Crisman Annual Report 2009 - Harold Vance Department of ...

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Using Downhole Temperature Measurement to Assist Reservoir Characterization and Optimization Introduction Downhole temperature distribution in horizontal wells can be an important source of information that helps us characterize the reservoir and understand the bottom-hole flow conditions. The temperature measurements are obtained from permanent monitoring systems such as downhole temperature gauges and fiber optic sensors. Also, production history and bottomhole pressures are usually readily available and are routinely used for history matching to improve the initial geological models. Combining the downhole temperature distribution and the production history, we can extract more reliable information about the reservoir permeability distribution and bottomhole flow conditions that help us optimize the wellbore performance, particularly in horizontal wells. Objectives We will use a thermal model and a transient, 3D, multiphase flow reservoir model to characterize the reservoir and horizontal well flow profile. Approach Earlier work has shown that downhole temperature interpretation can provide a coarse-scale reservoir permeability distribution (Li and Zhu, 2009). The question we address here is how to incorporate this information for geologic modeling and production history matching. There are two potential approaches, possibly among others. The first is to incorporate the coarse-scale permeability information as ‘secondary’ information while constructing the prior geologic model. This model can then be history matched to further update the geologic model. The second approach would be to include the temperaturederived coarse-scale permeability as a penalty function during the history matching process. We will adopt the former approach. Fig. 1 shows an outline of an integrated approach that combines the temperature interpretation and production history matching for dynamic reservoir characterization and modeling. It includes four major steps as follows: » Use temperature interpretation method to match the observed temperature data, and obtain a coarse-scale permeability distribution. » Generate a high-resolution geologic model constrained to the coarse-scale permeability estimate. This is accomplished using Sequential Gaussian Simulation with Block Kriging, much along the line of seismic data integration into geologic models. » Use the geologic model as the prior model for production history matching. The history matching is carried out using a fast streamline-based approach that is well-suited for the high resolution model. No Project Information 2.4.5 Production Monitoring and Control with Intelligent Technology Related Publications Li, Z. and Zhu, D. Predicting Flow Profile of Horizontal Well by Downhole Pressure and DTS Data for Water-Drive Reservoir. Paper SPE 124873, presented at the 2009 SPE Annual Technical Conference and Exhibition, New Orleans, Louisiana, 4-7 October. Contacts Ding Zhu 979.458.4522 ding.zhu@pe.tamu.edu Zhuoyi Li Temperature interpretation Obtain a coarse-scale perm distribution Downscale the coarsescale permeability via sequential Gaussian simulation with block kriging Temperature data match? Finish Yes Yes Prior geologic model for history matching Forward simulation for reservoir pressure and saturation Calculation of production data misfit Production data match? No Calculation of sensitivity coefficients from streamline Updating permeability via minimizing production data misfit Fig. 1. Integrated workflow for incorporating temperature data into history matching. (continued on next page) CRISMAN INSTITUTE Crisman Annual Report 2009 51
» Use forward modeling of wellbore temperature to cross-check that the history matched model reproduces the temperature data. If the updated model reproduces the wellbore temperature measurements within a pre-specified tolerance, we accept the refined permeability distribution. Otherwise, we go back to step two and repeat the process. Accomplishments We presented several synthetic cases to illustrate the procedure. The results show that with only production history matching without distributed data along the wellbore, the water entry location in horizontal wells cannot be detected satisfactorily. Combining production history matching with the temperature distribution in the wellbore, we can get an improved geological model that can match the production history and also locate the water entry correctly. Based on the downhole flow conditions and the updated geological model, we can now optimize the well performance by controlling the inflow rate distribution, such as shutting the high water inflow sections. Fig.2 shows an example of the procedure developed from this project. Fig. 2. Example of using temperature interpretation and history match to characterize reservoir and downhole flow. 52 Crisman Annual Report 2009
Page 1 and 2: Harold Vance Department of Petroleu
Page 3 and 4: Issue 3, February 2010 Stephen A. H
Page 5 and 6: Combustion Assisted Gravity Drainag
Page 7 and 8: 6 Crisman Annual Report 2009
Page 9 and 10: Summary The Crisman Institute has t
Page 11 and 12: Membership History The Crisman Inst
Page 13 and 14: 12 Crisman Annual Report 2009
Page 15 and 16: An Advisory System for Selecting Dr
Page 17 and 18: A procedure to measure the viscosit
Page 19 and 20: PRISE - Petroleum Resource Investig
Page 21 and 22: Gas Shales Simulation and Productio
Page 23 and 24: Characterization of Rock Transport
Page 25 and 26: An Analytical Approach to Model Sha
Page 27 and 28: P90 P50 P10 Fig. 3. P10, P50 and P9
Page 29 and 30: Density distribution from heat tran
Page 31 and 32: Experimental and Simulation Modelin
Page 33 and 34: Fig. 1. Set up of displacement appa
Page 35 and 36: Study of Solvent-Based Emulsion Inj
Page 37 and 38: Investigation of Hybrid Steam-Solve
Page 39 and 40: Experimental Studies of Steam Injec
Page 41 and 42: Combustion Assisted Gravity Drainag
Page 43 and 44: Well Spacing and Infill Drilling in
Page 45 and 46: Experimental and Numerical Simulati
Page 47 and 48: Enhanced Oil Recovery of Viscous Oi
Page 49 and 50: Alternate Power and Energy Storage/
Page 51: Propagation of Induced Hydraulic Fr
Page 55 and 56: Decision Matrix for Liquid Loading
Page 57 and 58: fractions involved, a detailed sens
Page 59 and 60: Transient Multiphase Sand Transport
Page 61 and 62: Carbonate Heterogeneity and Acid Fr
Page 63 and 64: Fracture Aperture Variation Caused
Page 65 and 66: that contained 12 wt% HCl showed th
Page 67 and 68: Evaluation of Polymer-Based In-Situ
Page 69 and 70: Modeling of Discrete Fracture Netwo
Page 71 and 72: Thermo-Poroelastic Finite Element A
Page 73 and 74: Measurement and Correlation of Gas
Page 75 and 76: The falling body viscometer is sele
Page 77 and 78: Fracture permeability (md) 12 10 8
Page 79 and 80: CO 2 Mobility Control using Cross-L
Page 81 and 82: (a) Standard EnKF for permeability
Page 83 and 84: Aquifer Management for CO 2 Sequest
Page 85 and 86: Bibliography List of Theses and Dis
Page 87 and 88: » Florence, Francois; Validation/E
Page 89 and 90: » Diyashev, Ildar; Problems of Flu
Page 91 and 92: » Freeman, C.M., Ilk, D., Moridis,
Page 93 and 94: and Catalyst. Paper presented at th
Page 95: Exhibition, San Antonio, Texas, 24-

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