DPR polymer gel treatment in oil reservoirs: A workflow for treatment optimization using static proxy models

Norouzi, Mohammad; Panjalizadeh, Hamed; Rashidi, Fariborz; Mahdiani, Mohammad Reza

doi:10.1016/j.petrol.2017.03.018

Cited by 13 publications

(7 citation statements)

References 39 publications

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“…Moreover, there was also a critical gas flow rate ( Q gc1 ) (∼ 0.4 cm 3 /min) below which Frr g < 1 (gas permeability increase) and above which Frr g > 1 (gas permeability reduction). Thus, when the gas flow rate increased, S wir decreased and in turn the lubrication effect toward the gas phase decreased, similar to the results reported previously. , Such lubrication effects are one of the main reasons for DPR when RPMs are used. ,,− Mechanistically, the gel layer on the rock reduces the pore surface roughness; furthermore, it forms a water film on the pore surface, and both effects increase k rg. , …”

Section: Resultssupporting

confidence: 83%

A Multiscale Investigation of Cross-Linked Polymer Gel Injection in Sandstone Gas Reservoirs: Implications for Water Shutoff Treatment

et al. 2020

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Excessive water production is a significant challenge during hydrocarbon production from oil and gas reservoirs, and it is typically controlled by polymer gel placement. However, the fundamental process in terms of how precisely this gel reduces water production in gas reservoirs is rarely reported. The objective of paper is to investigate the impact of cross-linked polyacrylamide (poly(acrylamide-co-acrylic acid) partial sodium salt) gel as a relative permeability modifier for a sandstone/gas/water system and provides insights into the detailed in situ gel behavior inside the porous medium. Stronger gels increased water retention inside the porous media yet decreased the lubrication effect of the gel. Moreover, as the water flow rate increased (during imbibition), the water relative permeability reduction decreased, which is attributed to (a) gel shear thinning behavior and (b) reduction in the residual gas saturation. However, the gel showed shear thickening behavior during gas flow. At low gas flow rates, gel performance is mainly controlled by the gel lubrication effect, while at higher gas flow rates, the significance of gel rigidity is greatly increased. These effects were associated by gas diffusion and gas dissolution in the gel, which in turn expanded the gel layer and reduced gas permeability. Moreover, we identified two counteracting mechanisms (i.e., water retention and lubrication effects) responsible for the disproportionate permeability reduction. In addition, we identified a critical flow rate above which the gel treatment becomes unsuccessful as both effects (i.e., water retention and lubrication) were significantly reduced. These findings thus provide novel insights into the factors leading to successful gel placement to better control water production.

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Section: Resultssupporting

confidence: 83%

A Multiscale Investigation of Cross-Linked Polymer Gel Injection in Sandstone Gas Reservoirs: Implications for Water Shutoff Treatment

et al. 2020

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“…Polymer adsorption on the pore wall can induce a major lubrication effect that favors the flow of nonwetting fluids (i.e., oil/gas) and ultimately leads to DPR. 22,24,30,35,119,145,151,[183][184][185]188 To elucidate, the lubrication effect can facilitate the flow of the nonwetting phase (i.e., oil/gas) and facilitate its displacement by (1) making it slip through the center of pore channels and (2) reducing the roughness of the pore surface. 24,33,36,75,151,160,183 Further, the formed water film on the RPM-covered pore surface can increase the lubrication effect.…”

Section: Lubrication Effectsmentioning

confidence: 99%

Rock/Fluid/Polymer Interaction Mechanisms: Implications for Water Shut-off Treatment

et al. 2021

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Several disproportionate permeability reduction (DPR) mechanisms have been proposed in the literature for water shutoff treatment using polymer relative permeability modifiers (RPM). However, none appear to be universally accepted. The lack of agreement may be because no single factor determines the success of DPR treatment. Moreover, there is still a lack of understanding of DPR mechanisms and the order of how these mechanisms work together. This paper provides a comprehensive review of the mechanisms behind the RPMs. We identify that sufficient polymer adsorption onto the rock surface is a primary condition for water shutoff treatment, while rock surface initial wettability and fluid−polymer−rock interaction/attraction plays a significant role in polymer adsorption. Furthermore, polymer concentration, polymer molecular weight, aging time, polymer injection volume, polymer injection rate, and reservoir temperature are also vital for polymer adsorption. After polymer adsorption, the mechanisms such as fluid segregation and wall effect help accomplish the required DPR. We also find that there is a more consistent agreement among the published studies on the order of DPR mechanisms e.g. initial rock wettability effect comes first, followed by initial segregation, adsorption wall effect (i.e., steric, lubrication, wettability alteration, and swelling/shrinkage), and then the final segregation. Depending on the RPM implementation, which depends on pore size, the polymer layer thickness can be adjusted after the placement permanently or temporarily by controlling swelling/shrinkage. The subject matter investigated in this review helps us understand the factors responsible for optimal performance of polymer solutions in controlling excess water production from hydrocarbon reservoirsthus assisting in more efficient oil/gas production.

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“…The experiment of [39], with the ED application, involved many simulations and are made changes on the input variable. The authors [5] mentioned that, in an experiment, one or more variables could be changed to quantify the effect of inputs on outputs (response variables). ED is used to avoid the time-consuming process to captured all changes with the minimum number of simulator runs [31,38].…”

Section: Experimental Designmentioning

confidence: 99%

“…It becomes advantageous, especially when the direct evaluation of the system is either impossible or involves a high computational cost to simulate [4]. Therefore, a proxy model is considered to be an efficient substitute for the simulation tool at higher levels of reservoir study including uncertainty analysis, risk analysis and production optimisation [5], and also to elaborate the risk curves [6], especially time-consuming simulators [3]. In other words, in cases where proxy models can effectively represent important output parameters, they can be used as an adequate substitution for full reservoir simulators [7].…”

Section: Introductionmentioning

confidence: 99%

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

Silva¹,

Avansi²,

Schiozer³

2020

IJAERS

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Proxy models are derived mathematical functions developed as substitutes for reservoir flow simulators. Several types of proxy models are reported in the literature, for instance, response surface models, surrogate models, or metamodels. These models are fast methods, recommended for their efficient response time to approximate model responses and, therefore, useful in the decision-making process related to reservoir management. These studies focus on modelling a limited set of factors, applications, and case studies of any technique. A systematic literature review (SLR) is performed to gather the aspects prompting the modelling of proxy models in the literature and state-of-the-art. For this, a set of search keywords with appropriate string were utilised to extract the most important studies that satisfied all the criteria defined and classified under journal and conference paper categories. The papers were condensed after removing redundancy, repetition and similarity through a sequential and iterative process. From the analysis carried out, several gaps were identified, especially during the proxy model construction. Proxy models have already been discussed in petroleum engineering as a representation of the real system of reservoir flow simulator software. However, the proxy model response is faster but has yet to establish the issues of uncertainty in the outputs. There is a need for the integration of fast methods and reservoir simulators which can improve and accelerate results within acceptance criteria and accuracy in decisionmaking processes related to reservoir management.

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DPR polymer gel treatment in oil reservoirs: A workflow for treatment optimization using static proxy models

Cited by 13 publications

References 39 publications

A Multiscale Investigation of Cross-Linked Polymer Gel Injection in Sandstone Gas Reservoirs: Implications for Water Shutoff Treatment

A Multiscale Investigation of Cross-Linked Polymer Gel Injection in Sandstone Gas Reservoirs: Implications for Water Shutoff Treatment

Rock/Fluid/Polymer Interaction Mechanisms: Implications for Water Shut-off Treatment

Development of proxy models for petroleum reservoir simulation: a systematic literature review and state-of-the-art

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