Novel Acid-Diversion Technique for Matrix Acidizing in Production and Injection Wells: Case Histories of Alger

Kritsanaphak, Kritsana; Vasquez, Julio Estuardo

doi:10.2523/15223-ms

Cited by 4 publications

(1 citation statement)

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“…To restore injectivity, methods such as acidzing can be employed (e.g. Moore et al 1959, Suzuki et al 1991, Kritsanaphak & Vasquez 2012. It is often found that it is more economically attractive to operate above the formation parting pressure to ensure stable injectivity.…”

Section: Introductionmentioning

confidence: 99%

Simulation of Polymer Injection under Fracturing Conditions - A Field Pilot in the Matzen Field, Austria

Zechner

Clemens

Suri³

et al. 2014

SPE Improved Oil Recovery Symposium

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Polymer flooding leads to enhanced oil recovery by accelerating oil production and improving sweep efficiency. However, owing to the higher viscosity, injectivity of polymer solutions is of some concern and is important to understand to predict incremental oil recoveries. Achieving high polymer injection rates is required to increase oil production rates.In the field test performed in the Matzen field (Austria), polyacrylamide polymers have been injected for the past two years. Core flood experiments with these polymers showed a significant increase in apparent viscosity due to the viscoelastic properties of the polymer solutions. Also, severe degradation of the polymer solution at high flow velocities was detected. In addition to core flood experiments, flow experiments through fractures were performed. In these experiments, shear-thinning and limited degradation of the polymer solution was observed and quantified.Detailed polymer injection simulations were conducted that included complex polymer rheology in the fractures and the matrix. The reservoir stress changes and its effects on the fractures were also taken into account due to cold polymer injection. The results of the simulations matched the field data both for water floods and polymer test floods.The simulations revealed two distinct phases during injection of the polyacrylamide polymer solution (1) injection under matrix conditions in an early phase resulting in severe degradation of the polymers and (2) injection under fracturing conditions once the formation parting pressure is reached, leading to limited degradation of the polymers.The calibrated model was used to investigate the impact of polymer rheology and particle plugging on injectivity and fracture growth.The results of the field test and the simulations indicate that screening of fields for polyacrylamide polymer projects need to include geomechanical properties of the reservoir sand and cap/base rock in addition to the conventional parameters used in the simulations such as oil viscosity, water salinity, reservoir temperature and reservoir permeability. Furthermore, it is shown that water quality is crucial for polymer EOR operations.

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Section: Introductionmentioning

confidence: 99%

Simulation of Polymer Injection under Fracturing Conditions - A Field Pilot in the Matzen Field, Austria

Zechner

Clemens

Suri³

et al. 2014

SPE Improved Oil Recovery Symposium

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Simulation of Polymer Injection Under Fracturing Conditions—An Injectivity Pilot in the Matzen Field, Austria

Zechner

Clemens

Suri

et al. 2015

SPE Reservoir Evaluation &Amp; Engineering

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Summary Polymer flooding leads to enhanced oil recovery by accelerating oil production and improving sweep efficiency. However, because of the higher viscosity, the injectivity of polymer solutions is of some concern and is important to understand to predict incremental oil recoveries. Achieving high polymer-injection rates is required to increase oil-production rates. In the field test performed in the Matzen field (Austria), polyacrylamide polymers were injected for the past 2 years. Coreflood experiments with these polymers showed a significant increase in apparent viscosity because of the viscoelastic properties of the polymer solutions. Also, severe degradation of the polymer solution at high flow velocities was detected. In addition to coreflood experiments, flow experiments through fractures were performed. In these experiments, shear thinning and limited degradation of the polymer solution were observed and quantified. Detailed polymer-injection simulations were conducted that included complex polymer rheology in the fractures and the matrix. The reservoir stress changes and their effects on the fractures were also taken into account as a result of cold-polymer injection. The results of the simulations matched the field data both for waterfloods and polymer-test floods. The simulations revealed two distinct phases during the injection of the polyacrylamide-polymer solution: Injection under matrix conditions in an early phase resulting in severe degradation of the polymers Injection under fracturing conditions after the formation parting pressure is reached, leading to limited degradation of the polymers The calibrated model was used to investigate the impact of polymer rheology and particle plugging on injectivity and fracture growth. The results of the field test and the simulations indicate that screening of fields for polyacrylamide-polymer projects needs to include geomechanical properties of the reservoir sand and cap/base rock in addition to the conventional parameters used in screening such as oil viscosity, water salinity, reservoir temperature, and reservoir permeability.

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Damage Remediation in a Mature Field Reservoir by Applying a Customized Treatment Using Surface Active Additives and Diversion Technologies: Case Histories from San Francisco Field

Lucuara

Campo

Sepulveda

et al. 2016

SPE International Conference and Exhibition on Formation Damage Control

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This paper discusses successful damage remediation performed in more than 10 wells in a mature oil field producing under a developed waterflooding project in Colombia. The primary damage mechanism observed is associated with a detriment to production related to reduced relative permeability caused by wettability preferences.A chemical treatment was proposed that consisted of crude oil with efficient and effective surface active additives, such as microemulsions (MEs) and/or formation mobility modifiers (FMMs) and associative polymers (APs) for a proper diversion. The treatment was proposed as an effective method to restore near-wellbore (NWB) permeability in or through the damaged zone in the formation, resulting in production recovery. All matrix-stimulation treatments were conducted rigless by means of an annulus without affecting the artificial lift method and resulted in a significant time and cost savings.Laboratory data confirmed the ability of the MEs and FMMs to modify interfacial tensions (IFTs) and contact angles. These materials helped promote a change in the degree of wetting of the system, which is dependent on the adhesion tension (the product of the IFT by the cosine of the contact angle). During well treatments, surface pressure spikes during the diversion stages were associated with the arrival of the APs at the perforations and were clearly observed during the development of the treatments, revealing that effective diversion was achieved. Finally, post-stimulation treatment data have shown positive results, confirming the effectiveness of combining these technologies. This paper discusses how the synergy of using surface active additives with diversion technologies can yield productivity increase in mature oil reservoirs and improve the level of sustainability of current field production.

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Novel Acid-Diversion Technique for Matrix Acidizing in Production and Injection Wells: Case Histories of Alger

Cited by 4 publications

References 0 publications

Simulation of Polymer Injection under Fracturing Conditions - A Field Pilot in the Matzen Field, Austria

Simulation of Polymer Injection under Fracturing Conditions - A Field Pilot in the Matzen Field, Austria

Simulation of Polymer Injection Under Fracturing Conditions—An Injectivity Pilot in the Matzen Field, Austria

Damage Remediation in a Mature Field Reservoir by Applying a Customized Treatment Using Surface Active Additives and Diversion Technologies: Case Histories from San Francisco Field

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