Se evalúa la factibilidad técnica y económica del uso de un ciclo binario del tipo ORC para la generación de electricidad, a partir del aprovechamiento del recurso geotérmico de baja temperatura disponible en varios campos de petróleo en Colombia. Las temperaturas del agua obtenida como subproducto durante la extracción de crudo son 118 ºC en boca de pozo y 82 ºC en etapas de disposición, con caudales de hasta 2,38 m3/s. Para incrementar la eficiencia del ciclo convencional, fueron evaluadas alternativas de calentamiento de la corriente del lado de alta temperatura y de enfriamiento del lado de baja temperatura. Se encontró que un equipo comercial ORC de 280 kW  produciría en uno de los campos 1.165,1 MWh anuales  con un costo de generación de 0,102 U$/KWh. Los resultados de este estudio no permiten la implementación de equipos ORC porque se requieren mayores temperaturas que garanticen la factibilidad técnica.Abstract: These paper analyze the technical and economic feasibility of generating electricity from low temperature geothermal resources available in oil oilfields in Colombia using binary ORC technology. The water obtained as a byproduct during oil extraction has 118°C temperatures at wellhead and 80ºC on average in disposal stages; the water flow rates reach values of 2.38 m3/s. Were studied to improve the efficiency, technical options for additional heating and cooling of hot and cold streams.  According to the results found, 1.165,1 MWh energy production by year and 0,102 U$/KWh in unitary generation cost is for the 280 kW commercial ORC machine. According to the experience developed in this study results do not permit ORC immediate implementation because are necessary higher temperatures to guarantee technical feasibility.Sumário: A viabilidade técnica e econômica da utilização de um ciclo ORC binário para geração de eletricidade a partir da utilização de recursos geotérmicos de baixa temperatura disponíveis em vários campos de petróleo na Colômbia é avaliada. As temperaturas da água obtida como um subproduto durante a extração de petróleo cru são 118 ºC na boca de poço e 82 ºC em fases de distribuição, com vazões de até 2,38 m3/s. Para aumentar a eficiência do ciclo convencional, foram avaliadas (várias) opções de aquecimento da corrente de alta temperatura e de esfriamento do lado de baixa temperatura. Verificou-se que um equipamento comercial ORC de 280 kW poderia gerar em um dos campos 1165,1 MWh anuais a um custo de 0,102 U$/kWh. Estes resultados não permitem a implementação de equipamentos ORC porque precisam-se temperaturas mais altas para assegurar a viabilidade técnica.

Casing design for oil and gas wells continues to evolve to adapt to increasing challenges. The casing program of most wells represents a significant portion of the total well cost, between approximately 15 and 35%. This paper discusses how expandable liner hanger (ELH) technology continues to evolve to meet the needs of an operator with a new thick walled casing design in fields with H2S and CO2. Circumstances are described wherein thick wall casing design was necessary (greater collapse pressure and room for production safety valves). Details are presented describing why the ELH was selected, challenges encountered, development of a new liner hanger to fit the smaller thick-walled casing inside diameter (ID), and how the liner hanger running tool was modified to work inside a smaller casing. Prejob analysis that was performed to help reduce risks while running in hole (RIH) is discussed. Also highlighted are improved procedures, torque and drag simulations, surge and swab simulation, and critical well review exercises. The operator chose a well design using 10 3/4 in. casing for a larger inside diameter (ID) installation of an arrangement using double electric submersible pumping (DESP). Casing weight of 79.2 ppf was selected to support the pressure load during well production. The ELH system complemented the new heavy wall casing design during construction and installation because of the many benefits it provided, such as high torque, washing and reaming, and multiple setting contingencies. Suitable expandable material was selected for the H2S and CO2 well environment. Two ELHs were used to run into 10 3/4 and 13 5/8 in. casing, 7 5/8- and 10 3/4-in. in liner through a sidetrack with deviation of more than 75° at the bottom, overcoming entrapment issues during the operation, and reaching total depth (TD). The cementing operation was executed successfully and the ELH expanded, leading to a successful operation with zero health, safety, and environment (HSE) or service quality issues. This paper discusses the latest ongoing developments in ELH technology applied using a new casing size and weight during the construction of oil and gas wells with sour service requirements.

It is well recognized that oil and gas companies have increased the implementation of collaborative centers to improve real-time decision making. This reduces nonproductive time (NPT) and improves efficiency in oilfield operations. Emerging technologies now enable end users to receive and send intelligent commands while tools operate under downhole conditions. This not only provides the advantage of fewer trips in and out of the hole, but also the ability to control operations from an office-based environment.In the last few years, Schlumberger has increased the number of collaborative centers, known as Operation Support Centers (OSC TM ), to work closely with operators throughout the world. Surface and downhole data are currently transmitted to these centers in real-time as part of the execution phase in the drilling optimization process. While the focus of this paper is on drilling, real-time data is clearly not limited to the drilling phase and in many cases has been used for completion monitoring and control.As the implementation of these centers has continued, drilling activity increased more quickly than experts could be developed in all areas of operation and support, despite aggressive recruiting and intense training and development. As a result, experts gathering in one room to advise jointly on several simultaneous rig operations became the norm and operators who experienced it quickly embraced the OSC TM concept.Real-time centers, therefore, have become the chief venue for collaboration, data capture, sharing and training, in a way that better meets the needs of fast-growing operations. Interestingly, they have also become a focal point for better coordination of operational changes, as improved communication with tools downhole and with service personnel have facilitated reduced crew and support requirements.This paper describes the challenges faced in implementing remote drilling operations, the work processes that allow one directional driller (DD) and one measurement while drilling (MWD) engineer to oversee several rigs simultaneously, and details the necessary infrastructure, communication systems and operating results.

At the beginning of 2015 in response to the well construction difficulties faced by drilling companies such as lost circulation, slow Rate of Penetration (ROP) and increasing flat times observed while drilling in an extra heavy oil asset in the Gulf of Mexico, the operator implemented a real-time drilling monitoring center called Centro Inteligente de Pozos (CIP by its Spanish acronym). The whole purpose of the team and technologies deployed at the CIP is to Anticipate and prevent drilling events; effectively and systematically reduce drilling Nonproductive times (NPT); implement best practices aimed to optimize drilling performance and operate closer to the wells’ technical limits; and accelerate initial oil production by finishing wells before expected. The CIP solution is comprised of a very well balanced combination of technologies, resources and processes as follow: Data acquisition, transmission and visualization: Vendor neutral technologies and services are deployed in both ends the rig and the office to enable data collection, integration, aggregation and transmission. Risk analysis: For each well and prior to start drilling, the CIP team prepares a detailed drilling risk analysis, which includes risk description, prevention and mitigation practices. Drilling optimization: CIP’s engineers use specialized drilling monitoring software to analyze available data, managed identified risks, optimize performance, and make operating recommendations to exceed performance while drilling within the wells’ technical limits. At the CIP, the well-coordinated efforts between the operator and the service company in conjunction with the application of efficient processes and innovative technologies, have been cornerstone to reach drilling optimization while minimizing the negative impact of drilling events; making the CIP initiate a success for the operator and service companies. As a result of implementing the CIP, wells in the Extra Heavy Oil Asset have been drilled in record times. For example, a well that was originally planned to be drilled in 116.7 days was drilled in 89.9 days. This represents total savings of 26.8 rig days (~23% time saved), with a corresponding oil production estimated at 6,000.00 bpd. Our industry constantly strives to drill faster and safer wells while drilling in more challenging environments. In the author’s opinion one way to achieve this is by adapting classic surveillance procedures with modern workflows based on real-time data and considering relevant analysis such as risk estimation, real-time geomechanics and flat times optimization. The work described in the following pages represents the first successful application of advance real-time drilling monitoring techniques in the Extra Heavy Oil Asset matter of this paper.

This article, which is based on the research conducted for the General Report 'Relief in Small and Simple Matters in an Age of Austerity' presented at the XV World Congress of Procedural Law, provides a contextualised and broad overview of these phenomena in the United States. After describing the general features of the federal and state judiciaries, including its adversarial model of judging, and the importance of the jury system, the article turns its attention to discuss the factors that affect the cost of litigation in the United States, the different models of litigation funding, the available legal aid mechanisms, and the procedural tools available for handling small and simple disputes. Furthermore, this article briefly revisits the discussion about the effect of austerity on the functioning of the United States legal system on the handling of small and simple matters and ends with a brief conclusion that summarises its contribution and sketches the points for future research on this important topic.