Reducing Formation Damage With Microbubble Based Drilling Fluid: Understanding the Blocking Ability

2007 ◽  
Author(s):  
N. Bjorndalen ◽  
E. Jossy ◽  
J.M. Alvarez ◽  
E. Kuru
Keyword(s):  
Drilling Fluid ◽  
Formation Damage

scholarly journals Experimental study on thermal, rheological and filtration control characteristics of drilling fluids: effect of nanoadditives

2020 ◽  
Vol 75 ◽  
pp. 36
Author(s):  
Erfan Veisi ◽  
Mastaneh Hajipour ◽  
Ebrahim Biniaz Delijani
Keyword(s):  
Thermal Conductivity ◽  
Heat Capacity ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Drill Bit ◽  
Rheological Characteristics ◽  
Cu Nanoparticles ◽  
Water Based

Cooling the drill bit is one of the major functions of drilling fluids, especially in high temperature deep drilling operations. Designing stable drilling fluids with proper thermal properties is a great challenge. Identifying appropriate additives for the drilling fluid can mitigate drill-bit erosion or deformation caused by induced thermal stress. The unique advantages of nanoparticles may enhance thermal characteristics of drilling fluids. The impacts of nanoparticles on the specific heat capacity, thermal conductivity, rheological, and filtration control characteristics of water‐based drilling fluids were experimentally investigated and compared in this study. Al2O3, CuO, and Cu nanoparticles were used to prepare the water-based drilling nanofluid samples with various concentrations, using the two-step method. Transmission Electron Microscopy (TEM) and X-Ray Diffraction (XRD) were utilized to study the nanoparticle samples. The nanofluids stability and particle size distribution were, furthermore, examined using Dynamic Light Scattering (DLS). The experimental results indicated that thermal and rheological characteristics are enhanced in the presence of nanoparticles. The best enhancement in drilling fluid heat capacity and thermal conductivity was obtained as 15.6% and 12%, respectively by adding 0.9 wt% Cu nanoparticles. Furthermore, significant improvement was observed in the rheological characteristics such as the apparent and plastic viscosities, yield point, and gel strength of the drilling nanofluids compared to the base drilling fluid. Addition of nanoparticles resulted in reduced fluid loss and formation damage. The permeability of filter cakes decreased with increasing the nanoparticles concentration, but no significant effect in filter cake thickness was observed. The results reveal that the application of nanoparticles may reduce drill-bit replacement costs by improving the thermal and drilling fluid rheological characteristics and decrease the formation damage due to mud filtrate invasion.

scholarly journals Application of Implicit Pressure-Explicit Saturation Method to Predict Filtrated Mud Saturation Impact on the Hydrocarbon Reservoirs Formation Damage

Mathematics ◽  
2020 ◽  
Vol 8 (7) ◽  
pp. 1057 ◽  
Author(s):  
Mingxuan Zhu ◽  
Li Yu ◽  
Xiong Zhang ◽  
Afshin Davarpanah
Keyword(s):  
Porous Media ◽  
Water Saturation ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Drilling Mud ◽  
Oil Viscosity ◽  
The Core ◽  
Oil Flow ◽  
Lower Porosity ◽  
Saturation Method

Hydrocarbon reservoirs’ formation damage is one of the essential issues in petroleum industries that is caused by drilling and production operations and completion procedures. Ineffective implementation of drilling fluid during the drilling operations led to large volumes of filtrated mud penetrating into the reservoir formation. Therefore, pore throats and spaces would be filled, and hydrocarbon mobilization reduced due to the porosity and permeability reduction. In this paper, a developed model was proposed to predict the filtrated mud saturation impact on the formation damage. First, the physics of the fluids were examined, and the governing equations were defined by the combination of general mass transfer equations. The drilling mud penetration in the core on the one direction and the removal of oil from the core, in the other direction, requires the simultaneous dissolution of water and oil flow. As both fluids enter and exit from the same core, it is necessary to derive the equations of drilling mud and oil flow in a one-dimensional process. Finally, due to the complexity of mass balance and fluid flow equations in porous media, the implicit pressure-explicit saturation method was used to solve the equations simultaneously. Four crucial parameters of oil viscosity, water saturation, permeability, and porosity were sensitivity-analyzed in this model to predict the filtrated mud saturation. According to the results of the sensitivity analysis for the crucial parameters, at a lower porosity (porosity = 0.2), permeability (permeability = 2 mD), and water saturation (saturation = 0.1), the filtrated mud saturation had decreased. This resulted in the lower capillary forces, which were induced to penetrate the drilling fluid to the formation. Therefore, formation damage reduced at lower porosity, permeability and water saturation. Furthermore, at higher oil viscosities, due to the increased mobilization of oil through the porous media, filtrated mud saturation penetration through the core length would be increased slightly. Consequently, at the oil viscosity of 3 cP, the decrease rate of filtrated mud saturation is slower than other oil viscosities which indicated increased invasion of filtrated mud into the formation.

scholarly journals Damage Mechanism of Oil-Based Drilling Fluid Flow in Seepage Channels for Fractured Tight Sandstone Gas Reservoirs

Geofluids ◽  
2019 ◽  
Vol 2019 ◽  
pp. 1-15 ◽  
Author(s):  
Peng Xu ◽  
Mingbiao Xu
Keyword(s):  
Drilling Fluid ◽  
Damage Control ◽  
Damage Mechanism ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Gas Reservoirs ◽  
Tight Sandstone ◽  
Stabilization Effect ◽  
Potential Damage ◽  
Physical And Chemical

Oil-based drilling fluids (OBDFs) have a strong wellbore stabilization effect, but little attention has been paid to the formation damage caused by oil-based drilling fluids based on traditional knowledge, which is a problem that must be solved prior to the application of oil-based drilling fluid. For ultradeep fractured tight sandstone gas reservoirs, the reservoir damage caused by oil-based drilling fluids is worthy of additional research. In this paper, the potential damage factors of oil-based drilling fluids and fractured tight sandstone formations are analyzed theoretically and experimentally. The damage mechanism of oil-based drilling fluids for fractured tight sandstone gas reservoirs is analyzed based on the characteristics of multiphase fluids in seepage channels, the physical and chemical changes of rocks, and the rheological stability of oil-based drilling fluids. Based on the damage mechanism of oil-based drilling fluids, the key problems that must be solved during the damage control of oil-based drilling fluids are analyzed, a detailed description of formation damage characteristics is made, and how to accurately and rapidly form plugging zones is addressed. This research on damage control can provide a reference for solving the damage problems caused by oil-based drilling fluids in fractured tight sandstone gas reservoirs.

scholarly journals Decreasing Coalbed Methane Formation Damage Using Microfoamed Drilling Fluid Stabilized by Silica Nanoparticles

2016 ◽  
Vol 2016 ◽  
pp. 1-11 ◽  
Author(s):  
Jihua Cai ◽  
Sui Gu ◽  
Fawen Wang ◽  
Xianyu Yang ◽  
Ye Yue ◽  
...  
Keyword(s):  
Silica Nanoparticles ◽  
Performance Appraisal ◽  
Coalbed Methane ◽  
Gas Permeability ◽  
Foam Stability ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Methane Formation ◽  
Coal Seams ◽  
20 Nm

Coalbed methane (CBM) reservoirs in China are featured in remarkable nanosized pores below 200 nm, acknowledged natural cleats, and tectonic fractures. This paper discussed the possibility that a clay free microfoamed drilling fluid could be stabilized by silica nanoparticles (CFMDF-NP) so as to avoid formation damage of CBM drilling. In accordance with the experimental results of foaming capacity and foam stability test, basic drilling fluid performance appraisal, micromorphology observation, swelling test, and gas permeability test, the mechanism of the CFMDF-NP was discussed in this paper. The results indicated that, with 10–20 nm nano-SiO2, the foaming volume of traditional foamed drilling fluid could be improved by up to 50% and an increased half-life period by up to 200%. Chemically treated nano-SiO2dispersions functioned as a foam stabilizer and a foaming agent as well. The CFMDF-NP had controllable density (0.7~1 g/cm3) and excellent rheological and sealing properties, which could satisfy the drilling requirements of the low pressure coal seams. With 5–8 mm slicing on the contaminated side of coal cores, the contaminated zone could be removed and the recovery rate of gas permeability could reach up to 70%. The CFMDF-NP laid good technical foundation to decrease formation damage of CBM reservoir.

Oil-Based Reservoir Drilling Fluid for Critical Field Cases: Integrated Formation-Damage Evaluation and System Development

1999 ◽  
Author(s):  
Jan Erik Hanssen ◽  
Jiang Ping ◽  
Marton Haga ◽  
Hans Ivar Berge ◽  
Tony Boassen ◽  
...  
Keyword(s):  
Critical Field ◽  
System Development ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Damage Evaluation

Dynamic Evaluation of Invasion and Backflow in Carbonate and Sandstone Reservoirs

2012 ◽  
Author(s):  
Bruno O. Silveira ◽  
Rosangela B. Z. L. Moreno
Keyword(s):  
Multiphase Flow ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Dynamic Flow ◽  
Dynamic Evaluation ◽  
The Core ◽  
Advancing Front ◽  
Sandstone Reservoirs ◽  
Flow Drilling ◽  
Protocol Test

This work aims to compare the drilling fluid invasion and oil backflow in sandstone and carbonate samples in order to evaluate the influence of kind of rock in the formation damage and its interaction with the drilling tested fluid. The tests were performed in sandstone and carbonate samples with similar gas absolute permeabilities and under a protocol test in steps that included preparation, characterization, multiphase flow, drilling fluid invasion and oil backflow. During the work it was observed that carbonate samples were less water wet than sandstone samples. From the obtained results for longer samples was possible to follow the advancing front of the invading fluid with pressure observations along the core. The dynamic flow permitted to conclude that invasion in carbonate samples was faster than in sandstone. It was also observed that in carbonate samples the backflow presented a higher and faster productivity return when compared with sandstone results.

Effects of surface modified nanosilica on drilling fluid and formation damage

2020 ◽  
Vol 194 ◽  
pp. 107559 ◽  
Author(s):  
Seyed Hasan Hajiabadi ◽  
Pavel Bedrikovetsky ◽  
Hassan Mahani ◽  
Ali Khoshsima ◽  
Hamed Aghaei ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Formation Damage ◽  
Surface Modified

scholarly journals Formation Damage Avoidance by Reducing Invasion with Sodium Silicate-Modified Water-Based Drilling Fluid

Energies ◽  
2019 ◽  
Vol 12 (8) ◽  
pp. 1485 ◽  
Author(s):  
Salaheldin Elkatatny ◽  
Tural Jafarov ◽  
Abdulaziz Al-Majed ◽  
Mohamed Mahmoud
Keyword(s):  
Rheological Properties ◽  
Sodium Silicate ◽  
Filter Cake ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Ct Scanner ◽  
Tight Sandstone ◽  
Ct Number ◽  
Mechanical Removal ◽  
Before And After

Drilling multilateral and horizontal wells through tight gas reservoirs is a very difficult task. The drilling fluid should be designed to reduce both fluid and solid invasion into the tight formation to avoid formation damage by aqueous phase trapping. The objective of this paper is to assess the effect of sodium silicate on the drilling fluid properties such as rheological and filtration properties. Rheological properties (RPs) were measured at different temperatures while the filtration test was performed at 300 °F and 300 psi differential pressure. A retained permeability calculation was determined to confirm the prevention of solid invasion. The rheological properties results confirmed that the optimal concentration of sodium silicate (SS) was 0.075 wt.% and at the same time, the temperature has no effect on the SS optimum concentration. Using 0.075 wt.% of SS reduced the filtrate volume by 53% and decreased the filter cake thickness by 65%. After mechanical removal of the filter cake, the return permeability of the tight sandstone core was 100% confirming the prevention of solid invasion. The computer tomography (CT) scanner showed that the CT number before and after the filtration test was very close (almost the same) indicating zero solid invasion and prevention of the formation damage.

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