An Experimentally Validated Wormhole Model for Self-Diverting and
Conventional Acids in Carbonate Rocks Under Radial Flow Conditions

Tardy, Philippe Michel Jacques; Lecerf, Bruno; Christanti, Yenny

doi:10.2523/107854-ms

Cited by 15 publications

(14 citation statements)

References 5 publications

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“…The linear PVBT and petrophyscial data reported here can be used first to validate mechanistic models for wormholing, such as the one described by Panga et al 8 or Golfier et al 14 . The radial PVBT can then be obtained by running the model in radial mode 15 . The results could be confirmed initially at least with a few key radial flow experiments.…”

Section: Applicationmentioning

confidence: 99%

The Effect of Pore-Scale Heterogeneities on Carbonate Stimulation Treatments

Ziauddin¹,

Bize²

2007

Proceedings of SPE Middle East Oil and Gas Show and Conference

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractMost carbonate reservoirs are heterogeneous at multiplelength scales. These heterogeneities strongly influence the outcome of acid stimulation treatments which are routinely performed to improve well productivity. However, most previous studies reported in the literature have focused on investigating the effects of injection rate, temperature, and fluid properties and few have focused on the influence of rock properties on stimulation treatments. This study primarily explores the influence of pore scale heterogeneities on stimulation treatments. Some results on the influence of core scale heterogeneities are also presented.Core samples from eight different carbonate rocks were selected for the study. Samples were characterized for mineralogy, texture, fabric, porosity and density distribution using Nuclear Magnetic Resonance (NMR), Computed Tomography (CT) scanning, Scanning Electron Microscopy (SEM), mercury injection as well as resistivity measurements, chemical testing, etc. Each sample was then classified into a Reservoir Rock Type (RRT) which is primarily based on the porosity spatial distribution (PSD) in the carbonate. Each RRT represents a group of carbonate rocks with similar porosity spatial distribution and is expected to exhibit similar behavior to fluid flow and, therefore, to acid dissolutions. The 8 carbonate rocks investigated in this study represent 6 different RRTs.Each carbonate type was treated with reactive fluids. Two different sets of coreflow tests were performed on 6 × 1.5 inch plugs. The first set of experiments involved determination of the evolution of permeability with porosity for the RRT. In these experiments the core was treated at high injection rates with a fluid of low reactivity. Injection at a high flow rate ensured uniform dissolution of the medium. Porosity was monitored by analysis of the effluent and permeability was monitored by the pressure drop across the cores.The second set involved determining the acid breakthrough curves for each of the carbonate types using HCl (hydrochloric acid) as the reacting fluid. The characteristic pore-volume to breakthroughs (PVBT) and the wormhole velocities were obtained for each carbonate by injecting acid at different flow rates.The results of the tests confirm the original hypothesis that the response of the carbonate rock to acid depends on the RRT it belongs to. In other words, rock samples with similar PSD exhibit similar trends in PVBT. The significance of the results to the design of matrix treatments in carbonate reservoirs is discussed.

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Section: Applicationmentioning

confidence: 99%

The Effect of Pore-Scale Heterogeneities on Carbonate Stimulation Treatments

Ziauddin¹,

Bize²

2007

Proceedings of SPE Middle East Oil and Gas Show and Conference

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“…Although several fluid placement simulators are today readily available (e.g., Jones and Davies 1998;Glasbergen and Buijse 2006;Tardy et al 2007;Cohen et al 2010), most of the difficulty to determine an appropriate design stems from the proper evaluation of key input parameters, such as rock characteristics or permeability distribution, which are often not well known. This poor characterization unfortunately leads to situations in which one would not know what to expect once pumping starts, nor even which fluid to use and/or which workflow to implement to efficiently control fluid placement.…”

Section: Introductionmentioning

confidence: 99%

An Innovative Methodology for Real-Time Control and Optimization of Dual Injection Increases Efficiency of Carbonate Stimulation in Horizontal Openhole Water Injectors

Ramondenc

Burgos

Delgado

et al. 2015

Day 2 Mon, December 07, 2015

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An innovative methodology using a new bottomhole flow measurement tool and distributed temperature surveying was used to treat two openhole carbonate water injectors using coiled tubing (CT) equipped with fiber optics. The system capabilities were leveraged to control, in real time, the dual injection process and ensure that the treatment covered the entire horizontal section. The new level of efficiency of this approach was proven in the outstanding results of this stimulation campaign.The method takes advantage of the fiber optics present in a CT string to acquire, in real time, both downhole flow measurements and distributed temperature surveys to identify areas of higher and lower injectivity along the wellbore. It also enables clear and rapid evaluation of the depth to the level that bullheaded fluid would normally reach downhole. The real-time flow measurement is further used to optimize the stages of the treatment that aim at placing fluid across the interval initially poorly covered, as it gives direct feedback of the efficiency of the pumping through the annulus and CT.Matrix stimulation in water injector wells is often handled in a straightforward way by simply bullheading the treatment from surface. Used within the context of horizontal or highly deviated openhole wells, this frequently leads to an overstimulation at the casing shoe or along the first part of the zone of interest, and a significant section of wellbore is poorly covered or even remains untreated. The new approach not only enables visualizing where the treatment fluid goes, it also gives a new level of control of downhole injection, in real time. This new capability was taken advantage of within the context of long horizontal openhole water injectors, whose previous stimulation treatments left untouched a significant portion of the reservoir, even when complementing bullheading by the placement of treatment fluid with CT. The methodology enabled clear identification of which pumping method was beneficial to which interval. It also proved very efficient, leading to an increase in the injectivity index of the wells of nearly threefold, beyond the expectations based on previous stimulation interventions.The new downhole flow measurement tool and its use within this innovative workflow address many limitations usually encountered during the stimulation of horizontal or highly deviated openhole water injectors. In particular, the approach enables taking full advantage of the dual injection process, which often proves difficult to control and optimize in real time. The end result is an unprecedented level of efficiency of the process.

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“…This fluid operates as the sole treating fluid or in combination with other fluids and does not leave any residual formation damage. Diversion and resistance to flow occurs by the development of the diverter's apparent viscosity during acid spending (Tardy, Lecerf & Christanti 2007) (Lungwidtz et al 2004). …”

Section: Introductionmentioning

confidence: 99%

A New Methodology for Stimulation of a High-Water-Cut Horizontal Oil Well through the Combination of a Smart Chemical System with Real-Time Temperature Sensing: A Case Study of South Umm Gudair Field, PZ Kuwait

Al-Najim

Zahedi²,

Al-Khonaini

et al. 2012

All Days

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This paper presents a case study of a matrix acidizing treatment in a well located at the neutral zone between Kuwait and Saudi Arabia, whereby the combination of a "smart fluid" in a stimulation treatment pumped through a Coiled-Tubing (CT) with the real time distributed temperature sensing (DTS) technology helped improve the real-time decision process of fluid placement, temporary plugging placement, and treatment efficiency evaluation. As part of the analysis process and to facilitate the onsite decision-making process, a temperature inversion technique was also used to translate the actual temperature profiles into fluid invasion profiles across the horizontal open-hole section of the well. Additionally, a full scale acid placement and thermal modeling is proposed in order to perform an in-depth post-treatment evaluation. The bottom hole data evaluation further confirmed the benefits of using a smart fluid. Following the treatment, the well produced at a rate of 1500 bbl/day with 17% water cut, which is well below the field average of ~50%.

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An Experimentally Validated Wormhole Model for Self-Diverting and Conventional Acids in Carbonate Rocks Under Radial Flow Conditions

Cited by 15 publications

References 5 publications

The Effect of Pore-Scale Heterogeneities on Carbonate Stimulation Treatments

The Effect of Pore-Scale Heterogeneities on Carbonate Stimulation Treatments

An Innovative Methodology for Real-Time Control and Optimization of Dual Injection Increases Efficiency of Carbonate Stimulation in Horizontal Openhole Water Injectors

A New Methodology for Stimulation of a High-Water-Cut Horizontal Oil Well through the Combination of a Smart Chemical System with Real-Time Temperature Sensing: A Case Study of South Umm Gudair Field, PZ Kuwait

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