### Abstract

Naturally fractured reservoirs have been studied extensively in the past decades. These reservoirs consist of two distinct porous media: the macropores and the micropores. Several analytical models have been suggested to characterize such reservoirs. In this work, one of the proposed double-porosity pressure transient models is adopted in the description of the naturally fractured reservoirs. The forward solution component of the analytical model is used to generate the pressure transient data, given the characteristic parameters of the double-porosity reservoirs. The double-porosity systems are characterized by a pressure transient signature which is composed of two semi-log straight lines connected by a transitional curve. The pressure transient responses obtained by the analytical forward solution are subjected to a polynomial fit algorithm so that the aforementioned double-porosity signature can be represented by five polynomial coefficients. These coefficients, the known properties of the double-porosity reservoir, and the reservoir fluid and well parameters constitute the principal input given to the artificial neural network (ANN) during the training phase. The ANN, then, inversely predicts the desired unknown properties of the double-porosity system, namely the permeability of the fracture, the porosity of the matrix, the porosity of the fracture, and the permeability of the matrix. This final development of the ANN is achieved by utilizing this inverse protocol in gradually increasing levels of complexity. The complexity of the problem is elevated by increasing the number of unknown characteristics of the double-porosity system. This research demonstrates the efficiency of the ANN utilization in obtaining the desired properties of the double-porosity reservoirs.

Original language | English (US) |
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Title of host publication | Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology |

Subtitle of host publication | Time to Deliver" |

Pages | 215-226 |

Number of pages | 12 |

Volume | 1 |

State | Published - Dec 1 2007 |

Event | Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology: Time to Deliver" - Jakarta, Indonesia Duration: Oct 30 2007 → Nov 1 2007 |

### Other

Other | Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology: Time to Deliver" |
---|---|

Country | Indonesia |

City | Jakarta |

Period | 10/30/07 → 11/1/07 |

### Fingerprint

### All Science Journal Classification (ASJC) codes

- Fuel Technology
- Energy Engineering and Power Technology

### Cite this

*Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology: Time to Deliver"*(Vol. 1, pp. 215-226)

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*Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology: Time to Deliver".*vol. 1, pp. 215-226, Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology: Time to Deliver", Jakarta, Indonesia, 10/30/07.

**The development of an artificial neural network as a pressure transient analysis tool for applications in double-porosity reservoirs.** / Alajmi, M.; Ertekin, T.

Research output: Chapter in Book/Report/Conference proceeding › Conference contribution

TY - GEN

T1 - The development of an artificial neural network as a pressure transient analysis tool for applications in double-porosity reservoirs

AU - Alajmi, M.

AU - Ertekin, T.

PY - 2007/12/1

Y1 - 2007/12/1

N2 - Naturally fractured reservoirs have been studied extensively in the past decades. These reservoirs consist of two distinct porous media: the macropores and the micropores. Several analytical models have been suggested to characterize such reservoirs. In this work, one of the proposed double-porosity pressure transient models is adopted in the description of the naturally fractured reservoirs. The forward solution component of the analytical model is used to generate the pressure transient data, given the characteristic parameters of the double-porosity reservoirs. The double-porosity systems are characterized by a pressure transient signature which is composed of two semi-log straight lines connected by a transitional curve. The pressure transient responses obtained by the analytical forward solution are subjected to a polynomial fit algorithm so that the aforementioned double-porosity signature can be represented by five polynomial coefficients. These coefficients, the known properties of the double-porosity reservoir, and the reservoir fluid and well parameters constitute the principal input given to the artificial neural network (ANN) during the training phase. The ANN, then, inversely predicts the desired unknown properties of the double-porosity system, namely the permeability of the fracture, the porosity of the matrix, the porosity of the fracture, and the permeability of the matrix. This final development of the ANN is achieved by utilizing this inverse protocol in gradually increasing levels of complexity. The complexity of the problem is elevated by increasing the number of unknown characteristics of the double-porosity system. This research demonstrates the efficiency of the ANN utilization in obtaining the desired properties of the double-porosity reservoirs.

AB - Naturally fractured reservoirs have been studied extensively in the past decades. These reservoirs consist of two distinct porous media: the macropores and the micropores. Several analytical models have been suggested to characterize such reservoirs. In this work, one of the proposed double-porosity pressure transient models is adopted in the description of the naturally fractured reservoirs. The forward solution component of the analytical model is used to generate the pressure transient data, given the characteristic parameters of the double-porosity reservoirs. The double-porosity systems are characterized by a pressure transient signature which is composed of two semi-log straight lines connected by a transitional curve. The pressure transient responses obtained by the analytical forward solution are subjected to a polynomial fit algorithm so that the aforementioned double-porosity signature can be represented by five polynomial coefficients. These coefficients, the known properties of the double-porosity reservoir, and the reservoir fluid and well parameters constitute the principal input given to the artificial neural network (ANN) during the training phase. The ANN, then, inversely predicts the desired unknown properties of the double-porosity system, namely the permeability of the fracture, the porosity of the matrix, the porosity of the fracture, and the permeability of the matrix. This final development of the ANN is achieved by utilizing this inverse protocol in gradually increasing levels of complexity. The complexity of the problem is elevated by increasing the number of unknown characteristics of the double-porosity system. This research demonstrates the efficiency of the ANN utilization in obtaining the desired properties of the double-porosity reservoirs.

UR - http://www.scopus.com/inward/record.url?scp=52049100150&partnerID=8YFLogxK

UR - http://www.scopus.com/inward/citedby.url?scp=52049100150&partnerID=8YFLogxK

M3 - Conference contribution

AN - SCOPUS:52049100150

SN - 9781604238594

VL - 1

SP - 215

EP - 226

BT - Society of Petroleum Engineers - SPE Asia Pacific Oil and Gas Conference and Exhibition 2007 "Resources, Professionalism, Technology

ER -