Integrated stochastic workflow for optimum well spacing with data analytics, pilots, geomechanical-reservoir modeling, and economic analysis

Cao, Richard; Chen, Chaohui; Li, Ruijian; Firincioglu, Tuba; Ozgen, Chet; Croft, Tyler; Kathel, Prateek; Girardi, Alejandro; Chowdhury, Nitin

doi:10.15530/urtec-2018-2902138

Cited by 6 publications

(6 citation statements)

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“…Production is an oil-water two-phase flow process based on the complex fracture model depicted by the former. (2) This case focuses on flowback and production performances during the spontaneous production period. Considering that the formation pressure is always above the saturation pressure, there is isothermal flow of oil and water in hydraulic fractures and reservoir matrix.…”

Section: Assumptionsmentioning

confidence: 99%

“…Mahu oilfield is an unconventional tight conglomerate reservoir, which has been developed on a large scale by means of the multi-stage fracturing with horizontal well [1]. After years of exploration, the fracturing mode has changed from single well scattered treatment to the zipper fracturing of small space well pattern, greatly improving the construction efficiency [2]. The flowback process is an important step after the completion of fracturing, and flowback efficiency is a highly concerned indicator, which refers to the ratio of the cumulative production of fracturing fluid to the total amount of that injected.…”

Section: Introductionmentioning

confidence: 99%

“…However, there are also views that the retention fluids will form a filtration trap near hydraulic fractures, reducing oil phase permeability, and not conducive to long-term productivity [9,10]. (2) Closure behavior [11] and gravity segregation [12] in fracture system are the key factors. When the fracture propagation patterns are relatively simple, fracture closure is the main driving mechanics of fracturing fluid flowback [13].…”

Section: Introductionmentioning

confidence: 99%

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Flowback Characteristics Analysis and Rational Strategy Optimization for Tight Oil Fractured Horizontal Well Pattern in Mahu Sag

Tian,

Liao,

Liu

et al. 2023

Processes

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With the deep development of tight reservoir in Mahu Sag, the trend of rising water cut during flowback concerns engineers, and its control mechanism is not yet clear. For this purpose, the integrated numerical model of horizontal well pattern from fracturing to production was established, and its applicability has been demonstrated. Then the flowback performance from child wells to parent wells and single well to well pattern was simulated, and the optimization method of reasonable flowback strategy was discussed. The results show that the formation pressure coefficient decreases as well patterns were put into production year by year, so that the seepage driving force of the matrix is weakened. The pressure-sensitive reservoir is also accompanied by the decrease of permeability, resulting in the increase of seepage resistance, which is the key factor causing the prolongation of flowback period. With the synchronous fracturing mode of well patterns, the stimulated reservoir volume (SRV) is greatly increased compared with that of single well, which improves the reservoir recovery. However, when the well spacing is less than 200 m, well interference is easy to occur, resulting in the rapid entry and outflow of fracturing fluid, and the increased water cut during flowback. Additionally, the well patterns in target reservoir should adopt a drawdown management after fracturing, with an aggressive flowback in the early stage and a slow flowback in the middle and late stage. With pressure depletion in different development stages, the pressure drop rate should be further slowed down to ensure stable liquid supply from matrix. This research can provide a theoretical guidance for optimizing the flowback strategy of tight oil wells in Mahu sag.

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Section: Assumptionsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Flowback Characteristics Analysis and Rational Strategy Optimization for Tight Oil Fractured Horizontal Well Pattern in Mahu Sag

Tian,

Liao,

Liu

et al. 2023

Processes

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“…Therefore, multiple history matching was applied. Cao et al [20] determined the optimal well spacing for Delaware Basin by multiple history matching. What is more, they did not take the uncertainty of natural fractures into account, which is another challenge for the well spacing optimization in shale reservoirs.…”

Section: Introductionmentioning

confidence: 99%

The Application of Integrated Assisted History Matching and Embedded Discrete Fracture Model Workflow for Well Spacing Optimization in Shale Gas Reservoirs with Complex Natural Fractures

Chang

et al. 2021

Geofluids

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An appropriate well spacing plan is critical for the economic development of shale gas reservoirs. The biggest challenge for well spacing optimization is interpreting the subsurface uncertainties associated with hydraulic and natural fractures. Another challenge is the existence of complex natural fractures. This work applied an integrated well spacing optimization workflow in shale gas reservoirs of the Sichuan Basin in China with both hydraulic and natural fractures. The workflow consists of five components: data preparation, reservoir simulation, estimated ultimate recovery (EUR) analysis, economic calculation, and well spacing optimization. Firstly, the multiple realizations of thirteen uncertain parameters of matrix and fractures, including matrix permeability and porosity, three relative permeability parameters, hydraulic fracture height, half-length, width, conductivity, water saturation, and natural fracture number, length, and conductivity, were captured by the assisted history matching (AHM). The fractures were modeled by the embedded discrete fracture model (EDFM) accurately and efficiently. Then, 84 AHM solutions combining with five well spacing scenarios from 517 ft to 1550 ft would generate 420 simulation cases. After reservoir simulation of these 420 cases, we forecasted the long-term gas production for each well spacing scenario. Gas EUR degradation and well interference would imply the critical well spacing. The net present value (NPV) for all scenarios would be calculated and trained by K -nearest neighbors (KNN) proxy to better understand the relationship between well spacing and NPV. In this study, the optimum well spacing was determined as 793 ft, corresponding with a maximum NPV of 18 million USD, with the contribution of hydraulic fractures and natural fractures.

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“…Proper well spacing is critical for successful development of unconventional resources. Numerous studies have been conducted on spacing of horizontal wells in unconventional reservoirs [1,[4][5][6][7][8][9][10][11][12][13][14][15][16][17][18][19][20][21][22][23].…”

Section: Introductionmentioning

confidence: 99%

Optimal Spacing of the Wolfcamp in the Delaware Basin

Alzahabi¹

2021

GJES

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Proper well spacing for horizontal wells is one of the missing pieces for the Delaware Basin development in the Wolfcamp Formation. In the Wolfcamp formation in the Delaware Basin, well spacing varies with formation characteristics (rock and fluid) across the Basin. Finding the spacing intervals between horizontal wells right is crucial to maximizing productivity and estimated ultimate recovery (EUR) while avoiding detrimental frac hits and cross-well pressure and fluid interference during stimulation and production.Along with the various parameters affecting development, well patterns and completion methodologies are having the highest impact. Both parameters show a significant impact on the drainage area of wells and may in turn affect optimal spacing between the wells. The model outcomes are expected to improve recovery efficiency, oil production, and minimize detrimental frac hits and cross-well pressure and fluid interference during stimulation and production. A pool of private production and spacing data were analyzed in conjunction with data analytics. This step led to a newly developed model to optimize well spacing.• Fluid Bbls = the amount of fluid pumped downhole to initiate fracture and place proppant.• Fluid Gal/Cluster = the amount of fluid pumped per cluster.

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Integrated stochastic workflow for optimum well spacing with data analytics, pilots, geomechanical-reservoir modeling, and economic analysis

Cited by 6 publications

References 0 publications

Flowback Characteristics Analysis and Rational Strategy Optimization for Tight Oil Fractured Horizontal Well Pattern in Mahu Sag

Flowback Characteristics Analysis and Rational Strategy Optimization for Tight Oil Fractured Horizontal Well Pattern in Mahu Sag

The Application of Integrated Assisted History Matching and Embedded Discrete Fracture Model Workflow for Well Spacing Optimization in Shale Gas Reservoirs with Complex Natural Fractures

Optimal Spacing of the Wolfcamp in the Delaware Basin

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