Academic literature on the topic 'Synthetic Polymer-based mud'

<p><em>Drilling is one of the important things in the drilling process, from the start of drilling to the point of reaching the intended depth, can assist the smooth process of drilling. The potential problems that can arise one of them is the drilling mud reply (loss of circulation). One way to prevent and cope with the discovery of drilling mud is dissolved. At this time Polymers Synthesis and Sago Flour as material for dissolved system. Both materials enter into the colloidal effect. The colloid solution itself is a relatively large, relatively large dispersion system within the dispersing medium.</em></p><p><em>The purpose and objective in collecting these tasks is to determine the effectiveness of Synthetic and Sago Flour Polymer materials in tackling the drilling mud stock problem. Based on the results of the research found, that A sludge system can provide most of the standard specification where the value of physical properties and rheology. While the B sludge system is inversely proportional, most of it does not meet the standard specification. It can be underlined that B system with Sago Flour as LCM is effective in handling dispersion drilling mud.</em></p>

_ This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 204763, “Minimization of Ultrahigh-Temperature Filtration Loss for Water-Based Drilling Fluid With β-Cyclodextrin Polymer Microspheres,” by Hanyi Zhong, China University of Petroleum and the University of Oklahoma, and Xin Gao, SPE, and Zhengsong Qiu, China University of Petroleum, et al. The paper has not been peer reviewed. _ Because of the rapid degradation of conventional biopolymer or synthetic polymeric additives at high temperatures (HT) or ultra-HT, effective control of water-based drilling-fluid filtration in these environments remains a major challenge in drilling operations. In the complete paper, β-cyclodextrin polymer microspheres (β-CPMs), generally used for drug release and wastewater treatment, have been evaluated and found to be effective, environmentally friendly ultra-HT filtration reducers. Experimental Methods Sodium bentonite (16 g) and deionized water (400 mL) was homogenized by stirring at 10,000 rev/min for 30 minutes. After hydration for another 24 hours, the suspension, which would be the base mud, was ready for use. β-CPMs were mixed into the base mud and hot rolled under temperatures ranging from 120 to 240°C for 16 hours. After hot rolling, the low-temperature/low-pressure (LT/LP) filtration (ambient temperature/0.7 MPa) and high-temperature/high-pressure (HT/HP) filtration test was carried out according to recommended standards. For the HT/HP filtration test, the pressure difference was set to be 3.5 MPa, while the testing temperature was equal to the hot rolling temperature when the temperature was lower than 200°C, and kept at 200°C when the fluid was thermally aged to rise higher than 200°C. A typical HT-resistant water-based drilling fluid was used as a control sample. Several generally used HT filtration loss agents were added and hot rolled at 220°C to compare their effectiveness in HT filtration control.

Drilling deep holes or drilling to provide access to thermal waters places increasingly high demands on the properties of the drilling muds. Due to the very high temperature, it may be difficult to maintain the appropriate rheology of the drilling fluid during drilling, especially when an inflow of highly mineralized brines occurs. High temperatures significantly reduce the effectiveness of most of the polymeric agents currently used in the drilling muds technology, in extreme cases causing complete and irreversible damage to their structure. Polymers with ether bonds, which include starches and cellulose, are the most vulnerable. Based on the literature data, it can be concluded that the disadvantages of these polymers can be effectively compensated by the addition of synthetic polymers, e.g. sulfonated polymers. Another direction in improving the thermal resistance of drilling muds indicated in the literature is the use of carbon nanoparticles: graphene flakes and nanotubes. The article presents an analysis of the possibilities of improving thermal stability of drilling muds by using chemical agents that allow to maintain appropriate rheological and structural parameters and filtration at temperatures up to 130°C. During the tests, three types of chemicals were added to the polymer-potassium drilling mud at different concentrations. The impact of these modifications on technological parameters of the drilling mud was tested. Then, samples modified by the addition of selected agents were exposed to the temperature of 130°C for a period of 24 hours. After this time, the samples were cooled to 20°C, then their technological parameters were measured and compared with the results obtained before aging at high temperature, and based on the obtained results, the effectiveness of individual agents was assessed. Among the agents tested to protect drilling mud against the adverse effects of high temperature, the most beneficial effect was shown by potassium formate in combination with PoliAMPS.

Geopolymer systems are quite successfully used in such operations as industrial and civil construction, production of fire - resistant concrete, isolation and disposal of radioactive waste, etc. The oil and gas industry was no exception. They are one of the most promising alternatives to Portland cement in insulation operations. They allow achieving sufficiently high performances of well construction strength, corrosion resistance, and in some compositions these parameters significantly exceed those of Portland cement. In recent years, a significant amount of research has been carried out aimed at the development of geo polymer compositions for cementing oil and gas wells, which showed that these systems have strength characteristics comparable to Portland cement, low permeability, resistance to drilling mud and reservoir conditions, and the ability to self-repair. However, despite all the advantages of Geo polymer systems, their most significant disadvantage is poor regulation of rheological properties. Geo polymers (GP) with low ash content do not provide the proper rheological characteristics for the use in insulation operations. Low values of pumpability of solutions are still a serious restriction for wide practical implementation. The use of geopolymer solutions with the correct selection of the compositional composition capable of demonstrating significant improvements in strength and rheological parameters as a result of mixing with anhydrous drilling fluids is a very promising solution to this problem. The paper presents the results of research on the additives of non-aqueous fluids such as oil- based and synthetic-based drilling fluids and inverted emulsion drilling fluids on rheology of geo polymers. The obtained results allow stating that the rheological parameters of geo polymer compositions improve up to comparable values with Portland cement, which considerably extends the range of application of these solutions to use in operations of primary, squeeze cementing and well workover.

This study has endeavored to develop an Al2O3-filled natural fiber reinforced polymer composite which is intended to substitute the most widely used synthetic E-glass fiber material. To attain the desired objective of the work, 0, 5, 10, and 15 wt% Al2O3-filled chopped flax/unsaturated polyester resin composite have been developed by the conventional hand-lay-up method followed by a compression molding process. Consequently, characterization and mechanical property tests are conducted based on the ASTM standard. The results revealed that both tensile and impact strength properties of the base chopped flax/unsaturated polyester resin composite are all affected due to the inclusion and variation of the content of Al2O3 in 15 and 25 wt% fiber loading cases. It has been noticed that a 39.06% increase in the ultimate tensile strength of the composite in 25/UPR-5 composition has been gained. The effect of Al2O3 on the impact strength of the base composite has also been analyzed and a 45% increase has been observed in 15/UPR-10 composition. The findings also witnessed that the newly developed composite can be applied to make automotive parts such as mud guard and engine undercover.

Summary Viscoelasticity plays a significant role in improving the performance of the drilling fluid by manipulating its elastic properties. An appropriate value of the first normal stress difference (N1), extensional viscosity (ηe), and relaxation time (θ) enhance the cutting transportability, hole-cleaning ability, filtration loss, and lubrication behavior. However, the performance of the drilling fluid deteriorates during the drilling of high-pressure and high-temperature (HPHT) wells under acid gas and salt(s) contamination. Therefore, it is a challenging task to synthesize a thermally and rheologically stable drilling fluid, which is acid as well as salt(s) resistant, and maintain its desired properties. Although several water-soluble synthetic polymer-based drilling fluids have been used widely for the drilling of HPHT wells, most of these are limited at less than 200°C. Polyanionic cellulose (PAC) has an excellent heat-resistant stability, salt tolerance, calcium and magnesium resistant, and strong antibacterial activity, and it exhibits exceptional filtration and rheological behavior under HPHT conditions. However, using PAC beyond 200°C is limited because of the presence of the biodegradable cellulose units in it. To use the extraordinary properties of PAC, it is aimed to increase the thermal stability of PAC through appropriate modification. In this study, PAC-grafted copolymers involving acrylamide (a salt-tolerant viscosifying agent), 2-acrylamide-2-methyl-1-propane sulfonic acid (a thermally stable lubricating and fluid-loss control agent), and sodium 4-styrene sulfonate (a high-temperature deflocculant) is synthesized optimally through maximizing the thermal degradation stability of the grafted copolymer and minimizing the filtration loss as well as the coefficient of friction (CoF) of the drilling fluid simultaneously. Optimally synthesized PAC-grafted copolymers are then used to prepare water-based mud (WBM) involving American Petroleum Institute (API)-grade bentonite and alpha-glycol functionalized nano fly ash, and the tests for steady shear viscosity and viscoelasticity are performed to determine the rheological stability of mud beyond 200°C. The amplitude sweep tests for viscoelasticity are performed to determine the linear viscoelasticity range (LVR), structural stability, gel strength, and dynamic yield point (YP), whereas frequency, time, and temperature sweep tests are performed to obtain the elastic modulus (G′), viscous modulus (G″), and complex viscosity under HPHT conditions to check the stability of the drilling fluids under different holding times. Dynamic and static aging tests of the developed drilling fluids are performed at elevated temperature and pressure, and the aged muds are tested by evaluating the rheology, frictional, and filtration-loss behavior as per the API recommended procedure. The stability of the aged muds is also tested by evaluating the N1, ηe, and θ using a cone and plate rheometer. The performance of the proposed drilling fluids is also tested under acidic, sodium chloride (NaCl), and calcium chloride (CaCl2) environments at HPHT bottomhole conditions. The experimental results under HPHT conditions reveal that the performance of the mud (i.e., thermal stability, cutting transportability, hole-cleaning ability, filtration loss, and lubrication behavior) could be considerably improved by increasing the elastic properties of the drilling fluid by manipulating the molecular weight of the proposed PAC-grafted copolymer. Finally, the environmental effect of the developed muds is evaluated by finding the lethal concentration that kills 50% of the shrimp population (i.e., LC50) and the Hg and Cd contamination, and they are found to be environmentally safe.

As the oil and gas drilling industry moves into more technically challenging environments [e.g., drilling ultradeep onshore/offshore wells under extremely high temperature (above 300°F) and pressure (mud specific gravity above 2.0)], companies increasingly come under pressure to stretch technology and improve drilling performance while continuously striving to reduce costs and meet the requirements of stricter environmental regulations. Significant reserves additions may be realized if the risks associated with drilling in such harsh conditions (e.g., pressure control, wellbore instability, lost-circulation, sour gas) can be managed effectively. Design and development of a new generation of drilling fluids able to fulfill all of the attributed functions (e.g., stabilize the wellbore, control formation pressure, transport the drilled cuttings, minimize the fluid loss, and not reduce formation productivity) under such extreme pressure and temperature conditions is one of the key requirements for unlocking these resources. Drilling fluids used under ultrahigh pressures and temperatures need to be thermally stable and able to retain their rheological properties. Traditionally, nonaqueous drilling fluids (NADFs) have been used under these extreme conditions. NADFs, however, have significantly high operational costs with an associated health, safety, and environmental risk. As a result, there has been an increasing demand from operators to use aqueous drilling fluids [water-based muds (WBMs)], which are known to be environmentally benign and relatively less expensive. The use of WBMs under extreme temperatures and pressures, however, faces several challenges, including the breakdown of polymers and other additives used as fluid-loss preventers and rheological stabilizers. Therefore, recent research has focused on design and development of WBM systems meeting the following specifications: - Use of sodium chloride (for barite-laden formulation) and sodium bromide (for barite-free formulation) as base brines to reduce the total solids content for optimal fluid properties and to maximize the quality of wireline logs - Ensure inhibition of reactive shale formations to maintain wellbore stability while drilling intermediate sections - Provide optimal and stable rheological properties for excellent hole cleaning and drilling performance The newly developed ultrahigh-temperature water-based systems used custom-made branched synthetic polymers that exhibit superior rheological properties and fluid-loss control as well as long-term stability above 400°F. These branched synthetic polymers are compatible with most oilfield brines and maintain excellent low-end rheology. Other formulations proposed the use of β-cyclodextrin polymer microspheres (β-CPMs) as an environmentally friendly ultrahigh-temperature filtration reducer. When the temperature rose above 160°C, a hydrothermal reaction occurred for β-CPMs, and, as a result, numerous micro- and nanosized carbon spheres formed, which bridged across micro- and nanopores within the filter cake and reduced the filter cake permeability effectively. Bentonite-hydrothermal carbon nanocomposites also are proposed as nonpolymer additives to solve the ultrahigh-temperature/-pressure challenge in water-based drilling fluid. The nanocomposites are synthesized by a simple hydrothermal reaction in which biomass starch and sodium bentonite are used as the precursor and template, respectively. Such formulations have shown favorable rheology and filtration properties after hot rolling at temperatures as high as 460°F. This section presents selected papers showing examples of design, development, and field applications of the new generation of WBM fluid technologies. Recommended additional reading at OnePetro: www.onepetro.org SPE 206444 - Successful Application of a New Generation of Clay-Inhibitor Polymers While Drilling a Deep Exploration Well in the Astrakhan Region by Petr Leonidovich Ryabtsev, Akros, et al. SPE 205539 - Improvement of Rheological and Filtration Properties of Water-Based Drilling Fluids Using Bentonite-Hydrothermal Carbon Nanocomposites Under Ultrahigh-Temperature and High-Pressure Conditions by Hanyi Zhong, China University of Petroleum East China, et al. SPE 209805 - The Utilization of Self-Crosslinkable Nanoparticles as a High-Temperature Plugging Agent in Water-Based Drilling Fluid by Ming Lei, University of Alberta, et al.

The high-temperature stability and filtration property controlling of ultra-high-temperature water-based drilling fluids is a worldwide problem. To resolve this problem, a high-temperature-resistant quaternary copolymer (HTRTP) was synthesized based on molecular structure optimization design and monomer optimization. The physical and chemical properties were characterized by infrared spectroscopy, thermal weight, and spectrophotometry, and their temperature and salt resistance was evaluated in different drilling fluids, combined with adsorption, particle size analysis, and stability test. The results show that the thermal stability of HTRTP is very strong, and the initial temperature of thermal decomposition is above 320°C. The salt resistance of HTRTP is more than 162 g/L, and the calcium resistance is more than 5000 mg/L, which is equivalent to the foreign temperature-resistant polymer DCL-a, and is superior to the domestic metal ion viscosity increasing fluid loss agent PMHA-II for drilling fluids. It has excellent high-temperature resistance (245°C) and fluid loss reduction effect in fresh water base mud, fresh water weighted base mud, saturated brine base mud, and composite salt water base mud, which is better than foreign DCL-a (245°C) and domestic PMHA (220°C). The adsorption capacity of HTRTP on clay particles is large and firm, and the adsorption capacity changes little under the change of chemical environment and temperature. Both before and after HTRTP aging (245°C/16 h), the permeability of filter cake can be significantly reduced and its compressibility can be improved. By optimizing the particle size gradation of the drilling fluid and enhancing the colloid stability of the system, HTRTP can improve the filtration building capacity of the drilling fluid and reduce the filtration volume. The development of antithermal polymer provides a key treatment agent for the study of anti-high-temperature-resistant saline-based drilling fluid.