Rapid Field-Scale Well Spacing Optimization in Tight and Shale Oil Reservoirs Using Fast Marching Method

lino, Atsushi; Onishi, Tsubasa; Olalotiti-Lawal, Feyi; Datta‐Gupta, Akhil

doi:10.15530/urtec-2018-2901376

Cited by 6 publications

(3 citation statements)

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“…[80][81][82][83][84][85][86][87][88][89][90] Carbon dioxide (CO 2 ) injection is a well-known EOR method regarding its feasible application rather than other conventional methods. [91][92][93][94][95] Its application in shale reservoirs is of importance in recent decades. In this method, carbon dioxide has interacted with the formation fluid (oil phase).…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation on the application of carbon dioxide adsorption for a shale reservoir

Zhang

Khayatnezhad

Davarpanah

2021

Energy Science & Engineering

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Section: Introductionmentioning

confidence: 99%

Experimental investigation on the application of carbon dioxide adsorption for a shale reservoir

Zhang

Khayatnezhad

Davarpanah

2021

Energy Science & Engineering

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“…Some of them have investigated the controlling factors for the well spacing determination, such as fracture half-length, reservoir permeability, rock properties, and natural fractures [6][7][8]. However, due to shale reservoirs' complexity, it is still challenging to quantify the subsurface uncertainty-associated hydraulic and natural fractures [9,10]. Several methods, including the microseismic method, well test method, and rate-transient analysis (RTA) method, have applied to capture the uncertain parameters [11][12][13][14].…”

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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“…There are several aspects of challenges that need to be tackled for the well spacing optimization problem. For a shale reservoir, well spacing can be complicated by the subsurface uncertainties-associated hydraulic and natural fractures, multiphase flow, different types of interferences between wells such as frac-hits or long-term production/pressure interferences, and economic cost structures [2][3][4][5]. Methods such as rate transient analysis and pressure transient analysis, field pilot tests, and decline curve analysis are all feasible ways to partially solve some of the challenges mentioned above [6][7][8][9][10].…”

Section: Introductionmentioning

confidence: 99%

A Novel Optimization Workflow Coupling Statistics-Based Methods to Determine Optimal Well Spacing and Economics in Shale Gas Reservoir with Complex Natural Fractures

Chang

Liu

et al. 2020

Energies

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In order to account for big uncertainties such as well interferences, hydraulic and natural fractures’ properties and matrix properties in shale gas reservoirs, it is paramount to develop a robust and efficient approach for well spacing optimization. In this study, a novel well spacing optimization workflow is proposed and applied to a real shale gas reservoir with two-phase flow, incorporating the systematic analysis of uncertainty reservoir and fracture parameters. One hundred combinations of these uncertainties, considering their interactions, were gathered from assisted history matching solutions, which were calibrated by the actual field production history from the well in the Sichuan Basin. These combinations were used as direct input to the well spacing optimization workflow, and five “wells per section” spacing scenarios were considered, with spacing ranging from 157 m (517 ft) to 472 m (1550 ft). An embedded discrete fracture model was used to efficiently model both hydraulic fractures and complex natural fractures non-intrusively, along with a commercial compositional reservoir simulator. Economic analysis after production simulation was then carried out, by collecting cumulative gas and water production after 20 years. The net present value (NPV) distributions of the different well spacing scenarios were calculated and presented as box-plots with a NPV ranging from 15 to 35 million dollars. It was found that the well spacing that maximizes the project NPV for this study is 236 m (775 ft), with the project NPV ranging from 15 to 35 million dollars and a 50th percentile (P50) value of 25.9 million dollars. In addition, spacings of 189 m (620 ft) and 315 m (1033 ft) can also produce substantial project profits, but are relatively less satisfactory than the 236 m (775 ft) case when comparing the P25, P50 and P75 values. The results obtained from this study provide key insights into the field pilot design of well spacing in shale gas reservoirs with complex natural fractures.

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Rapid Field-Scale Well Spacing Optimization in Tight and Shale Oil Reservoirs Using Fast Marching Method

Cited by 6 publications

References 0 publications

Experimental investigation on the application of carbon dioxide adsorption for a shale reservoir

Experimental investigation on the application of carbon dioxide adsorption for a shale reservoir

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

A Novel Optimization Workflow Coupling Statistics-Based Methods to Determine Optimal Well Spacing and Economics in Shale Gas Reservoir with Complex Natural Fractures

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