The Static Laboratory Testing for Fracturing Fluid Optimization

Hydraulic fracturing operation is the common method to stimulate an oil well in order to make the permeability around the well become higher by injecting a mixing of fracturing fluid and proppant. Hopefully, this higher permeability can contribute to increase the production of oil and/or gas. The fundamental laboratory assessment of fracturing fluid as a part of injected component is important to be conducted before field scale implementation. One of the fundamental assessment is the static laboratory testing. In this test, the fracturing fluid sample is measured to obtain the data about its properties such as water quality, rheology, crown time and breaking time. These properties give important role to calculate the performance of the hydraulic fracturing field scale operation would be. In this research, we conducted the static laboratory testing for fracturing fluid in sensitivity of concentration which are 35, 40 and 45 systems. Every concentration have been measured its properties in order to compare each other to evaluate and select best fracturing fluid candidate for field scale application.

How to Make Sensitive Formations Produce Oil: Case Study of the Complex Laboratory Approach to Stimulation Fluid Optimization

The Bahrain field is one of the oldest developed oil fields in the Middle East, with over a dozen formations in production since the early 1930s. Currently, development of the shallow zones (<2,000 ft) of the Magwa and Ostracod formations is a challenge due to the unique complexity and extreme clay sensitivity. With previous fracturing attempts showing limited success, enhanced laboratory testing was undertaken to make fracturing treatments economic. Formation stabilization improvement is crucial in certain reservoir mineralogies, especially those with exposed shale streaks and high concentrations of clays that exhibit extremely high brine sensitivity. Lack of adequate stabilization of sensitive clays and shales risks the deconsolidation of those minerals into fines that may potentially damage the conductivity of the proppant pack in fracturing operations. Many problems associated with the use of water-based fluids in fracturing operations are caused by incompatibilities between the fracturing fluid and the shale minerals, resulting in a fines migration problem in the relatively low-permeability reservoir and a production decline after the fracturing operation. A scientific approach was applied to the selection of novel shale inhibitors to be used in fracturing applications. First, a laboratory testing program was followed to incorporate a new shale inhibitor into the fracturing fluid system. The fluid recipe was further optimized with a reduction in polymer loading, maximizing breaker concentration and ensuring fast shear recovery, because the stimulation design called for large-size proppant (up to 12/20 mesh) to be used in a low-temperature (124°F) environment. The laboratory results demonstrated that the new shale inhibitor significantly reduces alteration of the permeability of the treated core and improves shale stability. The new inhibitor was deployed in the field, as documented in several case histories. Production results of the treated wells demonstrated several-folds increase in production when compared to previously attempted proppant fracturing treatments. The pilot stimulation campaign proved the value of the laboratory research and brought on line two formations with large potential contribution to Bahrain's overall oil production. Although there is a substantial amount of literature on shale inhibition with water-based drilling fluid, the importance of the shale inhibition and the problems associated with shale reactivity during the fracturing operation remain largely unexplored. This paper presents the complex laboratory approach to stimulation fluid optimization in the Bahrain field. The novel solutions and comprehensive workflow description will benefit a broad variety of projects worldwide targeting water-sensitive or low-temperature formations that represent challenges to fracturing fluid selection.

Crystalloids vs. colloids for fluid optimization in patients undergoing brain surgery

BACKGROUND This randomised, double-blinded, single-centre study prospectively investigated the impact of goal directed therapy and fluid optimization with crystalloids or colloids on perioperative complications in patients undergoing brain surgery. METHODS 80 patients were allocated into two equal groups to be optimised with either crystalloids (n=40) or colloids (n=40). Invasive hemodynamic monitoring and optimization with fluids and vasoactive drugs were used to adjust and maintain mean arterial pressure and cerebral oxygenation within the baseline values (± 20%) and stroke volume variation (SVV) ≤13. Postoperative complications from different organ systems were monitored during the first 15 days after surgery. Hospital stay and mortality were also recorded. RESULTS Crystalloid group received significantly more fluids (p = 0.003) and phenylephrine (p = 0.02) compared to colloid group. This did not have any significant impact on intraoperative or postoperative complications, hospital stay or mortality, where no differences between groups were observed. CONCLUSIONS Either crystalloids or colloids could be used for fluid optimization in brain surgery. If protocolised perioperative haemodynamic management is used, the type of fluid does not have significant impact on the outcome. CLINICAL TRIAL REGISTRATION: Identified as NCT03249298 at www.clinicaltrials.gov KEY WORDS: Brain surgery, fluid optimization, haemodynamic management

A Success of Modified Water Based Mud as Drilling Fluid Optimization to Drill Shale Formation at South-S Wells

This paper is to explain the optimization of using Modified Shale Inhibitor Water Based Mud (WBM) to drill up to 5,500 ft interval of K-formation reactive shale on South-S Gas Wells. By combining a comprehensive method consists of drilling fluid laboratory test and lessons learned in S area, the optimization was done by determining the amount or concentration of Polyamine & KCl combination, pure Polyamine, Polyamine & NaCl combination, and Pure KCl-Polymer in WBM system as a shale inhibitor. The comparison of shale inhibitor compositions were made by comparing the achieved optimization of drilling fluid program such as drilling time, cost economic, and environment aspect. The basic idea of the WBM optimization was to improve drilling time during drill 5,000 ft footage in 12-1/4" hole section in reactive shale formation as per drilling program. Laboratory test consists of Linear swelling meter with various parameter concentration of Polyamine & KCl combination, pure Polyamine, Polyamine & NACl combination, and Pure KCl-Polymer in WBM system as a shale inhibitor and cation exchange capacity test (CEC or MBT) was done using composite of offset well shale cutting. Experience showed that on 12-1/4" hole section, while facing reactive shale (CEC 18 - 24 meq/100 gr) from K-formation on South-S, modified WBM was proven to eliminate reactive shale issues and lead to budget saving without environmental issues.

Non-invasive methods for the treatment of gingivitis and periodontitis mild severity

The methods of treatment of gingivitis and generalized periodontitis of mild severity are presented. Based on the analysis of modern views, it is concluded that the therapy of periodontal diseases of mild severity should be aimed at the normalization of the microflora of the gingival sulcus and oral fluid, optimization of dental occlusion, provide osteotropic, antihypoxic and anti-stress actions.

Unlocking the Effects of Fluid Optimization on Remaining Oil Saturation for the Combined Sulfate-Modified Water and Polymer Flooding

Interfacial interactions and wettability alteration remain as the main recovery mechanism when modified water is applied seeking to obtain higher oil recoveries. Fluid-fluid interaction could lead to the development of the called viscoelastic layer at the interface in oil-brine systems. This interfacial layer stabilizes thanks to the slow chemical interaction between oil polar compounds and salts in the brine. This study investigates the role of sulfate presence in injection brine that could possible lead to develop the interfacial viscoelastic layer and hence to contribute to the higher oil recovery. Furthermore, polymer flooding is performed in tertiary mode after brine flood to investigate/unlock the synergies and potential benefits of the hybrid enhanced oil recovery. Brine optimization is performed using the composition of two formation brines and four injection brines. Moreover, interfacial tension measurements and oil drop snap-off volume measurements are performed in parallel with the core flooding experiments to define the role of interfacial viscoelasticity as the recovery mechanism other than wettability alteration. Synthetic seawater spiked with double amount of sulfate depicted potential results of interfacial viscoelastic layer development and hence to contribute the higher oil recovery. Total oil recovery after secondary-mode using sulfate-modified water and tertiary-mode polymer flood was higher than the combination of seawater brine in secondary-mode and polymer flood in tertiary-mode. Nevertheless, experiments helped us concluding that the amount of sulfate added is a critical factor to obtain maximum oil recovery and to avoid pore-plugging problems. We, therefore, demonstrate that executing a detailed fluid optimization leads to promising laboratory results, potentially linked with an improvement in the economics of the field applications.

Perioperative Goal-Directed Hemodynamic Therapy: From Invasive Monitoring To Automated Physiological Closed-Loop Systems

Perioperative goal-directed hemodynamic therapy (GDHT) has evolved from invasive “supra-physiological” maximization of oxygen delivery into minimally and non-invasively guided automated stroke volume optimization. Throughout this evolution, investigators have simultaneously developed novel monitors, updated strategies, and automated technologies to aid them in GDHT implementation. In particular, closed-loop systems have been created to both increase GDHT compliance and decrease physician workload. Currently, these automated systems offer an elegant approach to help the clinician optimize cardiac output and end-organ perfusion during the perioperative period. Most notably, automated fluid optimization guided by dynamic parameters of fluid responsiveness has shown its feasibility, safety, and impact. Making the leap into fully automated GDHT has been accomplished on a small scale, but there are considerable challenges that must be surpassed before integrating all hemodynamic components into an automated system during general anesthesia. In this review we will discuss the potential future of automated GDHT by covering the key events that paved the way from initially complex and time consuming approaches to simple yet effective hands-free strategies.