Optimal well placement using machine learning methods: Multiple reservoir scenarios

Seyed Mahdi Mousavi, Hadi Jabbari, Mahdi Darab, Meysam Nourani, Saeid Sadeghnejad

Research output: Chapter in Book/Report/Conference proceedingConference article in proceedingspeer-review

7 Citations (Scopus)

Abstract

Determining the distribution of optimal injection and production wells along with their operating conditions is a complex problem. The objective of this study is to compare the effectiveness of an experimental based approach (central composite design, CCD) with a machine learning method (xGBoost) in a well-placement optimization application. In this study, the well-placement problem consists of the joint optimization of drainage radius, welloperating conditions, and the number of injection and production wells. Our objective function is the netpresent-value (NPV) for a specified operational life of the reservoir under study. Both algorithms (CCD and xGBoost) are applied to three different optimization scenarios, i.e., production from (I) homogeneous reservoir, (II) heterogeneous reservoir, and (III) waterflooding into a heterogeneous reservoir. Like all machine-learning algorithms, our methods need a training dataset. The fast predictor module (i.e., trained model) is obtained by running several numerical simulations by a commercial simulator internally called in an own developed Python code. Moreover, R-squared is chosen as the statistical quality measure in this study. In the first scenario, both algorithms show satisfying predictions (R-squared of 0.943 and 0.999 for CCD and xGBoost, respectively). In scenario II, the CCD and xGBoost show a similar response again (0.948 and 0.997, respectively). As a sub-result, the optimum distance between the two producers was found approximately five simulation blocks in the first case, and three blocks in the second one. The CCD method reveals unreliable results (0.840) in scenario III, while the NPV predictions of the xGBoost algorithm are still acceptable (0.986). Moreover, unlike CCD, xGBoost could find the optimum solution. In other words, the CCD method does not always converge to an optimum solution. However, the number of required simulation runs for CCD is equal to that for the xGBoost model. In this study, a machine learning approach and an experimental design method were compared together in detail. Their efficiency in predicting the NPV of a well-placement problem through multiple homogeneous and heterogeneous reservoir scenarios differ significantly.

Original languageEnglish
Title of host publicationSPE Norway Subsurface Conference 2020
PublisherSociety of Petroleum Engineers
ISBN (Electronic)978-1-61399-718-5
Publication statusPublished - 2 Nov 2020
EventSPE Norway Subsurface Conference 2020 - Virtual, Online
Duration: 2 Nov 20203 Nov 2020

Conference

ConferenceSPE Norway Subsurface Conference 2020
CityVirtual, Online
Period2/11/203/11/20

Programme Area

  • Programme Area 3: Energy Resources

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