Oil and gas recovery may cause formation damage during drilling, completion, and production phases. As a result of fundamental chemical, thermal, mechanical, and biological interactions, formation damage can occur due to impairment of permeability and porosity, causing undesirable operational and economic problem. The fluid-rock interactions resulting from oilfield chemicals injection during drilling, enhanced oil recovery (EOR) such as chemical flooding, or formation treatment could negatively impact on the formation properties such as geomechanical and geochemical, leading to alteration of the rock’s petrophysical properties. These chemical-rock interactions induce changes in both pore space geometry and rock strength. The resultant impact includes weakening of the formation bonding materials, formation damage, reduced production and consequently sand production simultaneously with reservoir fluids. It is therefore critical to evaluate these variables prior to designing any geo-sequestration, reservoir stimulation or EOR projects. Studies have shown that rock properties, especially permeability, porosity and strength, are altered or damaged during drilling, cementing, perforating, producing, stimulating, and injecting water or chemicals for EOR. Petroleum companies are likely to suffer significant financial losses due to this. This study provides a review on the influence of oilfield chemical-formation interactions on the formation rock properties both geophysical and mechanical, leading to formation damage and sand production. This study aims to provide researchers with a single document that gives insight and new perspectives on oilfield chemical-rock interactions through compilation of recent studies relating to the effect of chemical-rock interactions on rock's petrophysical properties, as well as geomechanical properties due to geochemical reactions that cause formation damage and eventually sand production. Having a solid understanding of fluid-rock interactions and how they impact petrophysical properties and cause formation damage is essential in predicting sand production and would help in minimizing economic losses, downtime and technicalities.

Drilling operation efficiency is enhanced by the application of drilling mud constituted with suitable additives. This work investigates the use of locally sourced plantain peels powder (PPP) and burnt palm head sponge powder (BPHSP) in comparison with the use of commercial sodium hydroxide (NaOH) as additives for the enhancement of the pH and rheological properties of water-based mud. The water-based mud samples with and without various amounts (1.0-5.0 g) of PPP, BPHSP and commercial NaOH, respectively. Analyses of the results revealed that the pH and rheological properties (apparent viscosity, plastic viscosity and yield point) of the formulated waterbased mud were relatively enhanced with the respective use of the commercial NaOH, BPHSP and PPP as additives. The pH, apparent viscosity and yield point respectively increased with increase in the quantity of each of the added additives (commercial NaOH, BPHSP and PPP). The commercial NaOH had the highest percentage of improvement on the mud pH with 22.2-50%, followed by that of BPHSP (16.7-44.4%) and PPP (11.1-33.3%), respectively. Therefore, commercial sodium hydroxide, burnt palm head sponge ash powder and plantain peels powder can respectively be used as additives to enhance or improve the pH and rheological properties (viscosity and yield point) of water-based mud.

As the world population increases, the generation of waste bones will multiply exponentially, increasing landfill usage and posing health risks.

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