La CFE adjudica proyecto de gasoducto a IEnova
/en NewsLa mejor propuesta para el Ramal Empalme se ubicó en 10 millones 845 mil 414 dólares.
La Comisión Federal de Electricidad (CFE) adjudicó a la empresa Gasoducto de Aguaprieta, filial de Infraestructura Energética Nova (IEnova), el proyecto Ramal Empalme, por presentar la mejor oferta.
De acuerdo con la empresa productiva del Estado, la propuesta de la compañía fue por 10 millones 845 mil 414 dólares, un ahorro de 72% a lo presupuestado originalmente.
La CFE precisa que el contrato comprende la ingeniería, permisos y autorizaciones, construcción, operación y mantenimiento por parte de la empresa que desarrollará de la obra.
El gasoducto tendrá una capacidad de transporte reservada por la CFE de 226 millones de pies cúbicos diarios, con un diámetro de 20 pulgadas y una longitud de 20 kilómetros, cuya operación se prevé para mayo de 2017.
El gasoducto se ubicará en el estado de Sonora, se interconectará con el gasoducto Sásabe- Guaymas y con el gasoducto Guaymas–El Oro para suministrar gas natural a las centrales de Ciclo Combinado Empalme I y Empalme II, ahora en construcción, agrega.
17 meses a la baja. La CFE también informó que logró sumar 17 meses consecutivos de reducción de tarifas eléctricas para el sector industrial, la cual prevé que disminuya entre 11 y 19% durante el presente mes.
Para el sector comercial la baja será de entre 2 y 9%; mientras que para el sector doméstico de alto consumo (tarifa DAC) se anticipa una disminución de 2%, dijo la empresa eléctrica.
En un comunicado, la CFE indicó que el sector doméstico de bajo consumo, cuya tarifa subía 4.0 por ciento cada año desde 2006 y hasta 2014, este año no subirá y a partir del 1 de enero de 2016 bajó 2.0 por ciento respecto a diciembre de 2015.
Además, la empresa productiva del Estado resaltó que se registró una reducción en las tarifas eléctricas de mayo respecto a las de abril del presente año en el segmento industrial de entre 10 y 14%; para el sector comercial de entre 5 y 9%; mientras que para el sector doméstico de alto consumo disminuye en 5%.
Fuente: El Universal
Oil Ends Steady Near $50; Best Monthly Gain in Brent in 7 years
/en NewsOil prices ended steady on Friday after hitting 2016 highs but finished April trading about 20 percent higher, with Brent crude having its best monthly gain in seven years. A weaker dollar and optimism that a global oil glut will ease have lifted crude futures by more than $20 a barrel since they plumbed 12-year lows below $30 in the first quarter. Brent futures settled just a penny lower at $48.13 a barrel, after reaching a 2016 peak at $48.50. It rose 21.5 percent in April, its largest monthly advance since May 2009. U.S. crude futures closed 11 cents lower at $45.92 a barrel, after hitting a year-to-date high at $46.78. It gained 20 percent in April, the biggest monthly gain in a year.
With prices less than $5 away from $50 a barrel, investment bank Jefferies said the market «is coming into better balance» and would flip into undersupply in the second half of the year. But others warned that the rally was driven by investors holding large speculative positions, while oil stockpiles were still high, with a Reuters survey showing OPEC output in April rising to its most in recent history. «The issue is that we haven’t seen price rallies … correlate with fundamentals,» said Hamza Khan, senior commodity strategist at ING. «The fundamentals – high stocks, high production – haven’t changed.» Technical analysts said crude could cruise to $50 a barrel but stiffer resistance before $55 could spark profit-taking on the market’s biggest rebound in two years. Analysts polled by Reuters raised their average forecast for Brent in 2016 to $42.30 per barrel, the second consecutive month of increases.
Bank of America Merrill Lynch said in a note that «non-OPEC oil supply is indeed hanging off a cliff», and estimated that global output would contract year-on-year in April or May for the first time since 2013. The OPEC survey aside, Saudi oil output was expected to edge up by 350,000 barrels per day to around 10.5 million bpd, sources told Reuters, as tankers filled with unsold oil floated at sea seeking buyers. The discount in spot U.S. crude to the next trading month meanwhile whittled to its smallest since January, reducing the advantages of storing oil in the United States for later delivery. (Additional reporting by Libby George and Karolin Schaps in LONDON and Henning Gloystein in SINGAPORE; editing by David Gregorio and Marguerita Choy)
Copyright: Rig Zone
Byron Energy encounters further hydrocarbons in the SM71-1 well in Gulf of Mexico
/en NewsByron Energy is pleased to provide an update on the Byron Energy SM71 #1 oil and gas discovery well located in the Gulf of Mexico in South Marsh Island Block 71 (‘SM71’).
Since the last report, on 27 April 2016, the well has been deepened, to the predrill planned total depth of 7,477 feet measured depth/6,915 feet true vertical depth and wireline logs have been run over the deeper portion of the well.
The processed open hole porosity logs from this deepened section of the well indicate the presence of a very high porosity gas or gas condensate reservoir from 7,212 feet to 7,226 feet measured depth. A 5” liner will now be run and cemented in place over the deeper portion of the SM71 #1 well.
As previously reported, the SM71 #1 well encountered 132 feet of TVT net oil pay in the I3 Sand, J Sand and D5 Sands. The final, processed version of the logs run over these three sands has now been received and confirm the previously reported net TVT pay count. Additionally, Isotube sample analysis indicates the likely presence of light, sweet crude oil from all three sand intervals.
Current operations are preparing to run 5″ liner over the deeper portion of the well before suspending the well for future production. It is expected that the rig will be demobilised within 10 days after mud line suspension operations are completed.
Byron’s CEO, Maynard Smith said:
‘We are very pleased to encounter our fourth hydrocarbon interval in this wellbore. This is the first time in my career I have seen four sands trap hydrocarbons stratigraphically in one well bore. Every pre-drill target sand, both primary and secondary, has been found to have hydrocarbons. These stratigraphic traps were found using a high resolution second generation Reverse Time Seismic Migration (RTM) and in conjunction with a very advanced seismic inversion model. To further enhance and fine tune our inversion model, we acquired acoustic shear wave data overall objective sands in this wellbore. This data will be key to understanding the seismic responses in both hydrocarbon and wet sands in the area. The shear log in our well is the first shear wave data collected in over 320 wells drilled thus far on the SM71 dome where 117 million barrels and 377 BCF of gas has been produced. We believe this information will give Byron a significant advantage in exploring for and exploiting other stratigraphic traps on our blocks and other blocks on the dome. We are immediately commencing plans for future production facilities and pipelines in order to shorten the time to production as much as possible.’
The SM71 #1 well is the second well to be drilled as part of Byron’s farm-out to Otto Energy, announced on 11 December 2015.
Byron, through its wholly owned subsidiary Byron Energy Inc. (the operator), currently has a 100% working interest and an 81.25% net revenue interest in SM71, located offshore Louisiana, 250 km southwest of New Orleans, Louisiana, USA, in water depth of approx. 131 feet (40 metres). Because the SMI71 #1 well has been drilled to the earning depth Otto has now earned the right to elect to earn a 50% working interest in the SM70 and SM71 blocks and has confirmed it will exercise its right. Consequently, Byron’s working and net revenue interests will be reduced by 50%, to 50% and 40.625% respectively.
Copyright: Your Oil an Gas News
Baja el costo de la deuda de Pemex
/en NewsEl anuncio del apoyo a Petróleos Mexicanos por parte del gobierno federal trajo una revaloración de los bonos en dólares de la petrolera mexicana.
El anuncio del apoyo a Petróleos Mexicanos (Pemex) por parte del gobierno federal trajo una revaloración de los bonos en dólares de la petrolera mexicana, luego del 13 de abril. Ésta se expresa en un decremento de hasta 40 puntos base (0.40%) en la tasa de interés que pagan los bonos de Pemex en los plazos de cinco, 10 y 30 años.
El rendimiento o tasa de los bonos de deuda es uno de los indicadores más importantes para evaluar el sentimiento de los mercados frente a un emisor. En los últimos meses, la deuda de Pemex ha vivido una montaña rusa, que comenzó el 24 de noviembre del 2015, con la baja en la calificación de Moody’s. En ese momento, la tasa que pagaban los bonos a 10 años estaba ligeramente por debajo de 5% y llegó a estar muy cerca de 7% entre mediados de enero y mediados de febrero, de acuerdo a información de Bloomberg. Al 16 de abril se situó en 5.62%, esto es 40 puntos por debajo de 6.02 que tenía el 13 de abril.
La semana pasada, la Secretaría de Hacienda anunció una inyección de 73,500 millones de pesos a la petrolera estatal con el objeto de fortalecer su posición financiera de corto plazo, fuertemente comprometida por un abultado pasivo circulante y un saldo vencido con proveedores por más de 120,000 millones de pesos.
Los bonos de deuda de Pemex han vivido una recuperación, en términos de valor desde la tercer semana de febrero, cuando el precio del petróleo empezó a revalorarse en los mercados internacionales. Los rendimientos que ofrece la deuda de Pemex reflejan una baja sostenida desde entonces. Esta tendencia a la baja no fue alterada por la segunda baja de calificación de Moody’s, anunciada el 31 de marzo.
La calificadora ha expresado en sus comunicados que le preocupa el alto nivel de deuda de Pemex y la reducción en su capacidad de ingresos, vinculada principalmente a la baja en los precios del petróleo que comenzó desde mediados del 2014. Pemex tiene una deuda aproximada a 87,000 millones de dólares. El servicio de la deuda pasó de 51,600 millones de pesos en el 2014 a 67,800 millones de pesos en el 2015.
Para el 2016, el Congreso autorizó a Pemex un endeudamiento en los mercados internacionales de 8,500 millones de dólares y un endeudamiento en pesos de 110,500 millones. Si se compara la tasa que Pemex debe pagar en los mercados, con la que pagan otras petroleras latinoamericanas, como Petrobras o la colombiana Ecopetrol, resulta que el 5.62% de Pemex es 361 puntos base menor que 9.23% que paga Petrobras y 145 puntos base menor que 6.67% que paga Ecopetrol.
Fuente: El Economista
U.S. economy looks good but Fed remains cautious: Dudley
/en NewsU.S. economic conditions are «mostly favorable» yet the Federal Reserve remains cautious in raising interest rates because threats loom, New York Fed President William Dudley said on Monday.
Dudley, a permanent voter on rates and a close ally of Fed Chair Janet Yellen, repeated his views in a speech, saying «policy adjustments are likely to be gradual and cautious, as we continue to face significant uncertainties and the headwinds to growth from the financial crisis have not fully abated.»
Addressing a conference at the New York Fed, he repeated he was confident that too-low inflation would rise to a 2 percent goal over the next few years, and that «economic conditions have finally warranted the start of U.S. monetary policy normalization.»
The Fed raised rates modestly from near zero in December, its first policy tightening in nearly a decade. Most economists predict it will move again in June.
Copyright: Reuters
Five reasons Development Banks hold the key to renewable energy investment boom
/en NewsNew Climate Economy report sets out how Multilateral Development Banks have a crucial role to play in mobilising clean energy investment
The New Climate Economy (NCE) group has this month published a major new report detailing the crucial role development banks need to play in ramping up clean energy investment in developing countries.
The coalition of 20 countries, chaired by former Mexican President Felipe Calderón and Lord Nicholas Stern, has previously said that investments in clean energy are one of the biggest steps that can be taken to close the so-called ‘emissions gap’.
By boosting investment to $1tr a year by 2030 yearly greenhouse emissions could be reduced by to 7.5 Gt CO2e, the new report said – an amount bigger than the annual emissions of the United States. Such deep emissions reductions would go a long way towards closing the gap between current projections and the level of emissions cuts needed to stand a reasonable chance of keeping global warming below 2C
However, the new report warns delivering a sharp increase in clean energy investment will require multilateral development banks (MDBs) to play an increasingly active role in supporting the mass deployment of renewable energy in emerging and developing economies.
1.- Development banks are ideal catalysts for clean energy investment
Clean energy had a record year in 2015, attracting $329bn in global investment. However, this is still far short of what is needed both to limit global warming and provide energy access to the 1.1 billion people who still lack it.
MDBs can leverage up to 20 times the amount of money they invest, the report calculates, meaning a big boost in their spending would have a catalytic effect on private sector investment.
2.- MDBs are well positioned to take on risks
While renewables are increasingly competitive in many developing markets with more investment now going into emerging markets than established ones, there are still risks that come with investment in these markets. Exchange rate risks, political risks and construction risk, all of which are higher than in OECD countries, are just some of the ways investors can be deterred from otherwise attractive clean energy projects.
However, since MDBs have a specific remit to promote development in the countries where they work, they are well positioned to take on the risks that other foreign investors may not be willing to shoulder. «They all have a public mandate to enable development globally, and from an energy perspective that is both scaling up energy and making it low carbon at the same time in the next 15 years,» Ilmi Granoff, co-author of the report and senior research associate and the Overseas Development Institute, tells BusinessGreen. «It’s making sure that those risks are addressed for clean energy, and relying on some of the older and new tools to scale up clean energy investments as the core of their energy strategy.»
3.- Co-operation with other players is key
This doesn’t mean that development banks will be taking on all the responsibility alone – a key message from the New Climate Economy is how cooperation between MDBs, governments, and the private sector can allow new projects to be considered that may be too risky for one player to take on alone. Meanwhile, governments will also play an additional important role by scaling up the enabling role they can play in mobilising financing for clean energy, the report notes.
4.-The money is there
A trillion dollars may sound like an awful lot, says Granoff, but there is no global shortage of global capital. Instead, the challenge is to shift incentives to ensure it is unleash in favour of clean energy.
The New Climate Economy group estimates that if low-cost, long-term financing were available for clean energy projects, the cost of clean electricity could be reduced by as much as 20 per cent in developed economies, and 30 per cent in emerging economies.
But in order to unlock this money, the financing system must be re-adjusted to take advantage of the benefits of renewables – their lack of fuel costs, lower operating costs, and flexibility in deployment – while also dealing with the challenges they bring, such as the need for higher grid investment.
«Clean energy is flexible and scalable, it has very low operating costs and often no fuel costs, so it has a bunch of really critical benefits,» says Granoff. «But it also functions differently: the upfront costs are greater, and so the project’s viability is more sensitive to financing costs than fossil fuel power investments. So there’s a bunch of enabling environment issues that have to happen in order to favour that clean energy framework.»
5.- Fossil fuels will have to go
The flip side of the coin, of course, is that while moves are being made to promote and support clean energy, they must also be made to revamp an energy financing structure which until now has heavily benefited fossil fuels.
«It’s not simply about scaling up clean energy investment,» observes Granoff. «If we want the incentives to favour clean energy, we have to incentivising and stop subsidising through public financing high carbon energy systems. We need to be phasing out the financing of carbon energy systems, except in exceptional circumstances where there is an absolutely critical development rational without any viable alternative.
Font: Business Green
Iran, India Sign MoU to Develop Oil, Gas Projects
/en NewsOPEC member Iran and India – one of Asia’s fastest growing source of energy demand – signed a memorandum of understanding (MoU) to develop oil and gas projects, including the Farzad B gas field, Iranian Petroleum Minister Bijan Zangeneh told the Iran-India business conference held at Teheran Chamber of Commerce Saturday, Shana – a media linked to Iran’s Ministry of Petroleum – reported Sunday. «We had thorough conversations today and signed an MoU for development of Farzad B gas field, refinery cooperation, export of crude oil and petroleum products and mutual cooperation in petrochemical industry,» Zangeneh said.
The MoU was signed during a visit to Teheran by Indian Petroleum and Natural Gas Minister Dharmendra Pradhan, who, the Ministry said on its website April 7, hoped to engage «with the Iranian political leadership to work with them, particularly in the hydrocarbon, petrochemicals and fertilizers sectors for mutual benefits, including strengthening of India’s energy security.» According to Zangeneh, Indian investors should consider the development of the Farzad B project as a top priority, adding that «we hope decisions regarding the project’s development will be made before 2017.»
He said the Farzad B gas field can produce 3 billion cubic feet per day (Bcf/d) of natural gas, but Iran has signed an MoU with Indian developers for the production of 1 Bcf/d of natural gas from the field. A consortium comprising three Indian companies, including ONGC Videsh Ltd. and Oil India Ltd., made a gas discovery at the offshore Farzad B field in 2008.
Meanwhile, Zangeneh said both nations have agreed to set up major joint ventures and enhance their strategic relations, adding that «we hope Iranian and Indian companies reach out to each other and, under the new circumstances, the two countries boost their investments.» Indian companies have indicated to Zangeneh their interests to purchase natural gas from Iran to feed their petrochemical and other energy-consuming industries, Shana reported. On its part, Iran could deliver gas to Indian customers in Chabahar or any other ports where the Indians are willing to invest to feed methanol, steel and aluminium plants.
Separately, shareholders of Turkmenistan-Afghanistan-Pakistan-India (TAPI) Pipeline Company Limited signed an agreement in Ashgabat, Turkmenistan Thursday to invest $200 million in the TAPI natural gas pipeline. According to the Asian Development Bank (ADB), the investment includes funds for detailed engineering and route surveys, environmental and social safeguard studies, and procurement and financing activities, to enable a final investment decision, after which construction can begin. Construction is estimated to take up to 3 years.
According to Pakistan’s Minister of State for Petroleum and Natural Resources Jam Kamal Khan, TAPI would supply 487.3 billion cubic feet (Bcf) or 13.8 billion cubic meters (Bcm) of gas from Turkmenistan to meet the South Asian country’s growing energy demand, Indian daily The Economic Times reported Friday. Sean O’ Sullivan, ADB’s Director General of Central and West Asia Department, said the gas pipeline will unlock economic opportunities and diversify the energy market for Turkmenistan and enhance energy security for the region.
Ground breaking of the 1,127 mile (1,814 kilometer) -long TAPI pipeline, a project seeking to ease energy shortages in South Asia, was carried out in December 2015 year in Turkmenistan. The pipeline will be equipped to transport 3.2 billion cubic feet per day (Bcf/d) or 90 million standard cubic meters a day (MMscm/d) gas for 30 years, with India and Pakistan originally expected to receive 1.3 Bscf/d (38 MMscm/d) each, while the remaining 494.4 million standard cubic feet per day (MMscf/d) or 14 MMscm/d was to be supplied to Afghanistan.
So far, Turkmenistan is the only country that has started work to build its section of the TAPI pipeline. The pipeline will travel 480 miles (773 kilometers) through Afghanistan and 514 miles (827 kilometers) in Pakistan before ending at Fazilka in Punjab, India, The Economic Times said.
Copyrigth: Rigzone
Instituto Mexicano del Petróleo (IMP ) crea tecnología que reduce costos en transporte de crudo pesado
/en NewsAnte la necesidad de Petróleos Mexicanos (Pemex) de contar con una tecnológica que facilite el transporte de aceite pesado y extrapesado, el Instituto Mexicano del Petróleo (IMP) desarrolló biotensoactivos que reducen la viscosidad del hidrocarburo y disminuye costos de operación.
La tecnología logra que la paraestatal tenga flexibilidad operativa en el transporte de petróleo que se realiza por medio de ductos desde los centros de producción hasta las refinerías.
En México, al menos el 50 por ciento de las reservas de petróleo crudo son delo tipo pesado y gran parte extrapesado. Por ello, Pemex está muy interesado en la tecnología, ya que en el transporte se generan problemas en caída de presión y calentamiento del hidrocarburo que cuesta dinero y producción de este por día. Ante ello, el proyecto del IMP funge como alternativa, señaló el doctor Jorge Arturo Aburto Anell, gerente de Transformación de Biomasa del IMP y líder de la investigación.
El proyecto consiste en mezclar el petróleo con agua por medio de biotensoactivos (sustancias que permitieran formar una emulsión), los cuales se obtienen de la biomasa vegetal, arboles, pasto, residuos de maíz y trigo, y que tienen en su composición cierto tipo de moléculas.
“Lo que hicimos fue obtener una fracción de esas moléculas, modificarlas de cierta forma que permitiera tener una emulsión estable del petróleo en agua. Es similar a la mayonesa, sólo que la cantidad de agua que tiene es muy pequeña y la nuestra es mayor”.
Al hacer emulsión se reduce de manera sustancial la viscosidad del petróleo. “Estamos hablando de un petróleo que es prácticamente sólido y viscoso, y cuando lo emulsionamos en agua la viscosidad es equivalente a la de un líquido que fluye sin ningún problema. Además, el proceso no modifica la composición y propiedades del hidrocarburo”, detalló el doctor Aburto Anell.
El investigador relató que el proyecto tiene beneficios debido a que en los campos de petróleo se produce mucha agua que está dispersa en el petróleo, lo cual aumenta la viscosidad y genera problemas de transporte; sin embargo, al hacer una emulsión inversa se elimina la densidad, se reducen problemas de operación asociados a compuestos químicos como asfalteno y parafina.
Gracias a que el proyecto pasó por fase de laboratorio y planta piloto se logró formular una emulsión en gran volumen y probar el flujo del petróleo en un ducto instalado en el estado de Veracruz. También se obtuvo una patente nacional y cuatro están en solicitud, de estas dos son mexicanas y el resto internacionales, en Estados Unidos y Canadá.
Actualmente se busca realizar pruebas in situ. “Vamos ir a un pozo de Pemex y hacer pruebas tecnológicas que nos van a permitir en situación real medir la viabilidad técnica y económica”.
Copyrigth: Gaceta México
Siete empresas ganan en la primera subasta eléctrica
/en NewsOnce ofertas de siete empresas privadas resultaron ganadoras en la primera subasta eléctrica de largo plazo en México, con lo que se asignó el 84.66 por ciento de la energía y 85.3 por ciento de los certificados de energía limpia, logrando una oferta de alrededor de tres mil 817 millones 892 mil 525 pesos.
De acuerdo con el Centro Nacional de Control de Energía (Cenace) se lograron colocar cinco mil 385.72 gigawatts-hora de energía, así como cinco millones 426 mil 458 certificados.
En tanto, los 500 megawatts de potencia contemplados para el proceso serán subastados en la siguiente etapa, al no recibir ofertas por parte de los participantes.
Las empresas ganadoras fueron Recurrent Energy Mexico Development, Parque Eólico Reynosa III, Sunpower Systems México, Energía Renovable del Istmo II, Enel Green Power, Gestamp Wind México II y Alten Energía Renovables México Cinco, quienes estarán autorizadas para producir y vender energía eléctrica en el país.
La empresa italiana Enel logró ganar con tres ofertas, obteniendo dos mil 249.947 gigawatts-hora de energía y dos millones 249 mil 947 CELs, con una oferta de mil 508 millones 189 mil 482 pesos.
Mientras que la firma Alten Energía Renovables México Cinco obtuvo con sus dos ofertas ganadoras 367.936 gigawatts-hora de energía y 414 mil 15 CELs, por un monto de 310 millones 18 mil 341 pesos.
A su vez, dos ofertas de Energía Renovable del Istmo II también resultaron ganadoras, obteniendo 585.731 gigawatts-hora de energía, así como 585 mil 731 certificados, por un monto aproximado de 434 millones 699 mil 411 pesos.
En tanto que Recurrent Energy Mexico Development ganó 140.970 gigawatts-hora de energía y 140 mil 970 CELs, por una oferta de 116 millones 936 mil 169.19 de pesos; el Parque Eólico Reynosa III ganó mil 617.376 gigawatts-hora de energía y un 617 mil 376 de certificados con una oferta de mil 243 millones 115 mil 193.60 de pesos.
La compañía Sunpower Systems México ganó 269.155 gigawatts-hora de energía y 263 mil 815 CELs, con una oferta de 204 millones 932 mil 823 de pesos; Gestamp Wind México I154.6 gigawatts-hora de energía y 154 mil 600 certificados, con una oferta de mil 106.68 pesos.
Copyrigth: Excelsior
NRGI Broker
Somos el enlace entre los riesgos que enfrentan las industrias del sector energético con las soluciones para administrarlos y respaldarlos mediante esquemas confiables de garantías financieras.
Contáctanos
Prolongación Paseo de la Reforma 1015 Torre A Piso 21. Col. Desarrollo Santa Fe, Contadero, C.P. 01219 CDMX, México
Tel: +52 (55) 9177 2100
Horario de Atención
Lunes – Viernes: 7:30-18:00



















