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.

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.

Study on Preparation and Evaluation of Micro Zirconia Particles Used in Drilling Fluid

2012 ◽  
Vol 578 ◽  
pp. 175-178
Author(s):  
Xiao Chun Cao ◽  
Yan Yu Li ◽  
Dong Liang Yang ◽  
Kun Ke
Keyword(s):  
Hydrothermal Synthesis ◽  
Rheological Properties ◽  
Particle Image ◽  
Drilling Fluid ◽  
Synthesis Method ◽  
Drilling Fluids ◽  
Micro Particles ◽  
Before And After ◽  
Preparation And Evaluation

This article explains how to prepare zirconia (ZrO2) mico particles and demonstrates how to evaluate the performance of drilling fluids containing ZrO2. Sheet ZrO2micro articles were prepared using hydrothermal synthesis method and were observed using particle image equipment. The performances of drilling fluids before and after various doses of ZrO2added were compared. The result shows that sheet ZrO2micro particles can adjust the rheological properties of drilling fluid.

Investigation of Drilling Fluids Containing Blast Furnace Slag for Their Potential Impact on Formation Damage—A Laboratory Study

1999 ◽  
Vol 121 (3) ◽  
pp. 149-153 ◽  
Author(s):  
U. A. Tare ◽  
N. E. Takach ◽  
S. Z. Miska ◽  
F. B. Growcock ◽  
N. Davis
Keyword(s):  
Blast Furnace ◽  
Blast Furnace Slag ◽  
Filter Cake ◽  
Drilling Fluid ◽  
Rapid Development ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Filter Cakes ◽  
The Impact ◽  
Furnace Slag

This work discusses the effect of incorporating blast furnace slag (BFS) as an additive in water-based drilling fluids. The intent of this treatment is rapid development of a thin, impervious, and easily removable filter cake, thereby minimizing detrimental impact of the drilling fluid on formation productivity as opposed to previous applications of BFS in universal fluids. To evaluate the impact of BFS on filter cake properties, permeability plugging apparatus (PPA) tests and dynamic formation damage (DFD) studies were conducted. Drill-in fluids and dispersed muds were tested using varying quantities of BFS. Once a steady rate of dynamic filter cake deposition was achieved, the BFS in the filter cakes was chemically activated. The results obtained from these activation studies were compared with those obtained with no BFS and with unactivated BFS. The nature of the filter cakes was examined with an environmental scanning electron microscope (ESEM). Results obtained from the PPA tests indicate substantial decreases in initial spurt loss and filtrate volume with increasing concentration of BFS. The DFD studies substantiate the aforementioned observations and show enhancement of return permeabilities with BFS activation. ESEM studies demonstrate that BFS can consolidate filter cakes.

scholarly journals Enhancement of the rheological properties of bentonite mud using natural polymers

2021 ◽  
Vol 7 (1) ◽  
pp. 047-059
Author(s):  
Muhammed Rufai ◽  
Koyejo Oduola
Keyword(s):  
Rheological Properties ◽  
Corn Starch ◽  
Potato Starch ◽  
Drilling Fluid ◽  
Research Work ◽  
Cassava Starch ◽  
Gel Strength ◽  
Natural Polymers ◽  
Saw Dust ◽  
Before And After

This research work focuses on finding more effective polymers that can improve the rheological properties of bentonite mud. Various mud samples were formulated with natural polymers obtained from corn starch, cassava starch, purple potato starch, yellow potato starch and saw dust consisting of different masses which were not treated or purified by any chemical method before and after preparation along with the control mud. Rheology tests were carried out to determine the plastic viscosity, apparent viscosity, yield point, gel strength among others. API standards were followed throughout the experimental study and the result from this investigation showed that increasing the concentration of polymers enhances the mud rheological properties studied at ambient condition, wherein thermal stability was exhibited up till 100°C. Thus, environmental friendly alternatives have been discovered for drilling fluid additives which are cheap, organic, bio-degradable, non-toxic and easily available

scholarly journals The Fundamental Principles and Standard Evaluation for Fluid Loss and Possible Extensions of Test Methodology to Assess Consequences for Formation Damage

Energies ◽  
2021 ◽  
Vol 14 (8) ◽  
pp. 2252
Author(s):  
Karl Ronny Klungtvedt ◽  
Arild Saasen ◽  
Jan Kristian Vasshus ◽  
Vegard Bror Trodal ◽  
Swapan Kumar Mandal ◽  
...  
Keyword(s):  
Filter Cake ◽  
Reverse Flow ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Fluid Loss ◽  
Testing Procedures ◽  
Potential Formation ◽  
Lift Off ◽  
Set Up ◽  
Insight Into

Industry testing procedures such as ANSI/API 13B-1 [1] describe a method for measuring fluid loss and studying filter-cake formation against a medium of either a filter paper or a porous disc, without giving information about potential formation damage. Considering the thickness of the discs, it may also be possible to extend the method to gain an insight into aspects of formation damage. A new experimental set-up and methodology was created to evaluate changes to the porous discs after HTHP testing to generate insight into signs of formation damage, such as changes in disc mass and permeability. Such measurements were enabled by placing the disc in a cell, which allowed for reverse flow of fluid to lift off the filter-cake. Experiments were conducted with different drilling fluid compositions to evaluate the use of the new methodology. The first test series showed consistent changes in disc mass as a function of the additives applied into the fluid. The data yield insights into how the discs are sealed and to which degree solids, fibers or polymers are entering the discs. A second series of tests were set up to extend the procedure to also measure changes in the disc’s permeability to air and water. The results showed that there was a positive correlation between changes in disc mass and changes in permeability. The conclusions are that the methodology may enable identifying signs of formation damage and that further studies should be conducted to optimize the method.

scholarly journals Rheological properties and damage-control mechanism of oil-based drilling fluid with different types of weighting agents

2018 ◽  
Vol 5 (7) ◽  
pp. 180358 ◽  
Author(s):  
Peng Xu ◽  
Mingbiao Xu ◽  
Zhengwu Tao ◽  
Zhihong Wang ◽  
Ting Huang
Keyword(s):  
Particle Size ◽  
Rheological Properties ◽  
Control Mechanism ◽  
Drilling Fluid ◽  
Damage Control ◽  
Solid Particles ◽  
Formation Damage ◽  
Mud Cake ◽  
Filtration Loss ◽  
Degree Of Damage

The great amount of solid particles contained in a weighting agent is a major cause of the problems in both rheology properties and damage control mechanism of an oil-based drilling fluid (OBM). Therefore, a proper type of weighting agent can be a solution for the application of OBM. In this study, three weighting agents that have been commonly used with OBM, namely, standard barite, submicron barite and superfine manganese ore, are studied. Rheological properties of OBM and the degree of formation damage are assessed with regard to the three weighting agents. The agents are also studied in aspects of particle size, micromorphology, filtration loss and wall-building property, acid dissolution efficiency of mud cake, lubricity and sedimentation stability to analyse the effects of the agents on rheological properties and the degree of damage as well as to figure out the mechanism of rheology control and damage control. For the OBM, there is a mutual effect between rheological stability and the degree of damage. In consideration of the agents' properties, we can enhance the rheological stability of the OBM and control the degree of formation damage by properly selecting particle size, using acid-soluble materials and forming the mud cake with ultra-low permeability that can easily be cleared away.

Incorporation of Fe3O4 Nanoparticles as Drilling Fluid Additives for Improved Drilling Operations

2016 ◽  
Author(s):  
Zisis Vryzas ◽  
Omar Mahmoud ◽  
Hisham Nasr-El-Din ◽  
Vassilis Zaspalis ◽  
Vassilios C. Kelessidis
Keyword(s):  
Electron Microscope ◽  
Rheological Properties ◽  
Fe3o4 Nanoparticles ◽  
Filter Cake ◽  
Drilling Fluid ◽  
Filter Press ◽  
Rheological Parameters ◽  
Fluid Loss ◽  
Fluid System ◽  
Custom Made

A successful drilling operation requires an effective drilling fluid system. Due to the variety of downhole conditions across the globe, the fluid system should be designed to meet complex challenges such as High-Pressure/High-Temperature (HPHT) environments, while promoting better productivity with a minimum interference for completion operations. This study aims to improve the rheological and fluid loss properties of water-bentonite suspensions by using both commercial (C-NP) and custom-made (CM-NP) iron oxide (Fe3O4) nanoparticles (NP) as drilling fluid additives. Superparamagnetic Fe3O4 NP were synthesized by the co-precipitation method. Both types of nanoparticles were characterized by a High Resolution Transmission Electron Microscope (TEM) and X-ray Diffraction (XRD). Base fluid (BF), made of deionized water and bentonite at 7wt%, was prepared according to American Petroleum Institute (API) procedures and nanoparticles were added at 0.5wt%. A Couette-type viscometer was used to analyze the rheological characteristics of these fluids at different shear rates and various temperatures (up to 158°F). The rheological parameters were obtained from analysis of viscometric data using non-linear regression. The API Low-Pressure/Low-Temperature (LPLT) and HPHT fluid filtrate volumes were measured, using a standard API LPLT static filter press (100 psi, 77°F) and an API HPHT filter press (300 psi, 250°F). Observation of the porous matrix morphology of the produced filter cakes was done with Scanning Electron Microscope (SEM). TEM showed that the mean diameter of the CM-NP was 7–8 nm, with measured surface areas between 100–250 m2/g. The C-NP had an average diameter of <50 nm, as per manufacturer specifications. The XRD of the CM-NP revealed peaks corresponding to pure crystallites of magnetite (Fe3O4) with no impurities. Rheological analysis showed very good fitting by the Herschel-Bulkley model with coefficient of determination (R2) greater than 0.99. Rheological properties of all samples were affected by higher temperatures, with increase in yield stress, decrease in flow consistency index (K) and slight increase in flow behavior index (n). Fluid filtration results indicated a decrease in the LPLT fluid loss and an increase in the filter cake thickness compared to the BF upon addition of higher concentrations of C-NP, because of a decrease in filter cake permeability. At HPHT conditions, samples with 0.5wt% C-NP had a smaller fluid loss by 34.3%, compared to 11.9% at LPLT conditions. CM-NP exhibited even higher reduction in the fluid loss at HPHT conditions of 40%. Such drilling fluids can solve difficult drilling problems and aid in achieving the reservoir’s highest potential by eliminating the use of aggressive, potentially damaging chemicals. Exploitation of the synergistic interaction of the utilized components can produce a water-based system with excellent fluid loss characteristics while maintaining optimal rheological properties.

scholarly journals Formation Damage due to Drilling and Fracturing Fluids and Its Solution for Tight Naturally Fractured Sandstone Reservoirs

Geofluids ◽  
2017 ◽  
Vol 2017 ◽  
pp. 1-9 ◽  
Author(s):  
Tianbo Liang ◽  
Fuyang Gu ◽  
Erdong Yao ◽  
Lufeng Zhang ◽  
Kai Yang ◽  
...  
Keyword(s):  
Drilling Fluid ◽  
Reservoir Rock ◽  
Formation Damage ◽  
Tight Sandstone ◽  
Rock Permeability ◽  
Overburden Pressure ◽  
Hydrocarbon Production ◽  
Fracturing Fluids ◽  
Wide Range ◽  
Fractured Sandstone

Drilling and fracturing fluids can interact with reservoir rock and cause formation damage that impedes hydrocarbon production. Tight sandstone reservoir with well-developed natural fractures has a complex pore structure where pores and pore throats have a wide range of diameters; formation damage in such type of reservoir can be complicated and severe. Reservoir rock samples with a wide range of fracture widths are tested through a multistep coreflood platform, where formation damage caused by the drilling and/or fracturing fluid is quantitatively evaluated and systematically studied. To further mitigate this damage, an acidic treating fluid is screened and evaluated using the same coreflood platform. Experimental results indicate that the drilling fluid causes the major damage, and the chosen treating fluid can enhance rock permeability both effectively and efficiently at least at the room temperature with the overburden pressure.

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