Shale gas platform multi-well plunger production system coordination method and terminal thereof

Abstract

This invention discloses a method for coordinating multi-well plunger production regimes on a shale gas platform and its terminal, the method comprising: obtaining the initial well opening time T of the gas well. open and well shut-in time T close According to the well opening time T open and well shut-in time T close Determine the initial arrival time T of the plunger mid and its range T min ≤T mid ≤T max Based on the wellhead pressure P after plunger lifting t Parameters and flow rate Q mid At least one of the parameters adjusts the optimal well opening time T of the gas well. o and well shut-in time T c Based on optimized well opening time T o and well shut-in time T c Initial arrival time T of the plunger mid Optimize to obtain the optimal plunger arrival time T m ; Optimize the arrival time T of the plunger for each well m The actual well start-up and shut-in times for each well are coordinated with the number of wells (M). This approach enables coordinated production from platform plunger wells.

Description

Technical Field

[0001] This invention relates to the field of oil and gas development technology, specifically to a method for coordinating multi-well plunger production systems on shale gas platforms and its terminal. Background Technology

[0002] As shale gas extraction time increases, formation energy continuously declines, and gas well production decreases. When production drops to the critical fluid-carrying capacity of the well, fluid accumulation in the wellbore will occur, rendering the well unable to produce normally. Currently, plunger gas lift drainage gas production technology has become the main technology for solving the problem of wellbore fluid accumulation in the later stages of shale gas production. It can effectively mitigate the impact of wellbore fluid accumulation and extend the self-flowing gas production period of the gas well.

[0003] The plunger gas lift process utilizes the cyclical up-and-down movement of a freely moving plunger within the wellbore to increase the lifting efficiency of the liquid. During well shut-in, the plunger falls to the bottom of the well under its own weight, accumulating bottomhole pressure. During well opening, sufficient pressure lifts the plunger and the liquid above it to the wellhead. Once the plunger reaches the wellhead, the gas flow resumes; when the energy is insufficient, the well is shut off, and the next cycle begins. This cyclical process is accomplished by a controller periodically controlling the opening and closing of pneumatic valves. The plunger gas lift process boasts high lifting efficiency and is widely used in shale gas wells. However, for shale gas plunger platforms, the large number of plunger wells and the severe mutual interference during well opening and closing can prevent the plungers from operating normally, significantly restricting well production capacity. If the next well is opened prematurely before the plunger reaches the wellhead, it will affect the pressure or flow rate within that well, leading to a reduction in natural gas or even backflow, impacting natural gas production. Furthermore, the greater the interference, the greater the fluctuation in gas production, making it difficult for compressors and other equipment to adapt to changes in gas production. Therefore, it is necessary to study the methods for determining the rational operating system of platform plunger wells in order to achieve coordinated production. Summary of the Invention

[0004] The purpose of this invention is to provide a method for coordinating the production system of multiple plunger wells on a shale gas platform and its terminal. By adopting this solution, coordinated production of plunger wells on the platform can be achieved.

[0005] This invention is achieved through the following technical solution:

[0006] A method for coordinating multi-well plunger production regimes on a shale gas platform, the method comprising:

[0007] Obtain the initial well opening time T of the gas well open and well shut-in time T close ;

[0008] Based on well opening time T open and well shut-in time T close Determine the initial arrival time T of the plunger mid and its range T min ≤Tmid ≤T max ;

[0009] Based on the wellhead pressure P after plunger lifting t Parameters and flow rate Q mid At least one of the parameters adjusts the optimal well opening time T of the gas well. o and well shut-in time T c ;

[0010] Based on optimized well opening time T o and well shut-in time T c Initial arrival time T of the plunger mid Optimize to obtain the optimal plunger arrival time T m ;

[0011] Optimized plunger arrival time T for each well m Coordinate the actual well opening and shut-in times for each well with the number of wells (M).

[0012] Compared to existing technologies, which suffer from problems such as mutual interference between wells during plunger production on the same shale gas platform, preventing plunger operation, and inconsistent production regimes causing difficulties for compressors and other equipment, this solution provides a method for coordinating the production regimes of multiple wells on a shale gas platform. In this method, the initial well opening time T of the gas wells can be set based on the experience of technical personnel. open and its optimization range (T) openmin ,T maxopen ), and shut-in time Tclose and its optimization range (T closemin ,T maxclose The well opening and shut-in times should both be optimized within this range; after setting the above parameters, the well opening time T should be adjusted accordingly. open and well shut-in time T close Determine the initial arrival time T of the plunger mid and its range T min ≤T mid ≤T max After determining the range, since both pressure and flow rate affect the plunger arrival time and gas production, it is necessary to base the wellhead pressure P after the plunger is lifted. t Parameters and flow rate Q mid At least one of the parameters adjusts the optimal well opening time T of the gas well. o and well shut-in time T c Then, based on the optimized well opening time T o and well shut-in time T c Initial arrival time of the plunger T mid Optimize to obtain the optimal plunger arrival time T mGas production can be optimized by determining the plunger arrival time; after determining the plunger arrival time for each well, the arrival time T needs to be optimized based on the plunger arrival time of each well. m Coordinate the actual well opening and shut-in times of each well with the number of wells M. For example, if there are two wells, and the plunger of the first well will reach the wellhead in 20 minutes after it is opened, then the well opening time of the second well should be after the plunger of the first well has reached the wellhead. If the well opening time is adjusted to 25 minutes later, it can prevent the early opening of the second well from affecting the gas production of the first well.

[0013] Further optimization includes a step of determining whether the plunger has reached the designated lifting position after the plunger is lifted:

[0014] If the plunger can be lifted into position, then based on the wellhead pressure P t Parameter or flow rate Q mid One of the parameters adjusts the optimal well opening time T of the gas well. o and well shut-in time T c ;

[0015] If the plunger fails to rise to the desired position, then based on the flow rate Q at the wellhead... mid Parameter adjustment optimizes the well opening time T of the gas well. o and well shut-in time T c ;

[0016] Among them, whether the plunger is lifted to the correct position refers to whether the plunger can reach the wellhead.

[0017] Further optimization involves considering the wellhead pressure P if the plunger can be lifted into position. t Parameter adjustment optimizes the well opening time T of the gas well. o and well shut-in time T c Includes the following steps:

[0018] Obtain the actual arrival time T of the plunger during at least one plunger lifting cycle. ariv and the wellhead pressure P when the plunger actually arrives trmax ;

[0019] If T ariv >T mid *1.2, then the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When *0.8, the shut-in time T c =T c -(T ariv -T mid) / T mid *T c *0.1; or P trmax >P t *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1;

[0020] If T ariv <T mid *0.8, then the well opening time T o =T o +(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1, or P trmax >P t *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1.

[0021] Further optimization involves adjusting the flow rate Q at the wellhead if the plunger can be lifted into position. mid Parameter adjustment optimizes the well opening time T of the gas well. o and well shut-in time T c Includes the following steps:

[0022] Set well opening flow rate Q openmax And obtain the actual plunger arrival time T during at least one plunger lifting cycle. ariv , Incoming traffic Q rmax ;

[0023] If T ariv >T mid *1.2, then the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and Qrmax <Q openmax When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1; or Q rmax >Q openmax *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1;

[0024] If T ariv <T mid *0.8, then the well opening time T o =T o +(T ariv -T mid ) / T mid *T o *0.1, and Q rmax <Q openmax When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1, or Q rmax >Q openmax *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1.

[0025] Further optimization involves adjusting the flow rate Q at the wellhead if the plunger fails to reach its designated position. mid Parameter adjustment optimizes the well opening time T of the gas well. o and well shut-in time T c Includes the following steps:

[0026] Set well opening flow rate Q openmax And obtain the actual plunger arrival time T during at least one plunger lifting cycle. ariv , Incoming traffic Q rmax ;

[0027] If Q rmax <Q openmax *At 0.8, the well shut-in time Tc =T c -(T ariv -T mid ) / T mid *T c *0.1, well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1;

[0028] If Q rmax >Q openmax *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1, well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1.

[0029] Further optimization, based on the optimized well opening time T o and well shut-in time T c Initial arrival time T of the plunger mid Optimize to obtain the optimal plunger arrival time T m Includes the following steps:

[0030] From T m =(T min ,T max Starting with ) / 2, with a step size T step =(T min ,T max The test runs are conducted in two steps each in the positive and negative directions, where M refers to the number of wells opened;

[0031] In at least one cycle, obtain each arrival time T. m Gas well production;

[0032] Choose the arrival time T with the highest gas production. mmax Well production.

[0033] Further optimization was performed, based on the plunger arrival time T for each well. m Optimize well opening time T o Well shut-in time T c Coordinating the actual well opening and shut-in times for each well with the number of wells M includes the following steps:

[0034] Set the cycle opening time for each well on the entire platform to T. 11 ,...,T 1n The well shut-in time is T. 21 ,...,T 2n Then: T1 = T 11 +....T 1n T2 = T 21 ....T 2N Then T = T1 + T2; N is a natural number;

[0035] Calculate the number of wells M that can be opened simultaneously. If M is less than 1, extend the opening time and shorten the shut-in time for each well by 1% until M>=1. When shutting down a well, check the current actual number of wells open, MR+1.

[0036] If MR > M, then shut in the well;

[0037] If YorS > 1, then extend the well shut-in time T. 2i / 10 minutes;

[0038] If YorS = 1, then shorten the shut-in time of the nearest well to be opened by T. 2j / 10 minutes.

[0039] Further optimization was performed, based on the plunger arrival time T for each well. m Optimize well opening time T o Well shut-in time T c Coordinating the actual well opening and shut-in times for each well with the number of wells M includes the following steps:

[0040] Obtain the influencing factors and use them to coordinate the actual well opening and shut-in times for each well.

[0041] Compared with the prior art, the present invention has the following advantages and beneficial effects:

[0042] This invention provides a method for coordinating the production regime of multiple plungers on a shale gas platform. Based on readily available surface data of the current plunger operating regime and casing pressure and flow rate, starting with single-well optimization, this method focuses on the coordinated production of the plunger platform and proposes a more comprehensive plunger well optimization method. It further determines a reasonable plunger operating regime, effectively improves the operating efficiency of the plungers, fully leverages the lifting advantage of plunger gas lift, and improves the recovery rate of shale gas wells. Attached Figure Description

[0043] To more clearly illustrate the technical solutions of the exemplary embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly described below. It should be understood that the following drawings only show some embodiments of the present invention and should not be considered as a limitation of the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort. In the drawings:

[0044] Figure 1 A flowchart of the steps provided for this invention;

[0045] Figure 2 A schematic diagram of the staggered production switch for the six plungers of the shale gas platform provided by the present invention;

[0046] Figure 3 This is a schematic diagram of the normal plunger process during plunger air lift;

[0047] Figure 4 This is a schematic diagram of the plunger process when the plunger has not reached its destination during plunger air lift. Detailed Implementation

[0048] To make the objectives, technical solutions, and advantages of the present invention clearer, the present invention will be further described in detail below with reference to the embodiments and accompanying drawings. The illustrative embodiments and descriptions of the present invention are only used to explain the present invention and are not intended to limit the present invention.

[0049] Example 1

[0050] This embodiment provides a method for coordinating the multi-well plunger production regime of a shale gas platform, such as... Figures 1 to 4 As shown, the specific steps include the following:

[0051] First, the optimization range for well opening time and well shut-in time needs to be set: (T) openmin ,T maxopen ), (T closemin ,T maxclose Determine the arrival time T of a given plunger. mid The range is (T) min ,T max Set oil pressure P. t The range is (P) tmin ,P tmax ), well opening flow rate Q open The range is (Q) openmin Q maxopen ), well shut-in flow rate Q closemin When the flow rate is less than Q after N minutes. closemin The well is shut off at the designated time. All optimizations are conducted within this range. Some parameters are initially set by technical personnel based on experience, and will be gradually implemented using computer software to recommend parameters and determine the final decision intelligently.

[0052] After determining the above parameter range, it is necessary to consider the wellhead pressure P after the plunger is lifted. t Parameters and flow rate Q mid At least one of the parameters adjusts the optimal well opening time T of the gas well. o and well shut-in time T c This includes the following situations:

[0053] (1) If the wellhead pressure is not zero and the plunger can reach the wellhead, then the well opening and shut-in times are optimized using pure pressure mode. The plunger arrival time is then optimized based on the optimized well opening and shut-in times. For example, the actual arrival times of the plunger in the three cycles are set as follows: T ariv1 T ariv2 T ariv3 The pressure when the plunger arrives is P. trmax1 P trmax2 P trmax3 Then: T ariv =(T ariv1 +T ariv2 +T ariv3 ) / 3;P trmax =(P trmax1 +P trmax2 +P trmax3 ) / 3;

[0054] If T ariv >T mid *1.2, then the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1; or P trmax >P t *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1;

[0055] If T ariv <T mid *0.8, then the well opening time T o=T o +(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1, or P trmax >P t *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1.

[0056] (2) If the flow rate is not zero and the plunger can reach the wellhead, then the well opening and shut-in times are optimized using the pure flow rate mode. The plunger arrival time is then optimized based on the optimized well opening and shut-in times. For example, the actual arrival times of the plunger in three cycles are set to Tariv1, Tariv2, and Tariv3, with an well opening flow rate of Q. rmax1 Q rmax2 Q rmax3 The arrival flow is Q rmid1 Q rmid2 Q rmid3 The pressure upon arrival is P. trmax1 P trmax2 P trmax3 ,but:

[0057] T ariv =(T ariv1 +T ariv2 +T ariv3 ) / 3;

[0058] P trmax =(P trmax1 +P trmax2 +P trmax3 ) / 3;

[0059] Q rmax =(Q rmax1 +Q rmax2 +Q rmax3 ) / 3;

[0060] Q rmid =(Q rmid1 +Q rmid2 +Qrmid3 ) / 3;

[0061] If T ariv >T mid *1.2, then the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and Q rmax <Q openmax When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1; or Q rmax >Q openmax *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1;

[0062] If T ariv <T mid *0.8, then the well opening time T o =T o +(T ariv -T mid ) / T mid *T o *0.1, and Q rmax <Q openmax When *0.8, the shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1, or Q rmax >Q openmax *At time 1.2, the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1.

[0063] (3) If the flow rate is not zero but the plunger cannot reach the wellhead, then the well opening flow rate needs to be optimized. The well opening and shut-in times should then be optimized based on the optimized flow rate. Finally, the plunger arrival time should be optimized based on the optimized well opening and shut-in times. For example, the actual arrival time of the plunger in three cycles can be set as T... ariv1 T ariv2 T ariv3 The well opening flow rate is Q. rmax1 Q rmax2 Q rmax3 The arrival flow is Q rmid1 Q rmid2 Q rmid3 The pressure upon arrival is P. trmax1 P trmax2 P trmax3 ,but:

[0064] T ariv =(T ariv1 +T ariv2 +T ariv3 ) / 3;

[0065] P trmax =(P trmax1 +P trmax2 +P trmax3 ) / 3;

[0066] Q rmax =(Q rmax1 +Q rmax2 +Q rmax3 ) / 3;

[0067] Q rmid =(Q rmid1 +Q rmid2 +Q rmid3 ) / 3;

[0068] If Q rmax <Q openmax *At 0.8, the well shut-in time T c =T c -(T ariv -T mid ) / T mid *T c *0.1, well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1;

[0069] If Q rmax >Q openmax *At time 1.2, the shut-in time T c=T c +(T ariv -T mid ) / T mid *T c *0.1, well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1.

[0070] (5) When the plunger cannot reach the wellhead and the flow rate is zero, and the wellhead is not zero, the technicians set a reasonable well opening and closing time according to the gas well conditions to achieve timing.

[0071] In the above-mentioned optimized well opening time T o and well shut-in time T c Then, the initial arrival time T of the plunger needs to be determined. mid Optimize to obtain the optimal plunger arrival time T m This optimizes the maximum gas production. Specifically, the optimization process involves adjusting the T... m =(T min ,T max Starting with ) / 2, with a step size T step =(T min ,T max The trial run (T) proceeds in two steps each in the positive and negative directions, with other production modes optimized at each arrival time. Here, M refers to the number of wells in operation. After optimization, the gas well production is calculated over five cycles, and the time with the highest gas production among the five arrival times is taken as the new T. mid This cycle repeats continuously.

[0072] In optimizing the maximum gas production rate as described above, the maximum gas production rate can also be optimized by adjusting the well opening gas production rate. Specifically, in the optimization process, from Q... open =(Q openmin +Q maxopen Starting with ) / 2, with a step size T step =(Q maxopen -Q openmin Two steps each in the positive and negative directions of the ) / M trial run. After optimization, the gas well production within 5 cycles is calculated, and the highest gas production among the 5 arrival times is taken as the new Q. open This process repeats continuously.

[0073] After optimizing the plunger time as described above, the entire platform's plunger wells need to be optimized to determine the well start-up and shut-in times for each well. For gas well production platforms with insufficient energy and short well start-up times in the later stages, in addition to considering the mutual interference between wells, staggered well start-up and shut-down should also be considered to avoid situations where no gas wells are operating on the entire platform. If there is excess well start-up time, check the wells sharing the platform's compressor before shutting them in. If there are wells that are operating, shut them in; if there are no wells that are operating, extend the shut-in time and start the well that is most recently scheduled to be started in advance. Figure 1 The diagram shows a staggered switching of the six plungers on a shale gas platform during production, with each well's switching time staggered. Here, 1 represents well shut-in and 2 represents well open.

[0074] Set the cycle opening time for each well on the entire platform to T. 11 ,...,T 1n The well shut-in time is T. 21 ,...,T 2n Then: T1 = T 11 +....T 1n T2 = T 21 ....T 2N Then T = T1 + T2; N is a natural number;

[0075] Calculate the number of wells M that can be opened simultaneously. If M is less than 1, extend the opening time and shorten the shut-in time for each well by 1% until M>=1. When shutting down a well, check the current actual number of wells open, MR+1.

[0076] If MR > M, then shut in the well;

[0077] If YorS > 1, then extend the well shut-in time T. 2i / 10 minutes;

[0078] If YorS = 1, then shorten the shut-in time of the nearest well to be opened by T. 2j / 10 minutes.

[0079] In the above optimization process, influencing factors also need to be considered to avoid interference between wells, especially for platforms with sufficient well opening time. The steps are as follows:

[0080] A. Set the well number and influence factor for well opening impact. For example, well J2, which shares a separator with well J1, has an influence factor of L1; well J3, which shares the same platform as well J1, has an influence factor of L2.

[0081] B. Set the minimum arrival time T for wells J1 and J2. mid (T min T max Before well J1 is opened, the well opening time T1 of wells with an influencing factor of L1 is checked. If T1 > T maxOpen the well; otherwise, the well shut-in time will increase by T. max -T1;

[0082] Before well C.J1 is opened, the well's opening time T2 is checked for factors L2. If T2 > T max -T min Open the well; otherwise, the well shut-in time will increase by T. max -T min -T2.

[0083] This embodiment, based on readily available ground-based data on current plunger operating regimes and casing pressure and flow rates, takes single-well optimization as a starting point, focuses on the coordinated production of the plunger platform, proposes a more comprehensive plunger well optimization method, further determines a reasonable plunger operating regime, effectively improves plunger operating efficiency, fully leverages the lifting advantages of plunger gas lift, and enhances shale gas well recovery rate.

[0084] Example 2

[0085] Plunger gas lift is a special type of intermittent lifting. Depending on the gas source, plunger gas lift technology is divided into externally sourced gas plunger gas lift and self-sourced gas plunger gas lift. The plunger, as a special gas-liquid interface, separates the lifting gas and the lifted liquid, reducing slippage losses caused by gas passing through the liquid slug and preventing liquid backflow, thus improving the gas well's liquid-carrying production capacity. During well shut-in, the plunger falls to the top of the buffer spring inside the production tubing under its own weight. After well opening, driven by the natural gas, the plunger and the liquid above it rise together. The liquid is lifted out of the wellhead, and the natural gas below the plunger enters the production process, completing one lift cycle. Plunger gas lift drainage and gas production primarily achieves gas production from the gas well, with liquid drainage as a secondary function, ensuring stable gas well production and reducing wellbore liquid accumulation.

[0086] During the above-mentioned plunger gas lift operation, the various operating factors for each plunger should first be determined according to the corresponding formulas, including:

[0087] Depth determination of the locking device:

[0088] H max : Maximum insertion depth of the locking device (m); W GLR : The gas-liquid ratio of the production well (m 3 / m 3 ); GL Rmin The minimum gas-liquid ratio required for the application of the plunger (200m can be taken for Sichuan-Chongqing gas fields). 3 / m 3 / 1000m, for wells with high pressure coefficients, the gas-liquid ratio can be appropriately reduced, such as the GLR of Guang'an 101 well: 135m. 3 / m 3 / 1000m).

[0089] Minimum working pressure: P cmin =P wh +P LH +P LF +P gt +P gtf -P gc +M p g / 10 6 A t ;

[0090] P cmin Minimum working pressure, MPa; P wh Wellhead oil pressure, MPa; P LH : Static pressure of the liquid section, MPa; P LF Pressure loss due to frictional resistance in the liquid section, MPa; P gt : Static air column pressure in the tubing, MPa; P gtf Pipeline flow friction loss pressure, MPa; P gc : Static air column pressure in the annulus, MPa; M p : Plunger mass, kg; A t Cross-sectional area inside the oil pipe, m 2 g: acceleration due to weight, taken as 9.81 m / s² 2 .

[0091] Maximum working pressure: P cmax =(1+A) t / A c )P cmin

[0092] P cmax Maximum working pressure, M Pa A t : Cross-sectional area inside the oil pipe, m2; A c Cross-sectional area of ​​the oil jacket annulus, m2.

[0093] Minimum air volume required for plunger operation:

[0094]

[0095] V g Minimum cycle gas volume for plunger operation, 10 4 m 3 V t : The volume of tubing on the fluid slug before well opening, in meters 3 ;F gs : Slip coefficient of gas through plunger and liquid slug, generally taken as 1.15; T - average wellbore temperature, K; Z - gas deviation coefficient.

[0096] Plunger operating cycle:

[0097]

[0098] n p : for: number of working cycles, cycles / day; t pr : t represents the piston's upward travel time, in seconds; pdg t pdl : represents the plunger's downward travel time in the gas and liquid respectively, in seconds; t ps : is the residence time of the plunger at the wellhead, in seconds; t pc : The dwell time of the plunger on the locking device, in seconds.

[0099] Minimum shut-in time:

[0100] T min =H max ÷V;

[0101] T min : Minimum time for the plunger to fall, min; H max : Depth of the locking device, m; v: Velocity of the plunger, including the velocity in the gas and the velocity in the liquid, m / min. Empirical value: The current plunger velocity we use can be calculated as 50 m / min.

[0102] After determining the various operating factors for each plunger during the aforementioned plunger gas lift operation, the flow rate, time, and pressure were subsequently optimized:

[0103] Flow rate optimization and debugging: Through analysis of the wellhead production capacity and the operating parameters of the plunger when the wellhead is fully open during previous well opening, it was initially determined that the instantaneous production of the plunger gas lift process well should be controlled within 5 to 8 × 10⁴ m³ / d during the initial opening stage, and the instantaneous production after the plunger arrives should be controlled at around 2 × 10⁴ m³ / d. This can effectively protect the stable production of the gas well, ensure that the plunger arrives at the wellhead smoothly, and maximize the liquid carrying production.

[0104] Time optimization and debugging: Time optimization and debugging mainly includes optimization of follow-through time, shut-in time, and follow-through + shut-in time. By comparing the actual plunger ascent time with the target plunger ascent time (well depth ÷ plunger ascent speed), the follow-through time and shut-in time are optimized and debugged. The ultimate goal is to make the actual plunger ascent time consistent with the target plunger ascent time, at which point the plunger drainage and gas production effect is optimal.

[0105] Pressure Optimization and Adjustment: The pressure optimization mode optimizes and adjusts the well based on the pressure values ​​measured by the pressure sensor. Once the minimum shut-in time for the plunger to fall to the buffer spring position is reached, the pressure is monitored. If the set well opening pressure is met, the gas well is opened for production; if the pressure does not reach the set well opening pressure, the gas well will continue to be shut in until the set value is reached. After production is completed and the well is shut in, the minimum time for the plunger to reach the wellhead must be met first, and then the pressure value is checked. If the pressure is lower than the shut-in pressure set value, the gas well is shut in; if the pressure is higher than the high-pressure well shut-in set value, the gas well will continue to produce, but the total well-opening production time must be less than the maximum well-opening time of the well cycle to ensure that the gas well has sufficient energy for stable plunger cycle operation. Field applications have shown that a comprehensive approach combining casing pressure, oil pressure, and transmission pressure is needed for plunger system optimization and adjustment.

[0106] In case of other abnormal situations, the following handling methods shall be adopted:

[0107]

[0108] Based on the above determination and optimization of factors related to plunger gas lift, the optimal plunger speed range is determined to be 500 to 1000 feet per minute (152 to 305 meters per minute). If the speed is below 500 feet per minute, stalling will occur, while if the speed exceeds 1000 feet per minute, the gas well will not be able to produce at its highest efficiency, and excessive speed will also damage the equipment.

[0109] The absolute minimum shut-in time is the time it takes for the plunger to reach the bottom of the tubing. Typically, the plunger descent velocity is 200 to 1000 feet per minute (61 to 305 meters per minute) in dry gas and 20 to 250 feet per minute (6 to 76 meters per minute) in liquid.

[0110] The descent time can vary greatly depending on factors such as plunger type, fluid volume in tubing, tubing condition, and tubing or wellbore deviation.

[0111] Example 3

[0112] In some exemplary embodiments, this embodiment also provides a method for coordinating the production regime of multiple wells of a shale gas platform, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the minimum technical solution of a method for coordinating the production regime of multiple wells of a shale gas platform, as described in Embodiment 1, for achieving the purpose of "coordinated production of platform plunger wells".

[0113] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0114] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0115] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0116] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0117] Those skilled in the art will understand that all or part of the steps in the above facts and methods can be implemented by a program instructing related hardware. The program or the program described therein can be stored in a computer-readable storage medium. When the program is executed, it includes the following steps: at this time, the corresponding method steps are introduced. The storage medium can be ROM / RAM, magnetic disk, optical disk, etc.

[0118] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above description is only a specific embodiment of the present invention and is not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A method for coordinating multi-well plunger production regimes on a shale gas platform, characterized in that, The method includes: Obtain the initial well opening time T of the gas well open and well shut-in time T close ; Based on well opening time T open and well shut-in time T close Determine the initial arrival time T of the plunger mid and its range T min ≤T mid ≤T max ; Based on the wellhead pressure P after plunger lifting t Parameters and flow rate Q mid At least one of the parameters adjusts the optimal well opening time T of the gas well. o And optimize shut-in time T c ; Based on optimized well opening time T o And optimize shut-in time T c Initial arrival time T of the plunger mid Optimize to obtain the optimal plunger arrival time T m ; Optimized plunger arrival time T for each well m Coordinate the actual well opening time and actual well shut-in time of each well with the number of wells M; The process based on plunger lifting also includes a step of determining whether the plunger has reached the designated lifting position. If the plunger can be lifted into position, then based on the wellhead pressure P t Parameter or flow rate Q mid One of the parameters adjusts the optimal well opening time T of the gas well. o And optimize shut-in time T c ; If the plunger fails to rise to the desired position, then based on the flow rate Q at the wellhead... mid Parameter adjustment optimizes the well opening time T of the gas well. o And optimize shut-in time T c ; Among them, whether the plunger lift is in place refers to whether the plunger can reach the wellhead; If the plunger can be lifted into position, then based on the wellhead pressure P t Parameter adjustment optimizes the well opening time T of the gas well. o And optimize shut-in time T c Includes the following steps: Obtain the actual arrival time T of the plunger during at least one plunger lifting cycle. ariv and the wellhead pressure P when the plunger actually arrives trmax ; If T ariv >T mid *1.2, then optimize the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When the value is 0.8, the shut-in time T is optimized. c = T c -(T ariv -T mid ) / T mid *T c *0.1; or P trmax >P t *When the time is 1.2, the shut-in time T is optimized. c =T c +(T ariv -T mid ) / T mid *T c *0.1; If T ariv <T mid *0.8, then optimize the well opening time T o =T o +(T ariv -T mid ) / T mid *T o *0.1, and P trmax <P t When the value is 0.8, the shut-in time T is optimized. c =T c -(T ariv -T mid ) / T mid *T c *0.1, or P trmax >P t *When the time is 1.2, the shut-in time T is optimized. c =T c +(T ariv -T mid ) / T mid *T c *0.1; If the plunger can be lifted into position, then based on the flow rate Q at the wellhead... mid Parameter adjustment optimizes the well opening time T of the gas well. o And optimize shut-in time T c Includes the following steps: Set well opening flow rate Q openmax And obtain the actual plunger arrival time T during at least one plunger lifting cycle. ariv , Incoming traffic Q rmax ; If T ariv >T mid *1.2, then optimize the well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1, and Q rmax <Q openmax When the value is 0.8, the shut-in time T is optimized. c = T c -(T ariv -T mid ) / T mid *T c *0.1; or Q rmax >Q openmax *When the time is 1.2, the shut-in time T is optimized. c =T c +(T ariv -T mid ) / T mid *T c *0.1; If T ariv <T mid *0.8, then optimize the well opening time T o =T o +(T ariv -T mid ) / T mid *T o *0.1, and Q rmax <Q openmax When the value is 0.8, the shut-in time T is optimized. c =T c -(T ariv -T mid ) / T mid *T c *0.1, or Q rmax >Q openmax *When the time is 1.2, the shut-in time T is optimized. c =T c +(T ariv -T mid ) / T mid *T c *0.1; If the plunger fails to rise to the desired position, then based on the flow rate Q at the wellhead... mid Parameter adjustment optimizes the well opening time T of the gas well. o And optimize shut-in time T c Includes the following steps: Set well opening flow rate Q openmax And obtain the actual plunger arrival time T during at least one plunger lifting cycle. ariv , Incoming traffic Q rmax ; If Q rmax <Q openmax When the value is 0.8, the optimized shut-in time T is... c =T c -(T ariv -T mid ) / T mid *T c *0.1, Optimize well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1; If Q rmax >Q openmax *At time 1.2, optimize the shut-in time T c =T c +(T ariv -T mid ) / T mid *T c *0.1, Optimize well opening time T o =T o -(T ariv -T mid ) / T mid *T o *0.1; Based on optimized well opening time T o And optimize shut-in time T c Initial arrival time T of the plunger mid Optimize to obtain the optimal plunger arrival time T m Includes the following steps: From T m =(T min ,T max Starting with ) / 2, with a step size T step =(T min ,T max The test runs are conducted in two steps each in the positive and negative directions, where M refers to the number of wells opened; In at least one cycle, obtain the optimized arrival time T of each plunger. m Gas well production; Choose the arrival time T with the highest gas production. mmax Well production; Optimized plunger arrival time T for each well m Optimize well opening time T o Optimize well shut-in time T c Coordinating the actual well opening time and actual well shut-in time for each well with the number of wells M includes the following steps: Set the cycle opening time for each well on the entire platform to T. 11 , ... ,T 1n The well shut-in time is T. 21 , ... ,T 2n Then: T1 = T 11 +....T 1n T2=T 21 ....T 2N Then T = T1 + T2; N is a natural number; Calculate the number of wells M that can be opened simultaneously; if M is less than 1, extend the opening time and shorten the shut-in time by 1% for each well until M>=1; when shutting in a well, check the current actual number of wells opened MR+1; If MR > M, then shut in the well; If YorS > 1, then extend the well shut-in time T. 2i / 10 minutes; If YorS=1, then shorten the shut-in time of the nearest well to be opened by T. 2j / 10 minutes; Optimized plunger arrival time T for each well m Optimize well opening time T o Optimize well shut-in time T c Coordinating the actual well opening time and actual well shut-in time for each well with the number of wells M includes the following steps: Obtain the influencing factors and use them to coordinate the actual well opening time and actual well shut-in time for each well.

2. A terminal, characterized in that, It includes at least one processor and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform a shale gas platform multi-well plunger production system coordination method as described in claim 1.

3. A storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the method for coordinating the multi-well plunger production system of a shale gas platform as described in claim 1.

Images