CN109614736B - Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field - Google Patents
Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field Download PDFInfo
- Publication number
- CN109614736B CN109614736B CN201811580527.0A CN201811580527A CN109614736B CN 109614736 B CN109614736 B CN 109614736B CN 201811580527 A CN201811580527 A CN 201811580527A CN 109614736 B CN109614736 B CN 109614736B
- Authority
- CN
- China
- Prior art keywords
- well
- oil
- directional
- puff
- radius
- 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.)
- Active
Links
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Theoretical Computer Science (AREA)
- Computer Hardware Design (AREA)
- Evolutionary Computation (AREA)
- Geometry (AREA)
- General Engineering & Computer Science (AREA)
- General Physics & Mathematics (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
- Earth Drilling (AREA)
Abstract
The invention discloses a method for determining the capacity factors of a directional well and a vertical well for steam huff and puff development of an offshore thickened oil field, which comprises the following steps: measuring geological oil reservoir parameters of an offshore thick oil field, and establishing steam huff and puff of the offshore thick oil field according to the geological oil reservoir parameters to develop a vertical well productivity prediction model, and developing a directional well simulated skin factor under different well angle conditions and a directional well productivity prediction model under different well angle conditions according to the steam huff and puff; and establishing a model for developing the productivity of the directional well and the productivity multiple of the vertical well according to the obtained model for predicting the productivity of the vertical well and the model for predicting the productivity of the directional well. The invention provides a method for determining the productivity multiple of a directional well and a vertical well for the steam huff and puff development of an offshore thick oil field, which can provide a basis for the directional well production energy of different well angles for the steam huff and puff development of the offshore thick oil field. The invention provides a quantitative and operable technical method and implementation steps, and the method is suitable for development of a steam huff-puff directional well of an offshore thickened oil field.
Description
Technical Field
The invention relates to a method for determining steam huff and puff capacity of an offshore thick oil field, in particular to a method for determining production capacity multiples of a directional well and a vertical well for steam huff and puff development of the offshore thick oil field.
Background
The thick oil of Bohai sea has huge reserves, and has low cold recovery capacity, low recovery ratio and poor economic benefit for special thick oil with viscosity more than 350 mPa.s. The thermal oil extraction is an effective means for improving the single well yield and the recovery ratio of the special heavy oil reservoir, and has remarkable economic and social benefits in the thermal recovery development of land oil fields such as Liaohe, xinjiang, victory, henan and the like in China. In order to effectively utilize the special thickened oil reserves, the offshore oil field at present carries out thermal recovery pilot tests of multi-element thermal fluid throughput and steam throughput in the Bohai sea, and compared with the conventional water flooding, the development effect is obvious.
Because offshore oilfield platforms have limited space, for multi-layer reservoirs, the platforms are drilled to orient the wells at a plurality of locations with different well angles, as shown in FIG. 1. For the steam huff and puff development of the offshore thick oil, the determination of the directional well production energy under different well inclination angle conditions is an important parameter for accurately predicting the thick oil thermal recovery development index, and is also a key for the establishment of an oil field development scheme.
At present, the steam throughput capacity prediction research mainly focuses on two well types of a vertical well and a horizontal well, but the steam throughput capacity prediction research of directional wells with different well angles is less, and the related research of the directional wells and the capacity multiple of the vertical well is not performed.
Disclosure of Invention
The invention aims to provide a method for determining the productivity factors of a directional well and a vertical well under the condition of developing different well inclination angles by using the steam huff and puff of an offshore heavy oil reservoir, and the method can consider the influence of different well inclination angles, different well distances and different heating radiuses on the productivity factors; the method has strong operability and high accuracy, and can guide the steam huff and puff development of the offshore multilayer heavy oil reservoir to determine the directional well production energy of different well angles.
The invention provides a method for determining the capacity factors of a directional well and a vertical well for the steam huff-puff development of an offshore thickened oil field, which comprises the following steps:
(1) Measuring geological oil reservoir parameters of an offshore heavy oil field, and establishing steam huff and puff development vertical well productivity prediction models, oriented well simulated skin factors under different well diagonal conditions and steam huff and puff development oriented well productivity prediction models under different well diagonal conditions according to the geological oil reservoir parameters;
(2) And (3) establishing a directional well and vertical well productivity multiple model for developing the steam throughput of the offshore thickened oil field according to the vertical well productivity prediction model and the directional well productivity prediction model obtained in the step (1).
In the determining method, in the step (1), the geological oil reservoir parameters include absolute permeability of a stratum, relative permeability of crude oil of the stratum, horizontal permeability of an oil layer, vertical permeability of the oil layer, thickness of the oil layer, length of a well body of an inclined well, average crude oil viscosity of the stratum in a hot zone, heating radius of the hot zone, radius of a shaft, pollution skin coefficient of a directional well, crude oil viscosity of the stratum in a cold zone and oil drainage radius.
In the determining method, in the step (1), the establishment of a vertical well productivity prediction model is developed by steam huff and puff, the steam huff and puff heavy oil reservoir is considered to be a composite coupling reservoir of hot zone and cold recovery, and the following assumptions are considered:
(1) The hot zone and the cold zone are isothermal models, the hot zone is an isothermal zone, and the cold zone is the temperature of an original oil layer;
(2) Single-phase, steady flow;
(3) All reservoir sections of the inclined shaft are shot;
(4) The longitudinal temperature distribution is equal;
according to the Darcy formula, conventionally developing a vertical well productivity formula:
determining a steam huff-puff vertical well productivity model of the hot zone and cold zone composite oil reservoir according to an equivalent seepage flow method:
in the formula (1), J vh Represents the productivity of the vertical well developed by steam huff and puff, m 3 /(d·MPa)；Q vh Represents the production of a vertical well for steam huff and puff development, m 3 /d; Δp represents the production pressure difference, MPa; k represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; u (u) h Represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; s represents the pollution skin coefficient of the directional well; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R e Represents the oil drainage radius, m.
In the determining method, in the step (1), the pseudo-epidermal factor of the directional well is shown as a formula (2):
in the formula (2), the amino acid sequence of the compound,
θ represents well inclination angle, °; h represents the thickness of the oil layer, m; l represents the length of the inclined shaft well body, m; k (K) h Represents the reservoir horizontal permeability, mD; k (K) v Represents the vertical permeability of the oil layer, mD; r is R w Represents the wellbore radius, m.
In the determining method, in the step (1), the steam throughput development directional well productivity prediction model taking different well inclination angle conditions into consideration is as follows:
according to an equivalent seepage flow method, establishing a steam throughput capacity model of the directional well of the composite oil reservoir in the hot zone and the cold zone as follows:
wherein J is dθh Represents the steam throughput development directional well production energy, m 3 /(d·MPa)；Q dθh Indicating steam huff and puff directional well production, m 3 D, ΔP represents the production pressure difference, MPa; k represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R e Represents the oil drainage radius, m; r is R w Represents the radius of the well bore, m; s is S θ Represents the directional well pseudo-skin factor, and S represents the directional well pollution skin factor.
In the determining method, in the step (2), the steam throughput development directional well and vertical well productivity multiple model can be obtained by using a steam throughput development vertical well productivity prediction model and a directional well productivity prediction model. Assuming that the pollution skin coefficient S is 0, the absolute permeability K of an oil layer and the relative permeability K of an oil phase ro And (3) establishing a model for developing the productivity multiples of the directional well and the vertical well by using the steam throughput according to the obtained steam throughput development vertical well and the directional well productivity prediction model (formula (1) and formula (3), wherein the model is shown in formula (4):
in the formula (4), u h Represents the average formation crude oil viscosity in the hot zone, mPa.s; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; r is R e Represents the oil drainage radius, m; s is S θ Representing the directional well epidermoid factor.
According to the offshore thickened oil field steam huff and puff development directional well and vertical well productivity multiple model provided by the invention, the productivity of the offshore thickened oil field steam huff and puff development directional well can be determined by combining the following steps:
1) Establishing a relation model between the average crude oil viscosity in the hot zone with different heating radiuses and the different heating radiuses according to the crude oil viscosity change with different radial distances;
2) According to the directional well and vertical well capacity factor model obtained by the method, the average crude oil viscosity in the hot zone, the shaft radius, the oil drainage radius, the formation crude oil viscosity in the cold zone and the simulated skin factor of the directional well under the different heating radiuses obtained in the step 1) are combined to obtain the capacity factors of the directional well and the vertical well developed by steam huff and puff; and developing the productivity of the vertical well according to the steam huff and puff determined by offshore oilfield tests, and obtaining the productivity of the offshore thickened oil oilfield steam huff and puff developed directional well.
In step 1), the relation model is shown as formula (5):
in the formula (5), u h Represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; x represents any distance from the wellbore and m.
The invention provides a method for determining the productivity multiple of a directional well and a vertical well for the steam huff and puff development of an offshore thick oil field, which can provide a basis for the directional well production energy of different well angles for the steam huff and puff development of the offshore thick oil field. The invention provides a quantitative and operable technical method and implementation steps, and the method is suitable for development of a steam huff-puff directional well of an offshore thickened oil field.
Drawings
FIG. 1 is a schematic diagram of an offshore directional well development.
FIG. 2 is a steam huff and puff hot zone and cold recovery complex reservoir model.
FIG. 3 is a schematic diagram of a steam huff and puff directional well model.
FIG. 4 is a graph of the viscosity profile of the formation crude oil at the end of the soak of the thermal recovery huff well.
FIG. 5 is a graph showing the variation of the production capacity of a directional well and a vertical well with the inclination angle of the well.
Detailed Description
The experimental methods used in the following examples are conventional methods unless otherwise specified.
Materials, reagents and the like used in the examples described below are commercially available unless otherwise specified.
Establishing a vertical well productivity prediction model for steam huff and puff development of an offshore heavy oil field, taking a steam huff and puff heavy oil reservoir into consideration as a composite coupling reservoir for hot zone and cold recovery, and taking the following assumptions into consideration:
(1) The hot zone and the cold zone are isothermal models, the hot zone is an isothermal zone, and the cold zone is the temperature of an original oil layer;
(2) Single-phase, steady flow;
(3) All reservoir sections of the inclined shaft are shot;
(4) The longitudinal temperature distribution is equal.
Steam stimulation vertical well model as shown in figure 2,
according to the Darcy formula, conventionally developing a vertical well productivity formula:
wherein K represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; j (J) v Represents the productivity of a conventional vertical well, m 3 /(d·MPa)；Q v Represents the production of a conventional vertical well, m 3 /d; Δp represents the production pressure difference, MPa; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; s represents the directional well contamination skin coefficient.
Determining a steam huff-puff vertical well productivity model of the hot zone and cold zone composite oil reservoir according to an equivalent seepage flow method:
in the formula (1), J vh Represents the productivity of the vertical well developed by steam huff and puff, m 3 /(d·MPa)；Q vh Represents the production of a vertical well for steam huff and puff development, m 3 /d; Δp represents the production pressure difference, MPa; k represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; u (u) h Represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; s represents the pollution skin coefficient of the directional well; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R e Represents the oil drainage radius, m.
A schematic of a steam-huff directional well is shown in fig. 3, wherein θ represents the well inclination angle, °; h represents the thickness of the oil layer, m; l represents the length of the inclined shaft well body, and m.
Oriented well simulated surface factor S under different well inclination angle conditions θ Can be expressed as:
in the formula (2), the amino acid sequence of the compound,
θ represents well inclination angle, °; h represents the thickness of the oil layer, m; l represents the length of the inclined shaft well body, m; k (K) h Represents the reservoir horizontal permeability, mD; k (K) v Represents the vertical permeability of the oil layer, mD; r is R w Represents the wellbore radius, m.
The steam throughput development productivity prediction model of different well inclination conditions is as follows:
wherein J is dθ Represents the production energy of a steam huff-puff directional well, m 3 /(d·MPa)；Q dθ Indicating steam huff and puff directional well production, m 3 /d。
According to an equivalent seepage flow method, establishing a steam throughput capacity model of the directional well of the composite oil reservoir in the hot zone and the cold zone as follows:
assuming that the pollution skin coefficient S is 0, the absolute permeability K of an oil layer and the relative permeability K of an oil phase ro And (3) developing a vertical well and directional well productivity prediction model according to the obtained steam huff and puff, and establishing a steam huff and puff development directional well and vertical well productivity multiple model:
determining a function u of the viscosity of the crude oil in the hot zone along with the change of the radial distance according to the numerical simulation of the oil reservoir h (x) Establishing average crude oil viscosity u in hot zone with different heating radius h Different from the heating radius R eh Relationship model:
u h represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the wellbore radius, m.
Taking a certain heavy oil reservoir of Bohai sea as an example, the average porosity of the reservoir is 28.5%, the average permeability is 668mD, the longitudinal multiple sets of oil-water systems are of lamellar structure, the heavy oil reservoir is of side water, and the density of ground crude oil is 0.972t/m 3 The viscosity of the crude oil of the stratum is calculated to be 472 mPa.s, and the function u of the viscosity of the crude oil of the hot zone along with the change of the radial distance is determined through oil reservoir numerical simulation h (x) As shown in fig. 4.
By the method of u h (x) The weights are integrated over different distance wells to solve for the hot zone average crude oil viscosity, which in this example is 17.2mpa·s for a heating radius of 20 m.
Different heating radii R obtained by the above eh Average crude oil viscosity in hot zone u h And radius R of the well bore w Radius of drainage R e Crude oil viscosity u of formation in cold zone c Skin-like factor S of inclined shaft θ Carrying out steam huff and puff development of a directional well and vertical well capacity model (4), and solving the steam huff and puff development of the directional well and vertical well capacity
Taking the hot zone heating radius of 20m as an example, when the well spacing is 200m, the steam throughput capacity curve of the directional well and the vertical well under different well inclination angle conditions can be determined, as shown in fig. 5.
Considering that the offshore platform has more wells and the change of the steam throughput capacity of the directional wells and the vertical wells is slower when the well inclination angle is smaller, the steam throughput capacity and the directional well yield are developed by classifying according to the well inclination angle in order to ensure that the directional well yield can be determined to have operability, and the specific classification is shown in table 1.
By taking a certain heavy oil reservoir of Bohai sea as an example, determining that the steam huff-puff directional well yield is 40m through offshore testing 3 /d。
TABLE 1 steam huff and puff thermal recovery capacity for different well angles
Claims (1)
1. A method for determining the productivity multiple of a directional well and a vertical well for the steam huff and puff development of an offshore thick oil field comprises the following steps:
(1) Measuring geological oil reservoir parameters of an offshore heavy oil field, and establishing steam huff and puff development vertical well productivity prediction models, oriented well simulated skin factors under different well diagonal conditions and steam huff and puff development oriented well productivity prediction models under different well diagonal conditions according to the geological oil reservoir parameters;
the geological oil reservoir parameters comprise stratum absolute permeability, stratum crude oil relative permeability, reservoir horizontal permeability, reservoir vertical permeability, reservoir thickness, inclined shaft length, hot zone average stratum crude oil viscosity, hot zone heating radius, shaft radius, directional well pollution skin coefficient, cold zone stratum crude oil viscosity and oil drainage radius;
the vertical well productivity prediction model is shown as (1):
in the formula (1), J vh Represents the productivity of the vertical well developed by steam huff and puff, m 3 /(d.MPa); k represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; u (u) h Represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; s represents the pollution skin coefficient of the directional well; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R e Represents the oil drainage radius, m;
the oriented well pseudo-epidermal factor is shown as a formula (2):
in the formula (2), the amino acid sequence of the compound,
θ represents well inclination angle, °; h represents the thickness of the oil layer, m; l represents the length of the inclined shaft well body, m; k (K) h Represents the reservoir horizontal permeability, mD; k (K) v Represents the vertical permeability of the oil layer, mD; r is R w Represents the radius of the well bore, m;
the directional well productivity prediction model is shown in formula (3):
in the formula (3), J dθh Represents the development of directional well production energy by steam huff and puff,m 3 /(d.MPa); k represents the absolute permeability of the stratum, mD; k (K) ro Represents the relative permeability of the formation crude oil, mD; h represents the thickness of the oil layer, m; u (u) h Represents the average formation crude oil viscosity in the hot zone, mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; s is S θ Representing a directional well simulated skin factor; s represents the pollution skin coefficient of the directional well; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R e Represents the oil drainage radius, m;
(2) Establishing a directional well and vertical well productivity multiple model for developing steam huff and puff of the offshore thickened oil field according to the vertical well productivity prediction model and the directional well productivity prediction model obtained in the step (1);
the steam throughput development directional well and vertical well capacity coefficient model is shown as (4):
in the formula (4), u h Represents the average formation crude oil viscosity in the hot zone, mPa.s; u (u) c Indicating the viscosity of crude oil in a formation in a cold zone, and mPa.s; r is R eh Representing the heating radius of the hot zone, m; r is R w Represents the radius of the well bore, m; r is R e Represents the oil drainage radius, m; s is S θ Representing the directional well epidermoid factor.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201811580527.0A CN109614736B (en) | 2018-12-24 | 2018-12-24 | Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201811580527.0A CN109614736B (en) | 2018-12-24 | 2018-12-24 | Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN109614736A CN109614736A (en) | 2019-04-12 |
| CN109614736B true CN109614736B (en) | 2023-04-28 |
Family
ID=66011308
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201811580527.0A Active CN109614736B (en) | 2018-12-24 | 2018-12-24 | Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN109614736B (en) |
Families Citing this family (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110080745B (en) * | 2019-05-16 | 2023-04-07 | 中国石油化工股份有限公司胜利油田分公司勘探开发研究院 | Method and device for predicting productivity of vertical well through separate-layer fracturing |
| CN110513089A (en) * | 2019-09-06 | 2019-11-29 | 中国海洋石油集团有限公司 | A kind of Offshore Heavy Oil Field thermal recovery, which is handled up, develops production capacity multiple and determines method |
| CN110513090A (en) * | 2019-09-06 | 2019-11-29 | 中海石油(中国)有限公司 | A kind of Offshore Heavy Oil Field steam soak is with producing the method for determination |
| CN113033862B (en) * | 2020-01-10 | 2023-09-22 | 重庆科技学院 | Method for predicting throughput capacity of supercritical multi-element thermal fluid of heavy oil reservoir |
| CN111485863B (en) * | 2020-04-16 | 2022-09-06 | 北京默凯斯能源技术有限公司 | Method for calculating capacity multiple of steam huff-puff well of heavy oil field |
| CN115405273B (en) * | 2021-05-27 | 2023-07-25 | 中国石油天然气股份有限公司 | Thickened oil multi-medium throughput intelligent mining method and device based on ensemble learning |
Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105354639A (en) * | 2015-11-10 | 2016-02-24 | 中国石油天然气股份有限公司 | Complete-period capacity prediction method and device of tight oil multiple-media coupling seepage |
| CN106779211A (en) * | 2016-12-13 | 2017-05-31 | 中国石油大学(华东) | A kind of PRODUCTION FORECASTING METHODS for oil field injection and extraction well pattern displacement exploitation |
| CN109033565A (en) * | 2018-07-06 | 2018-12-18 | 中国石油天然气股份有限公司 | A kind of horizontal wells in heavy oil reservoir superheated steam is handled up Dynamic Productivity Calculation prediction technique |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105095986B (en) * | 2015-06-23 | 2018-12-25 | 中国石油天然气股份有限公司 | The method of stratified reservoir overall yield prediction |
-
2018
- 2018-12-24 CN CN201811580527.0A patent/CN109614736B/en active Active
Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105354639A (en) * | 2015-11-10 | 2016-02-24 | 中国石油天然气股份有限公司 | Complete-period capacity prediction method and device of tight oil multiple-media coupling seepage |
| CN106779211A (en) * | 2016-12-13 | 2017-05-31 | 中国石油大学(华东) | A kind of PRODUCTION FORECASTING METHODS for oil field injection and extraction well pattern displacement exploitation |
| CN109033565A (en) * | 2018-07-06 | 2018-12-18 | 中国石油天然气股份有限公司 | A kind of horizontal wells in heavy oil reservoir superheated steam is handled up Dynamic Productivity Calculation prediction technique |
Non-Patent Citations (2)
| Title |
|---|
| 渤海S油田高含水期加密井产能评价;马奎前等;《断块油气田》;20130125(第01期);第71-73页 * |
| 稠油油藏水平井热采吞吐产能预测新模型;马奎前等;《西南石油大学学报(自然科学版)》(第01期);全文 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN109614736A (en) | 2019-04-12 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN109614736B (en) | Method for determining production capacity factors of directional well and vertical well for steam huff and puff development of offshore thickened oil field | |
| CN109667564B (en) | Method for determining yield of directional well for steam huff-puff development of offshore heavy oil field | |
| He et al. | Waterflood direction and front characterization with four-step work flow: a case study in changqing oil field China | |
| CN112627733B (en) | Method and equipment for optimizing hydraulic parameters of deepwater pressure-controlled drilling in real time | |
| CN110334431A (en) | A kind of low permeability tight gas reservoir single well controlled reserves calculating and remaining gas analysis method | |
| Guo et al. | Well productivity handbook | |
| CN107313759B (en) | Hypotonic heavy crude reservoir straight well thermal recovery pressure distribution forecasting method and system | |
| CN104632157A (en) | Low permeability reservoir equilibrium displacement method | |
| CN105089612A (en) | Determining method for distance of well-drain and length of pressure break of low penetration oil reservoir artificial fracture | |
| CN110454135B (en) | Shale oil well spacing method for long horizontal well with small well spacing, multiple strata series and close cutting | |
| CN107066769A (en) | Suitable for the efficient acidifying design method of ultra deep slit formation carbonate reservoir | |
| CN111485863B (en) | Method for calculating capacity multiple of steam huff-puff well of heavy oil field | |
| Zhang et al. | Practice and understanding of sidetracking horizontal drilling in old wells in Sulige Gas Field, NW China | |
| CN103122756B (en) | Method for confirming deepwater water separating pipe gas lift drilling well gas injection volume | |
| CN112597644B (en) | Multilayer commingled production reservoir development full-cycle productivity correction method considering interlayer interference | |
| Tremblay | Cold flow: a multi-well cold production (CHOPS) model | |
| CN112836438B (en) | Method and device for predicting water breakthrough time of gas well of heterogeneous edge water-gas reservoir | |
| Zhang et al. | Computation method for water influx in different layers of natural edge water | |
| CN107247816A (en) | A kind of heavy crude reservoir is carried out cold chemical viscosity reduction of adopting and farthest constructed the decision method of radius | |
| Moradi | Cost-effective and safe oil production from existing and near-future oil fields | |
| CN113177363A (en) | Reservoir engineering method for quantitatively characterizing reservoir large pore channel parameters | |
| CN112901126B (en) | Yield splitting method based on phase permeation and water flooding characteristics | |
| CN114004078B (en) | Method for calculating multilayer commingled production seepage simulation phase seepage of thin interbed oil reservoir | |
| Liu | A miscible CO2 injection project and evaluation in Daqing, China | |
| Liu et al. | A New Method to Quantify Interwell Connectivity Using Performance Data and Intelligence Algorithm |
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 |