Waterflood Surveillance by Calibrating Streamline-Based Simulation with Crosswell Electromagnetic Data

Mishra, Shubham; Shrivastava, Chandramani; Ojha, Aditya; Miotti, Fabio

doi:10.2523/iptc-19286-ms

Cited by 3 publications

(1 citation statement)

References 17 publications

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“…As an important means of geophysical survey, the cross‐well electromagnetic method can be used to detect the distribution of remaining oil and find oil and gas enrichment zones, to improve the success rate of drilling and enhance recovery efficiency 1‐4 . In the past 20 years, cross‐well detection technology has gradually developed into two kinds of detection methods with different physical mechanisms: cross‐well seismic and cross‐well electromagnetic detection 5‐9 .…”

Section: Introductionmentioning

confidence: 99%

Research on cross‐well pseudorandom electromagnetic detection method and extraction of response characteristics

Song

Momayez

Wang

et al. 2020

Energy Science & Engineering

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Section: Introductionmentioning

confidence: 99%

Research on cross‐well pseudorandom electromagnetic detection method and extraction of response characteristics

Song

Momayez

Wang

et al. 2020

Energy Science & Engineering

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Enhancing Reservoir Characterization by Calibrating 3D Reservoir Model with Inter-Well Data in 2D Space

Mishra

Shrivastava

Ojha

et al. 2019

SPE Oil and Gas India Conference and Exhibition

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Until recently, reservoir characterization methods in the industry were limited to use of seismic technologies in exploration of oil and gas and had a very constrained role in production and development. In the past, using characterization for development fields was considered a very perilous task. Technological advancements and the risk-averse mindset have significantly expanded the application of reservoir characterization. Today, reservoir characterization is the basis of any development plans made for a commercial field. Development of 3D reservoir modeling techniques to generate field development plans (FDPs) marked a step-change in reservoir characterization methods. Introduction of geostatistics and numerical simulation made it possible to build precise models to generate realistic field development scenarios. This is the state-of-the-art seismic-to-simulation method of reservoir characterization used in FDPs today. However, the struggle to estimate reservoir properties spatially away from the well continues. Surface seismic data provide excellent areal coverage but do not provide the vertical resolution required for a fine-scale reservoir model. Geostatistical methods reduce the uncertainty in spatial distribution of petrophysical properties from pseudo-point supports (wells) but are not calibrated spatially between the wells. Correspondingly, the fluid saturation distribution and the parameters used in dynamically calculating the same during numerical simulation are not calibrated in the interwell space. This paper details necessary data acquisitions and methods of calibration of 3D reservoir model to reduce uncertainty in the interwell space. The data acquisition methods have been available for some time, but have rarely been electronically incorporated in the 3D reservoir model and have been largely used to analytically guide the modeling and its inferences. A logical way of interpreting the results of acquisitions and calibrating the 3D reservoir model cell-by-cell is detailed in this paper.

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High Accuracy Estimation of Hydraulic Fracture Geometry Using Crosswell Electromagnetics

Mishra

Reddy

2021

SPE Annual Technical Conference and Exhibition

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Unconventional resources, which are typically characterized by poor porosity and permeability are being economically developed only after the introduction of hydraulic fracturing (HF) technology, which is required to stimulate the hydrocarbon flow from these impermeable/tight reservoir rocks. Since 1960, HF has been extensively used in the industry. HF is the process of (1) injecting viscous gel fluids through the wellbore into the subterranean hydrocarbon formation, at high pressures sufficient enough to exceed tensile strength of the rock and hydraulically induce cracks/fractures (2) followed by injecting proppant-laden fluid into the open fractures and packing up the fracture with proppant pack, after the injected fluid leaks off into formation. The resultant proppant pack keeps the induced fracture propped open and thus creates a highly conductive flow path for the hydrocarbon to flow from the far-field subterranean formation into the wellbore. Most the modern wells in unconventional reservoirs are horizontal/near-horizontal wells that are completed with large multiple HF treatments across the entire length of the horizontal wellbore (lateral), to increase the reservoir contact per well. Productivity of these wells is dictated by the stimulated reservoir volume (SRV), which is dependent on the number of fractures and conductive hydraulic fracture surface area of each fracture that is propped open. Therefore, estimation of the hydraulic fracture geometry (HFG) dimensions has become very critical for any unconventional field development. Key dimensions are hydraulic fracture length, height, and orientation, which are required to assess the optimum configuration of fracturing, well completion, and reservoir management strategy to achieve maximum production. Designs can be assessed based on HFG observations, and infill well trajectories, spacing, etc. can be planned for further field development. This workflow proposes a method to estimate and model all or at least two parameters of HFG in predominantly horizontal or nearly horizontal wells by use of interwell electromagnetic recordings. The foundation of this workflow is the difference in salinity, or more precisely resistivity, of the fracturing fluid and the resident fluid (hydrocarbon or formation water). The fracturing fluid is usually significantly less resistive than the hydrocarbon that is the dominant resident fluid where fracturing is usually conducted, or less resistive than the formation water in case the HF occurs in high water saturation regions. Therefore, the resistivity contrast between the two fluids will demarcate the boundary of hydraulic fractures and thus help in precisely modeling some or all parameters of HFG. The interwell recordings can be interpreted along a 2D plane between the two wells, one of them bearing the transmitter and the other with the receiver. The interpretations along a 2D plane can be used to calibrate a 3D unstructured HF model, thereby introducing a reliable calibration input that did not exist before. There can be multiple such 2D planes as more than one well can have a receiver, and, in that case, the 3D HF model has more calibration data and is even more precise. The reason this workflow significantly improves precision in HFG estimation and modeling is that it provides the ability to demarcate only the open portion of the HF and not the entire volume where pumping fluid entered, which would include parts that closed too quickly to contribute to the production from the well. Today, the industry, by its best methods, can only see the entire rock volume that broke due to fracturing, although significant parts of that broken volume might not be contributing to the production and thus are irrelevant in the 3D models upon which important decisions such as production forecast and project economics are based.

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Waterflood Surveillance by Calibrating Streamline-Based Simulation with Crosswell Electromagnetic Data

Cited by 3 publications

References 17 publications

Research on cross‐well pseudorandom electromagnetic detection method and extraction of response characteristics

Research on cross‐well pseudorandom electromagnetic detection method and extraction of response characteristics

Enhancing Reservoir Characterization by Calibrating 3D Reservoir Model with Inter-Well Data in 2D Space

High Accuracy Estimation of Hydraulic Fracture Geometry Using Crosswell Electromagnetics

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