CN117669199A - A time-sharing optimization design method for pumping unit wells - Google Patents

Abstract

The invention provides a time-sharing optimization design method of an oil pumping well, which comprises the following steps: predicting the production under different liquid levels according to the IPR equation of the oil well; different oil pumping well production parameter combinations are designed according to different production volumes and liquid levels, and grouping is carried out according to the same rod diameter, rod length, pipe diameter, pipe length, pump diameter, pump depth and stroke from the different production volumes and the different stroke times; for each group, different production time is applied for each electricity price period, a production time combination capable of completing target output is screened out, and daily electricity consumption cost is calculated; and selecting the production time and the production parameter combination with the lowest daily power consumption cost from all the production time and the production parameter combinations capable of completing the target yield as a time-sharing optimal design result. The invention reduces the electric cost of the oil pumping well more obviously, can help the oil field enterprises to eliminate the peak, further reduce the cost and increase the efficiency, and makes a contribution to guaranteeing the life of people and ensuring the stable operation of the electric power system.

Description

Time-sharing optimization design method for oil pumping well

Technical Field

The invention belongs to the field of artificial lifting in petroleum exploitation, relates to a time-sharing optimization design method of an oil pumping well, in particular to a time-sharing optimization design method of an oil pumping well, which divides the electricity consumption of the oil pumping well into time intervals according to a peak Gu Ping and adopts time-sharing electricity price settlement, and is suitable for optimizing and determining the mechanical production parameters for reducing the electricity consumption cost of the oil pumping well in time intervals.

Background

The mechanical recovery system is one of the main production energy consumption systems of Jiangsu oilfield, the mechanical recovery energy consumption accounts for 38% of the total energy consumption of Jiangsu oilfield, and the energy consumption cost is high. In two seasons of 2022 in summer and winter, the average price of industrial electricity is gradually increased due to the shortage of electricity and the influence of high-low temperature weather, and the energy consumption cost of an oilfield mechanical system is increased, so that the cost and the efficiency are further reduced. The oil field electricity consumption adopts large industrial electricity at present, adopts time-sharing electricity price settlement, and the price of peak period is more than 4 times of low valley period, and under the prerequisite of guaranteeing that pumping well output does not fall, how to reduce peak period, the energy consumption and the production time of ordinary section to reduce the oil pumping well production electric power cost as far as possible, become the oil field and reduce this synergy important demand. If the requirements can be met, the electric power company can be helped to cut Gu Pingfeng, the safe power transmission of the power grid can be realized, and the national security folk life and the security policy of the power are met.

Aiming at the extraction efficiency and cost reduction of the pumping well, the technology of mechanical parameter optimization, intermittent pumping exploitation, flexible control exploitation and the like is generally adopted. The existing optimization design technology is that an optimization model mainly comprises an analytic equation model, a wave equation model dynamically simulated according to an indicator diagram, a machine learning recommendation system and the like, an objective function mainly comprises machine learning recommendation and multi-objective optimization according to the minimum energy consumption, the maximum yield, the coordination of supply and discharge, the multi-factor machine learning recommendation and the multi-objective optimization, and the design methods mainly optimize continuous production of the oil pumping well at present, do not consider the influence of electricity price and production time change on energy consumption and cost, and cannot optimize according to time-of-use electricity price and time-of-use, real-time optimization and intermittent pumping optimization. The optimization of middle and low-yield wells, especially low-yield wells, mainly comprises a flexible oil extraction technology and a intermittent oil extraction technology. After the two technologies are implemented by the pump inspection design scheme of the pumping unit well, the automatic control technology for ensuring the coordination of supply and discharge and keeping the long-term high-efficiency operation of the pumping unit well mainly depends on the self-regulation of equipment, and is mainly applicable to low-yield wells, the problems of multi-scheme optimization and design energy conservation of the low-yield wells, the middle-yield wells and the high-yield wells are not solved, the influence of time-sharing electricity prices on the energy consumption cost is not considered in most, and better economic benefits can be obtained by combining the time-sharing electricity price adjustment.

In view of the foregoing, there is a need for a time-sharing optimization method for an oil pumping well, which meets the national price-computing policy of dividing peak and valley of electric power, reduces energy consumption and production time in peak time and normal time on the premise of ensuring that the output of the oil pumping well is not reduced, properly increases power consumption in valley time and production time of intermittent pumping well, operates at the lowest daily electric power cost, further reduces the electric power cost of the oil pumping well, helps electric power enterprises to realize peak shaving and peaked, and ensures folk life.

Disclosure of Invention

Aiming at the problems that the existing oil pumping well optimization design method cannot optimize according to time-of-use electricity price and time, optimize in real time, optimize intermittent pumping and fail to realize the lowest electric cost, the application provides the oil pumping well time-of-use optimization design method.

The application provides a time-sharing optimization design method of an oil pumping well, which comprises the following steps:

s101, predicting the production under different liquid levels according to an oil well IPR equation;

s103, designing different oil pumping well production parameter combinations according to different yields and liquid levels, and grouping according to the same rod diameter, rod length, pipe diameter, pipe length, pump diameter, pump depth and stroke from the different oil pumping well production parameter combinations, wherein the stroke times and the yields are different;

s105, for each group, applying different production time for each electricity price period, screening out a production time combination capable of completing target output, and calculating daily electricity consumption cost of the production time combination;

s107, selecting the production time and production parameter combination with the lowest daily power consumption cost as a time-sharing optimal design result from all production time and production parameter combinations capable of completing the target yield.

Wherein, S101, before predicting the production under different liquid levels according to the well IPR equation, comprises:

s1, giving oil well basic data, wherein the oil well basic data comprises: well depth H, well deviation parameters and average pressure of oil reservoirReservoir saturation pressure Pb, gas-oil ratio GOR and gas average dissolution parameter alpha; given the production objective of the pumping well during normal production: liquid yield Q ₀ Working fluid level h ₀ Oil pressure P _t Jacket pressure P _c Depth L of original pump _p0 ；

S2, selecting the type of the pumping unit, and keeping the type of the pumping unit unchanged for the old well to obtain the stroke range and rated load P of the pumping unit _max0 Rated torque M _max0 ；

S3, setting a selectable range of a rod, a pipe diameter, a pump diameter, a stroke frequency and a pump depth of the oil pumping well; if the well is required to be stopped in the peak-valley normal stage, the intermittent pumping mode adopts a non-stop intermittent pumping mode or a stop intermittent pumping mode, and the average input power outside the production time length is obtained to be P _input0 。

Wherein, S101, predicting the production under different liquid levels according to the well IPR equation, includes:

s4, selecting a yield prediction method from a Vogel equation or a Petrobras equation, substituting the yield prediction method into the oil well basic data required in the step S1, and obtaining q _max The IPR equation for the present well is obtained.

In step S1, if the well is a new well, a reasonable production target is predicted: liquid yield Q ₀ Working fluid level h ₀ Oil (oil)Pressure P _t Jacket pressure P _c The method comprises the steps of carrying out a first treatment on the surface of the Assume oil pressure P during well production _t Jacket pressure P _c Remain unchanged.

In step S3, if no-stop intermittent pumping is adopted to obtain P _input0 Taking P _input0 ＝P _d If the intermittent pumping is adopted, P _input0 ＝0。

Wherein, S103, design different oil pumping well production parameter combinations according to different output, liquid level, group according to same pole footpath, pole length, pipe diameter, pipe length, pump footpath, pump depth, stroke from there, and the stroke time, output difference, include:

step 5: will q _max Divided into n _q Parts, q _i ＝i*q _max /n _q ，i∈[0,n _q ]，n _q I is a positive integer, and p is calculated according to the IPR equation of the well _wfi ；

Step 6: maximum pump down depth H given in step 2 _max Given a pump depth step H _s The number of possible pump depths is n _pupmdepth ＝(H _max -H ₀ )/H _s Each q _i Can correspond to different pump depths Lp _ij ，Lp _ij ＝H ₀ +j*H _s ，j>=1, j is an integer up to Lp _ij <=hmax, will each p _wfi Substituted into the following formula:

p _wf ＝p _t +ρ _o (L _p -h)+ρ _l (H-L _p )

obtaining h _ij To form different q _i 、h _ij ,Lp _ij The combination number is n _q *n _pumpdepth A plurality of;

step 7: for each q _i 、h _ij ,Lp _ij Within the range set in step 3, n is set to _tubing Diameter n of seed tube _rodtype Steel grade of seed pole, n _pump Seed pump diameter, n _rod Seed pole combination, n _s Seed stroke, n _n The seed stroke times are combined one by one to calculate the yield q _ic Given an error e, if |q _i -q _ic |<e is true, the combination is that the yield can be maintainedQuantity q _i Invariable viable production parameter combinations; if not, the combination is discarded; calculating the corresponding maximum load, minimum load and maximum torque of each feasible production parameter combination, and calculating the maximum load and maximum torque required to meet the rated load and rated torque limit of the pumping unit, namely P _max <P _max0 、M _max <M _max0 Calculating the maximum load and the minimum load of each level of rod tube, verifying the stress intensity and the stress range, and if the maximum load and the minimum load of each level of rod tube are not met, discarding the combination; the number of possible combinations is at most n _q *n _pumpdepth *n _tubing *n _rodtype *n _pump *n _rod *n _s *n _n A plurality of;

step 8: calculating P corresponding to each production parameter combination selected in the step 7 _inputij ；

Step 9: combining the production parameters selected in the steps 7 and 8 according to the pipe diameter, the steel grade of the pole, the pump diameter, the pump depth, the pole combination and the same stroke, thereby obtaining the liquid yield q _i Stroke frequency, input power P _inputij Unlike, regrouping.

Wherein S105, for each group, applying different production times for each electricity price period, screening out a production time combination capable of completing a target yield, and calculating a daily electricity consumption cost thereof, includes:

step 10: combining the peak valley time duration according to the electricity price, combining the peak valley time duration into N sections according to the difference of the electricity price, and sequencing the peak valley time duration from high to low according to the electricity price, wherein the k-th section total time duration is L _k The electricity price of the kth section is X _k The production time length of the kth section is T _k ,T _k <＝L _k Average daily yield of Q in production period _k ；

Step 11: each q in each set of combinations of step 9 above _i May all be equal to Q _k The liquid yield in the kth period is q _i Corresponding liquid yield and Q for input power _ki ,P _inputijk Representation, Q _ki ＝q _i ,P _inputijk ＝P _inputij ；

Step 12: discretizing to determine T _k Value, sum of each segmentDuration L _k Dividing according to a certain step length Ts to make T _kB =b×ts, B is an integer, B _kmax ＝L _k Ts, 0 =per layer<B<B _kmax Each T _kB May be equal to T in step 9 _k ，T _kB The electricity consumption, electricity consumption cost and liquid production amount of each production combination of the time period are T _kB P _inputijk +(L _k -T _kB )P _input0 、(T _kB P _inputijk +(L _k -T _kB )P _input0 )X _k 、T _kB Q _ki 24; the maximum combined number of the production time length, the liquid production amount, the stroke frequency and the input power of each section is n _kqnTgroup ＝B _kmax *n _q *n _n And each.

Wherein, ts can be 0.1, 0.2, 0.5 or 1 hour.

Wherein, step S105, for each group, applies different production time for each electricity price period, screens out a production time combination capable of completing the target output, and further includes:

step 13: for at most n in step 9 _ggb Selecting one group of combinations from the groups, and executing the following steps;

step 14: in N time periods, at most N from the 1 st time period _1qnTgroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations;

step 15: from paragraph 2 up to n _2qnTgroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations;

step 16: from the nth segment up to N _Nqngroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations; calculating the production time of each layer to obtain daily yieldIf Q<Q ₀ Sequentially taking down one production time length, liquid production amount, stroke frequency and input power combination, and circularly executing step 16; if Q>＝Q ₀ And Q-Q ₀ <e, e is given error, calculate the daily power consumption cost +.>Storing the combination as a production combination capable of completing the original target liquid production amount, wherein the combination set is marked as G;

if the step 16 is completed, executing the step 15 in a circulating way;

if the step 15 is completed, executing the step 14 in a circulating way;

if the step 14 is completed, selecting the next combination in the step 13, and executing the steps 14, 15 and 16 again in a circulating way;

thereby finding all the liquid production amounts Q capable of completing the original target ₀ Is described in (a) to produce a combined set G.

S107, selecting the production time and production parameter combination with the lowest daily power consumption cost as a time-sharing optimal design result from all production time and production parameter combinations capable of completing the target yield, wherein the time-sharing optimal design result comprises the following steps:

step 17: from the original target liquid yield Q ₀ In the production combination set G, a group of combinations with the lowest daily electricity consumption Cost is found, and the production duration, liquid production amount, stroke frequency, input power and pipe diameter of each section corresponding to the combination, the steel grade of a pole column, the pump diameter, the pump depth and the pole column combination and stroke are used as a time-sharing optimization scheme.

The time-sharing optimization design method of the oil pumping well has the following beneficial effects:

compared with the traditional continuous production or intermittent production design method, the method provided by the invention has the advantages that aiming at different electricity prices in different time periods, the same underground pipe rod pump, the same stroke, different production time, different stroke times and different yields are adopted, the electric cost of the oil pumping well is reduced more remarkably, meanwhile, the method can help an oil field enterprise to eliminate valley and flat peaks, further reduce the cost and increase the efficiency, and the method contributes to ensuring the civil life and ensuring the stable operation of an electric power system.

Drawings

Fig. 1 is a schematic flow chart of a time-sharing optimization design method of an oil pumping well.

Detailed Description

The present application is further described below with reference to the drawings and examples.

The following description provides various embodiments of the invention that may be substituted or combined between different embodiments, and thus this application is also intended to encompass all possible combinations of the same and/or different embodiments described. Thus, if one embodiment includes feature A, B, C and another embodiment includes feature B, D, then the present application should also be considered to include embodiments that include one or more of all other possible combinations of features A, B, C, D, although such an embodiment may not be explicitly recited in the following.

Example 1

As shown in fig. 1, the time-sharing optimization design method of the oil pumping well of the application comprises the following steps: s101, predicting the production under different liquid levels according to an oil well IPR equation; s103, designing different oil pumping well production parameter combinations according to different yields and liquid levels, and grouping according to the same rod diameter, rod length, pipe diameter, pipe length, pump diameter, pump depth and stroke from the different oil pumping well production parameter combinations, wherein the stroke times and the yields are different; s105, for each group, applying different production time for each electricity price period, screening out a production time combination capable of completing target output, and calculating daily electricity consumption cost of the production time combination; s107, selecting the production time and production parameter combination with the lowest daily power consumption cost as a time-sharing optimal design result from all production time and production parameter combinations capable of completing the target yield.

The time-sharing optimization design method of the oil pumping well is based on large industrial electricity time-sharing electricity price and time period, a time-sharing optimization power-down and cost-down mathematical model of the oil pumping well is established, time-sharing production time, yield, working fluid level, energy consumption and cost coupling relation which ensure that daily yield is unchanged is established. Compared with the traditional continuous production or intermittent production design method, the method has the advantage that the electric cost of the oil pumping well is reduced remarkably.

Example two

The main calculation formula related by the invention is as follows:

1. daily power consumption, daily power consumption cost, daily liquid production amount calculation formula and objective function under time-sharing electricity price

The liquid yield of the pumping well during normal production is Q ₀ (Unit m) ³ D), the dynamic liquid level is h ₀ (unit m), oil pressure P _t (unit MPa), jacket pressure P _c The depth of the middle part of the oil layer is H (unit m) and the pump depth is L _p (unit m, if a new well is provided, the value is not needed), the peak-valley time-of-use electricity price is divided into N sections, and the k section duration is L _k (unit h), the k-th stage electricity price is X _k (Unit cell/kwh), the production time of the kth stage is T _k (unit h), production duration T _k The internal average daily yield is Q _k (Unit m) ³ /d) average input power P _inputk (kwh unit) average input power P outside production period _input0 (Unit kwh, if no-stop intermittent pumping is adopted, no-stop swing period P _input0 >0, e.g. P is not tested _input0 The no-load power P of the motor can be taken _d (units kwh); if the shutdown intermittent pumping is adopted, P _input0 =0), the daily electricity consumption (expressed as W, in kwh), the daily electricity consumption Cost (expressed as Cost, in yuan), the daily liquid production amount Q (in t/d) are calculated as

The invention provides an optimization method for completing the target yield Q ₀ For each T of different electricity price time periods _k 、Q _k Combinations, using the same tube, rod, pump, ramDifferent times of stroke, the daily electricity consumption cost is minimized. The objective function of the model solution is:

2. calculation formula of liquid yield Q

Q may be calculated from the IPR curve (Inflow Performance Relationship Curve). Typical IPR curves are Vogel equation, petrobras equation, etc. IPR curve depicts bottom hole liquid yield q and bottom hole flow pressure p _wf Is a relationship of (3). In the case of a related shut-in, the wellhead production Q is not synchronized with the bottom hole production Q due to the existence of the wellbore reservoir effect, and the influence of the wellbore reservoir effect is ignored for each period of time, herein, the average wellhead production Q is equal to the bottom hole average production Q.

Setting q _b For liquid yield at saturation pressure, q _omax Maximum oil production, q, at zero flow pressure _max The maximum liquid yield when the flow pressure is zero, q is the liquid yield, and the yield units are m ³ /d；J _L For the index of liquid production, m ³ /(d·MPa)；f _w Water content,%;is the average pressure of the stratum and MPa;

A. vogel equation prediction yield method:

(1) When reservoir pressure is below saturation pressure, there are:

(2) When the reservoir pressure is higher than the saturation pressure p _b While the bottom hole pressure is lower than p _b When the method is used, the following steps are included:

when p is _wf ≥p _b In the time-course of which the first and second contact surfaces,

when p is _wf ＝p _b In the time-course of which the first and second contact surfaces,

when p is _wf <p _b In the time-course of which the first and second contact surfaces,

B. the method for predicting the yield by using the oil-gas-water three-phase seepage oil well inflow dynamic Petrobras equation comprises the following steps:

q _omax ＝q _b +J _L p _b /1.8 (7.2)

in the test, if p _wftest ≥p _b Time of day

If p is _wftest <p _b Time of day

Wherein,

3. flow pressure calculation formula

Neglecting the column pressure, the relationship between the flow pressure and the working fluid level can be expressed as:

p _wf ＝p _t +ρ _o (L _p -h)+ρ _l (H-L _p ) (8)

for new wells without pump down, p _wf ＝p _t +ρ _l (H-h) (8.1)

ρ _l ＝ρ _o (1-f _w /100)+ρ _w f _w (9)

4、P _input Is calculated by the formula of (2)

In a certain production time, the input power P of the pumping well is under the condition that the liquid yield Q and the depth of the working fluid level h are not greatly changed _input Is a function of liquid yield, liquid level depth and production parameters, and can be divided into ground loss power P _u Viscous power loss P _r Power of slip loss P _k Expansion power P of dissolved gas _e Effective power P _ef Five parts (formula P in the middle) _u 、P _r 、P _k 、P _e 、P _ef kW), the calculation formulas are respectively:

P _input ＝P _u +P _r +P _k -P _e +P _ef (10)

P _u ＝P _d +k ₁ [(2F _g +F _l )sn-P _e -0.13P _r ]+k ₂ (P _ef +P _k +P _r -P _e ) (11)

P _k ＝2f _k ·q _rod ·g·L·s·n (13)

the liquid yield Q of the pumping well is determined by pumping parameters, pumping efficiency and gap leakage Q of the pump _l Together, the calculation formula is:

Q _l ＝7200πDδ ³ ρgh/(L _pl μ) (20)

5. maximum load maximum torque calculation formula

P _max ＝F _l +F _g (1+sn ² /1790) (21)

P _min ＝F _g (1-sn ² /1790) (22)

M _max ＝1800S+0.202S(P _max -P _min ) (23)

In the above formulae, P _d Representing the idle power of the motor, kW; f (F) _g The pumping rod is subjected to the gravity, kN; f (F) _l kN is the liquid column load borne by the pump plunger; s is stroke, m; n is the stroke frequency, 1/min; k (k) ₁ 、k ₂ The transmission coefficients of the transmission power and the polish rod power are respectively; mu (mu) _i In order to divide the oil pipe on the pump into N sections and i sections, the viscosity of the liquid in the oil pipe is mPa.s; l (L) _i For the length of the ith section of oil pipe, mThe method comprises the steps of carrying out a first treatment on the surface of the m is the diameter ratio of pipe diameter rods, and the dimension is zero; l is the length of a horizontal track of well deviation, m; q _r Is the weight of the rod, kN/m; f (f) _k The friction coefficient of the rod and the pipe is dimensionless; ρ, ρ _o The density of the mixed liquid and the density of the crude oil are respectively kg/m ³ ；P _b Is the saturated pressure of crude oil, mpa; alpha is the dissolution coefficient, m ³ /(m ³ .Mpa)；P _s Is sinking pressure, mpa; p (P) _w Oil pressure, mpa; g is gravity acceleration, m/s ² The method comprises the steps of carrying out a first treatment on the surface of the h is the effective lift, m; η is system efficiency,%. D is the pump diameter, m; η (eta) _p To ignore the pumping effect of the inertial force of the sucker rod,%; lambda is stroke loss, m,; beta is a gas influence coefficient, dimensionless; l (L) _rod1 、l _rod2 The length of the first level rod and the second level rod is m; f (f) ₁ 、f ₂ Is the sectional area of the first and second level rods, m ² ；f _t Is the section area of the metal part of the oil pipe, m ² ；L _p The depth of the pump is m; lambda is not taken into account L when anchoring the lower part of the oil pipe _p /f _t The method comprises the steps of carrying out a first treatment on the surface of the E is the elastic modulus of steel, 2.1X10 ¹¹ N/m ² ；L _p The depth of the pump is m; r is gas-oil ratio, m ³ /m ³ The method comprises the steps of carrying out a first treatment on the surface of the Alpha is the dissolution coefficient, m ³ /(m ³ .Mpa)；P _s Is sinking pressure, mpa; g is gravity acceleration, m/s ² ；Q _l For oil-well pump leakage, m ³ /d; delta is the annular clearance between the pump plunger and the pump cylinder, m; l (L) _pl The length of a pump plunger is m, mu is the viscosity of liquid in the oil pump, and mPa.s; p (P) _max 、P _min Respectively the maximum load and the minimum load, and kN; m is M _max For maximum torque kn.m.

For a given pumping well, because the production parameters of the pumping well such as pump diameter, oil pipe diameter, sucker rod diameter, stroke length, electricity price, peak-valley time period and the like are discrete parameters, all parameters can be arranged and combined for designing different production time and production parameter combinations of different electricity price corresponding to the least daily electricity consumption cost. The method comprises the following steps:

step 1: given well depth H, well deviation parameters (depth measurement, vertical depth and horizontal displacement of each measuring point), reservoir average pressureOil well basic data such as reservoir saturation pressure Pb, gas-oil ratio GOR, gas average dissolution parameter alpha and the like are given to the production target during normal production of the pumping well: liquid yield Q ₀ Working fluid level h ₀ Oil pressure P _t Jacket pressure P _c Original pump depth L _p0 If a new well is, a reasonable production target is predicted: liquid yield Q ₀ Working fluid level h ₀ Oil pressure P _t Jacket pressure P _c The method comprises the steps of carrying out a first treatment on the surface of the Assume oil pressure P during well production _t Jacket pressure P _c Remain unchanged.

Step 2: selecting the type of the pumping unit, and keeping the type of the pumping unit unchanged for the old well to obtain the stroke range and rated load P of the pumping unit _max0 Rated torque M _max0 ；

Step 3: setting a selectable range of a rod (rod steel grade, rod diameter), a pipe diameter, a pump diameter, a stroke frequency and a pump depth of the oil pumping well; if the well is required to be stopped in the peak-valley normal stage, the intermittent pumping mode adopts a non-stop intermittent pumping mode or a stop intermittent pumping mode, and the average input power outside the production time length is obtained to be P _input0 (if non-stop intermittent pumping is adopted, P is obtained through non-test _input0 Can take P _input0 ＝P _d If the intermittent pumping is adopted, P _input0 ＝0)；

Step 4: selecting a yield prediction method from Vogel equation (formula 6.1-6.4) or petrobros equation (formula 7.1-7.4), substituting the basic data required in step 1, and obtaining q _max Obtaining an IPR equation of the well;

step 5: will q _max Divided into n _q Parts, q _i ＝i*q _max /n _q (i∈[0,n _q ]，n _q I are positive integers), and according to the IPR equation of the well, p is calculated _wfi ；

Step 6: maximum pump down depth H given in step 2 _max (H _max <=h), given a pump depth step H _s (typically taking an integer multiple of 10 and H _s <=100), the number of possible pump depths is n _pupmdepth ＝(H _max -H ₀ )/H _s Each q _i Can correspond to different pump depths Lp _ij ，Lp _ij ＝H ₀ +j*H _s (j>=1, integer up to Lp _ij <=hmax), will each p _wfi Substituting formula 8 (formula 8.1 for new well), and obtaining h from the formula _ij To form different q _i 、h _ij ,Lp _ij The combination number is n _q *n _pumpdepth And each.

Step 7: for each q _i 、h _ij ,Lp _ij Within the range set in step 3, various pipe diameters (provided with n _tubing Seed), various pole steel grades (provided with n _rodtype Seed), various pump diameters (provided with n _pump Seed), various pole combinations (provided with n _rod Seed), various strokes (provided with n _s Seed), various times of punching (provided with n _n Seed) one by one, each production parameter combination is applied to 16-20, and the yield q is calculated _ic Given an error e, if |q _i -q _ic |<e is true, the combination is such that the yield q can be maintained _i Invariable viable production parameter combinations; if not, the combination is discarded. For each feasible production parameter combination, calculating the corresponding maximum load, minimum load and maximum torque according to the formulas 21, 22 and 23, and calculating the maximum load and maximum torque required to meet the rated load and rated torque limit of the pumping unit, namely P _max <P _max0 、M _max <M _max0 The maximum and minimum loads are calculated for each stage of the rod tube and the stress intensity and range are verified, the rod tube intensity limit is required to be met, and if not, the combination is omitted. The number of possible combinations is at most n _q *n _pumpdepth *n _tubing *n _rodtype *n _pump *n _rod *n _s *n _n And each.

Step 8: substituting the combination parameter values obtained in the step 7 according to formulas 10-20, and calculating to obtain P corresponding to each production parameter combination selected in the step 7 _inputij ；

Step 9: combining the production parameters selected in the steps 7 and 8 according to the pipe diameter, the steel grade of the pole, the pump diameter, the pump depth, the pole combination and the same stroke, thereby obtaining the liquid yield q _i Stroke frequency, input power P _inputij In contrast, regrouping (up to n in total _ggb ＝n _pumpdepth *n _tubing *n _rodtype *n _pump *n _rod *n _s Groups) each group being defined by q _i The number of times of the stroke, the magnitude of the input power are sequentially ordered (each group has n at most _q *n _n And (c) a).

Step 10: combining the peak valley time duration according to the electricity price, combining the peak valley time duration into N sections according to the difference of the electricity price, and sequencing the peak valley time duration from high to low according to the electricity price, wherein the k-th section total time duration is L _k The electricity price of the kth section is X _k The production time length of the kth section is T _k ,T _k <＝L _k Average daily yield of Q in production period _k ；

Step 11: each q in each set of combinations of step 9 above _i May all be equal to Q _k The liquid yield in the kth period is q _i Corresponding liquid yield and Q for input power _ki ,P _inputijk Representation, Q _ki ＝q _i ,P _inputijk ＝P _inputij ；

Step 12: discretizing to determine T _k Value of the total length of time L of each segment _k Dividing according to a certain step length Ts (usually 0.1, 0.2, 0.5 and 1 hour are taken), and letting T _kB =b×ts (B is an integer, B _kmax ＝L _k Ts, 0 =per layer<B<B _kmax ) Each T _kB May be equal to T in step 9 _k ，T _kB The electricity consumption, electricity consumption cost and liquid production amount of each production combination of the time period are T _kB P _inputijk +(L _k -T _kB )P _input0 、(T _kB P _inputijk +(L _k -T _kB )P _input0 )X _k 、T _kB Q _ki 24; the maximum combined number of the production time length, the liquid production amount, the stroke frequency and the input power of each section is n _kqnTgroup ＝B _kmax *n _q *n _n And each.

Step 13: for at most n in step 9 _ggb Selecting one group of combinations from the groups, and executing the following steps;

step 14: in N time periods, the maximum is from the 1 st time periodn _1qnTgroup Sequentially taking one (production time, liquid production amount, impulse frequency and input power) combination from the production time, liquid production amount, impulse frequency and input power combination;

step 15: from paragraph 2 up to n _2qnTgroup Sequentially taking one (production time, liquid production amount, impulse frequency and input power) combination from the production time, liquid production amount, impulse frequency and input power combination;

step 16: from the nth segment up to N _Nqngroup Sequentially taking one (production time, liquid production amount, impulse frequency and input power) combination from the production time, liquid production amount, impulse frequency and input power combination; calculating the production time of each layer to obtain daily yieldIf Q<Q ₀ Sequentially taking down one production time length, liquid production amount, stroke frequency and input power combination, and circularly executing step 16; if Q>＝Q ₀ And Q-Q ₀ <e (given error e), calculate the cost of power consumption per dayThe combination is stored as a production combination capable of completing the original target liquid production amount, and the combination set is denoted as G.

If the step 16 is completed, executing the step 15 in a circulating way;

if the step 15 is completed, executing the step 14 in a circulating way;

if the step 14 is completed, selecting the next combination in the step 13, and executing the steps 14, 15 and 16 again in a circulating way;

thereby finding all the liquid production amounts Q capable of completing the original target ₀ Is described in (a) to produce a combined set G.

Step 17: from the original target liquid yield Q ₀ In the production combination set G, a group of combinations with the lowest daily electricity consumption Cost is found, and the production duration, liquid production amount, stroke frequency, input power and pipe diameter of each section corresponding to the combination, the steel grade of a pole column, the pump diameter, the pump depth and the pole column combination and stroke are used as a time-sharing optimization scheme.

Step 18: and (2) as the peak-valley period duration is combined according to the electricity price in the step (10), when the time-sharing optimization scheme is specifically executed, the designed production duration of each period is uniformly distributed to each execution period of the specific same time-sharing electricity price. For example, the peak electricity price time period is 9-12 hours and 18-23 hours, and if the time-sharing optimization scheme optimizes the peak time period production time period to be 4 hours, the production time periods at 9-12 hours and 18-23 hours are 3/8*4 and 5/8*4 hours respectively.

Step 19: the time division optimization scheme has the requirement of stopping pumping, so that the influence of stopping pumping on the output, pipeline heat preservation and the like is reduced as much as possible, if equipment permits, the designed production time of each section can be subdivided into a plurality of small sections according to a certain time length such as 30 minutes and 1 hour, and then the small sections are uniformly distributed into specific time-sharing electricity price execution time sections. If the peak level period is 9-12 hours and 18-23 hours, and the production duration of the time-sharing optimization scheme is 4 hours, and the time-sharing optimization scheme is carried out according to 30 minutes, the production can be carried out according to 4 x 60/30=8 time periods, the production duration of each of 9-12 hours and 18-23 hours is 3/8*4, 5/8*4 hours, the production of each of 9-12 hours and 18-23 hours is 3/8 x 4 x 60/30=3, 5/8 x 4 x 60/30=5 time periods, and the production of each of the time-sharing optimization scheme is carried out according to 3/8 x 4 x 60/30=3, 5/8 x 4 x 60/30=30 minutes after 30 minutes.

Compared with the traditional continuous production or intermittent production design method, the method provided by the invention has the advantages that aiming at different electricity prices in different time periods, the same underground pipe rod pump, the same stroke, different production time, different stroke times and different yields are adopted, the electric cost of the oil pumping well is reduced more remarkably, meanwhile, the method can help an oil field enterprise to eliminate valley and flat peaks, further reduce the cost and increase the efficiency, and the method contributes to ensuring the civil life and ensuring the stable operation of an electric power system.

Example III

The following is a 2022 month 8 electricity price list published by Jiangsu province electric company. And the comparison of the cost reduction effects of the continuous production and the time-sharing optimization production schemes is shown according to the time-sharing period and the electricity price example.

Table 1 Power price Meter of electric company of Jiangsu province of national network (2022, 8 months)

Taking a certain actual normal production well of Jiangsu oilfield as an example, the well is produced for 24 hours, and daily liquid yield is 15m ³ And/d, working fluid level 950m, pump depth of 38mm and pump 1400m, working system of 3m 4 times/min and input power of 6kW.

The well is optimized by 'peak Gu Ping' time sharing, and a shutdown intermittent pumping optimization scheme is as follows: 50mm pump 1450m depth, IPR capacity prediction according to Petrobras equation, average daily liquid yield 20m ³ And/d, the average working fluid level is 1220m during production, the peak period is 3 hours, the normal period is 6 hours, the working system is 3m, 3.4 times/min, and the input power is still 6kW; during the off-peak period, the production time is 8 hours, and the daily liquid yield is 22.5m according to the IPR productivity prediction ³ And/d, an average working fluid level 1350m, a working system 3m 3.8 times/min, an input power increased to 8kW, and a total daily output of time-sharing optimization: 20 x 3/24+20 x 6/24+22.5 x 8/24=15 t/d, consistent with 24 hours continuous production. The electric power costs of the two production states are respectively:

24 hours production power cost=8h×6kw× 1.1478 yuan/kw+8h×6kw× 0.6675 yuan/kw+8h×6kw× 0.2793 yuan/kw= 100.5408 yuan, energy consumption=24h×6kw=144 kWh;

time-sharing optimization power cost=3 h×6kw× 1.1478 yuan/kw+6h×6kw× 0.6675 yuan/kw+8h×8kw× 0.2793 yuan/kw= 62.5656 yuan, energy consumption=3 h×6kw+6h×6kw+8h×8 kw=118 kWh;

the power cost can be reduced by time sharing (100.5408-62.5656)/100.5408 ×100% = 37.77%, the power saving rate is (144-118)/144×100% = 18.8%, the annual power cost is saved by (100.5408-62.5656) ×365= 13860.95 yuan, and annual power saving= (144-118) ×365=9490 kWh.

When the time-sharing optimization is implemented, the peak period is produced for 3 hours and is evenly divided into two peak periods (8:00-11:00, 17:00-22:00), the peak period is produced for 3*3/8 hours from 8:00-11:00, and the peak period is produced for 3*5/8 hours from 17:00-22:00; in order to minimize the influence of the withdrawal on the output, pipeline heat preservation and the like, if equipment permits, 8:00-11:00 and 17:00-22:00 can be subdivided per hour, and the production is evenly divided into 3/8 hours and 5/8 hours per 1 hour; as above, the production time of the normal period is divided into two normal periods (11:00-17:00, 22:00-24:00) evenly, the production time of the normal period can be divided into two periods (11:00-17:00, 22:00-24:00) according to each hour, and the production time of the normal period is divided into 6/8 hours and 2/8 hours.

In this example, the peak period can be reduced from 8 hours of original production to 3 hours, the peak period can be reduced by (8-3) by 6=30 kilowatt hours of power consumption, and the valley period can be increased by 8 (8-6) =24 kilowatt hours of power consumption, so that the peak shaving and leveling can be realized for the power grid enterprises.

Compared with other continuous production mode optimization methods: assuming that the example well can achieve 30% power savings using other continuous production optimization methods, 24 hours production power cost= (8hx6kW x 1.1478/kW+8hx6kW x 0.6675/kW+8hx6kW x 0.2793/kW) = (1-30%) = 70.38, energy saving = 24h x 6kW x 30% = 43.2kWh.

The calculation example shows that the time-sharing optimization technology can realize time-sharing pumping production on the middle-low-yield well, and peak-shifting production on the middle-high-yield well, so that the production power cost of the pumping well can be further reduced, and good cost-reducing benefit and good energy-saving benefit are obtained.

The invention provides a peak-shifting production method which adopts the same pipe, rod, pump and stroke and can furthest reduce the electric cost of the pumping unit well by establishing a time-sharing production time, yield, working fluid level, energy consumption and cost coupling relation which ensures that daily yield is unchanged, and different production time, yield and stroke times can eliminate valley and flat peaks, further reduce cost and increase efficiency, and contributes to ensuring folk life and ensuring the stable operation of an electric power system.

The above description is only of the preferred embodiments of the present invention and is not intended to limit the present invention, but various modifications and variations can be made to the present invention by those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims (10)

1. The time-sharing optimization design method of the oil pumping well is characterized by comprising the following steps of:

s101, predicting the production under different liquid levels according to an oil well IPR equation;

s103, designing different oil pumping well production parameter combinations according to different yields and liquid levels, and grouping according to the same rod diameter, rod length, pipe diameter, pipe length, pump diameter, pump depth and stroke from the different oil pumping well production parameter combinations, wherein the stroke times and the yields are different;

s105, for each group, applying different production time for each electricity price period, screening out a production time combination capable of completing target output, and calculating daily electricity consumption cost of the production time combination;

s107, selecting the production time and production parameter combination with the lowest daily power consumption cost as a time-sharing optimal design result from all production time and production parameter combinations capable of completing the target yield.

2. The method for time-sharing optimization design of an oil pumping well according to claim 1, wherein S101 comprises the steps of:

s1, giving oil well basic data, wherein the oil well basic data comprises: well depth H, well deviation parameters and average pressure of oil reservoirReservoir saturation pressure Pb, gas-oil ratio GOR and gas average dissolution parameter alpha; given the production objective of the pumping well during normal production: liquid yield Q ₀ Working fluid level h ₀ Oil pressure P _t Jacket pressure P _c Depth L of original pump _p0 ；

S2, selecting the type of the pumping unit, and keeping the type of the pumping unit unchanged for the old well to obtain the stroke range and rated load P of the pumping unit _max0 Rated torque M _max0 ；

S3, setting a selectable range of a rod, a pipe diameter, a pump diameter, a stroke frequency and a pump depth of the oil pumping well; if the well is required to be stopped in the peak-valley normal stage, the intermittent pumping mode adopts a non-stop intermittent pumping mode or a stop intermittent pumping mode, and the average input power outside the production time length is obtained to be P _input0 。

3. The time-sharing optimization design method of the rod-pumped well according to claim 2, wherein S101 predicts the production of different liquid levels according to the IPR equation of the oil well, comprising:

s4, selecting a yield prediction method from a Vogel equation or a Petrobras equation, substituting the yield prediction method into the oil well basic data required in the step S1, and obtaining q _max The IPR equation for the present well is obtained.

4. A time-division optimization design method for a rod-pumped well according to claim 2 or 3, wherein in step S1, if a new well is predicted, a reasonable production target is: liquid yield Q ₀ Working fluid level h ₀ Oil pressure P _t Jacket pressure P _c The method comprises the steps of carrying out a first treatment on the surface of the Assume oil pressure P during well production _t Jacket pressure P _c Remain unchanged.

5. A time-sharing optimization design method for a rod-pumped well according to claim 2 or 3, wherein in step S3, if no-stop intermittent pumping test is adopted to obtain P _input0 Taking P _input0 ＝P _d If the intermittent pumping is adopted, P _input0 ＝0。

6. A time-sharing optimization design method for a rod-pumped well according to claim 2 or 3, wherein S103 designs different combinations of production parameters of the rod-pumped well according to different production volumes and liquid levels, and groups the rod-pumped well according to the same rod diameter, rod length, pipe diameter, pipe length, pump diameter, pump depth and stroke, and different stroke times and production volumes, comprising:

step 5: will q _max Divided into n _q Parts, q _i ＝i*q _max /n _q ，i∈[0,n _q ]，n _q I is a positive integer, and p is calculated according to the IPR equation of the well _wfi ；

Step 6: maximum pump down depth H given in step 2 _max Given a pump depth step H _s The number of possible pump depths is n _pupmdepth ＝(H _max -H ₀ )/H _s Each q _i Can correspond to different pump depths Lp _ij ，Lp _ij ＝H ₀ +j*H _s ，j>=1, j is an integer up to Lp _ij <=hmax, will each p _wfi Substituted into the following formula:

p _wf ＝p _t +ρ _o (L _p -h)+ρ _l (H-L _p )

obtaining h _ij To form different q _i 、h _ij ,Lp _ij The combination number is n _q *n _pumpdepth A plurality of;

step 7: for each q _i 、h _ij ,Lp _ij Within the range set in step 3, n is set to _tubing Diameter n of seed tube _rodtype Steel grade of seed pole, n _pump Seed pump diameter, n _rod Seed pole combination, n _s Seed stroke, n _n The seed stroke times are combined one by one to calculate the yield q _ic Given an error e, if |q _i -q _ic |<e is true, the combination is such that the yield q can be maintained _i Invariable viable production parameter combinations; if not, the combination is discarded; calculating the corresponding maximum load, minimum load and maximum torque of each feasible production parameter combination, and calculating the maximum load and maximum torque required to meet the rated load and rated torque limit of the pumping unit, namely P _max <P _max0 、M _max <M _max0 Calculating the maximum load and the minimum load of each level of rod tube, verifying the stress intensity and the stress range, and if the maximum load and the minimum load of each level of rod tube are not met, discarding the combination; the number of possible combinations is at most n _q *n _pumpdepth *n _tubing *n _rodtype *n _pump *n _rod *n _s *n _n A plurality of;

step 8: calculating P corresponding to each production parameter combination selected in the step 7 _inputij ；

Step 9: combining the production parameters selected in the steps 7 and 8 according to the pipe diameter, the steel grade of the pole, the pump diameter, the pump depth, the pole combination and the same stroke, thereby obtaining the liquid yield q _i Stroke frequency, input power P _inputij Unlike, regrouping。

7. A time-of-use optimization design method of an oil pumping well according to claim 2 or 3, wherein S105, for each group, applying different production times for each electricity price period, screening out a combination of production times capable of completing a target yield, and calculating a daily electricity consumption cost thereof, comprises:

step 10: combining the peak valley time duration according to the electricity price, combining the peak valley time duration into N sections according to the difference of the electricity price, and sequencing the peak valley time duration from high to low according to the electricity price, wherein the k-th section total time duration is L _k The electricity price of the kth section is X _k The production time length of the kth section is T _k ,T _k <＝L _k Average daily yield of Q in production period _k ；

Step 11: each q in each set of combinations of step 9 above _i May all be equal to Q _k The liquid yield in the kth period is q _i Corresponding liquid yield and Q for input power _ki ,P _inputijk Representation, Q _ki ＝q _i ,P _inputijk ＝P _inputij ；

Step 12: discretizing to determine T _k Value of the total length of time L of each segment _k Dividing according to a certain step length Ts to make T _kB =b×ts, B is an integer, B _kmax ＝L _k Ts, 0 =per layer<B<B _kmax Each T _kB May be equal to T in step 9 _k ，T _kB The electricity consumption, electricity consumption cost and liquid production amount of each production combination of the time period are T _kB P _inputijk +(L _k -T _kB )P _input0 、(T _kB P _inputijk +(L _k -T _kB )P _input0 )X _k 、T _kB Q _ki 24; the maximum combined number of the production time length, the liquid production amount, the stroke frequency and the input power of each section is n _kqnTgroup ＝B _kmax *n _q *n _n And each.

8. The method for time-sharing optimization design of oil pumping well according to claim 7, wherein Ts is 0.1, 0.2, 0.5 or 1 hour.

9. The time-of-use optimization design method of an oil pumping well according to claim 7, wherein step S105, for each group, applies different production times for each electricity price period, screens out a production time combination capable of completing a target yield, further comprising:

step 13: for at most n in step 9 _ggb Selecting one group of combinations from the groups, and executing the following steps;

step 14: in N time periods, at most N from the 1 st time period _1qnTgroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations;

step 15: from paragraph 2 up to n _2qnTgroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations;

step 16: from the nth segment up to N _Nqngroup Sequentially taking one combination from the production time, liquid production amount, stroke frequency and input power combinations; calculating the production time of each layer to obtain daily yieldIf Q<Q ₀ Sequentially taking down one production time length, liquid production amount, stroke frequency and input power combination, and circularly executing step 16; if Q>＝Q ₀ And Q-Q ₀ <e, e is given error, calculate the daily power consumption cost +.>Storing the combination as a production combination capable of completing the original target liquid production amount, wherein the combination set is marked as G;

if the step 16 is completed, executing the step 15 in a circulating way;

if the step 15 is completed, executing the step 14 in a circulating way;

if the step 14 is completed, selecting the next combination in the step 13, and executing the steps 14, 15 and 16 again in a circulating way;

thereby finding all the liquid production amounts Q capable of completing the original target ₀ Is described in (a) to produce a combined set G.

10. The time-sharing optimization design method of the rod-pumped well according to claim 2 or 3, wherein S107, in all the production time and production parameter combinations capable of completing the target production, selects the production time and production parameter combination with the lowest daily power consumption cost as the time-sharing optimization design result, and includes:

step 17: from the original target liquid yield Q ₀ In the production combination set G, a group of combinations with the lowest daily electricity consumption Cost is found, and the production duration, liquid production amount, stroke frequency, input power and pipe diameter of each section corresponding to the combination, the steel grade of a pole column, the pump diameter, the pump depth and the pole column combination and stroke are used as a time-sharing optimization scheme.