scholarly journals Transient Pressure and Pressure Derivative Analysis for Non-Newtonian Fluids

10.5772/50415 ◽  
2012 ◽  
Author(s):  
Freddy Humberto
Keyword(s):  
Newtonian Fluids ◽  
Transient Pressure ◽  
Pressure Derivative ◽  
Derivative Analysis

scholarly journals Pressure and pressure derivative analysis for non-newtonian pseudoplastic fluids in double-porosity formations

2011 ◽  
Vol 4 (3) ◽  
pp. 47-60 ◽  
Author(s):  
Freddy-Humberto Escobar ◽  
Angela-Patricia Zambrano ◽  
Diana-Vanessa Giraldo ◽  
José-Humberto Cantillo
Keyword(s):  
Oil Recovery ◽  
Reservoir Characterization ◽  
Numerical Models ◽  
Simulated Data ◽  
Newtonian Fluids ◽  
Well Testing ◽  
Well Test ◽  
Well Test Analysis ◽  
Pressure Derivative ◽  
Derivative Analysis

Non-Newtonian fluids are often used during various drilling, workover and enhanced oil recovery processes. Most of the fracturing fluids injected into reservoir-bearing formations possess non-Newtonian nature and these fluids are often approximated by Newtonian fluid flow models. In the field of well testing, several analytical and numerical models taking into account Bingham, pseudoplastic and dilatant non-Newtonian behavior have been introduced in the literature to study their transient nature in porous media for a better reservoir characterization. Most of them deal with fracture wells and homogeneous formations and well test interpretation is conducted via the straight-line conventional analysis or type-curve matching. Only a few studies consider the pressure derivative analysis. However, there exists a need of a more practical and accurate way of characterizing such systems. So far, it does not exist any methodology to characterize heterogeneous formation bearing non-Newtonian fluids through of well test analysis.  In this study, an interpretation methodology using the pressure and pressure derivative log-log plot is presented for non-Newtonian fluids in naturally fractured formations, so the dimensionless fracture storativity ratio, ω, and interporosity flow parameter, λ, are obtained from characteristics points found on such plot. The developed equations and correlations are successfully verified by their application only to synthetic well test data since no actual field data are available. A good match is found between the results provided by the proposed technique and the values used to generate the simulated data.  

scholarly journals The Effect of Rheology of Viscoelastic Polymer on Pressure Transient Response in Near-Wellbore Regions

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-12
Author(s):  
Jia Zhang ◽  
Shiqing Cheng ◽  
Jie Zhan ◽  
Qi Han
Keyword(s):  
Shear Thickening ◽  
Shear Thinning ◽  
Polymer Flooding ◽  
High Shear ◽  
Pressure Data ◽  
Transient Pressure ◽  
Pressure Derivative ◽  
Shear Rates ◽  
Viscoelastic Polymer ◽  
Thickening Behavior

Viscoelastic polymer solution shows shear thinning behavior at low shear rates and shear thickening behavior at high shear rates in reservoirs. However, models that ignored shear thickening behavior were commonly employed to interpret transient pressure data derived from tested wells in viscoelastic polymer flooding systems; although, viscoelastic polymer solutions show shear thickening behavior in the near-wellbore region due to high shear rate. To better characterize the oilfield with pressure transient analysis in viscoelastic polymer flooding systems, we developed a numerical model that takes into account both shear thinning behavior and shear thickening behavior. A finite volume method was employed to discretize partially differential flow equations in a hybrid grid system including PEBI mesh and Cartesian grid, and the Newton-Raphson method was used to solve the fully implicit nonlinear system. To illustrate the significance of our model, we compared our model with a model that ignores the shear thickening behavior by graphing their solutions on log-log plots. In the flow regime of near-wellbore damage, the pressure derivative computed by our model is distinctly larger than that computed by the model ignoring shear thickening behavior. Furthermore, the effect of shear thickening behavior on pressure derivative differs from that of near-wellbore damage. We then investigated the influence of shear thickening behavior on pressure derivative with different polymer injection rates, injection rates, and permeabilities. The results can provide a benchmark to better estimate near-wellbore damage in viscoelastic polymer flooding systems. Besides, we demonstrated the applicability and accuracy of our model by interpreting transient pressure data from a field case in an oilfield with viscoelastic polymer flooding treatments.

scholarly journals Pressure Transient Performance for a Horizontal Well Intercepted by Multiple Reorientation Fractures in a Tight Reservoir

Energies ◽  
2019 ◽  
Vol 12 (22) ◽  
pp. 4232 ◽  
Author(s):  
Guoqiang Xing ◽  
Shuhong Wu ◽  
Jiahang Wang ◽  
Mingxian Wang ◽  
Baohua Wang ◽  
...  
Keyword(s):  
Horizontal Well ◽  
Flow Behavior ◽  
Flow Equation ◽  
Finite Conductivity ◽  
Transient Pressure ◽  
Pressure Derivative ◽  
Fracture Conductivity ◽  
Fracture Spacing ◽  
Economic Production ◽  
Tight Reservoir

A fractured horizontal well is an effective technology to obtain hydrocarbons from tight reservoirs. In this study, a new semi-analytical model for a horizontal well intercepted by multiple finite-conductivity reorientation fractures was developed in an anisotropic rectangular tight reservoir. Firstly, to establish the flow equation of the reorientation fracture, all reorientation fractures were discretized by combining the nodal analysis technique and the fracture-wing method. Secondly, through coupling the reservoir solution and reorientation fracture solution, a semi-analytical solution for multiple reorientation fractures along a horizontal well was derived in the Laplace domain, and its accuracy was also verified. Thirdly, typical flow regimes were identified on the transient-pressure curves. Finally, dimensionless pressure and pressure derivative curves were obtained to analyze the effect of key parameters on the flow behavior, including fracture angle, permeability anisotropy, fracture conductivity, fracture spacing, fracture number, and fracture configuration. Results show that, for an anisotropic rectangular tight reservoir, horizontal wells should be deployed parallel to the direction of principal permeability and fracture reorientation should be controlled to extend along the direction of minimum permeability. Meanwhile, the optimal fracture number should be considered for economic production and the fracture spacing should be optimized to reduce the flow interferences between reorientation fractures.

scholarly journals RESERVOIR CHARACTERIZATION USING PRESSURE DERIVATIVE METHOD IN NA-20 WELL SENJA FIELD

PETRO ◽  
2019 ◽  
Vol 7 (3) ◽  
pp. 131 ◽  
Author(s):  
Nadhira Andini ◽  
Muh Taufiq Fathaddin ◽  
Cahaya Rosyidan
Keyword(s):  
Quality Data ◽  
Formation Damage ◽  
Well Test ◽  
Transient Pressure ◽  
Well Test Analysis ◽  
Transient Time ◽  
Pressure Derivative ◽  
Straight Line ◽  
Short Period ◽  
Pressure Analysis

<p><em>Th</em><em>e pressure behaviour of a well can be easily measured and is useful in analysing and predicting reservoir performance or diagnosing the condition of a well. Since a well test and subsequent pressure transient analysis is the most powerful tool available to the reservoir engineer for determining reservoir characteristics, the subject of well test analysis has attracted considerable attention. A well test is the only method available to the reservoir engineer for examining the dynamic response in the reservoir and considerable information can be gained from a well test. A well test is the examination of the transient behaviour of a porous reservoir as the result of a temporary change in production conditions performed over a relatively short period of time in comparison to the producing life of field. The build up can be both the part of the test when the well is shut in and a value represented by the difference in the pressure measured at any time during the build up and the final flowing pressure. The most common megods of transient (time dependant) pressure analysis required that data points be selected such that they fell on a well-defined straight line on either semi-logarithmic or cartesian graph paper. The well test analyst must the insure that the proper straight line has been chosen if more than one line can be drawn through the plotted data. This aspect of interpretation of well test data requires the input of reservoir engineer. Equally important is the design of a well test to ensure that the duration and format of the test is such that it produces good quality data for analysis. The results obtained from transient pressure analysis are used to discover the formation damage by detemining skin. This experiment will be analyzed oil well which is NA-20 well in Senja field. The results from the analysis of the data obtained on NA-20 well is 4.84 mD permeability, skin +1.42, pressure changes due to skin (ΔPskin) 264.384 psi, and flow efficiency 0.842 with 851.61 ft radius of investigation. The result from the analysis of the well showed that NA-20 well in Senja field have formation damage.</em></p>

Pressure and Pressure Derivative Analysis for Linear Homogeneous Reservoirs without using Type-Curve Matching

2004 ◽  
Author(s):  
Freddy H. Escobar ◽  
Nestor F. Saavedra ◽  
Claudia M. Hernandez ◽  
Yuly A. Hernandez ◽  
Juan F. Pilataxi ◽  
...  
Keyword(s):  
Curve Matching ◽  
Pressure Derivative ◽  
Type Curve ◽  
Derivative Analysis

Inflow Performance and Transient Pressure Behavior of Selectively Completed Vertical Wells

1998 ◽  
Vol 1 (05) ◽  
pp. 467-475 ◽  
Author(s):  
Turhan Yildiz ◽  
Yildiray Cinar
Keyword(s):  
Latin American ◽  
Petroleum Engineering ◽  
Transient Pressure ◽  
Vertical Wells ◽  
Pressure Derivative ◽  
Pressure Behavior ◽  
Original Manuscript ◽  
New Interpretation ◽  
Engineering Conference ◽  
Inflow Performance

This paper (SPE 51334) was revised for publication from paper SPE 38973, first presented at the 1997 SPE Latin American and Caribbean Petroleum Engineering Conference, Rio de Janeiro, Brazil, 30 August-3 September. Original manuscript received for review 21 October 1997. Revised manuscript received 12 June 1998. Paper peer approved 24 June 1998. Summary This paper presents new methods to estimate the inflow performance and transient pressure behavior of selectively completed vertical wells. In the first part, inflow performance of wells perforated at several intervals along the producing formation is investigated. It is observed that formation anisotropy, total perforated length/formation thickness ratio, and mechanical skin distribution caused by formation damage are the parameters controlling the well productivity. In the second part, transient pressure and pressure-derivative response of selectively perforated wells are modeled and examined. A new interpretation technique, which combines the conventional semilog straightline analysis and type-curve matching method, is presented to determine reservoir parameters. P. 467

Pressure and Pressure Derivative Analysis without Type-Curve Matching for Triple Porosity Reservoirs

2004 ◽  
Author(s):  
Freddy H. Escobar ◽  
Nestor F. Saavedra ◽  
Gerson D. Escorcia ◽  
John H. Polania
Keyword(s):  
Curve Matching ◽  
Pressure Derivative ◽  
Type Curve ◽  
Derivative Analysis

scholarly journals Pressure and pressure derivative analysis for asymmetry finite-conductivity fractured vertical wells

2017 ◽  
Vol 15 (2) ◽  
pp. 71-78 ◽  
Author(s):  
Freddy Humberto Escobar ◽  
◽  
Alfredo Ghisays-Ruiz ◽  
Cristhian Eduardo Caicedo ◽  
◽  
...  
Keyword(s):  
Finite Conductivity ◽  
Vertical Wells ◽  
Pressure Derivative ◽  
Derivative Analysis

scholarly journals Determination of well-drainage area for power-law fluids by transient pressure analysis

2012 ◽  
Vol 5 (1) ◽  
pp. 45-56 ◽  
Author(s):  
Freddy-Humberto Escobar ◽  
Laura-Jimena Vega ◽  
Luis-Fernando Bonilla
Keyword(s):  
Power Law ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Drainage Area ◽  
Well Test ◽  
Transient Pressure ◽  
Well Test Analysis ◽  
Pressure Derivative ◽  
Oil Companies ◽  
Power Law Fluids

Since conventional oil is almost depleted, oil companies are focusing their efforts on exploiting heavy oil reserves. A modern and practical technique using the pressure and pressure derivative, log-log plot for estimating the well-drainage area in closed and constant-pressure reservoirs, drained by a vertical well is presented by considering a non-Newtonian flow model for describing the fluid behavior. Several synthetic examples were presented for demonstration and verification purposes.Such fluids as heavy oil, fracturing fluids, some fluids used for Enhanced Oil Recovery (EOR) and drilling muds can behave as either Power-law or Bingham, usually referred to as the non-Newtonian fluids. Currently, there is no way to estimate the well-drainage area from conventional well test analysis when a non-Newtonian fluid is dealt with; therefore, none of the commercial well test interpretation package can estimate this parameter (drainage area).

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