An Analytical Study of Interference in Composite Reservoirs

1985 ◽  
Vol 25 (02) ◽  
pp. 281-290 ◽  
Author(s):  
Abdurrahman Satman
Keyword(s):  
Pressure Drop ◽  
Composite System ◽  
Pressure Response ◽  
Oil Field ◽  
Observation Well ◽  
Wellbore Storage ◽  
Interference Test ◽  
Interference Tests ◽  
Inner Region ◽  
Observation Wells

Satman, Abdurrahman; SPE; Technical U. of Istanbul Abstract This paper discusses the interference test in composite reservoirs. The composite model considers all important parameters of interest: the hydraulic diffusivity, the mobility ratio, the distance to the radial discontinuity, the distance between wells, the wellbore storage, and skin effect at the active well. Type curves expressed as a function of proper combinations of these parameters are presented. Introduction Interference tests are widely used to estimate the reservoir properties. An interference test is a multiwell test that requires at least one active well, either a producer or injector, and at least one observation well. During the test, pressure effects caused by the active well are measured at the shut-in observation wells. Basic techniques for analyzing interference tests in uniform systems are discussed in Ref. 1. Usually, type-curve matching is the preferred technique for analyzing the pressure data from the test. Early interference test studies assumed that the storage capacity of the active well and the skin region around the sandface have a negligible effect on the observation well response. Recently, investigators have focused on wellbore storage and skin effects. Tongpenyai and Raghavan presented a new solution for analyzing the pressure response at the presented a new solution for analyzing the pressure response at the observation well, which took into account the effects of wellbore storage and skin at both the active and the observation wells. They produced type curves expressed as a function of exp(2S) products, the ( / ) ratios, and ( / ) to correlate the pressure response at the observation well. Composite systems are encountered in a wide variety of reservoir situations. In a composite system, there is a circular inner region with fluid and rock properties different from those in the outer region. Such a system can occur in hydrocarbon reservoirs and geothermal reservoirs. The injection of fluids during EOR processes can cause the development of fluid banks around the injection wells. This would be true in the case of a in-situ combustion or a steamflood. In a geothermal reservoir, pressure reduction in the vicinity of the well may cause the phase boundaries. A producing well completed in the center of a circular hot zone surrounded by producing well completed in the center of a circular hot zone surrounded by a concentric cooler water region is also a composite system. During the early to late 1960's, there was great interest in the composite reservoir flow problem. Hurst discussed the "sands in series" problem. He presented the formulas to describe the pressure behavior of problem. He presented the formulas to describe the pressure behavior of the unsteady-state flow phenomenon for fluid movement through two sands in series in a radial configuration, with each sand of different permeability. Mortada studied the interference pressure drop for oil fields located in a nonuniform extensive aquifer comprising two regions of different properties. He presented an expression for the interference pressure drop properties. He presented an expression for the interference pressure drop in an oil field resulting from a constant rate of water influx in another oil field. Loucks and Guerrero presented a qualitative discussion of pressure drop characteristics in composite reservoirs. Ramey and Rowan and pressure drop characteristics in composite reservoirs. Ramey and Rowan and Clegg developed approximate solutions. Refs. 11 through 13 also discuss composite reservoir systems and present either analytical or numerical solutions. Composite system model solutions have been used to determine some critical parameters during the application of EOR processes. The formation of a fluid bank around the injection well makes the reservoir a composite system. Van Poollen and Kazemi discussed how to determine the mean distance to the radial discontinuity in an in-situ combustion project. Refs. 16 and 17 discuss the effect of radial discontinuity in interpretation of pressure falloff tests in reservoirs with fluid banks. Sosa et al. examined the effect of relative permeability and mobility ratio on falloff behavior in reservoirs with water banks. The presence of different temperature zones in nonisothermal reservoirs may resemble permeability boundaries during well testing. Mangold et al. presented a numerical study of a thermal discontinuity in well test analysis. Their results indicated that nonisothermal influence could be detected and accounted for by tests of sufficient duration with suitably placed observation wells. Horne et al. indicated the possibility of determining compressibility and permeability contrasts across the phase boundaries in geothermal reservoirs. The most recent study of well test analysis in composite reservoirs was by Eggenschwiler, Satman et al. Their studies presented a very general composite system model. The problem was solved analytically by using the Laplace transformation with numerical inversion. The solution concerned the transient flow of a slightly compressible fluid in a porous medium during injection or falloff for a single well confined in concentric regions of differing mobilities and hydraulic diffusivities. The system assumed both wellbore storage and a skin effect. Their results indicated that a pseudosteady-state pressure response exists in the transition region between the inner region and outer region semilog straight lines. This response is drawn on a Cartesian vs. plot, the slope of which is used to estimate the bulk volume of the inner region. SPEJ p. 281

The Influence of Vertical Fractures Intercepting Active and Observation Wells on Interference Tests

1982 ◽  
Vol 22 (06) ◽  
pp. 933-944 ◽  
Author(s):  
Naelah A. Mousli ◽  
Rajagopal Raghavan ◽  
Heber Cinco-Ley ◽  
Fernando Samaniego-V.
Keyword(s):  
Test Data ◽  
A Priori ◽  
Pressure Response ◽  
Fracture Plane ◽  
Observation Well ◽  
Compass Orientation ◽  
Vertical Fracture ◽  
Wellbore Storage ◽  
Interference Test ◽  
Observation Wells

Abstract This paper reviews pressure behavior at an observation well intercepted by a vertical fracture. The active well was assumed either unfractured or intercepted by a fracture parallel to the fracture at the observation well. We show that a vertical fracture at the observation well has a significant influence on the pressure response at that well, and therefore wellbore conditions at the observation well must be considered. New type curves presented can be used to determine the compass orientation of the fracture plane at the observation well. Conditions are delineated under which the fracture at the observation well may influence an interference test. This information should be useful in designing and analyzing tests. The pressure response curve at the observation well has no characteristic features that will reveal the existence of a fracture. The existence of the fracture would have to be known a priori or from independent measurements such as single-well tests. Introduction In this work, we examine interference test data for the influence of a vertical fracture located at the observation well. All studies on the subject of interference testing have been directed toward understanding the effects of reservoir heterogeneity or wellbore conditions at the active (flowing) well. Several correspondents suggested our study because many field tests are conducted when the observation well is fractured. They also indicated that it is not uncommon for both wells (active and observation) to be fractured. To the best of our knowledge, this is the first study to examine the influence of a vertical fracture at the observation well on interference test data. Two conditions at the active well are examined: an active well that is unfractured (plane radial flow) and an active well that intercepts a vertical fracture parallel to the fracture at the observation well. The parameters of interest include effects of the distance between the two wells, compass orientation of the fracture plane with respect to the line joining the two wellbores, and the ratio of the fracture lengths at the active and observation wells if both wells are fractured. The results given here should enable the analystto interpret the pressure response at the fractured observation well.to interpret the pressure response when both the active and the observation wells are fracturedto design tests to account for the existence of a fracture at one or both wells, andto determine quantitatively the orientation and/or length of the fracture at an observation well. We also show that one should not assume a priori that the effect of a fracture on the observation well response will be similar to that of a concentric skin region around the wellbore-i.e., idealizations to incorporate the existence of the fracture, such as the effective wellbore radius concept, may not be applicable. Mathematical Model and Assumptions In this study, we consider the flow of a slightly compressible fluid of constant viscosity in a uniform and homogeneous porous medium of infinite extent. Fluid is produced at a constant surface rate at the active well. Wellbore storage effects are assumed negligible because the main objective of our work is to demonstrate the influence of the fractures. However, note that wellbore storage effects may mask the early-time response at the observation well. Refs. 1 and 2 discuss the influence of wellbore storage on interference test data. We obtained the solutions to the problems considered here by the method of sources and sinks. The fracture at the observation well was assumed to be a plane source of infinite conductivity. SPEJ P. 933^

Pressure Response at Observation Wells in Fractured Reservoirs

1984 ◽  
Vol 24 (06) ◽  
pp. 628-638 ◽  
Author(s):  
C.C. Chen ◽  
N. Yeh ◽  
R. Raghavan ◽  
A.C. Reynolds
Keyword(s):  
Fractured Reservoirs ◽  
Pressure Response ◽  
Fracture System ◽  
Unsteady State ◽  
Fractured Reservoir ◽  
Observation Well ◽  
Naturally Fractured ◽  
The Matrix ◽  
Interference Test ◽  
Observation Wells

Abstract This work examines interference test data in a naturally fractured reservoir. The reservoir model examined here assumes that the reservoir can be represented by a system of horizontal fractures that are separated by the matrix. This model is identical to the deSwaan-Kazemi model. The main contribution of our work is that we combine the parameters of interest in a simple way and present solutions that can be used directly for field application. These solutions can be used to design or analyze interference tests. We also compare the solution for unsteady-state flow in the matrix with the Warren-Root model, which assumes pseudosteady-state fluid flow in the matrix. Introduction This work examines the pressure response at an observation well in a fractured reservoir. Previous works by Kazemi et al. and Streltsova-Adams have examined the pressure response based on the Warren and Root model. In this work, however, we assume unsteady-state fluid transfer from the matrix to the fracture system. We consider the model proposed by deSwaan and Kazemi. This model assumes that the fractured reservoir can be replaced by an equivalent set of horizontal fractures separated by matrix elements (Fig. 1). The results of this study, however, can be applied to other unsteady-state models proposed in the literature. The main contribution of this work is that type curves convenient for analyzing data are presented. We have combined the parameters of interest and correlated results in terms of dimensionless groups that are commonly used in well test analysis. A comprehensive discussion of the pressure behavior at an observation well in a fractured reservoir is presented. Procedures to analyze data by conventional semilog methods also are discussed. New observations on the pressure response at an observation well are presented. For purposes of comparison, we also examined the pressure response in a reservoir that obeys the Warren and Root idealization. Assumptions and Mathematical Model The mathematical model considered here assumes the flow of a slightly compressible (of constant viscosity) fluid in a naturally fractured reservoir. We assume that the matrix-fracture geometry is as shown in Fig. 1. Individually, the fractures and the matrix are assumed to be homogeneous, uniform, and isotropic porous media with distinct properties. Gravitational forces are assumed negligible. The reservoir is assumed to be infinitely large-i.e., the outer boundaries have no effect on the pressure response. The initial condition assumes that the pressure is constant at all points in the reservoir. We assume that the flowing well produces at a constant rate and that the two wells both penetrate the fracture system. In addition, we impose four fundamental assumptions:all production is from the fracture system,flow in the matrix system is one-dimensional-i.e., in the z direction (see Fig. 1),flow in the fracture system is radial, andboth the producing and observation wells are line source wells and wellbore storage and skin effects are neglected. Assumptions 1, 2, and 3 have been used extensively in previous studies of naturally fractured reservoirs. Recent results of Reynolds et al. indicate that these assumptions are valid for the model considered in Fig. 1 if the flow capacity of the matrix system is small relative to the flow capacity of the fracture system (see Ref. 9 for specific details). Assumption 4 is used in virtually all studies of interference testing. (A comprehensive discussion of the influence of wellbore storage and skin effects on interference test data is given in Refs. 10 and 11.) It is important to realize that flee preceding four assumptions (see 2 in particular) imply that the pressure response at the observation well will be equal to the pressure response in the fracture system at the point where the observation well intersects the fractured system. All results given in this study are based on dimensionless variables for purposes of convenience. The dimensionless variables are defined as follows. The dimensionless pressure drop in the reservoir is ...............(1) Here, is the permeability of the fracture system and is the total thickness of the fracture system. If the model of Fig. 1 contains horizontal fractures, then = where is the thickness of each horizontal fracture. The term represents the surface flow rate, is the formation volume factor, is the viscosity of the fluid, and ( ) is the pressure at point at time . The subscript f refers to the fracture. All quantities are expressed in SPE-preferred SI metric units. SPEJ P. 628^

Methods To Obtain Quick Estimates of Formation Parameters in Interference Tests Derived From Features of the Line-Source Solution—Theory and Application

2013 ◽  
Vol 16 (01) ◽  
pp. 29-39
Author(s):  
Pierre-David Maizeret
Keyword(s):  
Line Source ◽  
Time Lag ◽  
Early Time ◽  
Integral Function ◽  
Pressure Response ◽  
Well Test ◽  
Diagnostic Plot ◽  
Single Well ◽  
Interference Test ◽  
Interference Tests

Summary Interference testing is the oldest, but still the most effective, way of establishing communication between wells and determining the interwell-reservoir transmissibility. Yet these tests are not run frequently because often the results are difficult to analyze as a result of unforeseen complications. This paper presents practical methods derived from the properties of the line-source solution that is used to design and interpret effective interference tests. In single-well transient tests, early-time features of the exponential integral function occur too early to be observed. However, these features appear much later in an interference test and can be used in an observation well to estimate the storativity and transmissibility ratios of the reservoir. The pressure response and the log derivative of the pressure intersect on the log-log diagnostic plot, and the pressure response itself exhibits an inflection point. With these characteristics, simple geometrical methods are proposed to estimate reservoir parameters. Moreover, a new expression of the “lag time,” or delay in the response, is formulated. The particular case of falloff or buildup is studied in detail, because the time lag in the reservoir response can bring extra information. A field example is included to demonstrate the application of these methods to actual data and their usefulness to a practicing well-test engineer.

Analysis of Interference Tests with Horizontal Wells

2005 ◽  
Vol 8 (04) ◽  
pp. 337-347 ◽  
Author(s):  
Mohammed N. Al-Khamis ◽  
Erdal Ozkan ◽  
Rajagopal S. Raghavan
Keyword(s):  
Horizontal Well ◽  
Horizontal Wells ◽  
Observation Point ◽  
Integral Solution ◽  
Observation Well ◽  
Vertical Wells ◽  
Exponential Integral ◽  
Test Analysis ◽  
Interference Test ◽  
Interference Tests

Summary One of the common assumptions in horizontal-well interference-test analysis is to ignore fluid flow in and out of the horizontal observation well and represent it by a point. In some cases, the active well is also approximated by a vertical line source. Using a semianalytical model, this paper answers three fundamental questions:• What is the critical distance between the wells to represent the horizontal observation well by an observation point?• Where should the observation point be placed along the horizontal well?• Under what conditions may the active well be approximated by a vertical line source and the exponential integral solution be used to analyze observation-well responses? Two correlations are presented to simplify the analysis of horizontal-well interference tests. Example applications are presented, and error bounds are documented. Introduction Analysis of horizontal-well interference tests is an extremely difficult problem because the lengths, orientations, locations, and distances between wells need to be considered. One of the assumptions used to make the horizontal-well interference-test analysis a tractable problem is to ignore the flow pattern that results because of the existence of the horizontal well and to treat the horizontal observation well as an observation point. It also has been suggested that if the distance between the two wells were sufficiently large, then the active horizontal well could be replaced by a vertical well. In this case, the observation-well responses may be approximated by the exponential integral solution, and the analysis is reduced to the conventional interference-test analysis between vertical wells. For the application of the approximate analytical techniques, two questions need to be answered. The first question is whether the distance between the two horizontal wells is large enough for the geometry of the wells to be ignored. Malekzadeh investigated this question by considering the interference between a horizontal active well and a vertical observation well in an isotropic reservoir. Because anisotropy has a major effect on the pressure-transient responses of horizontal wells, the results of Malekzadeh have limited applicability. In addition, the influence of the geometry of the observation well cannot be deduced from the model used by Malekzadeh. The second question is, where should the equivalent observation point (EOP)be placed in the reservoir if the horizontal well were to be replaced by a vertical well? This question has yet to be addressed in the literature. The EOP is defined as the location at which the pressure recorded at the heel of the horizontal observation well would exist in the absence of the observation well. Because of the lack of theoretical guidance, the physical location of the heel or the center of the observation well is usually chosen as the observation point.1 But such an assumption ignores the fact that fluids enter and leave the horizontal observation well although there is no surface production. Therefore, some disturbance of equipotential lines around the observation well should be expected. Thus, if the horizontal well were to be removed from the system, we may expect the pressure recorded at the heel of the horizontal well to exist at a different location. The location of the EOP would be a function of the variables that determine pressure at the observation well. This work uses a semianalytical model to answer the above questions. The model has been discussed in detail in Refs. 4 and 5 and is capable of considering interference between two horizontal wells in a homogeneous but anisotropic reservoir. Based on the results of the semianalytical model, two correlations have been developed to significantly simplify the analysis of horizontal-well interference tests without sacrificing accuracy. The first correlation provides the location of the EOP, which has not been available in the literature. The second correlation provides information on the distance under which both horizontal wells may be treated as vertical wells and the exponential integral solution may be used to analyze the interference test. Compared with the correlation presented by Malekzadeh, the correlation presented here is more comprehensive because it accounts for the effects of anisotropy, location of the EOP, and relative position of the wells. To assess the adequacy of the correlations, error bounds have been calculated and are documented in this paper. The correlations enable us to analyze horizontal-well interference tests by the single-horizontal-well solutions or by the exponential integral solution. The convenience of the single-horizontal-well models for the regression techniques used in well-test-analysis software becomes clear if the computational complexity of the rigorous horizontal-well interference-test models4,5 is noted (the increase in the speed of computations is usually more than six-fold).

Simultaneous Measuring Method for Both Volumetric Flow Rates of Air-Water Mixture Using a Turbine Flowmeter

1996 ◽  
Vol 118 (1) ◽  
pp. 29-35 ◽  
Author(s):  
K. Minemura ◽  
K. Egashira ◽  
K. Ihara ◽  
H. Furuta ◽  
K. Yamamoto
Keyword(s):  
Pressure Drop ◽  
Flow Rate ◽  
Volumetric Flow Rate ◽  
Oil Field ◽  
Liquid Density ◽  
Water Mixture ◽  
Rotor Speed ◽  
Flow Rates ◽  
Field Development ◽  
Turbine Flowmeter

A turbine flowmeter is employed in this study in connection with offshore oil field development, in order to measure simultaneously both the volumetric flow rates of air-water two-phase mixture. Though a conventional turbine flowmeter is generally used to measure the single-phase volumetric flow rate by obtaining the rotational rotor speed, the method proposed additionally reads the pressure drop across the meter. After the pressure drop and rotor speed measured are correlated as functions of the volumetric flow ratio of the air to the whole fluid and the total volumetric flow rate, both the flow rates are iteratively evaluated with the functions on the premise that the liquid density is known. The evaluated flow rates are confirmed to have adequate accuracy, and thus the applicability of the method to oil fields.

Low-Cost Measurement of Hydraulic Fracture Dimensions Using Pressure Data in Treatment and Observation Wells – A Workflow for Every Well

2021 ◽  
Author(s):  
A. Kirby Nicholson ◽  
Robert C. Bachman ◽  
R. Yvonne Scherz ◽  
Robert V. Hawkes
Keyword(s):  
Hydraulic Fracturing ◽  
Real Time ◽  
Hydraulic Fracture ◽  
Full Scale ◽  
Pressure Data ◽  
Observation Well ◽  
High Quality ◽  
Fracture Length ◽  
Geometry Model ◽  
Observation Wells

Abstract Pressure and stage volume are the least expensive and most readily available data for diagnostic analysis of hydraulic fracturing operations. Case history data from the Midland Basin is used to demonstrate how high-quality, time-synchronized pressure measurements at a treatment and an offsetting shut-in producing well can provide the necessary input to calculate fracture geometries at both wells and estimate perforation cluster efficiency at the treatment well. No special wellbore monitoring equipment is required. In summary, the methods outlined in this paper quantifies fracture geometries as compared to the more general observations of Daneshy (2020) and Haustveit et al. (2020). Pressures collected in Diagnostic Fracture Injection Tests (DFITs), select toe-stage full-scale fracture treatments, and offset observation wells are used to demonstrate a simple workflow. The pressure data combined with Volume to First Response (Vfr) at the observation well is used to create a geometry model of fracture length, width, and height estimates at the treatment well as illustrated in Figure 1. The producing fracture length of the observation well is also determined. Pressure Transient Analysis (PTA) techniques, a Perkins-Kern-Nordgren (PKN) fracture propagation model and offset well Fracture Driven Interaction (FDI) pressures are used to quantify hydraulic fracture dimensions. The PTA-derived Farfield Fracture Extension Pressure, FFEP, concept was introduced in Nicholson et al. (2019) and is summarized in Appendix B of this paper. FFEP replaces Instantaneous Shut-In Pressure, ISIP, for use in net pressure calculations. FFEP is determined and utilized in both DFITs and full-scale fracture inter-stage fall-off data. The use of the Primary Pressure Derivative (PPD) to accurately identify FFEP simplifies and speeds up the analysis, allowing for real time treatment decisions. This new technique is called Rapid-PTA. Additionally, the plotted shape and gradient of the observation-well pressure response can identify whether FDI's are hydraulic or poroelastic before a fracture stage is completed and may be used to change stage volume on the fly. Figure 1Fracture Geometry Model with FDI Pressure Matching Case studies are presented showing the full workflow required to generate the fracture geometry model. The component inputs for the model are presented including a toe-stage DFIT, inter-stage pressure fall-off, and the FDI pressure build-up. We discuss how to optimize these hydraulic fractures in hindsight (look-back) and what might have been done in real time during the completion operations given this workflow and field-ready advanced data-handling capability. Hydraulic fracturing operations can be optimized in real time using new Rapid-PTA techniques for high quality pressure data collected on treating and observation wells. This process opens the door for more advanced geometry modeling and for rapid design changes to save costs and improve well productivity and ultimate recovery.

Correlation and Interpretation of Microseismic Responses using Pressure Measurements in Offset Observation Wells

2015 ◽  
Author(s):  
Robert Downie ◽  
Joel Le Calvez ◽  
Barry Dean ◽  
Jeff Rutledge
Keyword(s):  
Surface Pressure ◽  
Source Parameters ◽  
Reservoir Pressure ◽  
Pressure Measurements ◽  
Observation Well ◽  
Fracture Pressure ◽  
Microseismic Data ◽  
Pressure Depletion ◽  
Microseismic Events ◽  
Observation Wells

Abstract Interpretation of the microseismic data acquired during hydraulic fracture treatments is based on a variety of techniques that make use of the locations, times, and source parameters of the detected events, in conjunction with the stimulation treatment data. It is sometimes possible to observe trends or changes in the microseismic data that correspond to the surface pressure measurements; however this aspect of interpretation becomes problematic due the variability of fluid friction, slurry density, perforation restrictions, and other near-wellbore pressures when computing bottom hole fracturing pressure. An interpretation technique is proposed that uses pressure measurements in observation wells that are offset to the treatment well during microseismic interpretations. The observation well can be any well with open perforations in close proximity to the treatment well. The observation well pressures are not affected by the many complicating factors that are encountered when estimating pressure in the fracture from the surface pressure measured in the treatment well. Example data from field observations are used to demonstrate that the detection of microseismic events near an observation well and corresponding detection of fluid pressure from the fracture in the observation well validates the calculated event locations. The relationship between fracture pressure, the state of stress, and microseismic responses is discussed using Mohr-Coulomb failure criteria. Observation-well pressures and microseismic events are also used to identify instances where reservoir pressure depletion near the observation well affects surface operations at the treatment well. The results of the study show that reliable measurements of fracture pressure for use in microseismic interpretations can be obtained from offset observation wells, and where reservoir pressure depletion causes deviations from expected fracture behavior. The results also show that microseismic responses are directly related to fracture pressure, and not simply the presence of fracturing fluid itself, leading to an improved understanding of the conditions under which microseismic events occur.

Toward Controllable Infill Completions Using Frac-Driven Interactions FDI Data

2021 ◽  
Author(s):  
Yuzhe Cai ◽  
Arash Dahi Taleghani
Keyword(s):  
Pressure Fluctuations ◽  
Pressure Response ◽  
Sudden Increase ◽  
Short Period ◽  
Coupled Geomechanics ◽  
Multi Phase ◽  
Shale Oil Reservoirs ◽  
Pressure Changes ◽  
Observation Wells ◽  
Bottomhole Pressure

Abstract Infill completions have been explored by many operators in the last few years as a strategy to increase ultimate recovery from unconventional shale oil reservoirs. The stimulation of infill wells often causes pressure increases, known as fracture-driven interactions (FDIs), in nearby wells. Studies have generally focused on the propagation of fractures from infill wells and pressure changes in treatment wells rather than observation wells. Meanwhile, studies regarding the pressure response in the observation (parent) wells are mainly limited to field observations and conjecture. In this study, we provide a partialcorrective to this gap in the research.We model the pressure fluctuations in parent wells induced by fracking infill wells and provide insight into how field operators can use the pressure data from nearby wells to identify different forms of FDI, including fracture hit (frac-hit) and fracture shadowing. First,we model the trajectory of a fracture propagating from an infill well using the extended finite element methods (XFEM). This method allows us to incorporatethe possible intersection of fractures independent of the mesh gridding. Subsequently, we calculate the pressure response from the frac-hit and stress shadowing using a coupled geomechanics and multi-phase fluid flow model. Through numerical examples, we assess different scenarios that might arise because of the interactions between new fractures and old depleted fractures based on the corresponding pressure behavior in the parent wells. Typically, a large increase in bottomhole pressure over a short period is interpreted as a potential indication of a fracture hit. However, we show that a slower increase in bottomhole pressure may also imply a fracture hit, especially if gas repressurization was performed before the infill well was fracked. Ultimately, we find that well storage may buffer the sudden increase in pressure due to the frac-hit. We conclude by summarizing the different FDIs through their pressure footprints.

Numerical Method of Estimating Distance Between Wells

2021 ◽  
Author(s):  
Ayobami Ezekiel ◽  
Prince Oduh ◽  
Emmanuel Okoh ◽  
Collins Onah ◽  
Michael Ojah ◽  
...  
Keyword(s):  
Integral Equation ◽  
Pressure Drop ◽  
Polynomial Equation ◽  
Important Variable ◽  
Well Testing ◽  
Model Calculations ◽  
New Approach ◽  
Pressure Drops ◽  
Quantum Leap ◽  
Interference Test

Abstract In this study, a simpler numerical model for calculating inter-well distance was developed. This model was developed as an alternative to the Ei-function used for computing pressure drops. The mainobjective of developing this model is tomake resolution of pilfering issues easyto resolve. With the developed model, calculations relating to pressure drops and more specifically, inter-well distance, can be done with greater ease and accuracy. In developing this model, the integral equation of the Eifunction in the pressure drop equation was solved numerically. The numerical solution reduced thepressure drop equation to a polynomial equation which is much easier to solve. The developed model was used to solve real problems. Results generated from it were compared with those obtained using previous approaches. Important informationsuch as well configuration, region of the reservoir, and transient history wherethe work is valid are stated. The development of the correlations and tables forthe range of validity and values of the Ei-function is a major quantum leap in well testing and analysis. It will be quite cumbersome to resolve integrals with unknowns, hence, methods of trials and errors have been resorted to over the years. However, this new approach resolved the pressure drop equation into a systemof polynomials which is much easier to solve. Consequently, the distance betweenpossibly interfering wells (which is an important variable during interference test) can now be gotten with ease. The developed model is valid within the range of validity of the Ei-function. Without doubt, this work will help redefine the pressure drop equation into a polynomial equation which can easily be resolved using any of the known approaches to solving problems involving polynomials. More so, getting the correct distance betweenthe two wells in question is pivotal to the test. With the model developed in this work, getting inter-well distance is now easier and more accurate.

Performance evaluation of an Indoxyl Sulfate Assay Kit “NIPRO”

2019 ◽  
Vol 57 (11) ◽  
pp. 1770-1776 ◽  
Author(s):  
Yuki Fushimi ◽  
Junko Tatebe ◽  
Yuko Okuda ◽  
Toshiaki Ishii ◽  
Shinji Ujiie ◽  
...  
Keyword(s):  
High Performance ◽  
Limit Of Detection ◽  
Cardiorenal Syndrome ◽  
Indoxyl Sulfate ◽  
Analytical Performance ◽  
Limit Of Quantitation ◽  
Interference Test ◽  
Interference Tests ◽  
The Relationship ◽  
Method R

Abstract Background The relationship between renal disease and cardiovascular disease (CVD) is currently known as cardiorenal syndrome. Indoxyl sulfate (IS) is one of the uremic toxins that accelerates the progression of cardiorenal syndrome. This report presents a new method for measuring IS in a simpler way. Methods We evaluated the analytical performance of an IS Assay Kit “NIPRO” loaded on LABOSPECT 008. The evaluated analytical performances included accuracy, precision, dilution linearity, limit of detection (LOD), limit of quantitation (LOQ), recovery test, interference test and comparison against assays performed by high-performance liquid chromatography (HPLC). Results Total precision showed a <5.3% coefficient of variation at IS concentrations of 3.57–277.73 μmol/L, and satisfactory results were observed in the dilution linearity, LOD, LOQ, recovery and interference tests. The IS Assay Kit “NIPRO” showed a high correlation with the HPLC conventional method (r = 0.993). Conclusions The IS Assay Kit “NIPRO” demonstrated satisfactory analytical performance, and this suggests it could shortly become another common method to measure circulating IS.

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