Application of Innovative High Density High-Performance Water-Based Drilling Fluid Technology in the Efficient Development and Production of Ultra-Deep Complicated Formations in the Tian Mountain Front Block in China

2018 ◽  
Author(s):  
Li Long ◽  
Yin Da ◽  
Li Lei ◽  
Yan Zihang ◽  
Huang Chao ◽  
...  
Keyword(s):  
High Performance ◽  
Drilling Fluid ◽  
High Density ◽  
Water Based ◽  
Mountain Front

Development of New Models to Determine the Rheological Parameters of Water-based Drilling Fluid Using Artificial Intelligence

2021 ◽  
Author(s):  
Farqad Hadi ◽  
Ali Noori ◽  
Hussein Hussein ◽  
Ameer Khudhair
Keyword(s):  
Rheological Properties ◽  
High Performance ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Solid Content ◽  
Rheological Parameters ◽  
Water Based ◽  
Fluid Properties ◽  
Drilling Operations ◽  
Marsh Funnel

Abstract It is well known that drilling fluid is a key parameter for optimizing drilling operations, cleaning the hole, and managing the rig hydraulics and margins of surge and swab pressures. Although the experimental works present valid and reliable results, they are expensive and time consuming. On the other hand, continuous and regular determination of the rheological mud properties can perform its essential functions during well construction. More uncertainties in planning the drilling fluid properties meant that more challenges may be exposed during drilling operations. This study presents two predictive techniques, multiple regression analysis (MRA) and artificial neural networks (ANNs), to determine the rheological properties of water-based drilling fluid based on other simple measurable properties. While mud density (MW), marsh funnel (MF), and solid% are key input parameters in this study, the output functions or models are plastic viscosity (PV), yield point (YP), apparent viscosity (AV), and gel strength. The prediction methods were demonstrated by means of a field case in eastern Iraq, using datasets from daily drilling reports of two wells in addition to the laboratory measurements. To test the performance ability of the developed models, two error-based metrics (determination coefficient R2 and root mean square error RMSE) have been used in this study. The current results of this study support the evidence that MW, MF, and solid% are consistent indexes for the prediction of rheological properties. Both mud density and solid content have a relative-significant effect on increasing PV, YP, AV, and gel strength. However, a scattering around each fit curve is observed which proved that one rheological property alone is not sufficient to estimate other properties. The results also reveal that both MRA and ANN are conservative in estimating the fluid rheological properties, but ANN is more precise than MRA. Eight empirical mathematical models with high performance capacity have been developed in this study to determine the rheological fluid properties based on simple and quick equipment as mud balance and marsh funnel. This study presents cost-effective models to determine the rheological fluid properties for future well planning in Iraqi oil fields.

Psyllium husk performance in drilling fluid at elevated temperature and pressure conditions

2018 ◽  
Vol 58 (1) ◽  
pp. 112
Author(s):  
Son Ly ◽  
Xiao Yu ◽  
Xinsong Zhang ◽  
Alireza Salmachi
Keyword(s):  
High Performance ◽  
Elevated Temperatures ◽  
Performance Enhancement ◽  
Drilling Fluid ◽  
Filter Press ◽  
Water Soluble ◽  
Natural Polymers ◽  
Psyllium Husk ◽  
Water Based ◽  
Temperature And Pressure

High performance water-based drilling fluid alternatives that meet performance objectives with minimal environmental impact must continually be developed. Drilling fluid performance is dependent on fluid characteristics, and among those most critical are viscosity and filtration. One avenue to improve drilling fluid performance is through enhancement by use of potent, water-soluble natural polymers. Psyllium husk powder is an environmentally friendly natural polymer derived from ground-up surfaces of psyllium seeds (Plantago ovata). When in contact with water, psyllium husk powder forms a gel-like, extraordinarily viscous substance at very low concentrations. It was previously shown that pure psyllium husk is an excellent viscosity and filtration agent for water-based drilling fluid under standard conditions. Psyllium husk can also be used as a clay-extender to enhance viscosity and filtration performance of bentonite mud; however, further laboratory testing of this performance enhancement under elevated temperatures and pressures is required. Extensive laboratory experiments were therefore conducted to test husk performance in bentonite mud under such conditions. An electronic rheometer and a temperature and pressure adjustable API filter press were used to evaluate viscoelastic and filtration mud characteristics respectively. Concentrations of 0.05–0.4% husk with 5% bentonite were tested at 25−120°C under 1500 psi. An optimal husk concentration of 0.1% was determined, increasing bentonite viscosity and yield point by up to 46.9% and 68.1% respectively. Filtrate loss rate and filtration cake thickness were reduced by up to 25.8% and 35.3% respectively. The optimal concentration was useable up to 70°C (~2800 m) before deflocculating was required.

scholarly journals Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

2020 ◽  
Author(s):  
Xian-Bin Huang ◽  
Jin-Sheng Sun ◽  
Yi Huang ◽  
Bang-Chuan Yan ◽  
Xiao-Dong Dong ◽  
...  
Keyword(s):  
High Performance ◽  
Drilling Fluid ◽  
Nitrogen Adsorption ◽  
Drill String ◽  
Wellbore Stability ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Mechanism Analysis ◽  
Water Based ◽  
Inhibition Performance

Abstract High-performance water-based drilling fluids (HPWBFs) are essential to wellbore stability in shale gas exploration and development. Laponite is a synthetic hectorite clay composed of disk-shaped nanoparticles. This paper analyzed the application potential of laponite in HPWBFs by evaluating its shale inhibition, plugging and lubrication performances. Shale inhibition performance was studied by linear swelling test and shale recovery test. Plugging performance was analyzed by nitrogen adsorption experiment and scanning electron microscope (SEM) observation. Extreme pressure lubricity test was used to evaluate the lubrication property. Experimental results show that laponite has good shale inhibition property, which is better than commonly used shale inhibitors, such as polyamine and KCl. Laponite can effectively plug shale pores. It considerably decreases the surface area and pore volume of shale, and SEM results show that it can reduce the porosity of shale and form a seamless nanofilm. Laponite is beneficial to increase lubricating property of drilling fluid by enhancing the drill pipes/wellbore interface smoothness and isolating the direct contact between wellbore and drill string. Besides, laponite can reduce the fluid loss volume. According to mechanism analysis, the good performance of laponite nanoparticles is mainly attributed to the disk-like nanostructure and the charged surfaces.

Salt-Responsive AM/AMPS/ATC Terpolymers as Modifiers for Rheology and Fluid Loss in Water-Based Drilling Fluid

2018 ◽  
Vol 765 ◽  
pp. 106-112
Author(s):  
Yin Bo He ◽  
Guan Cheng Jiang ◽  
Wu Ge Cui
Keyword(s):  
High Performance ◽  
Drilling Fluid ◽  
Fluid Loss ◽  
Trimethylammonium Chloride ◽  
Polymer Conformation ◽  
Nacl Concentration ◽  
Water Based ◽  
Lower Fluid ◽  
Performance Additives ◽  
Potential Use

In this study, we report salt-responsive amphoteric terpolymers prepared by copolymerization of acrylamide (AM), 2-acrylamido-2-methylpropanesulfonate (AMPS) and 3-acrylamidopropyl trimethylammonium chloride (ATC), and their use as rheology and fluid loss modifiers in water-based drilling fluid (WDF). The dependence of viscosity and turbidity on NaCl concentration indicates the salt-responsiveness of terpolymers, which results from salt-induced polymer conformation changes. In the presence of large quantities of NaCl, comparing with BT/polyanioins solution, bentonite (BT)/terpolymer solution has better shear thinning and thixotropic performance as well as lower fluid loss. Morphology shows that BT/terpolymer solution with NaCl creates high-quality filtrate cake which is compact and thin. A salt-resistant WDF prepared with terpolymers is evaluated and compared with polyanioinc WDF and polyanionic sulfonated WDF. The salt-resistant WDF possesses more favorable rheology, lower fluid loss and stronger tolerance for temperature, suggesting the potential use of AM/AMPS/ATC terpolymers as high-performance additives for salt-resistant WDFs.

Successful Application of Specialized High-Performance Water Based Drilling Fluid to Drill a TAR Section

2019 ◽  
Author(s):  
Abdullah Abahussain ◽  
Rafael Pino ◽  
Hesham El-Dakroury ◽  
Ajay Addagalla
Keyword(s):  
High Performance ◽  
Drilling Fluid ◽  
Water Based

Rapid, Green Synthesis of High Performance Viscosifiers via Photoiniferter Approach for Water-based Drilling Fluid

2021 ◽  
Author(s):  
Sivaprakash Shanmugam ◽  
Georgesha Ross ◽  
Christelle Yimgnia Mbuncha ◽  
Ashok Santra
Keyword(s):  
Green Synthesis ◽  
Carbon Footprint ◽  
High Performance ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Water Based

Generation of high-performance materials under benign conditions is very much needed in the efforts to reduce carbon footprint of oil and gas explorations. Developing high performance novel additives for drilling...

Sodium Silicate Based Drilling Fluid Application in Gulf of Thailand to Stabilise Wellbore: A Case Study

2021 ◽  
Author(s):  
Waleepon Sukarasep ◽  
Rahul Sukanta Dey ◽  
Visarut Phonpuntin
Keyword(s):  
Sodium Silicate ◽  
High Performance ◽  
Drilling Fluid ◽  
Wellbore Stability ◽  
Drilling Fluids ◽  
Gulf Of Thailand ◽  
Hole Cleaning ◽  
Water Based ◽  
Wellbore Strengthening ◽  
Effective Seal

Abstract Sodium Silicate were first used in water-based drilling fluids to stabilize claystone formations in the 1930's, but found favour in the 1990's in high performance, non dispersed water based systems for drilling problematic claystone formations as an alternative to oil-based drilling fluids. In Bongkot South field, Gulf of Thailand, sodium silicate-based drilling fluid (SSBDF) were used with mixed success in shallow gas drilling. Typically, platform WP-33, the claystone formation of the 12¼" section were drilled with 5% v/v Sodium Silicate in the water based drilling fluid together with excessive circulation as intention to improve hole cleaning frequently result in a wellbore that was overgauge by upto 18.9% in some case. This led to further hole cleaning problem that also compromised cement job quality. A further 6 well campaign on WPS-16 required a re-evaulation of the SSBDF coupled to an understanding of the wellbore instability mechanisms that leads to hole enlargement. To overcome better wellbore stability, sodium silicate has been designed by increased concentration to 8% v/v sodium silicate treated drilling fluid showed optimal design for application base on application of SSBDF has been used on platform WP-11 in 2002. Rheology, hydraulic and flow regime was adjusted for laminar flow that reduced the erosion of fragile claystone formation in the wellbore. The revised SSBDF formulation at WPS-16 result in a significant reduction of hole enlargement to 3.2% in the claystone section through a combination of chemicals and mechanical inhibition that contribute improved hole cleaning. The addition of wellbore strengthening material also provide an effective seal to minimize gas invasion. This paper describes the field trials in the Gulf of Thailand drilled with revised sodium sodium silicate based drilling fluid, the use of wellbore strengthening materials to manage gas influxes, better drilling practice and hydraclic simulation concluded that high performance water based drilling fluid of this nature have wider application where oil-base drilling fluid have traditionally been used.

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