CN107083943A - A kind of hot CO of segment level well2The method that the heterogeneous hydrate of exploitation of handling up is hidden - Google Patents
A kind of hot CO of segment level well2The method that the heterogeneous hydrate of exploitation of handling up is hidden Download PDFInfo
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- CN107083943A CN107083943A CN201710402535.5A CN201710402535A CN107083943A CN 107083943 A CN107083943 A CN 107083943A CN 201710402535 A CN201710402535 A CN 201710402535A CN 107083943 A CN107083943 A CN 107083943A
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- hydrate
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/164—Injecting CO2 or carbonated water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
Abstract
The invention discloses a kind of hot CO of segment level well2The method that the heterogeneous hydrate of exploitation of handling up is hidden, mainly beats a bite horizontal production well, first carries out conventional hot CO2Determination of handling up is segmented number and its particular location, then changes the oil pipe column of horizontal production well, and Collaborative Control is respectively segmented the injection rate of tubing string.Its specific practice is：A bite horizontal production well is beaten in heterogeneous hydrate Tibetan, hot CO is injected2Carry out the production of handling up in two to four cycles, the Temperature Distribution of net horizontal section when recording each end cycle respectively, the number and its particular location of net horizontal section are determined using the optimum segmentation algorithm of Ordered Sample, the oil pipe column of horizontal production well is redesigned and changed according to result of calculation, and the hot CO of parameter guarantee is adopted by adjusting the note of each segmentation tubing string2Reasonable injection, the heterogeneous hydrate of exploitation of handling up hides.Present device is simple and convenient to operate, and the implementation that can hide well stimulation for heterogeneous hydrate provides guidance.
Description
Technical field
The present invention relates to a kind of recovery method of gas hydrates, a kind of segmentation is espespecially played in heterogeneous hydrate Tibetan
Horizontal well Collaborative Control is respectively segmented the hot CO of tubing string2Injection rate and progress handles up exploitation to improve gas hydrates recovery ratio
Method.
Background technology
Gas hydrates are stable in the presence of in the environment of high-temperature low-pressure in solid form, and its reserves is big, energy density is high,
It is important novel energy.With the development of the social economy, gas hydrates have caused universal concern, research is effective
Recovery method it is significant for the commercial development of gas hydrates.
Current exploitation of gas hydrate makes the gas hydrate dissociation of solid-state mainly by destroying its phase balance condition
Into gaseous natural gas and the water of liquid, recovery method mainly has voltage drop method, temperature activation method, chemical injection method and CO2Displacement method.
But the effect that is developed and utilized using single recovery method is limited and there are many shortcomings, such as voltage drop method easily causes water
The secondary generation of compound blocks flow channel；Temperature activation method heat loss is big；CO2Displacement method utilization ratio is low.On the other hand, it is non-equal
Matter generally existing in hydrate Tibetan, hides, high permeability area and hypotonicity area for the stronger hydrate of anisotropism
The hydrate in domain substantially, significantly affects development effectiveness by effect degree difference.
The research that a variety of Combination of Methods exploitation hydrates are hidden at present is few, and there is no for the effective of heterogeneous hydrate Tibetan
Recovery method, largely constrains the exploitation of hydrate Tibetan.The present invention utilizes segment level well cyclic injection heat
CO2Exploit heterogeneous hydrate to hide, voltage drop method, temperature activation method and CO can be realized2The advantageous combination of displacement method, compensate for single
The own limitations that method exploitation hydrate is hidden, CO is realized significantly improving while heterogeneous hydrate hides exploitation effect2
Ground storage, its equipment is simple and convenient to operate, and economy is strong, can be provided for the implementation of heterogeneous hydrate Tibetan well stimulation
Instruct.
The content of the invention
The present invention relates to a kind of hot CO of segment level well2The method that the heterogeneous hydrate of exploitation of handling up is hidden, it is main include with
Lower step：
(1) according to areal geology data, the hydrate for choosing coefficient of permeability variation ＞ 0.5 hides progress construction operation；
(2) hidden positioned at hydrate apart from topThe water that a bite horizontal section length is 500~1000m is beaten at position
Flat producing well, carries out perforation, on the binding site of the vertical well section of the horizontal production well and net horizontal section to the net horizontal section
Packer is installed in oil jacket annular space at 2~5m of side, uses polythene material to reduce heat positioned at the oil pipe of the vertical well section
Spacing between loss, the mounting temperature sensor in the oil pipe of the net horizontal section, the temperature sensor is 10~20m；
(3) hot CO is injected2The routine in two to four cycles by a definite date of progress is handled up production, and a described cycle of handling up includes
Two processes of injection stage and production phase, wherein, during injection stage, CO2Source of the gas and fuel are through hot CO2Generating means produce temperature
Spend the hot CO for 100~300 DEG C2, the hot CO2Injected from the well mouth oil pipe of the horizontal production well, at the end of the oil pipe
End enters oil jacket annular space, is hidden under the barrier of the packer through entering hydrate at the perforating site, heated point of hydrate
Solution, while the hot CO2Displace the CH in hydrate4, during the production phase, with the reduction of pressure near the net horizontal section,
Hydrate is further decomposed, and decomposes the CH of generation4, water and CO2Composition fluid-mixing is produced through the oil pipe, through surface separator
It is separated into CH4, water and CO2, wherein CO2Next periodic fever CO can be used as2Part source reuse, persistently record the water
The aerogenesis speed of flat producing well, when aerogenesis speed is less than 3000~5000m3During/d, terminate this cycle and start next cycle；
(4) distributed data of the temperature along the net horizontal section, two to four end cycles when recording each end cycle respectively
Afterwards, according to obtained temperature profile data, using the optimum segmentation algorithm of Ordered Sample determine the net horizontal section number and
Its particular location；
The optimum segmentation algorithm of the Ordered Sample belongs to prior art, referring specifically to bibliography：Zhong L.；
Zhang S.；Wu F.；et al.Improve Heavy Oil Recovery by Seperated-Zones Horizontal
Well Steam Stimulation；In:Society of Petroleum Engineers.Canadian
Unconventional Resources and International Petroleum Conference[C]；2010；
Its specific segmentation method is：
1. data matrix is built according to the temperature profile data, and regular turned to [0,1]；
2. segmentation diameter matrix is calculated；
3. respectively carry out optimize 2 times segmentation, 3 times segmentation until K time split, record respectively corresponding the best cutting point and
Sum of squares of deviations in corresponding group；K typically takes more than 5 according to different situations value；
4. change curve of the interior sum of squares of deviations of group with segmentation times is made；
5. corresponding segmentation times are defined as the level when sum of squares of deviations changes steady with segmentation times increase in organizing
Cut-point under the segmentation number of well section, corresponding segmentation times is the particular location of each segmentation；
(5) oil pipe column of the horizontal production well is redesigned and changed according to result of calculation, in the net horizontal section
Packer is installed in the oil jacket annular space at each segmentation position, the oil pipe column endcapped of the horizontal production well and not with stratum
Connection, each segmentation tubing string is provided with flow controller, to control hot CO2Injection and output；
(6) the hot CO of each segmentation tubing string described in Collaborative Control2Note adopt parameter, the hot CO2Injection rate press described each point
Duan Guanzhu length is allocated, the hot CO of unit level well section length2Injection rate be 0.5~2m3/ d, the cycle note
The angle of incidence is 7~15d, and exploitation hydrate of handling up is hidden, wherein, in the injection stage, the hot CO2From level production
Injected in the well mouth oil pipe of well, in the oil jacket annular space that each segmentation is entered through the flow controller, and in the resistance of the packer
Hidden every lower through entering hydrate at the perforating site, in the production phase, with pressure near the net horizontal section
Reduction, hydrate is further decomposed, the CH of each segmentation decomposition generation4, water and CO2Fluid-mixing is constituted through the flow controller
Into in the oil pipe and it is plucked out of, the fluid-mixing is separated into CH through surface separator4, water and CO2, it is lasting to record described
The aerogenesis speed of horizontal production well, when aerogenesis speed is less than 3000~5000m3During/d, terminate this cycle and start next cycle.
The beneficial effects of the invention are as follows：
It utilizes the hot CO of segment level well cyclic injection2Exploit heterogeneous hydrate to hide, not only compensate for single method
The own limitations that hydrate is hidden are exploited, CO is realized2Ground storage, and opening of significantly improving that heterogeneous hydrate hides
Effect is adopted, its equipment is simple and convenient to operate, economy is strong, the implementation that can hide well stimulation for heterogeneous hydrate provides guidance.
Brief description of the drawings
Fig. 1 is the hot CO of conventional horizontal well2The heterogeneous hydrate of exploitation of handling up hides injection stage schematic diagram.
Fig. 2 is the hot CO of conventional horizontal well2The heterogeneous hydrate of exploitation of handling up hides production phase schematic diagram.
Fig. 3 is distribution curve of the temperature obtained after conventional production of handling up terminates along net horizontal section.
Fig. 4 be in temperature data group sum of squares of deviations with segmentation times change curve.
Fig. 5 is the hot CO of segment level well2The heterogeneous hydrate of exploitation of handling up hides injection stage schematic diagram.
Fig. 6 is the hot CO of segment level well2The heterogeneous hydrate of exploitation of handling up hides production phase schematic diagram.
In figure：1st, heterogeneous hydrate is hidden；2、CO2Source of the gas；3rd, fuel；4th, hot CO2Generating means；5th, wellhead assembly；6th, cover
Pipe；7th, vertical adiabatic well section；8th, packer；9th, hot CO2；10th, temperature sensor；11st, perforation；12nd, net horizontal section；13rd, mix
Fluid；14th, surface separator；15、CH4；16th, water；17、CO2；18th, flow controller.
Embodiment
The invention will be further described below in conjunction with the accompanying drawings, but does not limit the practical range of the present invention.
According to areal geology data, the hydrate that choosing has stronger anisotropism, which is hidden, carries out construction operation, as shown in figure 1,
The coefficient of permeability variation that heterogeneous hydrate hides 1 is 0.7；
As shown in figure 1, hiding 1 apart from top positioned at hydrateA bite horizontal production well is beaten at position, horizontal production well
The length of net horizontal section 12 is 800m, perforation 11 is carried out to net horizontal section 12, in the vertical well section 7 of horizontal production well and net horizontal section
Packer 8 is installed, the oil pipe positioned at vertical well section 7 uses polyethylene material in the oil jacket annular space above 12 binding site at 2~5m
Material is to reduce heat loss, and clipping room is away from the temperature sensor 10 for 20m in the oil pipe of net horizontal section 12；
Inject hot CO2The routine in three cycles by a definite date of progress is handled up production, and as shown in Fig. 19, described one handles up week
Phase includes two processes of injection stage (Fig. 1) and production phase (Fig. 2)；
As shown in figure 1, during injection stage, CO2Source of the gas 2 and fuel 3 are through hot CO2It is 260 DEG C that generating means 4, which produce temperature,
Hot CO2, as shown in Figure 9, hot CO2Injected from the oil pipe of the well head 5 of horizontal production well, enter oil jacket annular space in oil pipe end,
Enter hydrate through perforation 11 under the barrier of packer 8 and hide 1, hydrate is thermally decomposed, while hot CO2Displace in hydrate
CH4；
As shown in Fig. 2 during the production phase, with the reduction of pressure near net horizontal section 12, hydrate is further decomposed, point
Solve the CH of generation4, water and CO2Composition fluid-mixing 13 is produced through oil pipe, and CH is separated into through surface separator 144, water and CO2,
As shown in figure 15,16 and 17, wherein CO2Next periodic fever CO can be used as2Part source reuse, continue recording level
The aerogenesis speed of producing well, when aerogenesis speed is less than 3000m3During/d, terminate this cycle and start next cycle；
As shown in figure 3, distributed data of the temperature along net horizontal section when recording each end cycle respectively, three cycle knots
Shu Hou, according to obtained temperature profile data, the number of the net horizontal section is determined using the optimum segmentation algorithm of Ordered Sample
And its particular location；
The optimum segmentation algorithm of the Ordered Sample belongs to prior art, referring specifically to bibliography：Zhong L.；
Zhang S.；Wu F.；et al.Improve Heavy Oil Recovery by Seperated-Zones Horizontal
Well Steam Stimulation；In:Society of Petroleum Engineers.Canadian
Unconventional Resources and International Petroleum Conference[C]；2010；
Its specific segmentation method is：
1. data matrix is built according to the temperature profile data, and regular turned to [0,1]；
2. segmentation diameter matrix is calculated；
3. respectively carry out optimize 2 times segmentation, 3 times segmentation until 5 times segmentation, record respectively corresponding the best cutting point and
Sum of squares of deviations in corresponding group；
4. as shown in figure 4, making change curve of the interior sum of squares of deviations of group with segmentation times；
5. corresponding segmentation times are defined as net horizontal section when sum of squares of deviations changes steady with segmentation times increase in organizing
Segmentation number, the cut-point under corresponding segmentation times is the particular location of each segmentation, as shown in figure 4, segmentation number is 3, such as
Shown in Fig. 3, the length of the first segmentation tubing string is 360m, and the length of the second segmentation tubing string is 230m, the length of the 3rd segmentation tubing string
For 210m；
As shown in figure 5, the oil pipe column of horizontal production well is redesigned and changed according to result of calculation, in net horizontal section 12
Packer 8 is installed in the oil jacket annular space at each segmentation position, the oil pipe column endcapped of horizontal production well and is not connected with stratum
Logical, each segmentation tubing string is provided with flow controller 18, to control hot CO2Injection and output；
Collaborative Control is respectively segmented the hot CO of tubing string2Note adopt parameter, hot CO2Injection rate by it is each segmentation tubing string length enter
Row distribution, the hot CO of unit level well section length2Injection rate be 1m3/ d, cycle injection length is 12d, exploitation hydration of handling up
Thing hides 1, as shown in figure 5, in injection stage, hot CO2Injected from the oil pipe of the well head 5 of horizontal production well, through flow control
Device 18 enters in the oil jacket annular space of each segmentation, and hides 1 through entering hydrate at the perforating site under the barrier of packer 8；
As shown in fig. 6, in the production phase, with the reduction of pressure near net horizontal section 12, hydrate is further decomposed,
The CH of each segmentation decomposition generation4, water and CO2Composition fluid-mixing 13 enters in oil pipe and is plucked out of through flow controller 18, mixes
Fluid is separated into CH through surface separator 144, water and CO2, as shown in figure 15,16 and 17, continue recording level producing well
Aerogenesis speed, when aerogenesis speed is less than 3000m3During/d, terminate this cycle and start next cycle.
The part do not addressed in detail above is the common knowledge of those of ordinary skill in the art, and the present invention is not limited to
Preferred forms are stated, it is every to have with of the invention anyone should learn that the structure change made under the enlightenment of the present invention
Same or like technical scheme, each falls within the scope of the present invention.
Claims (6)
1. a kind of hot CO of segment level well2The method that the heterogeneous hydrate of exploitation of handling up is hidden, its dozen of a bite horizontal production wells are advanced
The conventional hot CO of row2Handle up and determine the segmentation number and its particular location of net horizontal section, then redesign and change level production
The oil pipe column of well, the hot CO of parameter guarantee is adopted by adjusting the note of each segmentation tubing string2Reasonable injection, realize hot CO2Homogeneous wave
And, so as to significantly improve the development effectiveness that heterogeneous hydrate is hidden, greatly improve recovery ratio, it is characterised in that including following step
Suddenly：
Step (1)：According to areal geology data, the hydrate that choosing has stronger anisotropism, which is hidden, carries out construction operation；
Step (2)：Hidden positioned at hydrate apart from topA bite horizontal production well is beaten at position, to the horizontal production well
Net horizontal section carry out perforation, in the oil above the binding site of the vertical well section of the horizontal production well and net horizontal section at 2~5m
The collar installs packer in the air, and the oil pipe positioned at the vertical well section uses heat-insulating material, positioned at the oil pipe of the net horizontal section
Mounting temperature sensor；
Step (3)：Inject hot CO2The routine in two to four cycles by a definite date of progress is handled up production, and a described cycle of handling up includes
Two processes of injection stage and production phase, wherein, during injection stage, CO2Source of the gas and fuel are through hot CO2Generating means produce heat
CO2, the hot CO2Injected from the well mouth oil pipe of the horizontal production well, enter oil jacket annular space in the end of the oil pipe,
Hidden under the barrier of the packer through entering hydrate at the perforating site, hydrate is thermally decomposed, while the hot CO2Put
The CH swapped out in hydrate4, during the production phase, with the reduction of pressure near the net horizontal section, hydrate is further decomposed,
Decompose the CH of generation4, water and CO2Composition fluid-mixing is produced through the oil pipe, and CH is separated into through surface separator4, water and
CO2, wherein CO2Next periodic fever CO can be used as2Part source reuse, persistently record the aerogenesis of the horizontal production well
Speed, when aerogenesis speed is less than 3000~5000m3During/d, terminate this cycle and start next cycle；
Step (4)：Distributed data of the temperature along net horizontal section when recording each end cycle respectively, two to four end cycles
Afterwards, according to obtained temperature profile data, using the optimum segmentation algorithm of Ordered Sample determine the net horizontal section number and
Its particular location；
The optimum segmentation algorithm of the Ordered Sample belongs to prior art, referring specifically to bibliography：Zhong L.；Zhang
S.；Wu F.；et al.Improve Heavy Oil Recovery by Seperated-Zones Horizontal Well
Steam Stimulation；In:Society of Petroleum Engineers.Canadian Unconventional
Resources and International Petroleum Conference[C]；2010；
Its specific segmentation method is：
1. data matrix is built according to the temperature profile data, and regular turned to [0,1]；
2. segmentation diameter matrix is calculated；
3. carry out optimizing 2 segmentations, 3 segmentations respectively until K time splits, corresponding the best cutting point and correspondingly is recorded respectively
Group in sum of squares of deviations；K typically takes more than 5 according to different situations value；
4. change curve of the interior sum of squares of deviations of group with segmentation times is made；
5. corresponding segmentation times are defined as the net horizontal section when sum of squares of deviations changes steady with segmentation times increase in organizing
Segmentation number, the cut-point under corresponding segmentation times is the particular location of each segmentation；
Step (5)：The oil pipe column of the horizontal production well is redesigned and changed according to result of calculation, in the net horizontal section
Packer is installed in the oil jacket annular space at each segmentation position, the oil pipe column endcapped of the horizontal production well and not with stratum
Connection, each segmentation tubing string is provided with flow controller, to control hot CO2Injection and output；
Step (6)：The hot CO of each segmentation tubing string described in Collaborative Control2Note adopt parameter, the hot CO2Injection rate by described each
The length of segmentation tubing string is allocated, the hot CO of unit level well section length2Injection rate be 0.5~2m3/ d, the cycle
Injection length is 7~15d, and exploitation hydrate of handling up is hidden, wherein, in the injection stage, the hot CO2From level life
Produce in the well mouth oil pipe of well and inject, in the oil jacket annular space that each segmentation is entered through the flow controller, and in the packer
Hidden under barrier through entering hydrate at the perforating site, in the production phase, with pressure near the net horizontal section
Reduction, hydrate further decomposes, the CH of each segmentation decomposition generation4, water and CO2Composition fluid-mixing is controlled through the flow
Device enters in the oil pipe and is plucked out of, and the fluid-mixing is separated into CH through surface separator4, water and CO2, persistently record institute
The aerogenesis speed of horizontal production well is stated, when aerogenesis speed is less than 3000~5000m3During/d, terminate this cycle and start next week
Phase.
2. a kind of hot CO of segment level well as claimed in claim 12The method that the heterogeneous hydrate of exploitation of handling up is hidden, its feature
It is, the coefficient of permeability variation ＞ 0.5 that the hydrate is hidden.
3. a kind of hot CO of segment level well as claimed in claim 12The method that the heterogeneous hydrate of exploitation of handling up is hidden, its feature
It is, the hot CO2Temperature be 100~300 DEG C.
4. a kind of hot CO of segment level well as claimed in claim 12The method that the heterogeneous hydrate of exploitation of handling up is hidden, its feature
It is, the length of the net horizontal section is 500~1000m.
5. a kind of hot CO of segment level well as claimed in claim 12The method that the heterogeneous hydrate of exploitation of handling up is hidden, its feature
It is, the spacing between the temperature sensor is 10~20m.
6. a kind of hot CO of segment level well as claimed in claim 12The method that the heterogeneous hydrate of exploitation of handling up is hidden, its feature
It is, the heat-insulating material that the oil pipe of the vertical well section is used is polyethylene.
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108104776A (en) * | 2017-12-12 | 2018-06-01 | 大连理工大学 | A kind of water erosion method exploiting ocean natural gas hydrates device of combination decompression |
| CN108798607A (en) * | 2018-07-04 | 2018-11-13 | 中国石油大学(华东) | A kind of method that horizontal well in segments perforation develops heterogeneous gas hydrates |
| CN112360408A (en) * | 2020-12-03 | 2021-02-12 | 西南石油大学 | Novel method for improving recovery ratio of thickened oil by injecting carbon dioxide hot fluid |
| CN115111519A (en) * | 2021-03-23 | 2022-09-27 | 中国石油天然气股份有限公司 | Full-wellbore gas storage device suitable for huff and puff development mode and use method thereof |
| CN115111519B (en) * | 2021-03-23 | 2024-04-30 | 中国石油天然气股份有限公司 | Full-shaft gas storage device suitable for throughput development mode and application method thereof |
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| CN105464634A (en) * | 2015-12-15 | 2016-04-06 | 中国科学院力学研究所 | Method for exploiting methane hydrate by using stored carbon dioxide |
| CN105909223A (en) * | 2016-05-03 | 2016-08-31 | 中国石油大学(华东) | Method for electric heating assisted depressurizing production of natural gas hydrate reservoir through dual horizontal shafts |
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| US20120061084A1 (en) * | 2010-09-03 | 2012-03-15 | Landmark Graphics Corporation | Detecting and Correcting Unintended Fluid Flow Between Subterranean Zones |
| CN105464634A (en) * | 2015-12-15 | 2016-04-06 | 中国科学院力学研究所 | Method for exploiting methane hydrate by using stored carbon dioxide |
| CN105909223A (en) * | 2016-05-03 | 2016-08-31 | 中国石油大学(华东) | Method for electric heating assisted depressurizing production of natural gas hydrate reservoir through dual horizontal shafts |
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108104776A (en) * | 2017-12-12 | 2018-06-01 | 大连理工大学 | A kind of water erosion method exploiting ocean natural gas hydrates device of combination decompression |
| CN108798607A (en) * | 2018-07-04 | 2018-11-13 | 中国石油大学(华东) | A kind of method that horizontal well in segments perforation develops heterogeneous gas hydrates |
| CN108798607B (en) * | 2018-07-04 | 2020-07-07 | 中国石油大学(华东) | Method for developing heterogeneous natural gas hydrate reservoir by horizontal well sectional perforation |
| CN112360408A (en) * | 2020-12-03 | 2021-02-12 | 西南石油大学 | Novel method for improving recovery ratio of thickened oil by injecting carbon dioxide hot fluid |
| CN115111519A (en) * | 2021-03-23 | 2022-09-27 | 中国石油天然气股份有限公司 | Full-wellbore gas storage device suitable for huff and puff development mode and use method thereof |
| CN115111519B (en) * | 2021-03-23 | 2024-04-30 | 中国石油天然气股份有限公司 | Full-shaft gas storage device suitable for throughput development mode and application method thereof |
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| CN107083943B (en) | 2019-10-18 |
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