3/min。
Drawings
FIG. 1 is a plan view of a 3003 well IX group 6 sub-layer in an embodiment of the present invention;
FIG. 2 is a microphase diagram of a 3003 well IX group 6 small layer deposition in accordance with an embodiment of the present invention;
FIG. 3 is a plan view of a small layer of a 3003 well IX bank 12 in accordance with an embodiment of the present invention;
FIG. 4 is a microphase diagram of the deposition of a 3003 well IX group 12 small layer in an embodiment of the present invention;
FIG. 5 is a simulation of the fracture morphology of a 3003 well according to an embodiment of the present invention;
FIG. 6 is a simulation of a lower 13 well fracture morphology in an embodiment of the present invention.
Detailed Description
The following describes the practice of the present invention in detail with reference to specific examples.
The specifications or types of the raw materials in the following examples are described below, and the relevant raw materials are all commercially available conventional materials unless otherwise specified.
Example 1
The comprehensive fracturing method for the multilayer small sand bodies aiming at the sedimentary microfacies of the underwater flow-dividing riverway comprises the following steps aiming at installing a 3003 well:
(1) defining characteristics of targeted small sand gas reservoirs
The buried depth of the target layer is 3700-3900 m. Reservoir temperature 140-. On a plane, the oil-gas area is 0.5km2. Natural gas reserve of 0.4X 108m3Condensate oil reserve 0.4X 104t. The number of layers of the sand body is as follows: 3 layers; the thickness of the single-layer sand body is 5m, 10m and 15 m.
Rock compactness: the compressive strength is 300Mpa, the elastic modulus is 50Gpa, the Poisson ratio is 0.2, and the rock density is 2.7g/cm3。
Physical properties: permeability of 0.001 to 0.01X 10-3μm3The porosity: 1%, irreducible water saturation 30%;
logging parameters: resistivity of 80. omega. m, acoustic wave time difference of 185. mu.s/m.
(2) The well type of the 3003 well is a straight well, and a shaft cannot be reformed by mechanical separate fracturing. The distance between two layers is 30m from top to bottom, and the ratio of the thickness of the sand body between two layers is as follows: 2, the ratio of the sand permeability between the two layers: 2, the improved sand body deposition microphase is as follows: and splitting the river deposit microphase underwater.
The plan view of well IX set 6 small layers of 3003 and the microphase diagram of deposition are shown in FIGS. 1 and 2. A plan view of group IX 12 small layers and a deposition microphase diagram are shown in fig. 3 and 4.
The fracturing pump procedure is shown in table 1 below.
TABLE 1 An 3003 well fracturing Pump injection procedure
The working fluids referred to in table 1 are illustrated below:
the acid solution comprises the following components in percentage by mass: 15% of hydrochloric acid, 3% of hydrofluoric acid, 1% of clay stabilizer, 0.5% of cleanup additive, 2% of mutual solvent, 2% of high-temperature corrosion inhibitor, 2% of iron ion stabilizer and the balance of water. Briefly stated, the method comprises the following steps: 15% of hydrochloric acid, 3% of hydrofluoric acid, 1% of clay stabilizer, 0.5% of cleanup additive, 2% of mutual solvent, 2% of high-temperature corrosion inhibitor and 2% of iron ion stabilizer.
Sliding water: 0.1% of drag reducer, 0.2% of fracturing cleanup additive and 1% of potassium chloride.
Crosslinking liquid: 0.55 percent of hydroxypropyl guar gum, 1 percent of potassium chloride, 0.2 percent of formaldehyde, 0.2 percent of fracturing cleanup additive, 0.1 percent of sodium hydroxide and 0.6 percent of cross-linking agent. The type of the cross-linking agent is a high-temperature cross-linking agent for fracturing, which is purchased from petroleum technology Co., Ltd., Beijing Baofengchun (http:// bfckj. webd. testwell. cn/product _ detail/id/6. html). The cross-linking liquid is 'delayed cross-linking liquid', the fracturing liquid with the formula has the functions of delaying cross-linking time and resisting high temperature, and the base liquid is stirred for 2-3min to form a jelly-like phenomenon after the cross-linking agent is added, so that the frictional resistance between the liquid and a pipe column is reduced, and fibers for fracturing, a propping agent and the fracturing liquid are uniformly mixed in the base liquid with low viscosity on the ground.
With reference to table 1, the small sand body modification includes steps of acid treatment, first pad fluid pumping, first sand-carrying fluid pumping, first plugging fluid pumping, second pad fluid pumping, second sand-carrying fluid pumping, second plugging fluid pumping, third pad fluid pumping, third sand-carrying fluid pumping, and top fluid pumping.
In the acid treatment step, an acid solution is pumped to reduce the fracture pressure of the tight sandstone formation.
The first pad fluid pumping stage, the first sand carrying fluid pumping stage and the first plugging fluid pumping stage firstly transform and plug the part with high permeability.
The first front liquid pumping stage comprises sequentially pumping slickwater, sand-carrying slickwater and crosslinking liquid, wherein the volume ratio of the slickwater to the sand-carrying slickwater to the crosslinking liquid is 1:1: 1; the sand-carrying slickwater consists of slickwater and a propping agent, the sand-liquid ratio is 3%, and the propping agent is 30/50-mesh ceramsite.
The first sand-carrying fluid pumping stage comprises the steps of pumping 8 groups of the cross-linking fluid-slickwater combination in sequence and pumping the tail end sand-carrying cross-linking fluid. The cross-linking liquid-slickwater combination comprises a sand-carrying cross-linking liquid and slickwater which are injected in sequence, wherein the volume ratio of the sand-carrying cross-linking liquid to the slickwater is 1 (1-2); the sand-carrying cross-linking liquid and the tail-end sand-carrying cross-linking liquid are both composed of cross-linking liquid, propping agent and fiber for fracturing. The proppant is 30/50-mesh ceramsite. The fiber for fracturing is purchased from oil engineering technology Limited of Dongying Sporui, and is used for stabilizing the sand cluster column support and preventing the proppant from flowing back and spitting.
8 groups of cross-linking liquid-slickwater combinations and tail end sand-carrying cross-linking liquid, wherein the sand-liquid ratio is 5-40%, and the sand-liquid ratio is sequentially increased according to the pumping sequence and is respectively 5%, 8%, 10%, 15%, 20%, 25%, 30%, 35% and 40%; the addition amount of the fiber for fracturing is 0.35 to 2.8Kg/m3The addition of the fiber for fracturing is increased in sequence and is 0.35, 0.56, 0.70, 1.05, 1.40, 1.75, 2.10, 2.45 and 2.80Kg/m in sequence3. The fiber for fracturing is mixed and injected in the stage of carrying the sand liquid, the fiber can wind loose sand grains into sand balls, and the sand balls are arranged in a high-elasticity moldThe damage degree of single sand grains is reduced under the extrusion of dense rocks with low Poisson ratio, a gas flow channel is established at the bottom of the well, high flow conductivity is obtained, and the gas production time is prolonged.
In the process, the propping agent firstly supports the stratum in the sandstone in the form of discontinuous sectional sand masses, and the fibers for later-stage fracturing can be naturally degraded along with the time extension under the soaking of underground water with certain mineralization degree. The proppant falls into a sand bank state to support the formation. The propping time of the propping agent is prolonged, and the crushing degree is reduced.
The pulse type sand adding mode of the combination of the cross-linking liquid and the slickwater is adopted, the sand-carrying cross-linking liquid enters a stratum in a sand column mode, and the slickwater (instant emulsion resistance reducing agent, purchased from Beijing Baofengchun oil technology Co., Ltd., http:// bfckj. webd. testwell. cn/product _ detail/id/39.html) plays a role in making a dendritic joint and further improves the seepage capability of sandstone. In addition, compared with a cross-linking liquid, the slippery water has lower frictional resistance with the tubular column, reduces the construction pump pressure of a ground special vehicle, reduces the pressure bearing pressure of a well mouth and the tubular column, and reduces the abrasion to pump truck equipment and a pump injection liquid pipeline by reducing construction fracturing.
The first plugging liquid consists of slippery water and plastic balls. The function is to block the pressed layer, so that the follow-up fracturing fluid enters the sand layer of other perforation.
And transforming the part with the second highest permeability by the stages of pumping the second pad fluid, pumping the second sand carrying fluid and pumping the second plugging fluid. Wherein the working fluid properties of each stage are the same as those of the first stage.
And transforming the part with the lowest transformation degree in stages of pumping the third pad fluid, pumping the third sand-carrying fluid and pumping the displacement fluid. And working fluid of the third pad fluid pumping stage and the third sand carrying fluid pumping stage is consistent with that of the first stage. And the liquid displacement stage comprises the step of pumping the cross-linking liquid and the slickwater in sequence, wherein the volume ratio of the cross-linking liquid to the slickwater is 1: 15.
And after the sand is added, pumping a displacement liquid with the volume of the oil pipe column, and flushing residual propping agent in the pipe column. And opening the well immediately after the sand fracturing construction is finished, and forcibly closing the artificial cracks. And after the construction is finished, the well is opened and the fracturing fluid is drained back, so that the damage of the liquid entering the well to the reservoir is reduced.
The fracture morphology simulation diagram finally obtained by adopting the fracturing mode of the embodiment is shown in FIG. 5.
Example 2
The comprehensive fracturing method for the multilayer small sand bodies aiming at the sedimentary microfacies of the underwater flow-dividing riverway comprises the following steps aiming at a lower 13 wells:
(1) the well type of the lower 13 wells is a vertical well, the fracturing layer is located in the same layer of sand body, 2-4 layers of perforation sections are arranged, the perforation sections are relatively close to each other and are 2-3m apart from each other, the rock of the layer is observed by a rock core to have micro cracks, and the sedimentary microfacies of the sand body are sedimentary microfacies of an underwater diversion river channel.
(2) The fracturing pump-in procedure for the 13 wells is shown in table 2.
Table 2 fracturing pump injection procedure for 13 wells
In Table 2, the composition of the crosslinking liquid was the same as in example 1. The dope solution differs from the crosslinking solution in that it does not contain a crosslinking agent.
In connection with table 2, the fracturing stages of the lower 13 wells include a first fracturing, pump down, and a second fracturing stage.
The first fracturing stage comprises pumping pad fluid, sand carrying fluid and displacing fluid in sequence.
The pad fluid comprises a cross-linking fluid, a sand-carrying primary glue fluid, a first sand-carrying cross-linking fluid, a second sand-carrying cross-linking fluid and a cross-linking fluid which are pumped and injected in sequence; the sand-carrying primary glue solution consists of a primary glue solution and a propping agent. The sand-carrying cross-linking liquid consists of cross-linking liquid and propping agent. The sand-liquid ratios of the sand-carrying raw glue solution, the first sand-carrying cross-linking liquid and the second sand-carrying cross-linking liquid are gradually increased to 5%, 8% and 10% respectively. The proppant in the sand-carrying raw glue solution, the first sand-carrying cross-linking solution and the second sand-carrying cross-linking solution is 70/140-mesh ceramsite, 40/70-mesh ceramsite and 40/70-mesh ceramsite respectively. The sand adding mode of the pre-liquid stage is slug sand adding.
In the pre-fluid stage, the sand-carrying raw rubber solution and the raw rubber solution are matched with the cross-linking solution, so that the raw rubber solution has the characteristics of low viscosity and strong fluidity, and can fracture more ranges of rocks on a plane, but the fractured rock gaps are narrow, and after the rocks fracture, the raw rubber solution and the propping agent with small particle size are required to be carried and filled, so that the fracture is ensured not to be closed. The use of the segmented plug type sand adding has the function that the propping agent with smaller particle size is wrapped in the tiny cracks of the stratum by the original glue solution with low viscosity and stronger fluidity for filling, so that the crack filling effect of the propping agent is improved, and more compact oil gas is used.
And a sand carrying liquid stage, wherein 6 groups of sand carrying cross-linking liquid are pumped and injected in sequence, the sand adding mode is continuous sand adding, the sand-liquid ratio is 12-40%, and the sand-liquid ratio is gradually increased and is 12%, 18%, 24%, 30%, 35% and 40% in sequence. The proppant used was 20/40 mesh ceramsite.
The displacing liquid is the primary glue liquid.
And stopping the pump for 90 minutes after the first fracturing stage is finished, and constructing again to perform second fracturing after the pump is stopped for 90 minutes. The function of stopping the pump is that after the first fracturing, more proppants enter the fracturing fluid and are wrapped by the fracturing fluid in the rock layer with higher porosity and permeability than in the rock layer with lower porosity and permeability. After fracturing for the first time is completed, the ground pump truck stops working, after the underground rock crack is closed, the ground pump truck is started to start fracturing for the second time, so that fracturing fluid enters the rock layer with lower porosity and permeability, and sand is added to the rock layer with lower porosity and permeability.
The second fracturing stage comprises pumping and injecting the pad fluid, the sand carrying fluid and the displacing fluid in sequence.
The pad fluid stage comprises sequentially pumping and injecting a virgin rubber solution, a sand-carrying cross-linking solution and a cross-linking solution, wherein a propping agent in the sand-carrying cross-linking solution is 40/70-mesh ceramsite.
And a sand carrying liquid stage, wherein 7 groups of sand carrying cross-linking liquid are pumped and injected in sequence, the sand adding mode is continuous sand adding, the sand-liquid ratio is 10-40%, and the sand-liquid ratio is gradually increased and is 10%, 16%, 20%, 25%, 30%, 35% and 40% in sequence. The proppant used was 20/40 mesh ceramsite.
The displacing liquid is the primary glue liquid.
The simulation of the fracture morphology of the 13 wells obtained by the example is shown in fig. 6.
Second, Experimental example
The results of the single well before and after the measures for the small sand compact gas reservoir reforming using the methods of examples 1 and 2 above are shown in table 3.
TABLE 3 Single well Effect comparison before and after measurements
From the results in table 3, it can be known that the method of the embodiment can effectively reform small sand bodies with high buried depth, compact lithology and multiple layers of layers for the shaft which cannot be reformed by mechanical layered fracturing, and improve the stratum flow conductivity and the gas production rate.
Claims (10)
1. The comprehensive fracturing method for the multilayer small sand bodies aiming at the sedimentary microfacies of the underwater flow-dividing riverway is characterized by comprising the following steps of: aiming at a sedimentary microfacies underwater diversion river channel, a longitudinal upper target layer is a small sand compact gas reservoir with more than two layers, first fracturing construction is firstly carried out according to the position of a sand body of the target layer to change the heterogeneous difference between the target layers, then at least one fracturing construction is carried out, and fracturing reconstruction is carried out on each target layer.
2. The method for comprehensive fracturing of multiple layers of small sand bodies aiming at sedimentary microphase of an underwater diversion river channel according to claim 1, wherein the target layer is on different sand bodies; the first fracturing construction comprises acid liquor treatment, preposed liquid pumping and sand-carrying liquid pumping in sequence; the changing of the heterogeneous difference among the target layers comprises pumping plugging liquid to plug the pressed layer; the at least one fracturing construction comprises a second fracturing construction, a pumping plugging fluid and a third fracturing construction in sequence; the second fracturing construction comprises the steps of sequentially pumping a pad fluid and a sand carrying fluid; and the third fracturing construction comprises the steps of sequentially pumping the pad fluid and the sand carrying fluid.
3. The method for comprehensively fracturing the multi-layer small sand bodies aiming at the sedimentary microphase of the underwater diversion river channel according to claim 2, wherein the pumping-in stages of the sand-carrying fluid in the first fracturing construction, the second fracturing construction and the third fracturing construction comprise that 8-10 combination cross-linking fluid-slickwater combination is pumped in sequence, and then the tail end sand-carrying cross-linking fluid is pumped in; the cross-linking liquid-slickwater combination comprises a sand-carrying cross-linking liquid and slickwater which are injected in sequence, wherein the volume ratio of the sand-carrying cross-linking liquid to the slickwater is 1: 1-2; the sand-carrying cross-linking liquid and the tail-end sand-carrying cross-linking liquid are both composed of cross-linking liquid, propping agent and fiber for fracturing.
4. The method for comprehensively fracturing the multi-layer small sand bodies aiming at the sedimentary microphase of the underwater shunt riverway as claimed in claim 3, wherein in the 8-10 combination cross-linking fluid-slickwater combination sand-carrying cross-linking fluid and the tail end sand-carrying cross-linking fluid, the sand-liquid ratio is 5-40%, and the sand-liquid ratio is sequentially increased according to the pumping sequence; the addition amount of the fiber for fracturing is 0.35 to 2.8Kg/m3The addition of the fibers for fracturing is increased in sequence according to the pump injection sequence.
5. The comprehensive fracturing method of the multi-layer small sand body aiming at the sedimentary microphase of the underwater diversion river channel as claimed in claim 2, wherein the pre-pumping in the first fracturing construction, the second fracturing construction and the third fracturing construction comprises the steps of pumping in slickwater, sand-carrying slickwater and cross-linking liquid in sequence, wherein the volume ratio of the slickwater, the sand-carrying slickwater and the cross-linking liquid is (10-12): 8-12); the sand-carrying slickwater consists of slickwater and a propping agent.
6. The method for comprehensive fracturing of multiple layers of small sand bodies aiming at sedimentary microphase of an underwater diversion river channel as claimed in claim 5, wherein the sand-liquid ratio of the sand-carrying slickwater is 3%.
7. The method for the comprehensive fracturing of the multilayer small sand bodies aiming at the sedimentary microphase of the underwater divided flow river channel in any one of claims 2 to 6, wherein the plugging fluid consists of slippery water and plastic pellets.
8. The method for comprehensive fracturing of multiple layers of small sand bodies aiming at sedimentary microphase of an underwater diversion river channel according to claim 1, wherein the target layer is on the same sand body; the first fracturing construction comprises sequentially pumping and injecting a pad fluid, a sand carrying fluid and a displacing fluid; the step of changing the heterogeneous difference among the target layers comprises stopping the pump for 60-90 min; and then carrying out second fracturing construction, wherein the second fracturing construction comprises sequentially pumping and injecting the pad fluid, the sand carrying fluid and the displacing fluid.
9. The comprehensive fracturing method of the multi-layer small sand body aiming at the sedimentary microphase of the underwater shunt riverway as claimed in claim 8, wherein in the first fracturing construction, the pumping of the pad fluid comprises pumping of the crosslinking fluid, the sand-carrying base fluid, the first sand-carrying crosslinking fluid, the second sand-carrying crosslinking fluid and the crosslinking fluid in sequence; the sand-carrying primary glue solution consists of a primary glue solution and a propping agent; the sand-carrying cross-linking liquid consists of cross-linking liquid and propping agent; the sand-liquid ratio of the sand-carrying raw glue solution, the first sand-carrying cross-linking liquid and the second sand-carrying cross-linking liquid is gradually increased; the pump injection sand-carrying liquid comprises 6-7 groups of pump injection sand-carrying cross-linking liquid, the sand-liquid ratio is 12-40%, and the sand-liquid ratio is gradually increased according to the pump injection sequence; the particle sizes of the propping agents in the sand-carrying raw glue solution, the sand-carrying cross-linking solution in the pad fluid stage and the sand-carrying cross-linking solution in the sand-carrying fluid stage are sequentially increased and are 70/140 meshes, 40/70 meshes and 20/40 meshes respectively;
in the second fracturing construction, the pump injection pad fluid comprises pump injection raw glue solution, sand-carrying cross-linking liquid and cross-linking liquid in sequence; the pump injection sand carrying liquid comprises 6-7 groups of sand carrying cross-linking liquid for pump injection, the sand-liquid ratio is 10-40%, and the sand-liquid ratio is gradually increased according to the pump injection sequence; the particle sizes of the proppant in the sand-carrying cross-linking liquid in the pad fluid stage and the sand-carrying cross-linking liquid in the sand-carrying fluid stage are sequentially increased and are 40/70 meshes and 20/40 meshes respectively.
10. As claimed inThe comprehensive fracturing method of the multilayer small sand bodies aiming at the sedimentary microfacies of the underwater diversion river channel is characterized in that in the first fracturing construction and the second fracturing construction, the construction discharge capacities of a pad fluid stage and a sand carrying fluid stage are gradually increased; the construction discharge capacity of the pad fluid stage is 4.0-4.5 m3Min, sand carrying discharge capacity of 5m at sand carrying liquid stage3/min。
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111656851.8A CN114458275B (en) | 2021-12-30 | 2021-12-30 | Comprehensive fracturing method for multilayer small sand bodies of sediment microphase of underwater diversion river |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202111656851.8A CN114458275B (en) | 2021-12-30 | 2021-12-30 | Comprehensive fracturing method for multilayer small sand bodies of sediment microphase of underwater diversion river |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN114458275A true CN114458275A (en) | 2022-05-10 |
| CN114458275B CN114458275B (en) | 2024-04-02 |
Family
ID=81408602
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202111656851.8A Active CN114458275B (en) | 2021-12-30 | 2021-12-30 | Comprehensive fracturing method for multilayer small sand bodies of sediment microphase of underwater diversion river |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN114458275B (en) |
Citations (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102925133A (en) * | 2012-10-16 | 2013-02-13 | 中国石油天然气股份有限公司 | Fracturing fluid and fracturing method for controlling fracture extension height |
| CN206008626U (en) * | 2016-08-31 | 2017-03-15 | 中国石油化工股份有限公司 | A kind of device for adding fiber in fracturing fluid |
| CN106555576A (en) * | 2015-09-24 | 2017-04-05 | 中国石油化工股份有限公司 | Suitable for the fracturing process of thin layer |
| CN107313762A (en) * | 2016-04-26 | 2017-11-03 | 中国石油化工股份有限公司 | A kind of shale hydraulic fracturing method |
| CN107420081A (en) * | 2017-09-08 | 2017-12-01 | 中国石油天然气股份有限公司 | Fracturing method for realizing effective partial pressure of compact heterogeneous reservoir |
| CN107965305A (en) * | 2016-10-20 | 2018-04-27 | 中国石油化工股份有限公司 | One kind layering refracturing method |
| CN109138958A (en) * | 2018-07-26 | 2019-01-04 | 安东石油技术（集团）有限公司 | A kind of fracturing process of the complicated seam of tight sand gas reservoir |
| CN109958426A (en) * | 2017-12-26 | 2019-07-02 | 中国石油化工股份有限公司 | A kind of fracturing process improving deep layer shale gas crack complexity |
| RU2722893C1 (en) * | 2019-11-18 | 2020-06-04 | Некоммерческое партнерство "Технопарк Губкинского университета" (НП "Технопарк Губкинского университета") | Method for development of multilayer inhomogeneous oil deposit |
| CN112459761A (en) * | 2020-11-28 | 2021-03-09 | 濮阳华成恒业石油技术开发有限公司 | Temporary plugging acid fracturing method |
| CN113684010A (en) * | 2021-08-31 | 2021-11-23 | 陕西延长石油（集团）有限责任公司 | Temporary fracture plugging diverter and application thereof in temporary plugging diverting sand fracturing process |
| CN113738328A (en) * | 2021-09-27 | 2021-12-03 | 中国石油化工股份有限公司 | Production method for improving output of small sand compact gas reservoir |
| CN113738329A (en) * | 2021-09-28 | 2021-12-03 | 中国石油化工股份有限公司 | Method for exploiting offshore underwater fan oil reservoir |
-
2021
- 2021-12-30 CN CN202111656851.8A patent/CN114458275B/en active Active
Patent Citations (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102925133A (en) * | 2012-10-16 | 2013-02-13 | 中国石油天然气股份有限公司 | Fracturing fluid and fracturing method for controlling fracture extension height |
| CN106555576A (en) * | 2015-09-24 | 2017-04-05 | 中国石油化工股份有限公司 | Suitable for the fracturing process of thin layer |
| CN107313762A (en) * | 2016-04-26 | 2017-11-03 | 中国石油化工股份有限公司 | A kind of shale hydraulic fracturing method |
| CN206008626U (en) * | 2016-08-31 | 2017-03-15 | 中国石油化工股份有限公司 | A kind of device for adding fiber in fracturing fluid |
| CN107965305A (en) * | 2016-10-20 | 2018-04-27 | 中国石油化工股份有限公司 | One kind layering refracturing method |
| CN107420081A (en) * | 2017-09-08 | 2017-12-01 | 中国石油天然气股份有限公司 | Fracturing method for realizing effective partial pressure of compact heterogeneous reservoir |
| CN109958426A (en) * | 2017-12-26 | 2019-07-02 | 中国石油化工股份有限公司 | A kind of fracturing process improving deep layer shale gas crack complexity |
| CN109138958A (en) * | 2018-07-26 | 2019-01-04 | 安东石油技术（集团）有限公司 | A kind of fracturing process of the complicated seam of tight sand gas reservoir |
| RU2722893C1 (en) * | 2019-11-18 | 2020-06-04 | Некоммерческое партнерство "Технопарк Губкинского университета" (НП "Технопарк Губкинского университета") | Method for development of multilayer inhomogeneous oil deposit |
| CN112459761A (en) * | 2020-11-28 | 2021-03-09 | 濮阳华成恒业石油技术开发有限公司 | Temporary plugging acid fracturing method |
| CN113684010A (en) * | 2021-08-31 | 2021-11-23 | 陕西延长石油（集团）有限责任公司 | Temporary fracture plugging diverter and application thereof in temporary plugging diverting sand fracturing process |
| CN113738328A (en) * | 2021-09-27 | 2021-12-03 | 中国石油化工股份有限公司 | Production method for improving output of small sand compact gas reservoir |
| CN113738329A (en) * | 2021-09-28 | 2021-12-03 | 中国石油化工股份有限公司 | Method for exploiting offshore underwater fan oil reservoir |
Also Published As
| Publication number | Publication date |
|---|---|
| CN114458275B (en) | 2024-04-02 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN106567702B (en) | Method for improving complexity index of deep shale gas crack | |
| CN109838223B (en) | Deep complex shale gas volume fracturing method | |
| CN109751029B (en) | Deep shale gas fracturing method | |
| CN110761765B (en) | Volume fracturing method for activating natural fracture in large range | |
| CN112240191B (en) | Shale gas fracturing sand adding method | |
| CN109958411B (en) | Horizontal well cluster perforation staged fracturing method | |
| CN107545088B (en) | Normal-pressure shale gas horizontal well volume fracturing method | |
| MX2012013299A (en) | Hydraulic fracturing method. | |
| CN110984939B (en) | Process for temporary blocking volume fracturing of super seam net of horizontal well | |
| CN110805419A (en) | Large-liquid-volume large-displacement large-pad-fluid low-sand-ratio slickwater volume fracturing method | |
| CN109763805B (en) | Spiral variable-parameter fracturing method for deep shale gas | |
| CN107558981A (en) | Fracturing process for realizing complex cracks through multi-particle-size-difference temporary plugging | |
| CN115163020B (en) | Shale oil energy storage oil displacement pressure control fracture fracturing process | |
| CN110219634B (en) | Nano proppant high sand-liquid ratio volume fracturing method for deep shale gas | |
| CN112943185A (en) | Composite fracturing process based on supercritical carbon dioxide pre-fracturing | |
| CN108316909B (en) | Fracturing construction method for oil and gas reservoir | |
| CN110529089B (en) | Repeated fracturing method for open hole horizontal well | |
| CN110118079B (en) | Fracturing exploitation method for high-wax-content oil layer | |
| CN112443306A (en) | Pressure-control fracturing method for increasing fracture complexity of deep shale gas well | |
| CN111663930B (en) | Fracturing method for horizontal seam of shallow tight oil reservoir | |
| CN111911128B (en) | High-tectonic stress normal-pressure shale gas-accumulation fracturing method | |
| CN109611062B (en) | Novel method for improving reservoir reconstruction volume by combining subdivision cutting with temporary plugging steering technology | |
| CN113738328B (en) | Production method for improving small sand compact gas reservoir yield | |
| CN114458275A (en) | Multilayer small sand body comprehensive fracturing method for underwater diversion river sediment microphase | |
| CN112253074A (en) | Method for improving bridge plug pumping efficiency by deep horizontal well fracturing |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |