An Integrated Efficient Approach To Perform IPTT Interpretation

Chen, Xian; Carnegie, A.; Raisi, M.R. Al; Petricola, Mario; Chen, J.

doi:10.2118/88561-ms

Cited by 17 publications

(3 citation statements)

References 32 publications

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“…A complete treatise on the subject is presented by Dr. Fikri Kuchuk, Dr. Onur [3,5] and Dr. A Carnegie [4]. It can also reveal formations characteristics within all the different "spiked areas" observed and marked (green circles) on the density/porosity open hole logs.…”

Section: Vit For Vertical Interference Testingmentioning

confidence: 97%

Fluid Sampling in Carbonates-Challenges and Best Practices

2008

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A heterogeneous carbonate reservoir can be partly evaluated using OH logs but not fully. Even if production testing is used for evaluation, important details can often be overlooked such as individual pressure behavior of thin laminated sections and/or existence of different fluids within the reservoir section itself.Zonal pressure testing and sampling done with dynamic formation testers will more than often fill in the missing gaps and in fact will contribute into optimizing future testing and production for the field under investigation. This is usually achieved by an initial comprehensive pressure evaluation profiling (to obtain reservoir pressures and mobilities) followed immediately (in most cases same run) with a comprehensive formation fluid sampling program, by the end of which a comprehensive picture of individual streaks of interest, in terms of pressures and fluids, has been formed.The employment of Dynamic Formation Testers has nowadays become something of a norm, but the challenges faced in harsh environments can sometimes be daunting. These challenges include operations in extremely tight and overbalanced environments, high solid mud systems, distinction and sampling of formation water in WBM environments or oil in OBM systems, high percentages of H2S formations, long pumping times and stations, collecting representative (single phase) fluid samples and of course environments of high pressures and temperatures.The present paper will discuss the various problems faced with dynamic formation testers in a typical everyday wireline run, in a typical carbonate environment (U.A.E) and discuss a variety of topics that include formation heterogeneity, supercharging, tool options, real-time (RT) monitoring while logging, invasion, thick transition zones and vertical interference tests. Examples and where applicable recommendations to working around these problems are also presented.

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Section: Vit For Vertical Interference Testingmentioning

confidence: 97%

Fluid Sampling in Carbonates-Challenges and Best Practices

2008

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“…Ayan et al 16 and Xian et al 39 provide detailed information about integration of all such sources of data for building a prior model for IPTT interpretation. In this work, although it may not be very realistic, the structural geology and geometry of the system are assumed to be relatively known, i.e., the static model is fixed, and we only consider updating formation properties by history matching IPTT data sets.…”

Section: Mathematical Modelmentioning

confidence: 99%

Estimating Formation Properties in Heterogeneous Reservoirs Using 3D Interval Pressure Transient Test and Geostatistical Data

2005

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TX 75083-3836, U.S.A., fax 01-972-952-9435. ProposalThe medium scale formation heterogeneity (about 1 foot to 100 feet near-wellbore) cannot be usually resolved well by conventional well test data, particularly in vertical direction. Spatial pressure data sets from the interval pressure transient testing (IPTT) along the wellbore measured by using multiprobe and dual packer-probe wireline formation testers (WFT) provide information about near-wellbore heterogeneity. The objective of this work is to examine the use of spatial 3D (three dimensional) IPTT data acquired by dual packer-probe WFTs and geostatistical information for estimating heterogeneous formation properties (e.g. horizontal and vertical permeability) in both lateral and vertical directions along the wellbore. There has been no systematic study in the literature about resolving heterogeneity in horizontal and vertical permeability and porosity from spatial 3D IPTT data. Throughout, formation property and parameter will be used interchangeably.In this study, a 3D single-phase single-well (r-θ-z) numerical flow model (simulator) was developed to simulate the behavior of IPTT measurements in heterogeneous media. Heterogeneity in formation properties is modeled at the gridblock scale by using geostatistics that allows properties to be treated as random regional variables with certain correlation structures. Horizontal and vertical property distributions conditional to IPTT data sets are estimated by using the inverse problem methodology based on Bayesian probability theorem. For estimation of formation parameters (properties) conditional to IPTT spatial data sets and geostatistical model, we minimize the objective function resulting from the application of the Bayesian probability theorem by using the well-known Levenberg-Marquardt (LM) algorithm. The sensitivity coefficients required in the LM † Now with Schlumberger. algorithm are efficiently computed by using the adjoint method. We also show maps of sensitivity coefficients of packer interval and observation probe pressures with respect to parameter distributions (e.g., horizontal/vertical permeabilities and porosities) that offer important evidence about nearwellbore heterogeneities, where formation property distributions might be well resolved by interval pressure transient data. Synthetic examples are presented to show the methodology proposed in this work.

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“…It incorporates the physics of two-phase, axi-symmetric, immiscible fluid flow to simulate the measurements, and is combined with a rigorous nonlinear minimization algorithm for history matching purposes. Comparable inversion approaches have been recently introduced in the open technical literature 3,8,9 but they assume single-phase fluid flow. In addition, the developments considered in this paper integrate the flow simulator with a dynamically-coupled mudcake growth and mud-filtrate invasion algorithm 10 which improves the physical consistency and reliability of the quantitative estimation of both permeability and permeability anisotropy.…”

Section: Introductionmentioning

confidence: 99%

Efficient and Accurate Estimation of Permeability and Permeability Anisotropy from Straddle-Packer Formation Tester Measurements Using the Physics of Two-Phase Immiscible Flow and Invasion

et al. 2005

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractThis paper describes the successful application of a novel methodology to estimate permeability and permeability anisotropy from transient measurements of pressure acquired with a wireline straddle-packer formation tester. Unlike standard algorithms used for the interpretation of formation tester measurements, the methodology developed in this paper rigorously incorporates the physics of two-phase immiscible flow as well as the process of mudcake buildup and invasion. The effects of supercharge, skin, and convective transport of salt are also explicitly included in the estimation algorithm.An efficient 2D (cylindrical coordinates) implicit-pressure explicit-saturation finite-difference algorithm is used to simulate both the process of invasion and the pressure measurements acquired with the straddle-packer formation tester. Initial conditions for the simulation of formation tester measurements are determined by the spatial distributions of pressure and fluid saturation resulting from mud-filtrate invasion. Inversion is performed with a rigorous Levenberg-Marquardt nonlinear minimization algorithm. Sensitivity analyses are conducted to assess non-uniqueness and the impact of assumptions on rock-fluid and mud properties such as fluid viscosity, capillary pressure, relative permeability, mudcake growth, and time of invasion.Applications of the estimation algorithm to noisy synthetic measurements include homogeneous, anisotropic, layered, and multi-layered formations, for both low-and high-porosity rocks. We also study the effect of unaccounted impermeable bed boundaries on the inversion results. For cases where apriori information can be sufficiently constrained, our inversion methodology provides reliable and accurate estimates of permeability and permeability anisotropy.

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An Integrated Efficient Approach To Perform IPTT Interpretation

Cited by 17 publications

References 32 publications

Fluid Sampling in Carbonates-Challenges and Best Practices

Fluid Sampling in Carbonates-Challenges and Best Practices

Estimating Formation Properties in Heterogeneous Reservoirs Using 3D Interval Pressure Transient Test and Geostatistical Data

Efficient and Accurate Estimation of Permeability and Permeability Anisotropy from Straddle-Packer Formation Tester Measurements Using the Physics of Two-Phase Immiscible Flow and Invasion

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