Case History Evaluation of RPMs on Conform Fracturing Applications

Santos, José dos; Melo, Ricardo Cesar De; Lullo, Gino Di

doi:10.2523/94352-ms

Cited by 8 publications

(2 citation statements)

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“…inlayer, isothermal, and incompressible flow. The two-phase flow equation in porous media has the following form, in which the starting pressure gradient is considered: (1) and the two phase flow equations in the vertical fracture considering the variable fracture conductivity with time is:…”

Section: Two-phase Flow Equations Of Fractured Oil Wellmentioning

confidence: 99%

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Simulation on the Water Controlling Performance of RPM in Hydraulic Fracturing of Low Permeability Reservoirs

wen¹,

Liu²,

Liu³

et al. 2010

Proceedings of International Oil and Gas Conference and Exhibition in China

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Hydraulic fracturing is the most effective method for improving hydrocarbon production in low or ultra-low permeability oil reservoirs，but the majority of selected wells for fracture stimulation are considered "risky" because of significant water cut increase after stimulation. Relative Permeability Modifiers (RPM) have proven to be an effective method to enhance oil recovery, especially under linear flow conditions achieved after fracturing. However, RPM treatments are not always effective. At present, the evaluation of water controlling performance of RPM is mainly based on the core flow test in lab and the actual water product after RPM treatment and the results can not provide the effective support for the RPM treatments in hydraulic fracturing, especially for low or ultra-low permeability reservoir.In this paper, the interrelations between the water controlling performance of RPM and the main parameters in hydraulic fracturing such as the properties of reservoir matrix, fracture and fluid (reservoir fluid and treatment fluid) etc, were studied using a model. The model is a radial, isothermal, two-phase, multi-component and single layer mathematical model, in which the threshold pressure gradient is considered. Through simulation, we can conclude that the most influential factors in the treatment response, i.e. the water cut reduction, are the combination of polymer adsorption type (kinetic or equilibrium) with method of application of the resistance factors (threshold or variable), resistance factor ratio, reservoir fluid properties, fracture properties and reservoir layout. On the other hand, the polymer solution rheology is not an important factor regarding the treatment response. Hence, the factors that affect the polymer solution viscosity such as shear stress, reservoir salinity and pH are of some importance with respect to drawdown, but they do not have a major influence on the response outcomes in terms of oil recovery.

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Section: Two-phase Flow Equations Of Fractured Oil Wellmentioning

confidence: 99%

“…It can cost as much, if not more, to produce a barrel of water as it does to produce additional hydrocarbons. Water production can also lead to additional costly problems such as scale, corrosions, etc 1 .…”

Section: Introductionmentioning

confidence: 99%

Simulation on the Water Controlling Performance of RPM in Hydraulic Fracturing of Low Permeability Reservoirs

wen¹,

Liu²,

Liu³

et al. 2010

Proceedings of International Oil and Gas Conference and Exhibition in China

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Water Control and Fracturing: A Reality

Mahajan¹,

Rauf²,

Gilmore

et al. 2006

SPE Asia Pacific Oil &Amp; Gas Conference and Exhibition

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Relative-Permeability Modifiers and Their Use in Acid Stimulation in HP/HT Low-Permeability Carbonate Formations: Offshore Mexico Cases

Soriano

Robles

Inda

et al. 2007

Latin American &Amp; Caribbean Petroleum Engineering Conference

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Successful acid stimulation requires a method for diverting an acid across the entire hydrocarbon-producing zone. Because most producing wells are not homogeneous and contain sections of varying permeability, being able to completely acidize the interval is a major problem. This paper describes the use of a new low-viscosity system that uses a relative permeability modifier (RPM) that diverts acid from high-permeability zones to lower-permeability zones and inherently reduces formation permeability to water with little effect on hydrocarbon permeability. This system has been used effectively offshore Mexico with success for more than two years. The cases presented in this paper show the first application in a low-permeability carbonate formation where oil production was increased significantly compared to previous traditional acid treatments using conventional diverters. The other important feature of this work is that the downhole conditions were high-pressure/high-temperature (HPHT). Details from the jobs using this new RPM acid-diversion system will be presented showing pre- and post-job production results. Introduction Matrix acidizing enhances well productivity by reducing the skin factor. The skin factor can be reduced if near-wellbore damage is removed or if a highly conductive structure is superimposed onto the formation. In either case, the result is a net increase in the productivity index, which can be used either to increase the production rate or to decrease the drawdown pressure differential. Although the benefits of an increased production rate are evident, the benefits of reduced drawdown are often overlooked. Decreased drawdown can help prevent formation collapse in weak formations, reduce water or gas coning, minimize both organic and mineral scaling, and/or shift the phase equilibrium in the near-wellbore zone toward smaller fractions of condensate or solution gas. A reduced drawdown pressure can also help ensure that a greater percentage of the completed interval contributes to production.1 In attempts to achieve uniform placement of acid across all layers, various placement techniques have been used.2 The most reliable method uses mechanical isolation devices (such as straddle packers) that allow injection into individual zones one at a time until the entire interval is treated. However, this technique is often not practical, cost-effective, or feasible. Without a packer, some type of diverting agent must be used. Typical diverting agents include ball sealers, degradable particulates, viscous fluids, and foams. Although these agents have been used successfully, all have potential disadvantages and none address the problem of increased water production that often follows acid treatments. Therefore, it would be a major advantage to have a material that could inherently decrease the formation permeability to water while also providing diversion. One method of controlling water production uses dilute polymer solutions to decrease the effective permeability to water more than to oil. These treatments may be referred to as relative permeability modifiers (RPM), disproportionate-permeability modifiers, or simply, bullhead treatments. The latter name is so called because these treatments can be bullheaded into the formation without the need for zonal isolation. RPM systems are thought to perform by adsorption onto the pore walls of the formation flow paths.3–5

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Case History Evaluation of RPMs on Conform Fracturing Applications

Cited by 8 publications

References 0 publications

Simulation on the Water Controlling Performance of RPM in Hydraulic Fracturing of Low Permeability Reservoirs

Simulation on the Water Controlling Performance of RPM in Hydraulic Fracturing of Low Permeability Reservoirs

Water Control and Fracturing: A Reality

Relative-Permeability Modifiers and Their Use in Acid Stimulation in HP/HT Low-Permeability Carbonate Formations: Offshore Mexico Cases

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