Formation damage due to fines migration and its remedial methods

Galal, S. K.; Elgibaly, Ahmed A.; Elsayed, Said K.

doi:10.1016/j.ejpe.2015.11.005

Cited by 23 publications

(7 citation statements)

References 9 publications

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“…Under most circumstances, fi nes migration occurred deep in the formation and any chemical solution must be designed to be functioning retarded as far from the wellbore as possible. All systems produce precipitation in contact with clays (Galal, 2016).…”

Section: Proposals For Sustainable Sand Productionmentioning

confidence: 99%

Sand management approach for a field with high viscosity oil

Grigorev¹,

Tananykhin²,

Poroshin³

2020

J Appl Eng Science

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Oil production from weakly consolidated sandstone wasn't needed for decades, but as the time goes on, traditional oil reserves deplete and possibility of these reserves being produced is growing up. In the case of high viscosity oil, located in such reservoir, problem gets even worse. Traditional sand control methods cause lower production rates, thus, making production not profi table enough. In the industry there was need for new approach and it appearedsand management. Sand management is a risky business, but it allows some reservoirs to be produced with good enough profi t. But with right amount of preparations risk can be minimized and production becomes more likely. One of the most promising instruments of sand management is chemical treatment with UTTA. It allows to sand particles and fi nes to be held in the reservoir so they won't cause so much erosion and won't plug pore throats and fi ltration channels.

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Section: Proposals For Sustainable Sand Productionmentioning

confidence: 99%

Sand management approach for a field with high viscosity oil

Grigorev¹,

Tananykhin²,

Poroshin³

2020

J Appl Eng Science

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“…e production capacity of reservoirs declines and formation damage occurs when plugging layers are not promptly formed and removed [23,24]. In order to prevent loss of drilling fluid and reduce the formation damage effectively, it is the preferred option to use the engineering plugging materials with excellent performance as plugging materials.…”

Section: Performance Of Gzdmentioning

confidence: 99%

“…e results maintain consistency with the experimental results in Figure 5. e production capacity of reservoirs declines and formation damage occurs when plugging layers are not promptly removed [23,24]. Acid treatment is an important technology for removing plugging material in oilfields.…”

Section: Performance Of Gzdmentioning

confidence: 99%

Laboratory Study on a New Composite Plugging Material with High Bearing Strength and High-Temperature Resistance

Lian

Xiong

et al. 2019

Journal of Chemistry

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The reservoir in the Central Tarim Basin is a typical high-pressure fracture-vuggy carbonate reservoir with high temperatures, which easily leads to drilling fluid losses and the high-temperature carbonate. The conventional lost circulation materials (LCMs) cannot meet the reservoir. To resolve this problem, a rigid particle with high-temperature resistance, high acid solubility, and high rigidity was developed, tested, and evaluated. According to bridge rules of 1/2–2/3 opening degree of formation fracture, the formulation experiments of GZD and other lost circulation materials were conducted and a novel composite lost circulation material (LCM) was completed. Lastly, we investigated the compatibility of LCM and mud in site though compatibility experiment, analyzed the plugging effect of the system for fracture and vuggy by laboratory static lost circulation simulation and evaluation and sand-bed plugging experiments, respectively. The results show that compared with the conventional rigid lost material, the value of high-temperature resistance is more and acid solubility is over 98%. Also, it can work well with other fiber materials (E), variable filling particles (F and G), and superfine filling particles (H) and form a novel plugging material, named MGY-I, whose temperature resistance value is more than 473.15 K, the bearing strength is over than 9 MPa, the mud filtrate invasion depth of sand bed made from coarse particles (10∼20 mesh) is only 3.0 cm within 30 minutes, and the invasion depth is less than 1 cm within 30 minutes when the sand bed is made from 80∼100 mesh. The optimal concentrations of rigid granule, lignin fiber, elastic particle, and superfine calcium carbonate are 8% (A : B : CD = 2 : 1 : 1), 0.5%, 6%, and 1%, respectively. And, the plugging function of “GZD-rigidity bridge and filling, fiber network and deformable filing” is better exerted on the formation fracture with a high loading capacity and a high-temperature resistance.

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“…Conventionally, well treatment to remediate fines migration problems in oil producing field is taken via two techniques. The first method is through removal process by matrix acidizing (Okologume and Umeleuma 2015;Galal et al 2016;Reinoso et al 2016;Ayopo et al 2016;Hassan et al 2017;Shafiq and Hisham 2017). Mixture of hydrofluoric acid (HF) and hydrochloric acid (HCl) also known as mud acid was injected into the sandstone formation to dissolve the accumulated siliceous and clay minerals that will improve the rock porosity and permeability (Shafiq and Hisham 2017;Smith and Hendrickson 1965).…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of colloidal silica nanoparticles (C-SNPs) for fines migration control application

et al. 2021

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Formation damage due to fines migration is among the root causes for hydrocarbon productivity decline. This occurs due to minerals dislodging when reservoir fluid flow beyond critical velocity and by poor cementation after acid stimulation activities. Conventional chemical methods have been widely used to prevent the fines migration, however, most of the chemical stabilizer is less robust, functional based on composition of exchangeable cations in rock minerals, cause temporary stabilization and are not environmentally friendly. This paper explores the potential of colloidal silica nanoparticles (C-SNPs) as new solution for fines migration control application. A series of critical velocity core flooding experiments has been carried out to determine the C-SNPs efficiency in enhancing the critical velocity at various temperatures. Berea Buff cores pre-treated with 0.05% C-SNPs (35 nm), were exposed to elevated injection rates. Synthetic formation brine was injected via alternating increasing and return to baseline rate from 0.5 to 41.5 mL/min. The stabilize pressure drops generated during brine injection after C-SNPs injection were used to establish the baseline permeability, k w . The stabilized pressure drops generated after each elevated rate were calculated to determine the permeability, k (at 0.5 mL/min) and to establish the k/k w graph plot. The critical rate's value was obtained when permeability reduction occurred in the range from 10 to 20% from the initial permeability value. Microscopic visualization using FESEM of the treated cores showed traces of nanoparticles on the core surface and surface modification by surface roughness measurement via atomic surface microscopy (AFM). The permeability of all treated cores remained constant up to 5 mL/min. At 8.3 mL/min and above, variation in permeability was observed caused by fines mobilization but with no significant permeability drops up to 41.5 mL/min. Modification of pore walls and fines surfaces by nanoparticles attachment was described by low surface roughness. The attraction of fines particles on the pore wall and within the particles themselves had strengthened surface morphology, therefore, their detachment and mobilization in porous media were not seen when exposed to high injection velocity.

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Formation damage due to fines migration and its remedial methods

Cited by 23 publications

References 9 publications

Sand management approach for a field with high viscosity oil

Sand management approach for a field with high viscosity oil

Laboratory Study on a New Composite Plugging Material with High Bearing Strength and High-Temperature Resistance

Experimental investigation of colloidal silica nanoparticles (C-SNPs) for fines migration control application

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