CN105673001A - Processing method for reduction in formation pressure of carbonatite single well - Google Patents
Processing method for reduction in formation pressure of carbonatite single well Download PDFInfo
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Abstract
The invention provides a processing method for pressure decrease of a carbonatite single well. The carbonatite single well is a volatile reservoir single well. The reservoir type of the single well is a cave reservoir. The formation pressure of the single well is smaller than saturation pressure of oil reservoir and degassing occurs. The method comprises following steps: 1), measuring formation pressure of the single well in order to obtain difference between saturation pressure of oil reservoirs and formation pressure of the single well, wherein the difference is ground saturation pressure difference; 2), obtaining geological reserves of the single well; 3), obtaining secondary gas volume of the single well according to geological reserves of the single well; 4), obtaining required water filling quantity for restoring formation pressure of the single well above saturation pressure of oil reservoirs according to specific pressure drop of oil production and secondary gas volume prior to degassing; 5), filling water to the single well. The technical scheme can obtain required water filling quantity for restoring formation pressure of the single well above saturation pressure of oil reservoirs and helps avoid the drowning single well during a water filling process.
Description
Technical field
The present invention relates to a kind of carbonatite individual well drop in formation pressure treatment process, particularly relate to a kind of reservoir pressure at carbonatite individual well lower than the method processing individual well during its oil reservoir saturation pressure.
Background technology
Under normal circumstances, oil-field development well spacing great majority adopt spot flooding, gas injection to keep reservoir pressure, avoid at oil reservoir recovery process well pressure lower than oil reservoir saturation pressure, occur that undesirable stratum is degassed or retrograde fall out, and the mode of above-mentioned maintenance reservoir pressure needs to carry out when there being well to be connected usually.
For the individual well that reservoir isolates relatively, particularly carbonatite volatilization oil reservoir individual well, owing to seam hole is relatively isolated, when bottomless water energy supplement, reservoir pressure exhaustion speed is very fast, once after occurring that stratum is degassed, a large amount of crude oil heavy components precipitates out and remains in seam low position, hole, and the secondary pneumatic jack formed is gathered in seam height position, hole, the gas of the secondary pneumatic jack of the main extraction of opening well and making production, extraction the crude oil stitching low position, hole cannot be distributed in. Under normal circumstances, occurring that pressure is gone up to saturation pressure by degassed individual well to water filling, required water injection rate is all bigger, and cave type reservoir individual well, cavern location, cave form and cave scale to be met according to brill and judge whether applicable a large amount of water filling. Little cave is grown for shaft bottom, the individual well of fracture development around cave, easily individual well is drowned after full-scale water injection, equally, bore the individual well meeting seam low position, hole, water logging also can occur rapidly after water filling. Even if be applicable to the individual well of full-scale water injection according to above-mentioned micro-judgment, also there is the problem that water injection rate is difficult to accurately determine easily water logging with the injecting process, the situation of the current drop in formation pressure for carbonatite volatilization oil reservoir individual well, there is no proven technique and supplement stratum ENERGY METHOD, output of can only leaving reduces.
A kind of becoming for volatilization oil reservoir carbonatite individual well offer a kind of effective pressure reduction treatment process how is provided to have problem to be solved.
Summary of the invention
The present invention provides a kind of carbonatite individual well drop in formation pressure treatment process, obtained by specific method and the reservoir pressure of described individual well is returned to the required water injection rate of more than oil reservoir saturation pressure, and in conjunction with specific water flooding regime, the problem that individual well can be avoided to cause individual well drowned with water flooding regime raising reservoir pressure process, finally realizes the raising of per-well production.
A kind of carbonatite individual well drop in formation pressure treatment process provided by the invention, described carbonatite individual well is volatilization oil reservoir individual well, the reservoir type of described individual well is cave type reservoir, and the reservoir pressure of described individual well lower than oil reservoir saturation pressure and occurs degassed, described method comprises the following steps:
1) measure the reservoir pressure of described individual well, obtain the difference of the reservoir pressure of described oil reservoir saturation pressure and described individual well, pressure reduction of namely satisfying;
2) geologic reserve of described individual well is obtained;
3) geologic reserve according to described individual well obtains the secondary gas volume in described individual well;
4) according to the oil offtake of degassed unit drop in formation pressure before, and described secondary gas volume, obtain by formula 4 and described individual well reservoir pressure returned to the required water injection rate of more than oil reservoir saturation pressure,
VWater filling=VSecondary+ b Δ P ' γ formula 4,
Wherein VWater fillingFor the reservoir pressure of described individual well being returned to the required water injection rate of more than oil reservoir saturation pressure; VSecondaryFor the secondary gas volume in described individual well; B is the oil offtake of degassed unit pressure drop before, unit m3; The reservoir pressure that Δ P ' gos up needed for water filling, namely total voltage rise, is more than or equal to pressure reduction of satisfying, units MPa describedly; γ is profit volume gain factor;
5) described individual well is carried out water filling.
In the solution of the present invention, step 5) described individual well is carried out water filling carry out in the following ways: daily water-injection rate 300-600 side/sky, described water injection pressure is greater than 0MPa and is less than 8MPa.
In the scheme of the application, water injection rate calculates according to by the concrete pressure that the reservoir pressure of described individual well recovers, those skilled in the art can be as required, select the concrete pressure (at least will more than oil reservoir saturation pressure) to be returned to, thus the formula according to the application determines water injection rate. Certain those skilled in the art can also carry out taking turns or taking turns water filling more as required.
In a specific embodiment of the present invention, in step 4) obtain described water injection rate after, and step 5) individual well carried out water filling before, the brill of the target individual well of cave type reservoir can be met cavern location, the form in cave and cave scale and be judged whether applicable fairly large water filling by those skilled in the art as required. Such as, directly bore the individual well (having emptying, severe leakage) meeting cave, can come from judging to bore the position meeting seam hole according to the seismic wave inside story wave resistance attribute section of drilling trajectory, the applicable full-scale water injection in reservoir height position is met if bored, bore the low position meeting reservoir, then can not full-scale water injection; The non-emptying leakage of drilling well, but when acid fracturing curve shows to press off cave, it is possible to make seam length according to shaft bottom imaging crack angle and acid fracturing and determine to bore the roughly position meeting seam hole, bore the upper position individual well meeting cave and be applicable to water filling. Should be noted that: if the wave resistance inverting attribute of this well shows that transversely reservoir bodies grows individual well simultaneously, and being not suitable for full-scale water injection, oil is easily dispersed by full-scale water injection, if well test data display, if cave is less, and the well of fracture development is also not suitable for full-scale water injection.Above-mentioned judgement process can realize according to the existing experience in this area and equipment for those skilled in the art. The object of above-mentioned judgement process gets rid of the individual well of some not obvious applicable water fillings, the single well the solution of the present invention of water filling water injection rate can be calculated for according to above-mentioned micro-judgment, and the specific water flooding regime adopting the application carries out water filling, with the problem avoiding individual well to cause individual well drowned with water flooding regime raising reservoir pressure process, it is achieved the raising of per-well production.
In the solution of the present invention, described oil reservoir saturation pressure obtains according to following experimental formula 1
Wherein PbFor saturation pressure, units MPa; RsFor gas oil ratio; rgFor Sweet natural gas relative density; T is formation temperature; roFor crude oil density in stock tank, normal pressure, 20 DEG C record.
Same, described oil reservoir saturation pressure can also obtain according to following formula 1 ＇
Wherein PbFor saturation pressure, units MPa; R is gas oil ratio; roFor crude oil density in stock tank, normal pressure, 20 DEG C record; rgFor Sweet natural gas relative density; A is statistics constant; B is intercept. Wherein adding up constant A is linear gradient; Intercept b is the intercept of ordinate zou. Gas oil ratio in above-mentioned two formula and Sweet natural gas relative density, formation temperature, crude oil density in stock tank, all can adopt this area routine techniques means to obtain.
Formula 1, formula 1 ＇ may be used to obtain oil reservoir saturation pressure usually, and the PVT data that can utilize existing oil well is verified, can also by comparing the dependency of two formula, selecting the formula higher with the actual fitting correlation coefficient in oil field to carry out the calculating of oil reservoir saturation pressure, this can realize for a person skilled in the art. In actual production, the matching dependency of formula 1 ＇ is higher, and the saturation pressure not having PVT data individual well for calculating.
In another embodiment of the present invention, if there is water body in individual well, it is possible to obtain the geologic reserve (individual well reserves scale or cave size can also be become) of described individual well according to following formula 2
NpBo+WpBw=NBoiCotΔP+WeFormula 2
Wherein NpFor ground accumulation oil offtake, unit m3; BOFor oil volume factor under reservoir pressure; WpFor ground accumulation water production rate, unit m3; Bw is the volume coefficient of water; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient; CotFor total compression coefficient 1/MPa; Δ P is total pressure drop, units MPa; We is water influx rate, unit m3。
Further, if individual well does not exist water body, then can be reduced to the geologic reserve that formula 2 ＇ obtains described individual well,
NpBo/ Δ P=NBoiCotFormula 2 '
Wherein NpFor ground accumulation oil offtake, unit m3; BOFor oil volume factor under reservoir pressure; Δ P is total pressure drop, units MPa; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient; CotFor total compression coefficient 1/MPa.
In another embodiment of the present invention, it is possible to the secondary gas volume in individual well according to following formula 3
VSecondary=N ' a formula 3;
Wherein VSecondaryFor the secondary gas volume in described individual well; N ' is remaining geologic reserves when pressure is down to saturation pressure, unit m3; A be in described individual well containing gas ratio, gas, liquid content that described a is determined under the reservoir pressure of described individual well in described individual well by the isothermal pressure drop curve of resident fluid phase diagram obtain. When N ' pressure is down to saturation pressure, remaining geologic reserves can by step 2) the oil amount of the geologic reserve of described individual well that obtains and output calculates.
The solution of the present invention has following useful effect:
1) the solution of the present invention can be easier to and obtain accurately the reservoir pressure of individual well returns to the required water injection rate of more than oil reservoir saturation pressure.
2) the solution of the present invention is adopted to process, lower than carrying out during its oil reservoir saturation pressure, the problem that individual well can be avoided to cause individual well drowned with water flooding regime raising reservoir pressure process at the reservoir pressure of described carbonatite individual well.
3) the solution of the present invention is adopted can to significantly improve per-well production, and the advantage that validity period length, risk are little, cost is low.
Accompanying drawing explanation
The isothermal pressure drop graphic representation of the resident fluid phase diagram of carbonatite individual well in Fig. 1 embodiment of the present invention 1. Wherein X-coordinate represents temperature, ordinate zou representative pressure, Pm is saturation pressure, article 5, curve is gas with various Molar content (20%, 40%, 60%, 80%, 100%) the isothermal pressure drop graphic representation under, the temperature of longitudinal represented by dotted arrows oil reservoir, the saturation pressure of horizontal represented by dotted arrows oil reservoir.
Embodiment
For making the object of the present invention, technical scheme and technique effect clearly; below in conjunction with the specific embodiment of the invention and accompanying drawing; technical scheme in the embodiment of the present invention is clearly and completely described; but following examples can not be interpreted as to the present invention can the restriction of practical range; based on the embodiment in the present invention; other embodiments all that those of ordinary skill in the art obtain under the prerequisite not making creative work, all belong to the scope of protection of the invention.
Embodiment 1 adopts the inventive method to process lower than during its oil reservoir saturation pressure at the reservoir pressure of carbonatite individual well.
A certain carbonatite individual well, well depth 6994.61m, belongs to volatility light oil reservoirs, the initial formation pressure 76.88MPa of individual well, owing to this well belongs to water energy cave type reservoir on the weak side, reservoir pressure rapid decrease after going into operation, exploited after 10 months, and this well reservoir pressure is down under saturation pressure, the degassed phenomenon in stratum occurs, steam oil ratio (SOR) from rising rapidly to 3500 less than 600, and daily output oil drops to 3 tons from 30 tons, and declining to a great extent occurs in oil density.
Adopt the method for the present invention that the reservoir pressure of this carbonatite individual well is as follows lower than carrying out treating processes during its oil reservoir saturation pressure:
1) measure the reservoir pressure of described individual well, obtain the difference of the reservoir pressure of described oil reservoir saturation pressure and described individual well, pressure reduction of namely satisfying;
Described oil reservoir saturation pressure can obtain according to following formula 1
Wherein PbFor saturation pressure, units MPa; RsFor gas oil ratio; rgFor Sweet natural gas relative density; T is formation temperature; roFor crude oil density in stock tank, normal pressure, 20 DEG C record; Or
Described oil reservoir saturation pressure obtains according to following formula 1 ＇
Wherein PbFor saturation pressure, units MPa; R is gas oil ratio; roFor crude oil density in stock tank, normal pressure, 20 DEG C record; rgFor Sweet natural gas relative density; A is statistics constant; B is intercept. By existing PVT data, utilizing formula 1 and formula 1 ' to carry out matching dependency contrast, the formula selecting fitting degree higher calculates.
The embodiment of the present application adopt formula 1 ' obtain the saturation pressure of described oil reservoir. This area routine techniques means can be adopted to obtain the gas oil ratio in above-mentioned formula 1 ' and Sweet natural gas relative density, crude oil density in stock tank. The gas oil ratio obtained is actual metered result, and Sweet natural gas relative density is fluid result of laboratory test, and crude oil density in stock tank is crude oil sampling metering result of laboratory test.
After obtaining above-mentioned value, calculating described oil reservoir saturation pressure according to formula 1 ' is 30.82MPa (this well saturation pressure of PVT test result is 31.12MPa, and error is very little).
The reservoir pressure of this well measurements individual well adopts direct-reading type pressure well to be surveyed stratum static pressure, and the reservoir pressure of the individual well recorded is 27.31MPa. The difference of described reservoir formation pressure and saturation pressure is 3.51MPa.
2) geologic reserve of described individual well is obtained;
If individual well exists water body, obtain the geologic reserve of described individual well according to following formula 2
NpBo+WpBw=NBoiCotΔP+WeFormula 2
Wherein NpFor ground accumulation oil offtake, unit m3; BOFor oil volume factor under reservoir pressure; WpFor ground accumulation water production rate, unit m3; Bw is the volume coefficient of water; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient; CotFor total compression coefficient 1/MPa; Δ P is total pressure drop, and described total pressure drop is the initial formation pressure and 1 of individual well) difference of the reservoir pressure of described individual well measured, units MPa; We is water influx rate, unit m3; Or
If individual well does not exist water body, obtain the geologic reserve of described individual well according to following formula 2 ＇,
NpBo/ Δ P=NBoiCotFormula 2 '
Wherein NpFor ground accumulation oil offtake, unit m3; BOFor oil volume factor under reservoir pressure; Δ P is total pressure drop, units MPa; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient; CotFor total compression coefficient 1/MPa.
The embodiment of the present application adopt formula 2 obtain described individual well reserves, the volume coefficient of oil volume factor under ground accumulation oil offtake that this area routine techniques means obtain in above-mentioned formula 2, reservoir pressure, ground accumulation water production rate, water can be adopted, virgin pressure lower volume coefficient, total compression coefficient, total pressure drop, water influx rate. The ground accumulation oil offtake obtained is 1.26 ten thousand tons (when substituting into formula 2, it is possible to be scaled volume, m3), under reservoir pressure oil volume factor be 2.5272, ground accumulation water production rate be 6 tons (when substituting into formula 2, it is possible to be scaled volume, m3), the volume coefficient of water can obtain according to this area ydrodynamics teaching material, the virgin pressure lower volume coefficient of water is 1.08, total compression coefficient 1/MPa, the initial formation pressure and 1 that total pressure drop is individual well) difference of the reservoir pressure of described individual well measured, i.e. 49.57MPa, water influx rate is approximately 0. After obtaining above-mentioned value, the geologic reserve calculating described individual well according to formula 2 is 6.7 ten thousand tons.
3) geologic reserve according to described individual well obtains the secondary gas volume in described individual well;
Secondary gas volume in individual well according to following formula 3
VSecondary=N ' a formula 3;
Wherein VSecondaryFor the secondary gas volume in described individual well; N ' is remaining geologic reserves when pressure is down to saturation pressure, unit m3; A be in described individual well containing gas ratio, described a can by the isothermal pressure drop curve of resident fluid phase diagram, it is determined that under the reservoir pressure of described individual well, the gas in described individual well, liquid content obtain. The isothermal pressure drop curve of described resident fluid phase diagram is see Fig. 1. Concrete grammar is for utilizing 1) in the actual formation pressure of individual well that records be 27.31MPa, at individual well temperature it is 145 DEG C, according to the position of point on phasor that the two intersects, and the gas with various Molar content (20%, 40%, 60% on phasor, 80%, 100%) the isothermal pressure drop curve under, estimates this some place gas volume molar content, thus obtain in this individual well containing gas ratio a. Such as: 20%, this is the method containing gas ratio in the acquisition individual well of this area routine, and those skilled in the art can also according to other gas volume molar content (40%, 60%, 80%, 85%, 87%100%) the isothermal pressure drop curve under obtains this containing gas ratio a.
Secondary gas volume in the described individual well obtained is close to 20,000 sides.
4) according to the oil offtake of degassed unit pressure drop before, and described secondary gas volume, obtain by formula 4 and described individual well reservoir pressure returned to the required water injection rate of more than oil reservoir saturation pressure,
VWater filling=VSecondary+ b Δ P ' γ formula 4,
Wherein VWater fillingFor the reservoir pressure of described individual well being returned to the required water injection rate of more than oil reservoir saturation pressure; VSecondaryFor the secondary gas volume in described individual well; B is the oil offtake of degassed unit pressure drop before, unit m3; The reservoir pressure that Δ P ' gos up needed for water filling, namely total voltage rise, is more than or equal to pressure reduction of satisfying, units MPa describedly; γ is profit volume gain factor;
Due to this well VSecondaryClose to 20,000 sides; Accumulative product oil 1.26 ten thousand tons before water filling, reservoir pressure drops to 27.31 MPas from 76.88 MPas; Profit volume gain factor adopts this area ordinary method to obtain, and is 2.04. Those skilled in the art can utilize formula 4, according to the concrete pressure (at least will more than oil reservoir saturation pressure) to be returned to by the reservoir pressure dropping to 27.31 MPas, determines described water injection rate.
Owing to this individual well remains in seam low position, hole after also having a large amount of heavy component to precipitate out, and this well bores chance seam height position, hole, cannot by degassed crude oil from seam hole low position extraction by conventional step-down exploitation, the individual well that mode is all not suitable for high gas oil ratio like this adopted by current any machine, also cannot implement cyclic gas injection and handle up. According to the existing experience in this area and equipment, the cavern location of described individual well, the form in cave and cave scale data being carried out water filling risk evaluation, contriver thinks that well can not be drowned by the fairly large water filling of this well.
5) with under type, described individual well being carried out water filling: daily water-injection rate 300-600 side/sky, water injection pressure is greater than 0MPa and is less than 8MPa.
First round water filling: stop water filling after injecting 4408 side's water for 1-14 days, check down-hole state after water filling, do not occur that well floods, formation testing pressure raises as 29.35MPa, reservoir pressure rises only about 2MPa, showing that pneumatic jack shrinks to some extent, after opening well, gas oil ratio still reaches 3000, and daily output oil is less than 5 tons.
2nd takes turns water filling: this well started to stop water filling to water filling in 7th month 2.66 ten thousand side in 3rd month, checking down-hole state after water filling, it does not have occur that well floods, formation testing pressure gos up to 52 MPas, obviously higher than this well saturation pressure 30.82MPa, illustrate that pneumatic jack shrinks substantially.
Closing well one month, after within the 8th month, opening well, oil increasing effect is obvious, and daily output oil reaches 50 tons, and day, oil increment was more than 45 tons, and gas oil ratio is down to about 300, ended 12nd month, and oil increment reaches 5668 tons, and still blowing is produced at present, and epicycle oil increment is estimated more than 7000 tons.
Can at epicycle pressure drop to continuing to carry out water injection to keep pressure when saturation pressure, it is contemplated that this well is by the exploitation of many rounds water injection to keep pressure, and this well can increase above the recovery ratio of 20%, and oil increment can more than 10,000 tons.
Adopt the solution of the present invention can make when reservoir pressure is carbonatite individual well lower than its oil reservoir saturation pressure, reservoir pressure can be allowed to go up to saturation pressure, make that the Sweet natural gas of precipitation is counter dissolves in crude oil, ensure that a large amount of water that injects can realize gravity displacement on stratum and crude oil simultaneously, people is lifting water-oil interface, realize increasing oil object, can't occur to improve, with water flooding regime, the problem that well presses through journey and cause individual well drowned.
Claims (6)
1. a carbonatite individual well drop in formation pressure treatment process, described carbonatite individual well is volatilization oil reservoir individual well, the reservoir type of described individual well is cave type reservoir, and the reservoir pressure of described individual well lower than oil reservoir saturation pressure and occurs degassed, and described method comprises the following steps:
1) measure the reservoir pressure of described individual well, obtain the difference of the reservoir pressure of described oil reservoir saturation pressure and described individual well, pressure reduction of namely satisfying;
2) geologic reserve of described individual well is obtained;
3) geologic reserve according to described individual well obtains the secondary gas volume in described individual well;
4) according to the oil offtake of degassed unit drop in formation pressure before, and described secondary gas volume, obtain by formula 4 and described individual well reservoir pressure returned to the required water injection rate of more than oil reservoir saturation pressure,
VWater filling=VSecondary+ b Δ P ' γ formula 4,
Wherein VWater fillingFor the reservoir pressure of described individual well being returned to the required water injection rate of more than oil reservoir saturation pressure; VSecondaryFor the secondary gas volume in described individual well; B is the oil offtake of degassed unit pressure drop before, unit m3; The reservoir pressure that Δ P ' gos up needed for water filling, namely total voltage rise, is more than or equal to pressure reduction of satisfying, units MPa describedly; γ is profit volume gain factor;
5) described individual well is carried out water filling.
2. method according to claim 1, step 5) described individual well is carried out water filling carry out in the following ways: daily water-injection rate 300-600 side/sky, water injection pressure is greater than 0MPa and is less than 8MPa.
3. method according to claim 1, in step 4) obtain described water injection rate after, also comprise and determine the cavern location of described individual well, the form in cave and cave scale, then according to form and the cave scale in described cavern location, cave, in step 5) to the capable water filling of described individual well.
4. method according to the arbitrary item of claim 1-3, described oil reservoir saturation pressure obtains according to following formula 1
Wherein PbFor saturation pressure, units MPa; RsFor gas oil ratio; rgFor Sweet natural gas relative density; T is formation temperature; roFor crude oil density in stock tank, normal pressure, 20 DEG C record; Or
The saturation pressure of described oil reservoir obtains according to following formula 1 ＇
Wherein PbFor saturation pressure, units MPa; R is gas oil ratio; roFor crude oil density in stock tank, normal pressure, 20 DEG C record; rgFor Sweet natural gas relative density; A is statistics constant; B is intercept.
5. method according to the arbitrary item of claim 1-3, if individual well exists water body, obtains the geologic reserve of described individual well according to following formula 2
NpBo+WpBw=NBoiCotΔP+WeFormula 2
Wherein NpFor ground accumulation oil offtake, unit m3; BO is oil volume factor under reservoir pressure; WpFor ground accumulation water production rate, unit m3; Bw is the volume coefficient of water; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient; CotFor total compression coefficient 1/MPa; Δ P is total pressure drop, and described total pressure drop is the initial formation pressure and 1 of individual well) difference of the reservoir pressure of described individual well measured, units MPa; We is water influx rate, unit m3; Or
If individual well does not exist water body, obtain the geologic reserve of described individual well according to following formula 2 ＇,
NpBo/ Δ P=NBoiCotFormula 2 '
Wherein NpFor ground accumulation oil offtake, unit m3; BOFor oil volume factor under reservoir pressure; Δ P is total pressure drop, units MPa; N is geologic reserve, unit m3; BoiFor virgin pressure lower volume coefficient;CotFor total compression coefficient 1/MPa.
6. method according to the arbitrary item of claim 1-3, the secondary gas volume in individual well according to following formula 3
VSecondary=N ' a formula 3;
Wherein VSecondaryFor the secondary gas volume in described individual well; N ' is remaining geologic reserves when pressure is down to saturation pressure, unit m3; A be in described individual well containing gas ratio, gas, the liquid content determined by the isothermal pressure drop curve of resident fluid phase diagram under the reservoir pressure of described individual well in described individual well are obtained.
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| CN106703796A (en) * | 2016-12-30 | 2017-05-24 | 中国石油天然气股份有限公司 | Method for obtaining dynamic reserve volume of oil deposit and water body dimension and device |
| CN106703796B (en) * | 2016-12-30 | 2020-01-07 | 中国石油天然气股份有限公司 | Method and device for acquiring dynamic reserves and water body sizes of oil reservoirs |
| CN113090236A (en) * | 2017-01-11 | 2021-07-09 | 西南石油大学 | Carbonate reservoir double-karst-cave reservoir body water injection indication curve interpretation model |
| CN107366533B (en) * | 2017-08-02 | 2020-06-09 | 中国石油天然气股份有限公司 | Method and device for determining yield increasing mode of oil reservoir |
| CN107366533A (en) * | 2017-08-02 | 2017-11-21 | 中国石油天然气股份有限公司 | The determination method and apparatus of the yield increase of oil reservoir |
| CN109944583A (en) * | 2017-12-19 | 2019-06-28 | 中国石油天然气股份有限公司 | The acquisition methods and device of Reservoir Body number in carbonate rock oil well |
| CN109944583B (en) * | 2017-12-19 | 2022-03-01 | 中国石油天然气股份有限公司 | Method and device for acquiring number of reservoirs in carbonate rock oil well |
| CN110005402A (en) * | 2017-12-29 | 2019-07-12 | 中国石油天然气股份有限公司 | The calculation method and device of carbonate rock oil well producing pressure differential |
| CN110067555A (en) * | 2018-01-24 | 2019-07-30 | 中国石油天然气股份有限公司 | The determination method and apparatus of the minimum dynamic holdup of carbonate rock oil well |
| CN110067555B (en) * | 2018-01-24 | 2022-03-29 | 中国石油天然气股份有限公司 | Method and device for determining minimum dynamic reserve of carbonate oil well |
| CN110805425A (en) * | 2018-08-06 | 2020-02-18 | 中国石油天然气股份有限公司 | Crude oil compression coefficient calculation method, device, equipment and readable storage medium |
| CN110185443A (en) * | 2019-06-25 | 2019-08-30 | 西南石油大学 | A kind of sampling method of water injection to keep pressure |
| CN110185443B (en) * | 2019-06-25 | 2022-02-01 | 西南石油大学 | Sampling method for water injection pressure maintaining |
| CN112267872A (en) * | 2020-10-27 | 2021-01-26 | 成都理工大学 | Method for determining volume of gas well drilling karst cave system by using production dynamic data |
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