The Experts below are selected from a list of 5010 Experts worldwide ranked by ideXlab platform
J L Pletcher - One of the best experts on this subject based on the ideXlab platform.
-
improvements to reservoir material balance methods
Spe Reservoir Evaluation & Engineering, 2002Co-Authors: J L PletcherAbstract:Summary Experience with material-balance data sets from the field and from simulation has revealed some procedures that can be used to improve analysis of both oil and gas reservoirs: Failure to account for a weak waterdrive can result in significant material-balance errors. The assertion of previous authors that weak waterdrive exhibits a negative slope on the Cole (gas) and Campbell (oil) plots has been confirmed. A weak waterdrive is much more unambiguous on these plots than on commonly used plots, such as the p/z plot for gas. A modified version of the Cole plot is proposed to account for Formation Compressibility. The reservoir drive indices are a useful tool for determining the correctness of the material-balance solution because they must sum to unity. The drive indices should never be normalized to sum to unity because this obscures their usefulness and leads to a false sense of security. A modified version of the Roach plot (for gas) is proposed that improves interpretation in some waterdrive situations. Material balance has not been replaced by reservoir simulation; rather, it is complementary to simulation and can provide valuable insights to reservoir performance that cannot be obtained by simulation.
-
improvements to reservoir material balance methods
SPE Annual Technical Conference and Exhibition, 2000Co-Authors: J L PletcherAbstract:Experience with a number of material balance data sets from the field and from simulation has revealed some procedures that can be used to improve analysis of both oil and gas reservoirs: ○ Failure to account for a weak water drive can result in material balance errors that are not insignificant. ○ The assertion of previous authors that a weak water drive exhibits a negative slope on the Cole Plot (gas) and Campbell Plot (oil) has been confirmed. A weak water drive is detected on these plots much more unambiguously than on other common plots such as the p/z plot for gas. ○ A Modified version of the Cole Plot is proposed to account for Formation Compressibility. ○ The reservoir drive indices are a useful tool for determining the correctness of the material balance solution because they must sum to 1.0. The drive indices should never be normalized to sum to 1.0 because this obscures their usefulness and leads to a false sense of security. ○ A modified version of the Roach Plot (for gas) is proposed that improves interpretation in some water drive situations. ○ Material balance has not been replaced by reservoir simulation, rather it is complementary to simulation and can provide valuable insights to reservoir performance that cannot be obtained by simulation.
Ali Ghalambor - One of the best experts on this subject based on the ideXlab platform.
-
Log-based rock Compressibility estimation for Asmari carbonate Formation
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Rahman Ashena, Peter Behrenbruch, Ali GhalamborAbstract:Rock Compressibility has many applications in the upstream petroleum industry, for example, reservoir material balance calculations and geomechanics, as related to possible Formation compaction and subsidence. When measurements on core are not available, empirical correlations may need to be considered, derived for specific fields. In the study presented, the suitability of the log-based method for evaluating rock Compressibility is investigated, with the aim of deriving a suitable correlation for Asmari carbonate, Southwest Iran. A stepwise log-based method of rock Compressibility determination is presented, including the construction of a geomechanical earth model, MEM. In comparing a log approach with core-derived results, it was found that the log-based method showed a rather reliable estimation of pore Compressibility for carbonates studied, except for intervals with extremely large wellbore washout. Although the selected procedure is similar to that used for sandstone by other researchers, involving in some cases complex procedures, a relatively good matching result could be obtained with a relatively simple procedure. To validate the results from this study, a comparison of Compressibility values is made with several industry correlations. An application of Formation Compressibility for estimating possible Formation compaction and associated subsidence is also presented. However, a minimal effect is indicated in this case, as the carbonates studied are rather consolidated. In summary, this study presents a new correlation for rock Compressibility for Southwestern Iranian carbonate oilfields (Asmari carbonate), validating the applicability of a log-based technique.
Rahman Ashena - One of the best experts on this subject based on the ideXlab platform.
-
Log-based rock Compressibility estimation for Asmari carbonate Formation
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Rahman Ashena, Peter Behrenbruch, Ali GhalamborAbstract:Rock Compressibility has many applications in the upstream petroleum industry, for example, reservoir material balance calculations and geomechanics, as related to possible Formation compaction and subsidence. When measurements on core are not available, empirical correlations may need to be considered, derived for specific fields. In the study presented, the suitability of the log-based method for evaluating rock Compressibility is investigated, with the aim of deriving a suitable correlation for Asmari carbonate, Southwest Iran. A stepwise log-based method of rock Compressibility determination is presented, including the construction of a geomechanical earth model, MEM. In comparing a log approach with core-derived results, it was found that the log-based method showed a rather reliable estimation of pore Compressibility for carbonates studied, except for intervals with extremely large wellbore washout. Although the selected procedure is similar to that used for sandstone by other researchers, involving in some cases complex procedures, a relatively good matching result could be obtained with a relatively simple procedure. To validate the results from this study, a comparison of Compressibility values is made with several industry correlations. An application of Formation Compressibility for estimating possible Formation compaction and associated subsidence is also presented. However, a minimal effect is indicated in this case, as the carbonates studied are rather consolidated. In summary, this study presents a new correlation for rock Compressibility for Southwestern Iranian carbonate oilfields (Asmari carbonate), validating the applicability of a log-based technique.
M J Akhtar - One of the best experts on this subject based on the ideXlab platform.
-
differentiating Formation Compressibility and water influx effects in overpressured gas reservoirs
Spe Reservoir Engineering, 1994Co-Authors: S W Poston, H Y Chen, M J AkhtarAbstract:Numerous authors have presented studies of overpressured gas reservoirs that are based on a particular model. Effects of pressure- and time-dependent Formation Compressibility, shale or aquifer water influx, or solution gas in the water are usually included, with varying degrees of emphasis and simplifying assumptions. However, a straightforward method to evaluate performance from overpressured gas reservoirs has never been presented. The authors present a rearranged form of the material-balance equation that provides such a method. Roach arranged the material-balance equation that includes the effect of Formation Compressibility for an overpressured gas reservoir in a new form. References cited in this paper showed the utility of this method to predict future performance. Field case history studies illustrated the usefulness of this plotting technique when studying partial-waterdrive gas reservoirs. In this paper, the authors show how this technique may be used not only to estimate OGIP, effective Compressibility, and water-influx values but also to interpret how each of these variables affects the reservoir performance history.
Peter Behrenbruch - One of the best experts on this subject based on the ideXlab platform.
-
Log-based rock Compressibility estimation for Asmari carbonate Formation
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Rahman Ashena, Peter Behrenbruch, Ali GhalamborAbstract:Rock Compressibility has many applications in the upstream petroleum industry, for example, reservoir material balance calculations and geomechanics, as related to possible Formation compaction and subsidence. When measurements on core are not available, empirical correlations may need to be considered, derived for specific fields. In the study presented, the suitability of the log-based method for evaluating rock Compressibility is investigated, with the aim of deriving a suitable correlation for Asmari carbonate, Southwest Iran. A stepwise log-based method of rock Compressibility determination is presented, including the construction of a geomechanical earth model, MEM. In comparing a log approach with core-derived results, it was found that the log-based method showed a rather reliable estimation of pore Compressibility for carbonates studied, except for intervals with extremely large wellbore washout. Although the selected procedure is similar to that used for sandstone by other researchers, involving in some cases complex procedures, a relatively good matching result could be obtained with a relatively simple procedure. To validate the results from this study, a comparison of Compressibility values is made with several industry correlations. An application of Formation Compressibility for estimating possible Formation compaction and associated subsidence is also presented. However, a minimal effect is indicated in this case, as the carbonates studied are rather consolidated. In summary, this study presents a new correlation for rock Compressibility for Southwestern Iranian carbonate oilfields (Asmari carbonate), validating the applicability of a log-based technique.