A method, system, and apparatus medium for mapping production to geological reserves of an oilfield

Abstract

The application discloses a kind of oilfield production and geological reserves homing method, system and equipment medium, the oil and gas products of each production unit of oilfield block is extracted, and actual production data is obtained;Determine whether the actual production data of block oil and gas products and the sum of the actual production data of each well oil and gas products in the block is closed, otherwise complete or restore;Determine whether actual production data includes non-geological unit production, if so, then data correction is carried out;Determine the oil and water splitting coefficient of each oil well, and the actual production data is split according to the splitting coefficient.Single well production splitting result is homed to data, and the actual production data of the reserve unit in proven geological reserves and the test area unit outside proven geological reserves is obtained respectively.The production of oil and gas products of oilfield and geological reserves are completely matched, so that the reserve index of reservoir is objective and true, which can effectively guide the decision and production of oilfield development plan.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas field development and relates to a method, system and equipment medium for the relocation of oil field production and geological reserves. Background Technology

[0002] In the process of oil reservoir development, the production data of extracted oil and gas products is crucial. If the production data is inaccurate, it will lead to an imbalance in reserve indicators. For example, distorted calculations of recovery rates can cause the failure of oilfield development plans.

[0003] In existing technologies, the production output of oil and gas products is generally achieved by first measuring the oil and gas products of each oil well, then allocating the production based on the well's allocation coefficient, and finally using the result of this allocation as the output of the well's oil and gas production. However, in actual production, it has been found that production data and reserve data do not completely correspond. The reservoir reserve indicators calculated from the production data differ significantly from the actual situation and are difficult to accurately reflect the current state of the reservoir. Summary of the Invention

[0004] The purpose of this invention is to overcome the shortcomings of the prior art and provide a method, system, and equipment medium for matching oilfield production with geological reserves, so that the production of oil and gas products in the oilfield is completely matched with the geological reserves, making the reservoir reserve indicators objective and accurate, and effectively guiding the decision-making and production of oilfield development plans, thus making it more practical.

[0005] To achieve the above objectives, the present invention employs the following technical solution:

[0006] A method for reconciling the production and geological reserves of an oil field includes the following steps:

[0007] Step 1: Measure the oil and gas products produced by each production unit in the oilfield block to obtain actual production data;

[0008] Step 2: Determine whether the actual production data of the block's oil and gas products is closed with the sum of the actual production data of each well in the block. If yes, proceed to Step 3; otherwise, complete or restore the actual production data.

[0009] Step 3: Determine whether the actual production data includes output from non-geological units. If so, perform data correction; otherwise, proceed to Step 4.

[0010] Step 4: Based on the test data and geological understanding of the oil wells, determine the oil production and water production splitting coefficients for each oil well, and split the actual production data into single-well production values ​​according to the splitting coefficients.

[0011] Step 5: The single-well production output results are sorted and the data is reallocated to obtain the actual production data of the reserve unit within the proven geological reserves and the test production area unit outside the proven geological reserves.

[0012] Preferably, in step two, the actual production data is supplemented or restored according to the following formula:

[0013] Monthly output = the sum of daily outputs;

[0014] Monthly production days = Sum of monthly production hours / 24;

[0015] Daily production capacity = Monthly output / Monthly production days;

[0016] Daily output level = Monthly output / Number of calendar days in a month;

[0017] Monthly stress data = arithmetic mean of daily and monthly stress;

[0018] Daily and monthly production figures are compiled separately for oil, gas, and water production.

[0019] Preferably, in step two, the verification period for data closure judgment is one calendar month, with an allowable error of ≤0.005%.

[0020] Preferably, in step three, the process of correcting the actual production data involves scaling the actual production data proportionally using closure coefficients. These closure coefficients include the wellhead oil production closure coefficient, the wellhead water production closure coefficient, the verified oil production closure coefficient (after removing light hydrocarbons), the verified oil production closure coefficient, and the verified water production closure coefficient. The closure coefficients within the verification period are calculated using the following formula:

[0021] Wellhead oil production closure coefficient = Block wellhead oil production / Sum of oil production from all individual wells within the block;

[0022] Wellhead water production closure coefficient = Block wellhead water production / Sum of water production from all individual wells within the block;

[0023] Closure coefficient for verified oil production after light hydrocarbon removal = (verified oil production - light hydrocarbon production) / wellhead oil production in the block;

[0024] Verification of oil production closure coefficient = Verified oil production / Block wellhead oil production;

[0025] Verification production closure coefficient = Verified production / Block wellhead production.

[0026] Preferably, in step four, determining the splitting coefficient includes the following steps:

[0027] A. Determine the type of oil well, including normal wells and wells with casing damage;

[0028] B. Determine the production type of a single well, including single-production wells, combined production wells with production profiles, and combined production wells without production profiles;

[0029] C. Determine the calculation methods for water splitting coefficient and oil splitting coefficient based on the type of oil well and the production type of a single well:

[0030] For normal wells and single-production wells, the oil production splitting factor for geological oil production is 1; the water production splitting factor for geological water production is 1.

[0031] For normal wells and wells with production profiles, the production profile data is used as the oil production splitting factor for geological oil production; and the production profile data is used as the water production splitting factor for geological water production.

[0032] For normal wells and commingled production wells without a production profile, the oil production splitting coefficient and the water production splitting coefficient of geological oil production are calculated comprehensively based on production dynamics, oil testing and production, and formation coefficients.

[0033] For wells with casing damage and single production wells, the geological oil production coefficient remains the same as before casing damage. For the water production coefficient, it includes the geological water production coefficient and the casing damage water production coefficient. The geological water production coefficient remains the same as before casing damage. The casing damage water production coefficient is calculated using the following formula: Casing damage water production coefficient = 1 - Geological water production / (Geological water production + Casing damage water production).

[0034] For wells with casing damage and co-production wells with production profiles, the production profile data is used as the oil production splitting coefficient for geological oil production; for water production splitting coefficients, it includes the geological water production splitting coefficient and the casing damage water splitting coefficient; the geological water production splitting coefficient is based on the production profile data; the casing damage water splitting coefficient is calculated according to the following formula: casing damage water splitting coefficient = 1 - geological water production / (geological water production + casing damage water production);

[0035] For wells with casing damage and no production profile, the oil production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The water production splitting coefficient includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The casing damage water splitting coefficient is calculated using the following formula: Casing damage water splitting coefficient = 1 - Geological water production / (Geological water production + Casing damage water production).

[0036] D. If the borehole does not reveal the stratigraphic position and it is found that it only produces water and not oil, then the oil splitting coefficient for geological oil production is 0, and the water splitting coefficient for geological water production is 1.

[0037] Preferably, in step one, each production unit is assigned a unique data query path as its index;

[0038] The index is set up according to the following steps: 1. Determine whether the current oil well has undergone a wellbore change operation; if not, the index of the actual production data is the current oil and gas well number; if yes, proceed to step 2; 2. Determine the start and end times of the current oil well and the wellbore change production; match the actual production data in the database according to the production time period, so that each actual production data corresponds to a unique index; the index setting rules are as follows: the index of the actual production data for the time period without wellbore change is the current oil well number; the index of the actual production data for the time period with wellbore change is the current oil well number followed by different characters for distinction; if the wellbore is changed multiple times, the index of the actual production data for each time period with wellbore change uses different characters for distinction.

[0039] Preferably, after step five is completed, the production rate of oil and gas products is verified to be reasonable by the recovery degree and the production rate; if reasonable, the production of the oil and gas field block is output; if unreasonable, the process returns to step four.

[0040] An oilfield production and geological reserve attribution system, comprising:

[0041] The actual production data acquisition module is used to measure the oil and gas products extracted from each production unit in the oilfield block and obtain actual production data.

[0042] The data closure judgment module is used to determine whether the actual production data of the oil and gas products in the block is closed with the sum of the actual production data of the oil and gas products of each well in the block. If it is closed, the module proceeds to the non-geological unit production judgment module; otherwise, it completes or restores the actual production data.

[0043] The non-geological unit output judgment module is used to determine whether the actual production data includes the output of non-geological units. If so, the data is corrected; otherwise, the output splitting module is entered.

[0044] The production splitting module is used to determine the oil production and water production splitting coefficients for each oil well based on the test data and geological understanding of the oil wells, and to split the production of each well according to the actual production data according to the splitting coefficients.

[0045] The data relocation module is used to relocate the single-well production splitting results, obtaining the actual production data of the reserve unit within the proven geological reserves and the test production area unit outside the proven geological reserves.

[0046] A computer device includes a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of the method for reconciling the production and geological reserves of an oil field as described in any of the preceding claims.

[0047] A computer-readable storage medium storing a computer program, which, when executed by a processor, implements the steps of the oilfield production and geological reserve relocation method as described in any of the preceding claims.

[0048] Compared with the prior art, the present invention has the following beneficial effects:

[0049] 1. The method for aligning oilfield production and geological reserves proposed in this invention separates the production outside the zone or the production outside the layer of unproven reserves into the pilot production area unit for separate management, so that the production and reserves are matched when calculating the reserve index, and an objective, true and accurate reserve measurement index is obtained.

[0050] 2. The method for allocating oilfield production and geological reserves proposed in this invention manages water production and oil production separately. When allocating production, water and oil are allocated using different allocation coefficients. Furthermore, when allocating water production, a casing loss water allocation coefficient is introduced. This changes the existing technology, which uses the same allocation coefficient for both oil and water, and for both normal geological water production and casing loss water production, to a more refined management using separate oil production allocation coefficients, geological water production allocation coefficients, and casing loss water allocation coefficients. This makes the allocated water production and oil production data more objective and accurate.

[0051] 3. The method for locating oilfield production and geological reserves proposed in this invention assigns different data query indices to different production stages of the same oil well, and manages each production stage as a separate oil and gas well in a refined manner, making the split water production and oil production data more objective and accurate.

[0052] 4. The method for reconciling oilfield production and geological reserves proposed in this invention employs data closure verification technology to check whether the sum of the production of each oil well is consistent with the production of the block. If they are inconsistent, the actual production data is restored to correct the error. Furthermore, the production is scaled proportionally as a whole through a closure coefficient, thereby ensuring the overall closure of oil and gas product production. In addition, the technical solution of this invention also includes checking the production of non-geological units and deducting them from the actual production data, making the actual production data more objective, true and accurate.

[0053] 5. The method for reconciling oilfield production and geological reserves proposed in this invention sets a rationality check for the splitting coefficient. The production data obtained by splitting using the splitting coefficient is verified by the degree of recovery and the oil production rate. If the production result is found to be unreasonable, the process returns to the splitting coefficient determination stage. A more reasonable and scientific splitting coefficient is obtained through multiple methods for production splitting, thereby making the oil and gas production results accurate and the output results objective, true and accurate. Attached Figure Description

[0054] Figure 1 This is a flowchart illustrating the method for allocating oilfield block production according to the present invention.

[0055] Figure 2 This is a schematic diagram of the off-site production of an oil field in one embodiment of the present invention;

[0056] Figure 3 This is a schematic diagram of the out-of-layer production of an oil well in one embodiment of the present invention;

[0057] Figure 4 This is a schematic diagram of the production segmentation of an oil well in one embodiment of the present invention. Detailed Implementation

[0058] The technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without creative effort are within the scope of protection of the present invention.

[0059] It should be noted that the terms “front,” “back,” “left,” “right,” “up,” and “down” used in the following description refer to the directions shown in the attached diagram, while the terms “inside” and “outside” refer to the directions toward or away from the geometric center of a specific component, respectively.

[0060] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention pertains. The terminology used herein in the specification of this invention is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. The term "and / or" as used herein includes any and all combinations of one or more of the associated listed items.

[0061] Definitions of terms used in this invention.

[0062] Production: The mass or volume of oil and water measured in an oil field; gas is measured by volume, while oil and water are measured by mass.

[0063] Wellhead production: The production measured at the wellhead tree or joint station for each well, excluding pipeline transmission losses and the oil (water, fluid) production measured at the wellhead.

[0064] Verify production output: Consider pipeline transmission losses and the oil (water, liquid) production measured at the oil gathering station.

[0065] Monthly transport difference coefficient of the block = monthly verified oil production of the block / monthly wellhead oil production of the block

[0066] Monthly oil (water, liquid) production at the wellhead: The sum of the monthly oil (water, liquid) production at the wellhead of each well in the oilfield.

[0067] Verified monthly oil (water, liquid) production: The sum of verified monthly oil (water, liquid) production for each well in the oilfield.

[0068] Splitting coefficient: A decimal that represents the proportion of the total output of a layer to be subdivided into smaller layers.

[0069] Geological reserves: The quantity of oil and natural gas and associated useful substances stored in oil reservoirs under original geological conditions, converted to standard surface conditions (20℃, 0.101MPa), generally targeting oil and natural gas resources.

[0070] Proven geological reserves: Geological reserves submitted to the National Reserves Committee generally refer to the geological reserves of oil and natural gas.

[0071] Proven reserve boundary: The outer boundary of the proven geological reserves of oil.

[0072] Cumulative oil (water, liquid) production: The sum of monthly oil (water, liquid) production of a well or oilfield from the initial stage of production, including verified oil (water, liquid) production and wellhead oil (water, liquid) production.

[0073] Monthly oil (water, liquid) production: The monthly oil (water, liquid) production of a well or oilfield, including verified production and wellhead production.

[0074] The method for reconciling oilfield production and geological reserves as described in this invention is as follows: Figure 1 As shown, it includes the following steps:

[0075] 1) Obtain actual production data of the oilfield: The oilfield includes several oil and gas wells; measure the oil and gas products produced by each production unit in the oilfield block to obtain actual production data; the production unit includes reserve units within the proven geological reserves and test production area units outside the proven geological reserves.

[0076] The geological reserves refer to the quantity of oil and natural gas and their associated useful substances stored in oil and gas reservoirs under the original geological conditions, converted to the standard surface conditions (20℃, 0.101MPa), with oil and natural gas generally being the target resources.

[0077] The aforementioned pilot production area unit includes all off-site and off-layer reserves. Within the oilfield block, the reservoir is divided into two categories: within proven reserves and outside proven reserves, using a planar partitioning and vertical segmentation method. The proven geological reserves refer to the geological reserves submitted to the National Reserves Committee, generally referring to the geological reserves of oil and natural gas. The reserve unit within proven geological reserves refers to the reserve unit submitted to the National Reserves Committee; the pilot production area unit outside proven geological reserves refers to the reserve unit not yet submitted to the National Reserves Committee, which includes both off-site reserves in the planar partitioning and off-layer reserves in the vertical segmentation. (See attached...) Figure 2 The diagram shown is a schematic representation of the off-site production of an oilfield in one embodiment of the present invention; wherein, wells A1-H1, A7-12C, A1, A1-H2 and A101 are proven production; well A7-10 is off-site production, which is proven off-site production that has not yet been submitted to the state.

[0078] As attached Figure 3 The diagram illustrates the out-of-layer production of an oil well in one embodiment of the present invention; the T111 layer represents the proven out-of-layer production that has not yet been submitted to the national authorities. The production process of each oil well can be divided into several production stages, with each stage corresponding to an actual reserve unit. For objectivity and accuracy in data processing, the present invention stores the unsubmitted reserve units as pilot production area units separately. This design aims to separate reserve units and production units, avoiding the inclusion of undiscovered reserves in the cumulative production data during oilfield recovery calculations, thus preventing data inaccuracies and ensuring that the presence of such undiscovered reserves does not interfere with the actual production data of the oil well.

[0079] The aforementioned reserve units can be located and uniquely identified by the well number and the layer being exploited. If the reserves have not yet been submitted to the national proven reserves, they will be uniformly placed in the pilot production area unit for separate management to avoid the production of unproven reserves affecting the calculation of reserve indicators.

[0080] The actual production data includes wellhead production and verified production; wellhead production refers to the oil and gas production measured at the wellhead of the oil well; verified production refers to the oil and gas production measured at the oil gathering station.

[0081] The production volume refers to the mass or volume of gas, oil, and water measured in an oil and gas field. Gas is generally measured by volume, while oil and water are measured by mass. The water content of the produced fluids is measured at the wellhead of the oil well to calculate the oil and water production.

[0082] The wellhead production refers to the oil (water, liquid) production measured at the wellhead tree or joint station of each oil well, without considering losses during the transmission of oil and gas products through pipelines.

[0083] The verified production volume takes into account the transmission losses in the oil and gas product pipelines, and is the amount of oil (water, liquid) produced when the oil and gas products are transmitted to the oil gathering station.

[0084] Wellhead production is calculated using the following formula: monthly wellhead oil (water, liquid) production is equal to the sum of monthly wellhead oil (water, liquid) production of every well in the oilfield.

[0085] The verified production is calculated using the following formula: The verified monthly oil (water, liquid) production is equal to the sum of the verified monthly oil (water, liquid) production of each well in the oilfield.

[0086] The verified production of the oilfield block is less than the wellhead production. The difference between the two productions is represented by the parameter "block monthly transport difference coefficient". The block monthly transport difference coefficient is calculated according to the following formula: Block monthly transport difference coefficient = monthly verified oil production of the block / monthly wellhead oil production of the block.

[0087] Each production unit has a unique index as its data query path. Due to the naming conventions of oilfield databases, well numbers are displayed using the current well number. However, if multiple reservoirs have been utilized in a well, such as through sidetracking or deepening, the data in the database cannot distinguish which stage of production data the well represents. This leads to a mismatch between the actual production data of the oilfield block and the production units, causing significant difficulties in managing the actual production data. The technical solution of this invention assigns a unique data query path as its index to each production unit based on its specific characteristics.

[0088] In one embodiment of the present invention, assuming that well L3 was sidetracked in January 2017, it was named well L3C to distinguish it from actual production data. Especially when a wellbore has been sidetracked multiple times and has production data, it is essential to ensure that each sidetracked wellbore has a unique index value. In one embodiment of the present invention, well L3 was sidetracked three times, and its naming is as follows: the wellbore with the initial production data is named L3, the wellbore with the first sidetracked production data is named L3C1, the wellbore with the second sidetracked production data is named L3C2, and the wellbore with the third sidetracked production data is named L3C3. The wellbores L3, L3C1, L3C2, and L3C3 should all be considered independent index values ​​and treated as four different wells in actual production data management.

[0089] The index is set according to the following steps: 1. Determine whether the current oil well has undergone a wellbore change operation; if not, the index of the actual production data is the current oil and gas well number; if yes, proceed to step 2; 2. Determine the start and end times of the current oil well and the wellbore change production; match the actual production data in the database according to the production time period, so that each actual production data corresponds to a unique index; the index setting rules are as follows: the index of the actual production data for the time period without wellbore change is the current oil well number; the index of the actual production data for the time period with wellbore change is the current oil well number followed by different characters for distinction; if the wellbore is changed multiple times, the index of the actual production data for each time period with wellbore change uses different characters for distinction.

[0090] 2) Data closure: Set an inspection period and compare the actual production data of the oil and gas products in the block with the sum of the actual production data of the oil and gas products of each well in the block within the inspection period. The allowable error is ≤0.005%.

[0091] If they match, proceed to step 3); if they do not match, complete or restore the actual production data.

[0092] The data closure test is performed on a monthly basis.

[0093] Cumulative oil (water, liquid) production: The sum of monthly oil (water, liquid) production from the initial production stage of a well or oilfield, including verified oil (water, liquid) production and wellhead oil (water, liquid) production. Monthly oil (water, liquid) production: The monthly oil (water, liquid) production of a well or oilfield, including verified production and wellhead production.

[0094] The actual production data is supplemented or restored according to the following formula:

[0095] Monthly output = the sum of daily output.

[0096] Monthly production days = Sum of monthly production hours / 24.

[0097] Daily production capacity = Monthly output / Monthly production days.

[0098] Daily output level = monthly output / number of calendar days in a month.

[0099] Monthly stress data = arithmetic mean of daily and monthly stress.

[0100] The daily and monthly output figures are calculated separately for oil, gas, and water.

[0101] If there are missing or incorrect entries in the monthly production data, the daily production data should be used to restore the data according to the formula mentioned above.

[0102] 3) Data Correction: Determine whether the actual production data includes output from non-geological units. If so, deduct the output from non-geological units, calculate the closure coefficient using the correction coefficient method, and correct the actual production data. If the oil and gas field's output includes not only the output from geological units but also the output from non-geological units, such as light hydrocarbons and liquefied gas from the combined station, then the output from the non-geological unit should be deducted from the monthly output. If the output of oil and gas products does not include the output from non-geological units, this step can be omitted.

[0103] Correcting the actual production data refers to scaling the actual production data proportionally using closure coefficients; the closure coefficients include wellhead oil production closure coefficient, wellhead water production closure coefficient, verified oil production closure coefficient after light hydrocarbon removal, verified oil production closure coefficient, and verified water production closure coefficient; the closure coefficients within the inspection period are calculated according to the following formula:

[0104] Wellhead oil production closure coefficient = Block wellhead oil production / Sum of oil production from all individual wells within the block.

[0105] Wellhead water production closure coefficient = Block wellhead water production / Sum of water production from all individual wells within the block.

[0106] Closure coefficient for verified oil production after light hydrocarbon removal = (verified oil production - light hydrocarbon production) / wellhead oil production in the block.

[0107] Verification of oil production closure coefficient = Verified oil production / Block wellhead oil production.

[0108] Verification production closure coefficient = Verified production / Block wellhead production.

[0109] If the sum of data from a single well and the cumulative production of the block are closed (closed here means that the data are consistent, with an acceptable error value within 0.005%), then no data closure correction is required; otherwise, data closure correction should be performed according to the method described above. Data correction uses the correction coefficient method, which refers to achieving overall data closure through a series of coefficient calculations.

[0110] Specifically, the data closure procedure for oil production includes wellhead oil production and verified oil production.

[0111] For wellhead oil production data closure, the actual production data of a single well within the inspection period are first summed and compared with the actual production data of the block wellhead within the inspection period. If the difference is within 0.005%, the wellhead oil production data is considered closed, and this data is used as the output of the oil production closure result. If the difference exceeds 0.005%, the data is corrected according to the wellhead oil production closure coefficient mentioned above, and the corrected data is used as the output of the oil production closure result.

[0112] For verifying the closure of oil production data, first check whether the verified oil production data for the block within the inspection period includes non-geological production, such as light hydrocarbons. If it includes non-geological production, deduct it before verifying the oil production data closure. If it does not include non-geological production, directly verify the oil production data closure. Sum the actual production data of verified oil production within the inspection period and compare it with the actual production data of verified oil production for the block within the inspection period. If the difference is within 0.005%, the verified oil production data is considered closed, and this data is used as the oil production repositioning result. If the difference exceeds 0.005%, the data is corrected according to the above-mentioned light hydrocarbon-free verified oil production closure coefficient or verified oil production closure coefficient, and the corrected data is used as the oil production repositioning result.

[0113] Specifically, the data closure procedure for water production includes wellhead water production and verified water production.

[0114] For wellhead water production data closure, the actual production data of single wellhead water production within the inspection period are first summed and compared with the actual production data of block wellhead water production within the inspection period. If the data difference is within 0.005%, the wellhead water data is considered closed, and this data is used as the water production closure result output. If the data difference exceeds 0.005%, the data is corrected according to the wellhead water production closure coefficient mentioned above, and the corrected data is used as the water production closure result output.

[0115] For verifying the closure of water production data, the actual water production data within the verification period are first summed and compared with the actual water production data of the block within the verification period. If the difference is within 0.005%, the water production data is considered closed, and this data is used as the water production relocation result. If the difference exceeds 0.005%, the data is corrected according to the aforementioned verification water production closure coefficient, and the corrected data is used as the water production relocation result.

[0116] In one embodiment of the present invention, the oil well comprises two production units: Unit A and Unit B, as shown in the attached figure. Figure 4As shown, in a certain month, the sum of the wellhead production of a single oil and gas well does not match the block production. Furthermore, it has been verified that the production includes contributions from non-geological reserves of light hydrocarbons. Therefore, data processing is performed using the example of single-well to block data closure. The calculation formula is as follows: Monthly wellhead oil (water) production of Unit A = Monthly wellhead oil (water) closure coefficient × Monthly wellhead oil (water) production × Unit A splitting coefficient; Monthly wellhead oil (water) production of Unit B = Monthly wellhead oil (water) closure coefficient × Monthly wellhead oil (water) production × Unit B... The data is divided into several parts: Monthly verified oil production for Unit A = Monthly oil production after light hydrocarbon removal × Verified oil closure coefficient × Unit A splitting coefficient; Monthly verified oil production for Unit B = Monthly oil production after light hydrocarbon removal × Verified oil closure coefficient × Unit B splitting coefficient; Monthly verified water production for Unit A = Monthly wellhead oil (water) production × Monthly verified water production closure coefficient × Unit A splitting coefficient; Monthly verified water production for Unit B = Monthly wellhead oil (water) production × Monthly verified water production closure coefficient × Unit B splitting coefficient. After data closure using the above methods, the production data is then repositioned after production splitting.

[0117] 4) Single-well production splitting: Determine the splitting coefficient for each oil well and split the single-well production according to the splitting coefficient; when the same oil well is produced by multiple layers, the splitting coefficient refers to the ratio of the production of different production layers to the total production of the oil well; when the same oil well is produced by a single layer, the splitting coefficient refers to the ratio of the production of different sub-layers of that layer to the total production of the oil well.

[0118] The splitting coefficients include water production splitting coefficients and oil production splitting coefficients; the water production and oil production of each oil well are split using the water production splitting coefficients and oil production splitting coefficients of the oil well, respectively.

[0119] The production of oil and gas from an oil well is measured by water cut, and the oil and water production are calculated. Within a testing cycle, if the production of the same oil well includes the extraction of different formations, its oil and water production needs to be divided according to the different formations. In one embodiment of the invention, the oil well's extraction formation includes two units, A and B. The wellhead oil (water, fluid) production of unit A = wellhead oil (water, fluid) production × unit A's division coefficient; the wellhead oil (water, fluid) production of unit B = wellhead oil (water, fluid) production × unit B's division coefficient.

[0120] Generally, the sum of the splitting coefficients of a well within the same time period must be equal to 1, to ensure the consistency of the total data before and after splitting. In the above embodiment, the sum of the splitting coefficients of unit A and unit B is 1.

[0121] Specifically, to account for engineering factors such as casing damage and external leakage that may cause oil production and water production to be from different geological strata, the technical solution of this invention proposes to use two splitting coefficients for oil production and water production respectively. One is the splitting coefficient for oil production, called the oil production splitting coefficient, and the other is the splitting coefficient for water production, called the water production splitting coefficient. In the same oil well, the sum of the water production splitting coefficients is 1; the sum of the oil production splitting coefficients is 1.

[0122] The splitting coefficient is determined by at least one of the following methods: stratified metering, production profile, oil testing data, modular formation dynamic testing, dynamic analysis, flow coefficient, thickness, and formation coefficient.

[0123] When allocating oil and gas product output, determining the allocating coefficient is crucial. In practice, one or more of the methods described above can be used to determine the allocating coefficient, which is then applied to allocate output. If the allocated output data matches the actual data, or if the result of the repositioning verification is reasonable, then the allocating coefficient is considered correct. If the result of the repositioning verification is unreasonable, the process returns to the allocating coefficient determination method, applying multiple methods to obtain an allocating coefficient that reflects the objective situation. The specific steps for determining the allocating coefficient using various methods are relatively mature in existing technologies and will not be elaborated upon in this invention.

[0124] The determination of the splitting coefficient includes the following steps: A. Determine the type of oil well, including normal wells and casing-damaged wells; B. Determine the production type of a single well, including single-production wells, combined-production wells with production profiles, and combined-production wells without production profiles; C. Based on the type of oil and gas well and the production type of a single well, determine the calculation methods for the water production splitting coefficient and the oil production splitting coefficient: For normal wells and single-production wells, the oil production splitting coefficient for geological oil production is 1; the water production splitting coefficient for geological water production is 1; for normal wells and combined-production wells with production profiles, the production profile data is used as the oil production splitting coefficient for geological oil production; Liquid profile data is used as the production water splitting coefficient for geological water production. For normal wells and commingled production wells without a liquid production profile, the oil production splitting coefficient and the water production splitting coefficient for geological oil production are calculated comprehensively based on production dynamics, oil testing and production, and formation coefficients. For casing-damaged wells that are single-production wells, the oil production splitting coefficient before casing damage is used for geological oil production. For the water production splitting coefficient, it includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient is the water production splitting coefficient before casing damage. The casing damage water splitting coefficient is calculated according to the following formula: Casing damage water splitting coefficient = 1 - (Geological water production splitting coefficient - Formation coefficient) Geological water production / (geological water production + casing loss water production); for casing loss wells that are co-production wells with a production profile, the production profile data is used as the oil production splitting coefficient for geological oil production; for water production splitting coefficient, it includes the geological water production splitting coefficient and the casing loss water splitting coefficient; the geological water production splitting coefficient is based on the production profile data; the casing loss water splitting coefficient is calculated according to the following formula: Casing loss water splitting coefficient = 1 - Geological water production / (geological water production + casing loss water production); for casing loss wells that are co-production wells without a production profile, based on production dynamics... The oil production splitting coefficient is calculated by comprehensively considering oil testing, production trials, and formation coefficients. The water production splitting coefficient includes the geological water production splitting coefficient and the casing water loss splitting coefficient. The geological water production splitting coefficient is calculated based on production dynamics, oil testing, production trials, and formation coefficients. The casing water loss splitting coefficient is calculated using the following formula: Casing water loss splitting coefficient = 1 - Geological water production / (Geological water production + Casing water loss production). D. If the borehole does not reveal the stratigraphic position and only produces water without oil, the oil production splitting coefficient for geological oil production is 0, and the water production splitting coefficient for geological water production is 1.

[0125] Generally, as production time increases and actual test data and other information accumulates, the well splitting coefficient should be adjusted according to the actual data to ensure the accuracy of the repositioning data.

[0126] 5) Results verification: Verify the reasonableness of oil and gas product output by examining the recovery rate and extraction rate;

[0127] If the result is reasonable, output the production of the oil and gas field block; if it is unreasonable, return to step 3.

[0128] It should be noted that, in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus.

[0129] It should be understood that the above description is for illustrative purposes and not for limitation. Many embodiments and applications beyond the provided examples will be apparent to those skilled in the art upon reading the above description. Therefore, the scope of this teaching should not be determined by reference to the above description, but rather by reference to the foregoing claims and the full scope of their equivalents. For purposes of completeness, all articles and references, including patent applications and publications, are incorporated herein by reference. The omission of any aspect of the subject matter disclosed herein in the foregoing claims is not intended as a waiver of that subject matter, nor should it be construed as an indication that the applicant has not considered that subject matter as part of the disclosed inventive subject matter.

Claims

1. A method of aligning production and geological reserves of an oil field, characterized in that, Includes the following steps: Step 1: Measure the oil and gas products produced by each production unit in the oilfield block to obtain actual production data; Step 2: Determine whether the actual production data of the block's oil and gas products is closed with the sum of the actual production data of each well in the block. If yes, proceed to Step 3; otherwise, complete or restore the actual production data. Step 3: Determine whether the actual production data includes output from non-geological units. If so, perform data correction; otherwise, proceed to Step 4. Step 4: Based on the test data and geological understanding of the oil wells, determine the oil production and water production splitting coefficients for each oil well, and split the actual production data into single-well production values ​​according to the splitting coefficients. Determining the splitting coefficient includes the following steps: A. Determine the type of oil well, including normal wells and wells with casing damage; B. Determine the production type of a single well, including single-production wells, combined production wells with production profiles, and combined production wells without production profiles; C. Determine the calculation methods for water splitting coefficient and oil splitting coefficient based on the type of oil well and the production type of a single well: For normal wells and single-production wells, the oil production splitting factor for geological oil production is 1; the water production splitting factor for geological water production is 1. For normal wells and wells with production profiles, the production profile data is used as the oil production splitting factor for geological oil production; and the production profile data is used as the water production splitting factor for geological water production. For normal wells and commingled production wells without a production profile, the oil production splitting coefficient and the water production splitting coefficient of geological oil production are calculated comprehensively based on production dynamics, oil testing and production, and formation coefficients. For wells with casing damage and single production, the geological oil production coefficient remains the same as before casing damage. The water production coefficient includes both the geological water production coefficient and the casing damage water production coefficient. The geological water production coefficient remains the same as before casing damage. The casing damage water production coefficient is calculated using the following formula: Casing damage water production coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). For wells with casing damage and which are combined production wells with a production profile, the production profile data is used as the oil production splitting coefficient for geological oil production. For the water production splitting coefficient, it includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient uses the production profile data as the geological water production splitting coefficient. The casing damage water splitting coefficient is calculated according to the following formula: Casing damage water splitting coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). For wells with casing damage and no production profile, the oil production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The water production splitting coefficient includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The casing damage water splitting coefficient is calculated using the following formula: Casing damage water splitting coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). D. If the strata are not explored in the borehole and it is found that it only produces water and not oil, then the oil splitting coefficient for geological oil production is 0, and the water splitting coefficient for geological water production is 1. Step 5: The single-well production output results are sorted and the data is reallocated to obtain the actual production data of the reserve unit within the proven geological reserves and the test production area unit outside the proven geological reserves.

2. The method of mapping production to reserves of an oil field of claim 1, wherein, In step two, the actual production data is supplemented or restored according to the following formula: Monthly output = the sum of daily outputs; Monthly production days = Sum of monthly production hours / 24; Daily production capacity = Monthly output / Monthly production days; Daily output level = Monthly output / Number of calendar days in a month; Monthly stress data = arithmetic mean of daily and monthly stress; Daily and monthly production figures are compiled separately for oil, gas, and water production.

3. The method of mapping production to reserves of an oil field of claim 1, wherein, In step two, the testing period for data closure judgment is one calendar month, with an allowable error of ≤0.005%.

4. The method for reconciling oilfield production and geological reserves according to claim 1, characterized in that, In step three, the process of correcting the actual production data involves scaling the actual production data proportionally using closure coefficients. These closure coefficients include the wellhead oil production closure coefficient, the wellhead water production closure coefficient, the verified oil production closure coefficient after light hydrocarbon removal, the verified oil production closure coefficient, and the verified water production closure coefficient. The closure coefficients within the verification period are calculated using the following formula: Wellhead oil production closure coefficient = Block wellhead oil production / Sum of oil production from all individual wells within the block; Wellhead water production closure coefficient = Block wellhead water production / Sum of water production from all individual wells within the block; Closure coefficient for verified oil production after light hydrocarbon removal = (verified oil production - light hydrocarbon production) / wellhead oil production in the block; Verification of oil production closure coefficient = Verified oil production / Block wellhead oil production; Verification of water production closure coefficient = Verified water production / Block wellhead water production.

5. The method for reconciling oilfield production and geological reserves according to claim 1, characterized in that, In step one, each production unit is assigned a unique data query path as its index; The index is set up according to the following steps:

1. Determine whether the current oil well has undergone a wellbore change operation; if not, the index for the actual production data is the current oil and gas well number; if yes, proceed to step 2; 2. Determine the start and end times of the current oil well and the wellbore change operation; match the actual production data in the database according to the production time period, so that each actual production data corresponds to a unique index; the index setting rules are as follows: the index for actual production data in the time period without wellbore change is the current oil well number; the index for actual production data in the time period with wellbore change is the current oil well number followed by different characters for distinction; If the wellbore is changed multiple times, the index of the actual production data for each time period of the wellbore change is distinguished by different characters.

6. The method for reconciling oilfield production and geological reserves according to claim 1, characterized in that, After step five is completed, the production rate of oil and gas products is verified to be reasonable based on the recovery rate and production speed. If reasonable, the production of the oil and gas field block is output. If unreasonable, the process returns to step four.

7. A system for reconciling oilfield production and geological reserves, characterized in that, include: The actual production data acquisition module is used to measure the oil and gas products extracted from each production unit in the oilfield block and obtain actual production data. The data closure judgment module is used to determine whether the actual production data of the oil and gas products in the block is closed with the sum of the actual production data of the oil and gas products of each well in the block. If it is closed, the module proceeds to the non-geological unit production judgment module; otherwise, it completes or restores the actual production data. The non-geological unit output judgment module is used to determine whether the actual production data includes the output of non-geological units. If so, the data is corrected; otherwise, the output splitting module is entered. The production splitting module is used to determine the oil production and water production splitting coefficients for each oil well based on the test data and geological understanding of the oil wells, and to split the production of each well according to the actual production data according to the splitting coefficients. Determining the splitting coefficient includes the following steps: A. Determine the type of oil well, including normal wells and wells with casing damage; B. Determine the production type of a single well, including single-production wells, combined production wells with production profiles, and combined production wells without production profiles; C. Determine the calculation methods for water splitting coefficient and oil splitting coefficient based on the type of oil well and the production type of a single well: For normal wells and single-production wells, the oil production splitting factor for geological oil production is 1; the water production splitting factor for geological water production is 1. For normal wells and wells with production profiles, the production profile data is used as the oil production splitting factor for geological oil production; and the production profile data is used as the water production splitting factor for geological water production. For normal wells and commingled production wells without a production profile, the oil production splitting coefficient and the water production splitting coefficient of geological oil production are calculated comprehensively based on production dynamics, oil testing and production, and formation coefficients. For wells with casing damage and single production, the geological oil production coefficient remains the same as before casing damage. The water production coefficient includes both the geological water production coefficient and the casing damage water production coefficient. The geological water production coefficient remains the same as before casing damage. The casing damage water production coefficient is calculated using the following formula: Casing damage water production coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). For wells with casing damage and which are combined production wells with a production profile, the production profile data is used as the oil production splitting coefficient for geological oil production. For the water production splitting coefficient, it includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient uses the production profile data as the geological water production splitting coefficient. The casing damage water splitting coefficient is calculated according to the following formula: Casing damage water splitting coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). For wells with casing damage and no production profile, the oil production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The water production splitting coefficient includes the geological water production splitting coefficient and the casing damage water splitting coefficient. The geological water production splitting coefficient is calculated based on production dynamics, oil testing and production, and formation coefficients. The casing damage water splitting coefficient is calculated using the following formula: Casing damage water splitting coefficient = 1 - Geological water production / (Geological water production + Casing damage water production). D. If the strata are not explored in the borehole and it is found that it only produces water and not oil, then the oil splitting coefficient for geological oil production is 0, and the water splitting coefficient for geological water production is 1. The data relocation module is used to relocate the single-well production splitting results, obtaining the actual production data of the reserve unit within the proven geological reserves and the test production area unit outside the proven geological reserves.

8. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the method for reconciling the production and geological reserves of an oil field as described in any one of claims 1 to 6.

9. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the steps of the method for reconciling the production and geological reserves of an oil field as described in any one of claims 1 to 6.

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