Determining Reservoir Model Based on Welltest Analysis for Production Forecasting

Harry Budiharjo Sulistyarso

doi:doi:10.11648/j.ajset.20210604.12

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Determining Reservoir Model Based on Welltest Analysis for Production Forecasting

Harry Budiharjo Sulistyarso

Published in American Journal of Science, Engineering and Technology (Volume 6, Issue 4)

Received: 30 August 2021 Accepted: 11 October 2021 Published: 19 October 2021

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Abstract

Welltest analysis is basically an analysis of fluid flow behavior in porous rocks, both in oil reservoirs and gas reservoirs that aim to obtain reservoir characteristics. Welltest analysis is not only limited to get reservoir characteristics and well productivity, but to determine the reservoir and boundary models that are close to the real situation. Until now, to determine the reservoir and boundary models are usually assisted by using a simulator, which is called modeling. However, to determine the reservoir and boundary models has its own challenges, because there are no specific methods or equations that can know for certain the model of a reservoir. Choosing the right type of model also requires some consideration, such as seismic data, geological data, log data, and information provided from other wells drilled into the same formation. From the determination of this model can be used as supporting information for a reservoir, which is then used to be a predictive model and renewal of its geological model, as well as allowing engineers to simulate production estimates. In this paper, we will present an analysis of determining the right reservoir model based on welltest analysis, which selected model is used to simulate production estimates. Case example is taken from an oil well named "HBR-05", which has been carried out a pressure build-up test on one productive layer that until now has not been produced or closed since the well testing was carried out. From the determination of the reservoir model based on welltest analysis, obtained heterogeneous anisotropic reservoir model and rectangular-no flow boundary model. The selected reservoir model is used to simulate the estimated production of the "HBR-05" well if it is produced from this layer. Production forecasting results for 48 months (4 years) the "HBR-05" well, the cumulative production is 107.8 Mbbl. In addition, the results of forecasting show that the reservoir pressure is already below the bubble point pressure in the 22nd month of forecasting.

Published in	American Journal of Science, Engineering and Technology (Volume 6, Issue 4)
DOI	10.11648/j.ajset.20210604.12
Page(s)	94-104
Creative Commons	This is an Open Access article, distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution and reproduction in any medium or format, provided the original work is properly cited.
Copyright	Copyright © The Author(s), 2021. Published by Science Publishing Group

Keywords

Pressure Derivatives, Matching, Modeling, Production Forecasting, Analysis

References

[1]	Horne, Roland N. 1990. “Modern Well Test Analysis”. United State of America. Petroway, Inc. pp. 19-20, 44.
[2]	Bahrami, H. 2004. “Well Test Analysis in a Layered Reservoir Using Geological Model”. Iran. Paper presented at 9th Iranian Chemical Engineering Congress, November 23-25. pp. 1-2.
[3]	Chaudhry, Amanat U. 2004. “Oil Well Testing Handbook”. Elsevier Inc. Houston, Texas. pp. 523.
[4]	Issaka, M. B., K. Zaoral, A. K. Ambastha, and L. Mattar. 2000. "Determination of Horizontal Permeability Anisotropy from Horizontal Well Tests". Dahran, Saudi Arabia. Paper presented at the 2000 SPE Saudi Arabia Section Technical Symposium, October 21–23. pp. 2.
[5]	Guira, Bendekim, Djebbar Tiap, and Freddy H. Escobar. 2002. “Pressure Behavior of a Well in an Anisotropic Reservoir”. USA. Paper presented at the SPE Western Regional/AAPG Pacific Section Joint Meeting, Anchorage, Alaska, May 2002. pp. 2.
[6]	Aguilera, Roberto F. 1980. “Naturally Fractured Reservoirs, Second Edition”. Oklahoma. Pennwell Publishing Company. pp. 4-6.
[7]	Velazquez, Rodolfo Camacho, Mario A. Vasquez-Cruz, Rafael Castrejon-Aivar, and Victor Arana-Ortiz. 2005. “Pressure Transient and Decline Curve Behaviors in Naturally Fractured Vuggy Carbonate Reservoirs”. SPE Res Eval & Eng 8 (02): 95–112. pp. 1-2.
[8]	Wang, Shuhua, Mingxu Ma, Menglu Lin, and Shengnan Chen. 2015. “Approximate Analytical Pressure Studies on Dual Porosity Reservoirs with Stress-sensitive Permeability”. Spain. Paper presented at the EUROPEC 2015, Madrid, Spain, June 2015. Pp. 1-2.
[9]	Warren, J. E and P. J. Root. 1963. "The Behavior of Naturally Fractured Reservoirs". Society of Petroleum Engineers Inc. SPEJ 426. pp. 2-3.
[10]	Al-Ajmi, Nab M., Hossein Kazemi, and Erdal Ozkan. 2008. “Estimation of Storativity Ratio in a Layered Reservoir With Crossflow”. SPE Res Eval & Eng 11 (02): 267–279. pp. 1-2.
[11]	Brown, L. P. 1985. “Pressure Transient Behavior of the Composite Reservoir”. Nevada. Paper presented at the SPE Annual Technical Conference and Exhibition, Las Vegas, Nevada, September 1985. pp. 1-2.
[12]	Ahmed, Tarek., Paul D. McKinney. 2005. “Advanced Reservoir Engineering”. Elsevier, Inc. Houston, Texas. pp. 1-72.
[13]	Cobanoglu, Mustafa. 2020. “Revealing of False Response of Constant Pressure Boundary Model for Gas Reservoir Pressure Transient Analysis PTA Enabled in Increased and Realistic in-Place Estimation: A Case Study Using Two Field Data”. UAE. Paper presented at the Abu Dhabi International Petroleum Exhibition & Conference, Abu Dhabi, UAE, November 2020. pp. 2.
[14]	Bourdet, Dominique. 2002. “Well Test Analysis: The Use of Advanced Interpretation Models”. Amsterdam, The Netherlands. Elsevier Science B. V. pp. 117, 161, 180-183, 206.
[15]	Lee, John, John B. Rollins, and John P. Spivey. 2003. "Pressure Transient Testing SPE Textbook Series, Vol. 9”. Texas. Henry L. Doherty Memorial Fund of AIME, Society of Petroleum Engineers. pp. 101.

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APA Style

Harry Budiharjo Sulistyarso. (2021). Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. American Journal of Science, Engineering and Technology, 6(4), 94-104. https://doi.org/10.11648/j.ajset.20210604.12

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Harry Budiharjo Sulistyarso. Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. Am. J. Sci. Eng. Technol. 2021, 6(4), 94-104. doi: 10.11648/j.ajset.20210604.12

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AMA Style

Harry Budiharjo Sulistyarso. Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. Am J Sci Eng Technol. 2021;6(4):94-104. doi: 10.11648/j.ajset.20210604.12

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@article{10.11648/j.ajset.20210604.12,
  author = {Harry Budiharjo Sulistyarso},
  title = {Determining Reservoir Model Based on Welltest Analysis for Production Forecasting},
  journal = {American Journal of Science, Engineering and Technology},
  volume = {6},
  number = {4},
  pages = {94-104},
  doi = {10.11648/j.ajset.20210604.12},
  url = {https://doi.org/10.11648/j.ajset.20210604.12},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ajset.20210604.12},
  abstract = {Welltest analysis is basically an analysis of fluid flow behavior in porous rocks, both in oil reservoirs and gas reservoirs that aim to obtain reservoir characteristics. Welltest analysis is not only limited to get reservoir characteristics and well productivity, but to determine the reservoir and boundary models that are close to the real situation. Until now, to determine the reservoir and boundary models are usually assisted by using a simulator, which is called modeling. However, to determine the reservoir and boundary models has its own challenges, because there are no specific methods or equations that can know for certain the model of a reservoir. Choosing the right type of model also requires some consideration, such as seismic data, geological data, log data, and information provided from other wells drilled into the same formation. From the determination of this model can be used as supporting information for a reservoir, which is then used to be a predictive model and renewal of its geological model, as well as allowing engineers to simulate production estimates. In this paper, we will present an analysis of determining the right reservoir model based on welltest analysis, which selected model is used to simulate production estimates. Case example is taken from an oil well named "HBR-05", which has been carried out a pressure build-up test on one productive layer that until now has not been produced or closed since the well testing was carried out. From the determination of the reservoir model based on welltest analysis, obtained heterogeneous anisotropic reservoir model and rectangular-no flow boundary model. The selected reservoir model is used to simulate the estimated production of the "HBR-05" well if it is produced from this layer. Production forecasting results for 48 months (4 years) the "HBR-05" well, the cumulative production is 107.8 Mbbl. In addition, the results of forecasting show that the reservoir pressure is already below the bubble point pressure in the 22nd month of forecasting.},
 year = {2021}
}

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TY  - JOUR
T1  - Determining Reservoir Model Based on Welltest Analysis for Production Forecasting
AU  - Harry Budiharjo Sulistyarso
Y1  - 2021/10/19
PY  - 2021
N1  - https://doi.org/10.11648/j.ajset.20210604.12
DO  - 10.11648/j.ajset.20210604.12
T2  - American Journal of Science, Engineering and Technology
JF  - American Journal of Science, Engineering and Technology
JO  - American Journal of Science, Engineering and Technology
SP  - 94
EP  - 104
PB  - Science Publishing Group
SN  - 2578-8353
UR  - https://doi.org/10.11648/j.ajset.20210604.12
AB  - Welltest analysis is basically an analysis of fluid flow behavior in porous rocks, both in oil reservoirs and gas reservoirs that aim to obtain reservoir characteristics. Welltest analysis is not only limited to get reservoir characteristics and well productivity, but to determine the reservoir and boundary models that are close to the real situation. Until now, to determine the reservoir and boundary models are usually assisted by using a simulator, which is called modeling. However, to determine the reservoir and boundary models has its own challenges, because there are no specific methods or equations that can know for certain the model of a reservoir. Choosing the right type of model also requires some consideration, such as seismic data, geological data, log data, and information provided from other wells drilled into the same formation. From the determination of this model can be used as supporting information for a reservoir, which is then used to be a predictive model and renewal of its geological model, as well as allowing engineers to simulate production estimates. In this paper, we will present an analysis of determining the right reservoir model based on welltest analysis, which selected model is used to simulate production estimates. Case example is taken from an oil well named "HBR-05", which has been carried out a pressure build-up test on one productive layer that until now has not been produced or closed since the well testing was carried out. From the determination of the reservoir model based on welltest analysis, obtained heterogeneous anisotropic reservoir model and rectangular-no flow boundary model. The selected reservoir model is used to simulate the estimated production of the "HBR-05" well if it is produced from this layer. Production forecasting results for 48 months (4 years) the "HBR-05" well, the cumulative production is 107.8 Mbbl. In addition, the results of forecasting show that the reservoir pressure is already below the bubble point pressure in the 22nd month of forecasting.
VL  - 6
IS  - 4
ER  -

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Author Information

Harry Budiharjo Sulistyarso

Petroleum Engineering Department, Faculty of Mineral Technology, Universitas Pembangunan Nasional Veteran Yogyakarta, Daerah Istimewa Yogyakarta, Indonesia

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APA Style

Harry Budiharjo Sulistyarso. (2021). Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. American Journal of Science, Engineering and Technology, 6(4), 94-104. https://doi.org/10.11648/j.ajset.20210604.12

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ACS Style

Harry Budiharjo Sulistyarso. Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. Am. J. Sci. Eng. Technol. 2021, 6(4), 94-104. doi: 10.11648/j.ajset.20210604.12

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AMA Style

Harry Budiharjo Sulistyarso. Determining Reservoir Model Based on Welltest Analysis for Production Forecasting. Am J Sci Eng Technol. 2021;6(4):94-104. doi: 10.11648/j.ajset.20210604.12

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@article{10.11648/j.ajset.20210604.12,
  author = {Harry Budiharjo Sulistyarso},
  title = {Determining Reservoir Model Based on Welltest Analysis for Production Forecasting},
  journal = {American Journal of Science, Engineering and Technology},
  volume = {6},
  number = {4},
  pages = {94-104},
  doi = {10.11648/j.ajset.20210604.12},
  url = {https://doi.org/10.11648/j.ajset.20210604.12},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ajset.20210604.12},
  abstract = {Welltest analysis is basically an analysis of fluid flow behavior in porous rocks, both in oil reservoirs and gas reservoirs that aim to obtain reservoir characteristics. Welltest analysis is not only limited to get reservoir characteristics and well productivity, but to determine the reservoir and boundary models that are close to the real situation. Until now, to determine the reservoir and boundary models are usually assisted by using a simulator, which is called modeling. However, to determine the reservoir and boundary models has its own challenges, because there are no specific methods or equations that can know for certain the model of a reservoir. Choosing the right type of model also requires some consideration, such as seismic data, geological data, log data, and information provided from other wells drilled into the same formation. From the determination of this model can be used as supporting information for a reservoir, which is then used to be a predictive model and renewal of its geological model, as well as allowing engineers to simulate production estimates. In this paper, we will present an analysis of determining the right reservoir model based on welltest analysis, which selected model is used to simulate production estimates. Case example is taken from an oil well named "HBR-05", which has been carried out a pressure build-up test on one productive layer that until now has not been produced or closed since the well testing was carried out. From the determination of the reservoir model based on welltest analysis, obtained heterogeneous anisotropic reservoir model and rectangular-no flow boundary model. The selected reservoir model is used to simulate the estimated production of the "HBR-05" well if it is produced from this layer. Production forecasting results for 48 months (4 years) the "HBR-05" well, the cumulative production is 107.8 Mbbl. In addition, the results of forecasting show that the reservoir pressure is already below the bubble point pressure in the 22nd month of forecasting.},
 year = {2021}
}

Copy | Download

TY  - JOUR
T1  - Determining Reservoir Model Based on Welltest Analysis for Production Forecasting
AU  - Harry Budiharjo Sulistyarso
Y1  - 2021/10/19
PY  - 2021
N1  - https://doi.org/10.11648/j.ajset.20210604.12
DO  - 10.11648/j.ajset.20210604.12
T2  - American Journal of Science, Engineering and Technology
JF  - American Journal of Science, Engineering and Technology
JO  - American Journal of Science, Engineering and Technology
SP  - 94
EP  - 104
PB  - Science Publishing Group
SN  - 2578-8353
UR  - https://doi.org/10.11648/j.ajset.20210604.12
AB  - Welltest analysis is basically an analysis of fluid flow behavior in porous rocks, both in oil reservoirs and gas reservoirs that aim to obtain reservoir characteristics. Welltest analysis is not only limited to get reservoir characteristics and well productivity, but to determine the reservoir and boundary models that are close to the real situation. Until now, to determine the reservoir and boundary models are usually assisted by using a simulator, which is called modeling. However, to determine the reservoir and boundary models has its own challenges, because there are no specific methods or equations that can know for certain the model of a reservoir. Choosing the right type of model also requires some consideration, such as seismic data, geological data, log data, and information provided from other wells drilled into the same formation. From the determination of this model can be used as supporting information for a reservoir, which is then used to be a predictive model and renewal of its geological model, as well as allowing engineers to simulate production estimates. In this paper, we will present an analysis of determining the right reservoir model based on welltest analysis, which selected model is used to simulate production estimates. Case example is taken from an oil well named "HBR-05", which has been carried out a pressure build-up test on one productive layer that until now has not been produced or closed since the well testing was carried out. From the determination of the reservoir model based on welltest analysis, obtained heterogeneous anisotropic reservoir model and rectangular-no flow boundary model. The selected reservoir model is used to simulate the estimated production of the "HBR-05" well if it is produced from this layer. Production forecasting results for 48 months (4 years) the "HBR-05" well, the cumulative production is 107.8 Mbbl. In addition, the results of forecasting show that the reservoir pressure is already below the bubble point pressure in the 22nd month of forecasting.
VL  - 6
IS  - 4
ER  -

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