Sand Consolidation Operations, Challenges and Remedy

Marfo, Solomon Adjei; Appah, Dulu; Joel, O.F.. F.; Ofori-Sarpong, Grace

doi:10.2118/178306-ms

Cited by 17 publications

(7 citation statements)

References 2 publications

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“…They reported that the regained permeability is 63% at the temperature range of 93-177 • C, [56]. Marfo et al [13] used an internally catalyzed epoxy resin to consolidate sand formation in the Mahakam Delta, Indonesia. The internally catalyzed system comprises a hardener and accelerator.…”

Section: Epoxy Resinmentioning

confidence: 99%

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Chemical Sand Consolidation: From Polymers to Nanoparticles

et al. 2020

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The chemical sand consolidation methods involve pumping of chemical materials, like furan resin and silicate non-polymer materials into unconsolidated sandstone formations, in order to minimize sand production with the fluids produced from the hydrocarbon reservoirs. The injected chemical material, predominantly polymer, bonds sand grains together, lead to higher compressive strength of the rock. Hence, less amounts of sand particles are entrained in the produced fluids. However, the effect of this bonding may impose a negative impact on the formation productivity due to the reduction in rock permeability. Therefore, it is always essential to select a chemical material that can provide the highest possible compressive strength with minimum permeability reduction. This review article discusses the chemical materials used for sand consolidation and presents an in-depth evaluation between these materials to serve as a screening tool that can assist in the selection of chemical sand consolidation material, which in turn, helps optimize the sand control performance. The review paper also highlights the progressive improvement in chemical sand consolidation methods, from using different types of polymers to nanoparticles utilization, as well as track the impact of the improvement in sand consolidation efficiency and production performance. Based on this review, the nanoparticle-related martials are highly recommended to be applied as sand consolidation agents, due to their ability to generate acceptable rock strength with insignificant reduction in rock permeability.

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Section: Epoxy Resinmentioning

confidence: 99%

“…Unconsolidated sand formation can occur because of relatively young geological age and depositional environment no cement between the rock grain to attach them together by mineral deposition [12]. Nevertheless, sand formation consolidation occurs when the natural bonds attach the grains by cementing materials in the formation [13].…”

Section: Introductionmentioning

confidence: 99%

Chemical Sand Consolidation: From Polymers to Nanoparticles

et al. 2020

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“…Sand production begins when the imposed in situ stresses on the formation exceeds the in situ formation strength (Gholami et al 2016). On the contrary, sand consolidation usually happens when the natural bonds attach the grains by the cement materials in formations (Marfo et al 2015).…”

Section: Introductionmentioning

confidence: 99%

“…Resins mostly are applied in sand control studies in which, in those cases, liquid polymeric resins have the ability to change phase to solid (Marfo et al 2015). Although resins are frequently used as a consolidation fluid in chemical methods, application of these materials is unpleasant under environmental and economic perspectives, due to their tendency to reduce the formation permeability (Sydansk 1992).…”

Section: Introductionmentioning

confidence: 99%

Polyacrylamide hydrogel application in sand control with compressive strength testing

2018

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Sand production is one of the major problems in sandstone reservoirs. Different mechanical and chemical methods have been proposed to control sand production. In this paper, we propose a chemical method based on using polyacrylamide/ chromium triacetate hydrogel to investigate sand production in a synthetic sandpack system. To this end, a series of bulk experiments including the bottle test and rheological analysis along with compression tests were conducted. Experimental results indicated that the compressive strength of the sandpack was increased as much as 30 times by injecting 0.5 pore volume of hydrogel. Also, it was found that the increases in cross-linker and polymer concentrations exhibited a positive impact on the compressive strength of the sandpack, mostly by cross-linker concentration (48 psi). Hydrogel with a higher value of cross-linker could retain its viscoelastic properties against the strain which was a maximum of 122% for 0.5 weight ratio of cross-linker/polymer. The presence of salts, in particular divalent cations, has a detrimental effect on the hydrogel stability. The maximum strain value applied on hydrogel in the presence of CaCl 2 was only about 201% as compared to 1010% in the presence of distilled water. Finally, thermogravimetric analysis and its derivative showed that the hydrogel could retain its structure up to 300°C. The results of this study revealed the potential application of the hydrogel to control sand production.

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“…The gelation point of polymers is temperature and time dependent at a determined favourable cross-linker concentration. There is a gradual rise in viscosity followed by an asymptotic increase to infinity as the gel point is approached Marfo [19]. Al-Muntasheri [14] developed correlation for gelation time as a function of temperature for watershutoff systems.…”

Section: Introductionmentioning

confidence: 99%

Modelling Gelation Time of Organically Cross-linked Water-shutoff Systems for Oil Wells

Sa¹,

Appah²,

Joel³

et al. 2016

J Pet Environ Biotechnol

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Water production is one of the major challenges in the petroleum industry, especially brown fields and water drive reservoirs. Water production can weaken the cementation of sand grains, thereby rendering formations partially or completely unconsolidated. This in turn initiates fines migration and aggravates safety concerns. The gelation time is an important characteristic of water-shutoff systems and it is influenced by different parameters. The gelation time gives an indication of the time required for a gel to transit from free flowing fluid to solid or semi-solid gel making it difficult to pump. Organically cross-linked gels have numerous applications in the industry such as shutoff systems. They are used to control water and gas production in oil wells. The effect of cross-linker concentration, temperature and brine concentration on the gelation time of an organically crosslinked system was studied. Based on the experimental results a mathematical model was developed for predicting the gelation time of the water-shutoff system. The results showed that temperature had the highest impact on the gelation time of the water-shutoff system with an effect estimate of (-2.292). The brine concentration of the mix water recorded the lowest impact with an effect estimate of 0.2083 and the interaction between cross-linker concentration and brine concentration of mix water had neutral impact. A predictable and effective water-shutoff system has been developed with an excellent initial viscosity which can easily be pumped and applied to solve water production and its associated problems. The gelation time of organically crosslinked water-shutoff system can be optimised in water control operations using this model and the effect estimates of these parameters.

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Sand Consolidation Operations, Challenges and Remedy

Cited by 17 publications

References 2 publications

Chemical Sand Consolidation: From Polymers to Nanoparticles

Chemical Sand Consolidation: From Polymers to Nanoparticles

Polyacrylamide hydrogel application in sand control with compressive strength testing

Modelling Gelation Time of Organically Cross-linked Water-shutoff Systems for Oil Wells

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