Experimental Pore-Scale Study of a Novel Functionalized Iron-Carbon Nanohybrid for Enhanced Oil Recovery (EOR)

Nanofluid flooding, as a new technique to enhance oil recovery, has recently aroused much attention. The current study considers the performance of a novel iron-carbon nanohybrid to EOR. Carbon nanoparticles was synthesized via the hydrothermal method with citric acid and hybridize with iron (Fe3O4). The investigated nanohybrid is characterized by its rheological properties (viscosity), X-ray diffraction (XRD), and Fourier transform infrared spectroscopy (FTIR) analysis. The efficiency of the synthetized nanoparticle in displacing heavy oil is initially assessed using an oil–wet glass micromodel at ambient conditions. Nanofluid samples with various concentrations (0.05 wt % and 0.5 wt %) dispersed in a water base fluid with varied salinities were first prepared. The prepared nanofluids provide high stability with no additive such as polymer or surfactant. Before displacement experiments were run, to achieve a better understanding of fluid–fluid and grain–fluid interactions in porous media, a series of sub-pore scale tests—including interfacial tension (IFT), contact angle, and zeta potential—were conducted. Nanofluid flooding results show that the nanofluid with the medium base fluid salinity and highest nanoparticle concertation provides the highest oil recovery. However, it is observed that increasing the nanofluid concentration from 0.05% to 0.5% provided only three percent more oil. In contrast, the lowest oil recovery resulted from low salinity water flooding. It was also observed that the measured IFT value between nanofluids and crude oil is a function of nanofluid concentration and base fluid salinities, i.e., the IFT values decrease with the increase of nanofluid concentration and base fluid salinity reduction. However, the base fluid salinity enhancement leads to wettability alteration towards more water-wetness. The main mechanisms responsible for oil recovery enhancement during nanofluid flooding is mainly attributed to wettability alteration toward water-wetness and micro-dispersion formation. However, the interfacial tension (IFT) reduction using the iron-carbon nanohybrid is also observed but the reduction is not significant.

The Use of Crude Coconut Oil (CCO) as an Alternative Oil Base Mud (OBM) for Drilling Operations by "VICOIL" Standard Drilling Simulation Rig

Shale is one of the rocks that often causes drilling problems because shale tends to swell or swell when in contact with mud filtrate, mainly water-based or Water-base Mud (WBM). This study aims to determine how the performance of Oil-base Mud (OBM) based on Crude Coconut Oil (CCO) in overcoming the swelling problem. The methodology used consists of drilling simulation and cutting analysis in the X-Ray Diffraction (XRD) laboratory. The series of activities in the study began with the preparation of rock layers, followed by testing the penetration rate using Water-base Mud as a comparison. After cutting analysis was carried out in the XRD laboratory of UPN "Veteran" Yogyakarta with the Rigaku tool, then replaced the type of drilling fluid Oil-base Mud with basic materials alternative to Crude Coconut Oil (CCO) and followed by a penetration test. Rate of Penetration (ROP) test results from WBM with Rheology 1 at interval depth of 1.64 ft-3.28 ft is 442.8 ft/h, Rheology 2 at interval depth of 4.92-6.5 ft is 118.5 ft/hr on the first day. Swelling occurred and results in pipe sticking at depth of 3.28 and 6.5 ft. Based on the Bulk Mineral analysis, clay mineral content is 23.84%. Based on the Clay Oriented, smectite dominates the clay by 29.09%. Based on MBT, shale belongs to class B (illite and mixed-layer montmorillonite illite), where this mineral can expand. Based on a Geonor As test, 5.18% of the cutting can develop when exposed to water. The drilling fluid was replaced with Oil-base Mud based on alternative Crude Coconut Oil (CCO), and obtained ROP Rheology 1 at Interval depth of 3.28 ft-4.92 ft is 492 ft/h and Rheology 2 at Interval depth of 6.5 ft-10.5 ft is 480 ft/h. The results of the Compressive Strength test interval A on the first, third, and fifth days were 31,699 psi, 42,265 psi, and 52,831 psi. The results of the Compressive Strength test interval B on the first, second, and third days were 31,496 psi, 41,517 psi, and 52,971 psi. Based on clay mineral analysis and magnitude of ROP value, is known that Crude Coconut Oil (CCO) based Oil-base Mud is effective because during the simulation, there are no drilling problems, and the resulting ROP value is greater than the first day Water-base Mud.

A Highly Successful Way to Consistently Drill to Target Depth with Nano Polymer Water-Based Mud in a Highly Active, Problematic Shale Interval

The operational drilling history in a particularly challenging shale consistently shows that once the formation's shale reacts, and starts to disperse, in the face of a typical water base mud application, a variety of hole problems are experienced by the operator. These problems include wellbore instability caused by an unstoppable sloughing of the shale; the experiencing of tight hole conditions while performing the wiper trip; caved shale sticking to shakers while drilling; an increased dilution rate due to mud weight; a low LGS % (low gravity solids), and fluid viscosity. To solve this longstanding drilling challenge, a team formed from operator and service provider experts determined via high-level research and testing the need for an innovative new technology of inhibitive fluid chemistry. After extensive testing, the team determined that a particular environmentally friendly Nano Polymer high-performance water-based mud (HPWBM)—one possessing the unique shale inhibition and cutting encapsulation capabilities capable of stabilizing this sticky shale—was the best fit for this application. We will present the investigational learning and effective field trial drilling of high problematic shale that was evaluated during and subsequently the utilization of nanoparticles (NP) to advance water-based mud (WBM) inhibition properties, proven to offer an eco-friendly Nano Polymer HPWBM substitute with the improved thermal and rheological permanency of the overall WBM formulation. Results will display that while providing more effective drilling and wellbore stability, this technology is also a far cleaner industry alternative.

Effect of Temperature and Nanoparticle Concentration on the Viscosity of Glycerine-water based SiO2 Nanofluids

Dynamic viscosity of SiO2/22nm nanofluids prepared in a glycerine-water (30:70 by volume) mixture base liquid, referred to as GW70, is measured experimentally. Nanofluids with concentrations of 0.2, 0.6, and 1.0 percent are produced, and viscosity measurements are carried out at temperatures ranging from 20 to 80 oC using a LVDV-2T model Brookfield Viscometer. The particle size and elemental composition of nanoparticles are determined using FESEM and EDX. XRD images confirm the SiO2 peaks in the crystalline structure. The rheology of nanofluids is influenced by the nanoparticle’s concentration. In the experimental temperature and concentration range, nanofluids show Newtonian behavior. The viscosity of nanofluids enhanced as particle concentration increased and reduced as temperature increased. For 1.0 percent vol. concentration at 20oC, the maximum viscosity value is achieved, and for 0.2 percent vol. concentration at 80oC, the lowest viscosity value is observed. The viscosity of the glycerine-water base fluid was also determined at 20, 40, 60, and 80 degrees Celsius. The viscosity ratio of nanofluids to the base liquid is found to be more than one for all the nanofluids. This viscosity data is useful to estimate HTC of glycerine-water-based silica nanofluids.

Essential Oil from Lemon Peel (Citrus lumion) and application in Skin-Care Lotion

Essential oil from peels of lemon (Citrus Lumion) fruit had been evaluated for its physiochemical, phytochemical compositions and application in skin-care product. Lemon peel oil, which is one of the under-utilized essential oil was isolated from the matured fruits peel using petroleum ether by soxhlet extraction method. The percentage yield of 3.7 %, for air-dried peels and 2.30 %, for fresh peels are acceptable for most plants essential oils. The ash content of both the dried and fresh peels were 1.42 ± 0.001 and 4.007±0.003. Some phytochemicals like, saponins, flavonoids, terpenes, carbohydrates, tannins, were determined using standard methods. The lemon-peel-oil skin-lotion formulation was carried out by mixing 5 ml of the peel oil sample with corresponding mass of basic lotion compositions, in water base-tank, and homogenously mixed in oil base-tank under 700 C. The pH range(6.30), viscosity, spreadability, and properties of the lotion were compared to the non-lemon-oil lotion and to a commercial grade skin lotion.

Effects of soaking in water, base oil, ionic liquid and grease of an epoxy/UHMWPE/MoS2 composite on mechanical and tribological properties

Liquid absorption and tribological studies of epoxy-based composite with ultra-high molecular weight polyethylene (UHMWPE) and MoS2, sliding against steel were conducted. Composites, as coating and as a bulk, were soaked in water, base oil, ionic liquid and lithium-based grease for different intervals of days or months. Liquid weight% gain was more in polar liquids when compared to non-polar. Coated composite soaked in grease for 10 days showed coefficient of friction of 0.08 with wear-life of more than 1 million cycles and wear rate of 1.7×10−8 mm3/Nm. Bulk polymer composite soaked in grease for 180 days provided the least coefficient of friction of 0.06 and specific wear rate of 2.60×10−7 mm3/Nm.

Synthesis of a Novel Filtrate Reducer and Its Application in Water-Based Drilling Fluid for Ultra-High-Temperature Reservoirs

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.