A straight-line DCA for a gas reservoir

Jongkittinarukorn, Kittiphong; Escobar, Freddy Humberto; Srisuriyachai, Falan

doi:10.1016/j.petrol.2021.108452

Cited by 9 publications

(7 citation statements)

References 9 publications

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“…Jongkittinarukorn et al [35] also discussed the changes in decline rate and decline exponent for constant BHP gas wells in volumetric reservoirs. They explained the relationship between production rate, decline rate, decline exponent, and λ vs. ðp/ZÞ/ðp i /Z i Þ based on the stabilized flow equation developed by Ansah et al [36,37] and estimated gas reserves by that explanation.…”

Section: Geofluidsmentioning

confidence: 99%

“…Furthermore, variable rate reservoir limits testing, DMB, and Blasingame's type curves can dispose fluctuations in production conditions, but the pseudotime needs to be calculated iteratively. The modified FMB approach is only suitable for constant rate gas wells, while explicit methods that rely on traditional decline parameters can merely handle constant BHP conditions or specific pressure conditions [32,34,35]. In addition, most of these methods do not consider the compressibility of pores and irreducible water during pressure depletion.…”

Section: Geofluidsmentioning

confidence: 99%

“…The left term of Equation ( 35), Fðp ave Þ, is the polynomial function dependent on gas properties. Knowledge of the right term of Equation (35) can solve the values of p ave in the interval of ðp wf , p i Þ by the polynomial rooting, bisection, or Newton iteration method.…”

Section: Geofluidsmentioning

confidence: 99%

“…Thirdly, gas production data are necessary such as rate, BHP, and cumulative gas production. Then, we need to choose a reference point in BDF to estimate the profile of ARP by Equation (35). Lastly, gas reserves can be inferred…”

Section: Mainmentioning

confidence: 99%

See 3 more Smart Citations

An Explicit Method for Estimating the Average Reservoir Pressure and Gas in Place Based on the Gas Property Polynomial Function

Zhang

Jiang

et al. 2023

Geofluids

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The fast and accurate determination of average reservoir pressure (ARP) and gas reserves is vital for the analysis and forecasting of gas well performance. An explicit and relatively rigorous method for estimating the ARP and gas in place, based on the dynamic material balance equation and the gas property polynomial function (GPPF), is presented to circumvent such drawbacks as high cost, empiricism, poor adaptability to variable production schedules, and the necessity for iteration processes, by which current approaches usually have been limited. The gas flow model is solved by introducing pseudofunctions and considering the compressibility effects of rock and irreducible water, and the pressure-rate correlations during boundary-dominated flow (BDF) which constitute the theoretical proofs of this method are derived from the superposition principle coupled with the constant rate solution. Production data under different production scenarios prove it effective. The error of estimation for formation pressure and gas reserves hardly ever goes beyond 4% given that the BDF condition is generally satisfied by the rate and bottom hole flowing pressure (BHP) data. We employ the GPPF to capture the nonlinear variations of gas viscosity and Z -factor, helpful to implement a quick conversion between pressure and pseudopressure and to solve the integral equation concerning pseudopressure and thus valid in overcoming the limitations of previous methods concerning pressure or pressure squared. The proposed methodology boasts its simpleness and practicability, which not only dispenses with iterations on pseudotime but also applies to various production systems of gas wells under constant BHP, constant rate, or variable BHP/variable rate conditions.

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Section: Geofluidsmentioning

confidence: 99%

Section: Geofluidsmentioning

confidence: 99%

Section: Geofluidsmentioning

confidence: 99%

Section: Mainmentioning

confidence: 99%

See 2 more Smart Citations

An Explicit Method for Estimating the Average Reservoir Pressure and Gas in Place Based on the Gas Property Polynomial Function

Zhang

Jiang

et al. 2023

Geofluids

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“…Jongkittinarukorn et al [39] presented a correlation between production rate, decline rate, and decline exponent that relates q vs. Dn • ½dðln λÞ/dp D −1 curve to reserve estimation, based on the viscosity-compressibility ratio λ defined by Carter [20] and the stabilized gas flow equation proposed by Ansah et al [40,41], where p D , a dimensionless pressure, is defined as ðp/ZÞ/ðp i /Z i Þ; D denotes decline rate and n is decline exponent. They considered the changes in decline exponent for the volumetric gas reservoir at constant-BHP conditions.…”

Section: Introductionmentioning

confidence: 99%

Performance Analysis of Gas Wells Based on the Conventional Decline Parameters and the Flow Integral Equation

Zhang

Song

et al. 2021

Geofluids

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The estimation of reserves and performance prediction are two vital tasks for the development of gas reservoirs where the evaluation of gas in place or well-controlled reserves, as the foundation of the performance analysis of gas wells, turns to be exceedingly significant. Advanced production data analysis or modern rate transient analysis (RTA) methods mainly depend on the iterative calculations of material balance quasitime ( t ca ) and type curve fitting, the essence of which is to update the average reservoir pressure data time and again. The traditional Arps’ decline models are of empirical nature despite the convenience and applicability to the constant bottomhole pressure (BHP) condition. In order to avoid the implicit iteration, this paper develops an explicit method for estimating the average reservoir pressure on the basis of dynamic material balance equation (DMBE), termed “flow integral method,” which can be applied to various gas production systems under boundary-dominated flow (BDF). Based on the flow integral method and the decline parameter evaluation, we employ the hyperbolic decline model to model the gas well performance at a constant BHP. The analytical formulations of decline rate and decline exponent are deduced from the DMBE and the static material balance equation (SMBE) considering the elastic compressibilities of rock pore and bound water. The resulting decline parameter method for explicit estimation of gas reserves boasts a solid and rigorous theory foundation that production rate, decline rate, and average reservoir pressure profiles have reference to each other, and its implementation steps are explained in the paper. The SMBE can, combined with the estimated pressure profile by the flow integral method, also be used to determine gas reserves which is not limited to the constant-BHP condition and can calibrate the estimates of the decline parameter method. The proposed methods are proven effective and reliable with several numerical cases at different BHPs and a field example.

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Global feature capture and spatially-aware neural networks for predicting CO2-flooding performance in heterogeneous low-permeable reservoirs

Dong,

Jin,

Zhang

et al. 2024

Geoenergy Science and Engineering

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A straight-line DCA for a gas reservoir

Cited by 9 publications

References 9 publications

An Explicit Method for Estimating the Average Reservoir Pressure and Gas in Place Based on the Gas Property Polynomial Function

An Explicit Method for Estimating the Average Reservoir Pressure and Gas in Place Based on the Gas Property Polynomial Function

Performance Analysis of Gas Wells Based on the Conventional Decline Parameters and the Flow Integral Equation

Global feature capture and spatially-aware neural networks for predicting CO2-flooding performance in heterogeneous low-permeable reservoirs

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