A novel steady-state productivity equation for horizontal wells in bottom water drive gas reservoirs

Zhang, Liehui; Zhao, Yulong; Liu, Zhibin

doi:10.1007/s12182-011-0116-2

Cited by 5 publications

(4 citation statements)

References 17 publications

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“…(13) and obtain the dependence of the potential gradient on the pressure gradient: g dz dp dz According to Eqs. (12) and (14), the necessary condition for the water at point M to be able to rise can be expressed in terms of the potential gradient:…”

Section: Theory Of the Startup State For Onset Of Water Risementioning

confidence: 99%

“…Consequently, the bottom water will rise with increasing velocity until the water floods into the wellbore. If the well is producing at a rate higher than Q m or with a pressure difference greater than p m , then according to the equations for the startup conditions (12) or (15), the water will begin to rise. And conversely, if g dz dp w z   0 / at point M, then the water will not rise.…”

Section: Theory Of the Startup State For Onset Of Water Risementioning

confidence: 99%

See 1 more Smart Citation

Study of Startup Parameters Triggering Water Cresting in Wells in Bottom-Water Reservoirs

Yue

Chen

Liu

et al. 2015

Chem Technol Fuels Oils

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Based on the description of the dynamic process of bottom-water cresting in horizontal wells, we have identified a startup state that precedes the water rise. We present formulas helping to understand the nature of the process of bottom-water cresting toward a horizontal well, and to analyze the cresting process in relation to well production rate. The goal of this paper is to improve understanding of bottom-water cresting toward a horizontal well.

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Section: Theory Of the Startup State For Onset Of Water Risementioning

confidence: 99%

Section: Theory Of the Startup State For Onset Of Water Risementioning

confidence: 99%

Study of Startup Parameters Triggering Water Cresting in Wells in Bottom-Water Reservoirs

Yue

Chen

Liu

et al. 2015

Chem Technol Fuels Oils

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“…To date, studies on water invasion have focused on homogeneous reservoirs [16][17][18][19]. However, due to the random distribution of the pore space, fractured-vuggy carbonate reservoirs are quite different from homogeneous reservoirs [20].…”

Section: Introductionmentioning

confidence: 99%

A Novel Method to Calculate Water Influx Parameters and Geologic Reserves for Fractured-Vuggy Reservoirs with Bottom/Edge Water

Yao,

Yan,

Zhou

et al. 2024

Energies

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In practical oilfield production, the phenomenon of water influx typically shortens the water-free recovery period of wells, leading to water flooding and causing a sharp decline in the production well yields, bringing great harm to production. Water invasion usually occurs as a result of the elastic expansion of the water as well as the compaction of the aquifer pore space. However, it can be due to the special characteristics of fractured-vuggy reservoirs such as non-homogeneity and the discrete distribution of the pore spaces. It is challenging to use traditional seepage flow theories to analyze the characteristics of water influx. Also, reservoir numerical simulation methods require numerous parameters which are difficult to obtain, which significantly reduces the accuracy of the results. In this study, considering the driving energy for water influx, a water influx characteristic model was obtained by fitting a graph plate. Subsequently, an iterative calculation method was used to simultaneously obtain water influx volume and OOIP. The aquifer to hydrocarbon ratio was determined by fitting the water influx curve with the graphic plate. Results show that the calculation method is sensitive to the values of reservoir pressure and the crude oil formation volume factor. After applying the method to one field case, it was discovered that water influx performance can be characterized into two types, i.e., linear water influx and logarithmic water influx. In the early stages, the water influx rate of logarithmic water influx is greater compared to linear water influx. However, the volume and energy of waterbody are limited, and the water invasion phenomenon occurs almost exclusively within a short period after the invasion. On the other hand, the volume of waterbody invaded by linear water influx is larger, and it can maintain a stable rate of water influx. The results of the study can provide theoretical support for the waterbody energy evaluation and dynamic analysis of water influx, as well as the control and management of water in these types of reservoirs.

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“…This necessitates the determination of the maximum waterfree oil production rate that a completed well can deliver. The flow mechanisms, correlations and methods to calculate this critical rate have been developed for wells completed in a continuous pay zone with oil-water contact or gas-oil contact or both (Meyer and Garder 1954;Chierici et al 1964;Høyland et al 1989;Menouar and Hakim 1995;Zhang et al 2011;Tabatabaei et al 2012). Correlations have also been developed to predict the water breakthrough time and time for a well to produce above its critical rate (Papatzacos et al 1989;Yang and Wattenbarger 1991).…”

Section: Introductionmentioning

confidence: 99%

A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells

Adeleye¹,

Olamigoke

Mumuni

2020

J Petrol Explor Prod Technol

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Producing an oilfield in a cost-effective way depends on how long water production could be delayed in the reservoir. Many flow mechanisms, correlations, and methods to calculate maximum water-free oil production rate have been published, However, those methods have generally failed to not consider the skin effect which affects the flow into the wellbore. In this paper, the semi-analytical perforation skin model as presented by Karakas and Tariq is incorporated into the Meyer and Garder correlation for critical oil rate from a perforated vertical well interval to obtain the maximum water-free oil production rate and optimal perforation parameters. The resulting coupled computational model is used to determine the sensitivity of the maximum water-free oil production rate to wellbore perforation parameters. Whilst an increase in perforation length and decrease in spacing between perforation increase the critical flow rate, an increase in perforation radius did not translate to higher productivity. The optimal perforation angles are 45° and 60°, however, for the data used in this work the maximum water-free oil rate of 23.2 std/d was obtained at 45° of phasing angle, 1 in of spacing between perforation, 0.36 in of perforation radius and 48 in of perforation length. Thus, the perforation strategy can be optimized prior to drilling and completion operations to improve productivity using the computational model presented in this work.

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A novel steady-state productivity equation for horizontal wells in bottom water drive gas reservoirs

Cited by 5 publications

References 17 publications

Study of Startup Parameters Triggering Water Cresting in Wells in Bottom-Water Reservoirs

Study of Startup Parameters Triggering Water Cresting in Wells in Bottom-Water Reservoirs

A Novel Method to Calculate Water Influx Parameters and Geologic Reserves for Fractured-Vuggy Reservoirs with Bottom/Edge Water

A predictive protocol to obtain maximum water-free oil production rate for perforated vertical wells

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