Invasion-Based Method For Estimating Permeability From Logs

Semmelbeck, M.E.; Dewan, J.T.; Holditch, Stephen A.

doi:10.2118/30581-ms

Cited by 34 publications

(3 citation statements)

References 11 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Under dynamic conditions, the filtration rate will approach asymptotically a limiting steady-state rate, which depends only on the shear stress at the cake's surface. Semmelbeck et al (1995) combined a filter-cake-buildingand-filtration model with a fluid-flow simulator for computing the fluid-invasion profile along the well. Further improvement of the filter-cake model was presented by Dewan and Chenevert (2001), who demonstrated the derived model's capability to reproduce complex laboratory experiments with sequential changes in dynamic shear rate and overbalance pressure.…”

Section: Introductionmentioning

confidence: 99%

Formation-Damage and Well-Productivity Simulation

et al. 2010

View full text Add to dashboard Cite

In this paper, we describe a simulation model for computing the damage imposed on the formation during overbalanced drilling. The main parts modeled are filter-cake buildup under both static and dynamic conditions; fluid loss to the formation; transport of solids and polymers inside the formation, including effects of porelining retention and pore-throat plugging; and salinity effects on fines stability and clay swelling. The developed model can handle multicomponent water-based-mud systems at both the core scale (linear model) and the field scale (2D radial model). Among the computed results are fluid loss vs. time, internal damage distribution, and productivity calculations for both the entire well and individual sections.The simulation model works, in part, independently of fluidloss experiments (e.g., the model does not use fluid-leakoff coefficients but instead computes the filter-cake buildup and its flow resistance from properties ascribed to the individual components in the mud). Some of these properties can be measured directly, such as particle-size distribution of solids, effect of polymers on fluid viscosity, and formation permeability and porosity. Other properties, which must be determined by tuning the results of the numerical model against fluid-loss experiments, are still assumed to be rather case independent, and, once determined, they can be used in simulations at altered conditions as well as with different mud formulations. A detailed description of the filter-cake model is given in this paper.We present simulations of several static and dynamic fluidloss experiments. The particle-transport model is used to simulate a dilute particle-injection experiment taken from the literature. Finally, we demonstrate the model's applicability at the field scale and present computational results from an actual well drilled in the North Sea. These results are analyzed, and it is concluded that the potential effects of the mechanistic modeling approach used are (a) increased understanding of damage mechanisms, (b) improved design of experiments used in the selection process, and (c) better predictions at the well scale. This allows for a more-efficient and more-realistic prescreening of drilling fluids than traditional core-plug testing. September 2010 SPE Journal Simulation ModelThis section describes the various modules that constitute the newly developed simulation model. The two main parts of the Maximize program are (1) the filter-cake model handling filter-cake buildup and controlling flow into the formation and (2) the reservoir-flow model handling flow inside the formation. The fluids introduced to the formation contain a number of dissolved and dispersed components, which, in turn, may change the original flow properties of the formation through various chemical and physical processes. The retention of solids and polymer is split into a pore-throat-trapping model and a pore-lining-adsorption model. Brine interaction with the rock surface and clays is described by a multicomponent cation-exchange mod...

show abstract

Section: Introductionmentioning

confidence: 99%

Formation-Damage and Well-Productivity Simulation

et al. 2010

View full text Add to dashboard Cite

show abstract

“…In terms of estimating in-situ multiphase fluid flow properties, it should be noted that Tobola and Holditch (1991), Yao and Holditch (1996), Semmelbeck et al (1995), Ramakrishnan and Wilkinson (1997), , Ramakrishnan and Wilkinson (1999), Alpak et al (2004aAlpak et al ( , 2004b, and Salazar et al (2006) have used resistivity measurements from wireline logging to estimate various dynamic formation properties in the filtrateinvaded zone and a few feet beyond. Marlinverno and Torres-Verdin (2000), Charara et al (2002), and Manin et al (2002) also used synthetic time-lapse resistivity data from a permanent array cemented outside of the casing with or without transient pressure measurements to monitor the water-injection fronts, while Alpak et al (2004c) applied the same synthetic data to estimate absolute permeability in different layers.…”

Section: Introductionmentioning

confidence: 99%

Characterization of Reservoir Heterogeneity Through Fluid Movement Monitoring With Deep Electromagnetic and Pressure Measurements

Zhan

Kuchuk

Al-Shahri

et al. 2010

SPE Reservoir Evaluation &Amp; Engineering

View full text Add to dashboard Cite

This paper presents a novel technique to characterize detailed formation heterogeneity for a carbonate reservoir using measurements from electrode resistivity array (ERA), a wireline formation tester, and a permanent downhole pressure sensor. The ERA was installed on tubing in a barefoot well rather than permanently cemented outside the casing as in previous applications. This notable difference provided flexibility for device installation and operation but also introduced particular issues in the ERA data acquisition and interpretation. Furthermore, the ERA measurements were carried out in conjunction with low-salinity water injection and oil and water production in the same well. The primary finding presented in this paper is that the time-lapse ERA voltages near a source electrode showed unique characteristics that represented local formation heterogeneity. This localized sensitivity of ERA data allows detailed characterization of the formation heterogeneity within the length of the ERA string in the vertical direction and about 100 ft laterally around the wellbore. The scale size of the investigated formation heterogeneity is comparable to typical grid sizes used in current reservoir simulations. Models were developed to identify stratified permeability heterogeneities from the time-lapse ERA voltages. The stratified heterogeneity estimated from the ERA measurements was compared to and verified by openhole logs and core analyses data. The final heterogeneous reservoir model from the ERA was subsequently applied to a numerical simulation that integrated the dynamic fluid flow, salt transport, and electrode array responses for monitoring water-front movement and estimating multiphase formation properties. The history matching of the time-lapse ERA data confirmed the first pass estimates of the identified heterogeneities. terization and fluid movement monitoring (Belani et al. 2000;van Kleef et al. 2001). In the present study, the ERA technology was applied to the identification of formation heterogeneity in a typical Middle East carbonate reservoir. The notable difference between

show abstract

“…For the modelling of formation damage due to mud and filtrate invasion, numerical models were developed based on two-phase flow simulations. The first simulations for investigating filtrate invasion 11,12 are for the purpose of improving log interpretation. In these works, well performances were not studied.…”

Section: Introductionmentioning

confidence: 99%

Modelling of Near-Wellbore Formation Damage for Open Hole Horizontal Wells in Anisotropic Media

Ding¹,

Renard²

2003

Proceedings of SPE European Formation Damage Conference

View full text Add to dashboard Cite

TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractIt is well known that formation damage due to drilling fluid has a huge impact on well productivities, especially for open hole completed horizontal wells. To evaluate this impact to keep maximum oil productivity, a numerical model has been developed to simulate formation invasion and damage during the drilling phase of a well. This model can be used to study the impact of various parameters related to drilling fluid properties or drilling conditions on well performances.In previous papers 1,2 , a methodology combining both experimental and numerical approaches has been proposed to model the near-wellbore formation damage for both waterbased mud (WBD) and oil-based mud (OBM) and filter cakes removal by natural clean up procedures. However, anisotropic permeability was not considered, although heterogeneities were taken into account. The main difficulty of near-well modelling of anisotropic media is that the generally recognised elliptic flow behaviour in the well vicinity is not valid as the well cannot be considered as a point (or line) source. Flow behaviour is radial at the wellbore boundary and becomes gradually elliptic when going away from the well. To accurately model near-wellbore formation damage, a new grid system, which is obtained based on elliptic coordinate transformation, is proposed in this paper, and a new numerical scheme is given for the modelling of near-well flow in anisotropic media.The proposed model can be used to study non-uniform formation damage and cleanup results around the well due both to permeability anisotropy and gravity effect. Examples are presented to study sensitivity of various parameters (fluid properties, drilling conditions, …) on well performances. This model is developed for the modelling of horizontal wells as well as slanted wells. It can be used as a tool for well design and construction. Finally, a field example in a deep offshore reservoir is presented to show an application of the developed model.

show abstract

Invasion-Based Method For Estimating Permeability From Logs

Cited by 34 publications

References 11 publications

Formation-Damage and Well-Productivity Simulation

Formation-Damage and Well-Productivity Simulation

Characterization of Reservoir Heterogeneity Through Fluid Movement Monitoring With Deep Electromagnetic and Pressure Measurements

Modelling of Near-Wellbore Formation Damage for Open Hole Horizontal Wells in Anisotropic Media

Contact Info

Product

Resources

About