Fiber Optic Measurements as Real Time PLT with New Transient Interpretation
- Dmitry Kortukov (Schlumberger) | Valery Shako (Schlumberger) | Thibault Pringuey (Schlumberger) | Alexander Savenko (Schlumberger) | Jacques Haus (Schlumberger) | Lev Kotlyar (Schlumberger) | Georgy Malaniya (Schlumberger)
- Document ID
- Society of Petroleum Engineers
- SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition, 29-31 October, Bali, Indonesia
- Publication Date
- Document Type
- Conference Paper
- 2019. Society of Petroleum Engineers
- Transient, PLT, Fiber Optic, Distributed Temperature measurements
- 2 in the last 30 days
- 143 since 2007
- Show more detail
- View rights & permissions
|SPE Member Price:||USD 5.00|
|SPE Non-Member Price:||USD 28.00|
Fiber Optic provides massive amount of information from downhole of the well. But as it is seen in practice, taking this data and converting into something valuable to Operator’s reservoir and production engineers is not straight forward and easy to achieve process. One of the major reasons for this situation is that existing interpretation techniques are mainly based on steady state type of analysis, which provides too many degrees of freedom in interpretation workflow. Respectively, the interpretation outputs have very high level of uncertainty and tuning the results to something sensible requires highly expertized engineer to perform interpretation. This prevented Fiber Optic to become real time PLT tool last several decades since its introduction.
Realized this gap, Schlumberger invested heavily in new concept of interpretation of DTS in production wells, which is based on Pressure-Temperature-Rate Transient Analysis.
Pressure-Temperature-Rate Transient Analysis or PTRA, is a concept of joint quantitative interpretation of full data set of the downhole and surface pressure-temperature-rate data for reservoir characterization and flow profiling. This approach opens a great deal of opportunities for reliable quantitative interpretation of the distributed measurements via adding much higher volume of the data to the interpretation workflow that could not be utilized otherwise with traditional steady-state techniques. One of the benefits is that it enhances the value of Pressure Transient Analysis (an established, robust and reliable reservoir testing tool) by introducing transient local and distributed downhole temperature measurements in the interpretation workflow to reduce uncertainty in the interpretation results and significantly reduce impact of the well-known problem of the non-uniqueness of the inversion.
PTRA involves model-based matching of the field pressure, temperature and rate data (logs and transients) and enables multiphase zonal allocation in wells of all inclinations, quantification of water and gas breakthrough as well as degassing in reservoir. It also enables more accurate injectivity profiling using the model-based match of the continuous DTS data recording while re-injection (hot- or cold-slug), as compared to traditional techniques. PTRA allows to quantify the dynamics of the reservoir properties over the well lifetime and integrate well-centric zonal allocation into multi-well interpretation for large-scale reservoir characterization.
This paper takes us into example of a production well, where we use sensitivity analysis to show level of interpretation uncertainty with conventional Steady State analysis and resulted improvement in interpretation output via applying PTRA analysis for quantitative interpretation of the full wellbore and surface data set recorded over some period of well life.
This example demonstrates how fiber optic data can be finally utilized approaching it to a real-time PLT tool even in horizontal wells, which opens to Reservoir management team new capabilities in maximizing well productions and improving Recovery factors of their assets.
|File Size||1 MB||Number of Pages||19|
Duru, O.O. and Horne, R.N. 2010. Joint Inversion of Temperature and Pressure Measurements for Estimation of Permeability and Porosity Fields. SPE Annual Technical Conference and Exhibition, Florence, Italy, 19–22 September. SPE-134290-MS. http://dx.doi.org/10.2118/134290-MS.
Duru, O.O. and Horne, R.N. 2011. Simultaneous Interpretation of Pressure, Temperature, and Flow-Rate Data Using Bayesian Inversion Methods. SPE Reservoir Evaluation & Engineering. SPE-124827-PA, 14 (2), 225–238. http://dx.doi.org/10.2118/124827-PA.
Duru, O.O. and Horne, R.N. 2011. Combined Temperature and Pressure Data Interpretation: Applications to Characterization of Near-Wellbore Reservoir Structures. SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 30 October–2 November. SPE-146614-MS. http://dx.doi.org/10.2118/146614-MS.
Mao, Y., & Zeidouni, M. (2017, April 23). Temperature Transient Analysis for Characterization of Multilayer Reservoirs with Crossflow. Society of Petroleum Engineers. doi:10.2118/185654-MS
Mao, Y., & Zeidouni, M. (2018, June 22). Transient and Boundary Dominated Flow Temperature Analysis under Variable Rate Conditions. Society of Petroleum Engineers. doi:10.2118/191353-MS
Kortukov, D., & Williams, M. (2019, April 8). Fast-Loop Quantitative Analysis of Proppant Distribution Among Perforation Clusters. Society of Petroleum Engineers. doi:10.2118/195219-MS
Sidorova, M., Shako, V., Pimenov, V., and Theuveny, B. 2015. The Value of Transient Temperature Responses in Testing Operations. SPE Middle East Oil & Gas Show and Conference, Manama, Bahrain, 8–11 March. SPE-172758-MS. http://dx.doi.org/10.2118/172758-MS.
Ramazanov, A., Valiullin, R., Shako, V., Pimenov, V., Sadretdinov, A.(BSU), Fedorov, V., and Belov, K. 2010. Thermal Modeling for Characterization of Near Wellbore Zone and Zonal Allocation. SPE Russian Oil and Gas Conference and Exhibition, Moscow, Russia, 26–28 October. SPE-136256-RU. http://dx.doi.org/10.2118/136256-RU
Valiullin, R., Ramazanov, A., Sadretdinov, A., Sharafutdinov, R., Shako, V., Sidorova, M., and Kryuchatov, D. 2014. Field Study of Temperature Simulators Application for Quantitative Interpretation of Transient Thermal Logging in a Multipay Well. SPE Russian Oil and Gas Exploration & Production Technical Conference and Exhibition, Moscow, Russia, 14–16 October. SPE-171233-MS. http://dx.doi.org/10.2118/171233-MS.
Valiullin, R., Ramazanov, A., Khabirov, T., Sadretdinov, A., Shako V., Kotlyar, L., Sidorova, M., Fedorov V., Salimgareeva, E. 2015. Interpretation of Non-Isothermal Testing Data based on the Numerical Simulation. SPE Russian Petroleum Technology Conference, Moscow, Russia, 26–28 October. SPE 176589-MS. http://dx.doi.org/10.2118/176589-MS.
Sidorova, M., Theuveny, B., Pimenov, V., Shako, V., and Guzman-Garcia, A. G. 2014. Do Not Let Temperature Transients Hinder Your Build-up Pressure Interpretation - Proper Gauge Placement in Highly Productive Reservoirs in Well Testing Operations. SPE Annual Caspian Technical Conference and Exhibition, Astana, Kazakhstan, 12–14 November. SPE-172278-MS. http://dx.doi.org/10.2118/172278-MS.
Sidorova, M., Shako, V., Pimenov, V., and Theuveny, B. 2015. The Value of Transient Temperature Responses in Testing Operations. SPE Middle East Oil & Gas Show and Conference, Manama, Bahrain, 8–11 March. SPE 172758. http://dx.doi.org/10.2118/172758-MS.
Nikolin, I., Dauboin, P., Shako, V., Kotlyar, L., Miklashevskiy, D., & Lovell, J. (2016, October 24). Well Inflow Profiling Verification Using Thermo-Hydrodynamic Modeling. Society of Petroleum Engineers. doi:10.2118/181988-MS
App, J.F. 2009. Field Cases: Nonisothermal Behavior Due to Joule-Thomson and Transient Fluid Expansion/Compression Effects. SPE Annual Technical Conference and Exhibition, New Orleans, Louisiana, USA, 4–7 October. SPE-124338-MS. http://dx.doi.org/10.2118/124338-MS.
App, J.F. 2010. Nonisothermal and Productivity Behavior of High Pressure Reservoirs. SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 21–24 September. SPE-114705-MS, 15 (1), 50–63. http://dx.doi.org/10.2118/114705-MS.
App, J.F. and Yoshioka, K. 2011. Impact of Reservoir Permeability on Flowing Sandface Temperatures; Dimensionless Analysis. SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 30 October–2 November. SPE-146951-MS, 18 (4), 685–694. http://dx.doi.org/10.2118/146951-MS.
App, J.F. 2015. Permeability, Skin and Inflow Profile Estimation from Production Logging Tool Temperature Traces. SPE Annual Technical Conference and Exhibition, Houston, Texas, USA, 28–30 September. SPE-174910-MS. http://dx.doi.org/10.2118/174910-MS.
Sui, W., Zhu, D., Hill, A.D., and Ehlig-Economides, C. 2008. Model for Transient Temperature and Pressure Behavior in Commingled Vertical Wells. SPE Russian Oil and Gas Technical Conference and Exhibition, Moscow, Russia, 28–30 October. SPE-115200-MS. http://dx.doi.org/10.2118/115200-MS.
Sui, W., Zhu, D., Hill, A.D., and Ehlig-Economides, C. 2008. Determining Multilayer Formation Properties from Transient Temperature and Pressure Measurements. SPE Annual Technical Conference and Exhibition, Denver, Colorado, USA, 21–24 September. SPE-116270-MS. http://dx.doi.org/10.2118/116270-MS.
Sui, W., Zhu, D., Hill, A.D., and Ehlig-Economides, C. 2010. Determining Multilayer Formation Properties from Transient Temperature and Pressure Measurements in Commingled Gas Wells. International Oil and Gas Conference and Exhibition in China, Beijing, China, 8–10 June. SPE-131150-MS. http://dx.doi.org/10.2118/131150-MS.
Palabiyik, Y., Tureyen, O.I., and Onur, M. 2015. Pressure and Temperature Behaviors of Single-Phase Liquid Water Geothermal Reservoirs under Various Production/Injection Schemes. Proceedings World Geothermal Congress 2015, Melbourne, Australia, 19–25 April. https://pangea.stanford.edu/ERE/db/WGC/papers/WGC/2015/22008.pdf.
Onur, M. and Çinar, M. 2016. Temperature Transient Analysis of Slightly Compressible, Single-Phase Reservoirs. SPE Europec featured at 78th EAGE Conference and Exhibition, Vienna, Austria, 30 May–2 June. SPE-180074-MS. http://dx.doi.org/10.2118/180074-MS.
Onur, M., & Cinar, M. (2017, June 12). Modeling and Analysis of Temperature Transient Sandface and Wellbore Temperature Data from Variable Rate Well Test Data. Society of Petroleum Engineers. doi:10.2118/185802-MS
Duru, O.O. and Horne, R.N. 2010. Modeling Reservoir Temperature Transients and Reservoir-Parameter Estimation Constrained to the Model. SPE Reservoir Evaluation & Engineering. SPE-115791-PA, 13 (6), 873–883. http://dx.doi.org/10.2118/115791-PA.