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Natural gas production is related to the demand for gas, which is low in summer and high in winter. While the gas storage is still being demonstrated and constructed, oil and gas fields should formulate and implement production control schemes suitable for gas reservoirs. The realization of natural gas production can not only meet the demand of gas consumption, but also ensure the scientific and efficient development of gas reservoirs, and meet the needs of dynamic analysis of gas reservoirs at different development stages and scientific research of gas reservoirs. In this paper, KAPPA Workstation 5.20 software is used to determine the inflow dynamic model of a single well. The nodal method is used to determine the reasonable production and peak shaving capacity in combination with the critical fluid carrying capacity of gas wells and the erosion rate of gas wells. The reasonable production allocation in each period, i.e. the production control scheme, is obtained. It solves the scientific and efficient development of natural gas in X gas field, which is still under the construction of gas storage, and provides guidance for gas reservoir development management and regulation.

In order to coordinate the contradiction between gas field production and market gas demand, most of the domestic and foreign countries have achieved effective solutions through the construction of some spare capacity, underground gas storage and introduction of LNG [

Gas wells are affected by many factors in the production process, such as gas well productivity, production decline, minimum liquid carrying speed, gas erosion on tubing and string and other factors will limit the production of gas wells.

The production capacity analysis method of unsteady flow considers the coupling effect of gas reservoir and wellbore. It uses the production dynamic data of gas well (daily monthly production, oil pressure, flow pressure, static pressure, production hours), through the theory of unsteady seepage and material balance equation, and takes the formation seepage well bore flow well orifice throttling as the production system for overall analysis. Considering not only the percolation characteristics of gas wells, but also the flow of wellbore, the long-term dynamic analysis and prediction of gas well productivity can be realized, avoiding the limitations of traditional semi empirical and semi theoretical analysis methods.

In this study, in kappa workstation 5.20 software, first use the TOPAZE module to fit the production dynamic data (

Using APRs production decline analysis to study the law of production decline [

α α i = ( Q A O F Q A O F i ) n (1)

where, α is capacity decline rate, α i is initial production decline rate, Q_{AOFi} is initial production capacity, n is decline index.

When n = 0 , a = a i = const , decrement for index (normal decrement).

When n = 1 , a = a i ( Q A O F / Q A O F i ) , decreasing for harmony.

When 0 < n < 1 , a = a i ( Q A O F / Q A O F i ) n , it's called decrement.

Specifically, when n = − 1 , it is called linear decrement.

When n = 0.5 , it is called decrement.

For exponential decrement n = 0 , α = α i = constant .

According to the definition of decline rate, when the law of production capacity decline satisfies the exponential decline of n = 0 , i.e. α i = constant , we can get:

− 1 Q A O F d Q A O F = α d t (2)

Definite integral on both sides − ∫ Q A O F i Q A O F d Q A O F Q A O F = α ∫ 0 t d t can get:

ln ( Q A O F / Q A O F i ) = − α t or Q A O F = Q A O F i e − α t (3)

In the same way, according to the definition, we can get the different expressions of the production decline rate α_{p} at the pressure level, α_{p}_{2} at the pressure square and α_{R} at the production degree under the exponential decline

{ Q A O F = Q A O F i e α p ( P − P i ) Q A O F = Q A O F i e α p 2 ( P 2 − P i 2 ) (4)

When the law of production capacity decline satisfies the harmonic decline of n = 1, α = α i ( Q A O F / Q A O F i ) , we can get:

− 1 Q A O F d Q A O F d t = α i Q A O F Q A O F i (5)

Take the definite integral on both sides − ∫ Q i Q d Q A O F Q A O F 2 = α i Q A O F i ∫ 0 t d t to get:

1 Q A O F = 1 Q A O F i + α i Q A O F i t = 1 + α i t Q A O F i

or ln ( Q A O F i Q A O F ) = ln ( 1 + α i t ) (6)

In the same way, the different expressions of the pressure level production decline rate α P and the pressure square production decline rate α P 2 under harmonic decline are obtained:

{ ln ( Q A O F i Q A O F ) = ln [ 1 − α P i ( P − P i ) ] ln ( Q A O F i Q A O F ) = ln [ 1 − α P 2 i ( P 2 − P i 2 ) ] (7)

When the production capacity decline law satisfies the hyperbolic decline of 0 < n < 1 , α = α i ( Q A O F / Q A O F i ) n , we can get

− 1 Q A O F d Q A O F d t = α i ( Q A O F Q A O F i ) n (8)

Separate variables − ∫ Q A O F i Q A O F 1 Q A O F n + 1 d Q A O F = α i Q A O F i n ∫ 0 t d t and take definite integral on both sides:

1 Q A O F n − 1 Q A O F i n = n α i Q A O F i n t (9)

Q A O F = Q A O F i / ( 1 + n α i t ) 1 / n (10)

In the same way, we can get different expressions about the decline rate of productivity in the pressure level, the decline rate of productivity in the pressure square and the production degree under the hyperbolic decline:

{ Q A O F = Q A O F i [ 1 − n α P i ( P − P i ) ] 1 / n Q A O F = Q A O F i [ 1 − n α p 2 i ( P 2 − P i 2 ) ] 1 / n (11)

By using the method of judging production decline type, the methods of judging production decline type (i.e. determining decline parameters I and N) of gas reservoir (well) include: graphic method, trial and error method, curve displacement method, binary linear regression method, typical curve fitting method [

Considering that there is no obvious relationship between production capacity change and production time in actual production, trial and error method is used to determine formation pressure level and pressure square decline type (

According to production capacity decline study, future capacity can be predicted. Take 1/3~1/4 of the production capacity as one of the current reasonable production reference values, so as to predict the reasonable production capacity.

The minimum velocity of fluid flow from the wellbore to the surface is called the minimum fluid carrying velocity or critical production. It is of great significance to keep the gas well production greater than the minimum liquid carrying speed for improving the recovery rate of gas reservoir, especially for water producing gas reservoir.

According to Coleman model [

u c r = 4.45 [ σ ( ρ 1 − ρ g ) ρ g 2 ] 0.25 (12)

where, u c r is Critical velocity of liquid carrying in gas wells, m/s. σ is Air-water interfacial tension, N/m. ρ 1 is Density of liquids, kg/m^{3.} ρ g is Density of gases, kg/m^{3}, ρ g = 3.4844 × 10 3 γ g p Z T , σ = 60 × 10 − 3 N / m .

Erosion velocity is the maximum limit flow rate to avoid the erosion effect of high-speed flowing gas in wellbore on tubing and tubing string. The safe flow rate of erosion can be calculated by formula (1) Beggs [

{ V e = C ρ g 0.5 q e = 40538.17 × D 2 ( p w h Z T γ g ) 0.5 (13)

where V e is erosion velocity, m/s. C = 122 . ρ g is gas density, kg/m^{3}; q e is Erosion discharge, m^{3}/d; A is Tubing section area,m^{2}. p w h is wellhead pressure, MPa; T is wellhead temperature, K; Z is deviation coefficient; γ g is relative density of natural gas.

The reasonable production of gas well is one of the important indexes of gas reservoir development, which is of great significance to the efficient development of gas reservoir. The determination of reasonable production of gas wells is related to gas reservoir reserves, reservoir properties and parameters, well bore structure, stable production period, economic benefits and other factors. According to the specific situation of gas reservoir, sometimes the reasonable production of gas well can be determined according to single factor, sometimes multiple factors should be considered to determine the reasonable production comprehensively, but the general principle is that the reasonable production must follow the principle of resource protection and environmental protection to ensure the stable and safe gas supply of gas well.

In order to realize the reasonable production scheduling of gas reservoir, the overall scheme of production regulation is studied. According to the production constraints, the distribution production of gas reservoir is q_{i}, and the single well production of gas reservoir is q_{ij}. The minimum fluid carrying capacity of the gas reservoir is q_{mini}, and the erosion velocity of the gas reservoir is q_{ei}. In this paper, assuming that a single well is assigned production according to the current maximum production capacity, the assigned production index is λ i j , and the switch well is represented by η i j , the assigned production model is established.

Min η i j ( q e i , q min i j , q max i j , r D , r W , P w f ( min ) , G P , P w f , P , λ i j ) { q i j < q e i q min i j < q i j < q max i j q i j = ∑ i , j η i j λ i j q max i j = q k P w f ( min ) = P t f 2 e 2 s + 1.324 × 10 − 18 d 5 f ( q min T ¯ Z ¯ ) 2 ( e 2 s − 1 ) s = 0.03415 γ g H T ¯ Z ¯ P Z = P i Z i [ 1 − G P G ] P D 2 = P 2 − 1.291 × 10 − 3 q × T × μ 1 ¯ × Z 1 ¯ K g × h ( ln r e r D + D q ) P w f 2 = P D 2 − 1.291 × 10 − 3 q × T × μ 2 ¯ × Z 2 ¯ K g ( r D ) ¯ × h ( ln r e r D + s + D q ) λ i j ∈ ( 0 , 1 ) η i j = 0 , 1

Take x gas reservoir as an example. According to the demand of different months, make the reasonable production of each well in different months (

Through the study of production regulation of X gas reservoir, the following conclusions and understandings have been obtained:

1) The gas well productivity is obtained by the evaluation method of non shut in productivity.

2) By defining the production decline rate, we can calculate the law of production decline in different periods and study the law of production decline. The law of single well production decline is mainly linear decline.

Mouth | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 |
---|---|---|---|---|---|---|---|---|---|---|---|---|

Gas demand 10^{4} m^{3} | 19,840 | 17,920 | 19,840 | 13,500 | 13,950 | 12,000 | 10,035 | 10,850 | 11,400 | 14,880 | 13,500 | 15,500 |

Well number | Qmax 10^{4} m^{3}/d | Erosion elocity 10^{4} m^{3}/d | Critical liquid carrying capacity 10^{4} m^{3}/d | Allocation coefficient | Yield distribution 10^{4} m^{3}/d | Shut in time d | Monthly cumulative production 10^{4} m^{3} |
---|---|---|---|---|---|---|---|

H2 | 35.50 | 37.75 | 5.78 | 0.74 | 26.38 | 5.00 | 672.66 |

H3 | 29.70 | 35.41 | 5.44 | 0.81 | 24.16 | 5.00 | 616.10 |

H5 | 36.10 | 35.41 | 5.44 | 0.84 | 30.47 | 5.00 | 776.99 |

H6 | 33.70 | 37.75 | 5.78 | 0.75 | 25.27 | 0.00 | 770.79 |

H1 | 32.16 | 34.93 | 5.38 | 0.81 | 26.12 | 5.00 | 666.06 |

M2 | 19.20 | 46.31 | 6.96 | 0.53 | 10.25 | 0.00 | 312.63 |

M3 | 73.60 | 82.87 | 8.85 | 0.60 | 44.47 | 5.00 | 1133.96 |

M4 | 52.80 | 76.18 | 8.18 | 0.39 | 20.70 | 0.00 | 631.35 |

M1 | 94.00 | 75.11 | 8.08 | 0.72 | 67.26 | 5.00 | 1715.07 |

P1 | 13.30 | 38.63 | 5.84 | 0.58 | 7.69 | 6.00 | 188.31 |

P2 | 5.92 | 34.41 | 5.20 | 0.41 | 2.40 | 0.00 | 73.25 |

P3 | 22.90 | 34.71 | 5.25 | 0.21 | 4.71 | 0.00 | 143.60 |

P7 | 18.50 | 34.64 | 5.24 | 0.58 | 10.72 | 6.00 | 262.65 |

P9 | 2.94 | 27.43 | 4.13 | 0.48 | 1.40 | 0.00 | 42.69 |

P6 | 28.18 | 32.99 | 4.99 | 0.58 | 16.25 | 6.00 | 398.20 |

P5 | 18.60 | 34.17 | 5.17 | 0.72 | 13.44 | 6.00 | 329.37 |

D1 | 25.90 | 45.63 | 6.97 | 0.35 | 9.07 | 5.00 | 231.31 |

D4 | 12.20 | 46.55 | 7.11 | 0.55 | 6.67 | 5.00 | 170.14 |

D5 | 12.40 | 50.96 | 7.75 | 0.73 | 9.07 | 5.00 | 231.35 |

D6 | 24.11 | 57.64 | 8.68 | 0.42 | 10.04 | 5.00 | 256.08 |

D3 | 5.45 | 45.63 | 6.97 | 0.46 | 2.53 | 5.00 | 64.54 |

D7 | 18.10 | 62.54 | 9.31 | 0.15 | 2.68 | 5.00 | 68.45 |

D8 | 22.00 | 64.95 | 9.96 | 0.50 | 10.97 | 5.00 | 279.73 |

Sum. | 10,035.28 |

3) Through the analysis and evaluation of production constraints in terms of gas well erosion velocity and critical liquid carrying capacity, the erosion velocity and critical liquid carrying capacity under different tubing sizes are obtained.

4) The optimization method is used to study the production control and establish the optimization mathematical model, which can give the reasonable production of gas wells according to the demand and conditions of different periods.

The authors declare no conflicts of interest regarding the publication of this paper.

Tan, J., Sun, E.H., Wang, W., Guo, J.M. and Yang, W. (2019) Study on Production Regulation of Reservoir under Different Demand. Journal of Power and Energy Engineering, 7, 39-49. https://doi.org/10.4236/jpee.2019.77004