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Field Specialist - Fluids - Corpus Christi, TX - Baker Hughes - Corpus Christi, TX
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Job Number:
1316917
)
LOCATION
Corpus Christi, Texas
EMPLOYMENT STATUS
Full Time Regular
ABOUT THIS JOB
This position at Baker Hughes will provide on site services by measuring, testing and supervising the running of fluid mixing and pumping, including technical analysis and specific product and practical recommendations for controlling fluid properties. This position is under general supervision,
KEY RESPONSIBILITIES/ACCOUNTABILITIES
Maintain inventory at customer well sites.
Maintain fluid properties on rigsites by testing fluid properties accurately.
Provide effective customer service by providing rig-site customers and coordinators information regarding the progress of a rig site and create / implement solutions to rig site problems.
May make sales calls on the field and field office level or accompany Sales Representative performing the same function.
Provide ongoing support to assist operations in providing our customers the most effective, environmentally safe drilling fluids available while optimizing the well-bore construction process and maximizing our customer's production.
Perform other related duties as required.
ESSENTIAL QUALIFICATIONS/REQUIREMENTS
High School Diploma or GED.
Basic product line knowledge in addition to meeting the compentcy requirements as outlined in LEARNLINK.
Good functional / Technical skills.
A great deal of focus on customer service.
Good communication and interpersonal skills.
Must have good team working skills.
PREFERRED QUALIFICATIONS/REQUIREMENTS
Two year Technical Degree preferred.
Industry experience and product training required.
OTHER DETAILS
Conducts all business activities in accordance with Baker Hughes HSE policies, Legal Compliance requirements and Baker Hughes Core Values. Account Manager
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CHHA for Home Health (Los Angeles)
Posting ID: 3648302846Posted: 2013-02-27, 4:54PM PSTEdited: 2013-02-27, 4:55PM PSTemail to a friendSorry, I could not read the content fromt this page.
Keystone XL pipeline shuns high-tech oil spill detectors
Construction for TransCanada's Keystone XL pipeline involves clearing land, often wooded areas, to make room for pipeline work and construction. Pictured here: Work in Wood County, Texas, on Oct. 24, 2012. (Cody Duty / Houston Chronicle)TransCanada Corp. (TRP), which says Keystone XL will be the safest pipeline ever built, isn’t planning to use infrared sensors or fiber-optic cables to detect spills along the system’s 2,000-mile (3,200-kilometer) path to Texas refineries from fields in Alberta.
Pipeline companies have been slow to adopt new leak detection technology, including infrared equipment on helicopters flying 80 miles an hour or acoustic sensors that can identify the sound of oil seeping from a pinhole-sized opening. Instead of tools that can find even the smallest leaks, TransCanada will search for spills using software-based methods and traditional flyovers and surveys.
As pipelines multiply across North America to carry booming supplies of oil and natural gas, a series of recent spills and explosions are raising concerns about the safety of the conduits, including Keystone XL, which is awaiting U.S. government approval.
“There are lots of things engineering-wise that are possible, that the industry doesn’t do,” said Carl Weimer, executive director of Pipeline Safety Trust, a fuel-transportation safety advocacy group in Bellingham, Washington. As pipeline executives say they’re changing their industry’s culture to tolerate zero incidents, companies aren’t spending on technology to catch even pinhole-sized leaks that can turn into bigger problems, Weimer said.
Though the so-called external leak detection tools have been recommended by the U.S. Environmental Protection Agency for TransCanada’s Keystone XL pipeline, the Calgary-based company says they’re impractical for the entire project. At the EPA’s request, TransCanada is studying whether to add the systems in sensitive environmental areas, Grady Semmens, a company spokesman, said in an e-mail.
Studying Leaks
Keystone XL is part of an additional 4.7 million barrels a day of new U.S. oil pipeline capacity expected to be built during the next two years, according to the Association of Oil Pipe Lines, a Washington-based industry group. About 19.2 million barrels of crude are transported each day in the U.S.
Pipelines spilled an average of 112,569 barrels per year in the U.S. from 2007 to 2012, a 3.5 percent increase from the previous five-year period, according to U.S. Transportation Department figures compiled by Bloomberg.
The department is studying leak detection as it considers new rules to improve safety. Equipment available to spot spills more quickly would have cut 75 percent off the estimated $1.7 billion toll in property damage caused by major incidents on oil lines from 2001 to 2011, consultants said in a December report prepared for the department.
Internal Detection
The figure doesn’t include cleanup costs in environmentally sensitive areas, fines, lost life and the potentially much bigger financial impact to operators related to investor concerns.
Leak-detection technology consists of internal and external systems. Much of the newest technology tends to be for external monitors that look for leaks outside the pipeline, such as the infrared sensors and fiber-optic cables.
Internal systems, most often employed by operators, rely on computer-based tools to remotely analyze flow data transmitted every few seconds by sensors along the conduit. Operators using software-based systems are alerted if pressure drops, indicating a possible leak.
Keystone XL would have to be spilling more than 12,000 barrels a day — or 1.5 percent of its 830,000 barrel capacity – - before its currently planned internal spill-detection systems would trigger an alarm, according to the U.S. State Department, which is reviewing the proposal. In comparison, BP Plc (BP/)’s Macondo well in the Gulf of Mexico was leaking at an estimated rate of about 53,000 barrels a day, according to a U.S. Interior Department report.
Leak Threshold
“You’re talking about a system that isn’t going to be able to detect a leak that’s greater than half a million gallons a day,” said Anthony Swift, a lawyer at the Natural Resources Defense Council, an environmental advocacy group in Washington.
The company’s leak detection specialist would be able to spot leaks “well below” the 1.5 percent threshold by analyzing trends in data collected over a period in time, said Vern Meier, vice president of pipeline safety and compliance at the company.
TransCanada is seeking U.S. approval for Keystone XL amid heightened regulatory scrutiny following spills such as the 5,000 barrels leaked in March by Exxon Mobil Corp (XOM).’s Pegasus line in Arkansas, and the 2010 rupture of an Enbridge Inc (ENB). line in Marshall, Michigan.
Enbridge, which spilled more than 20,000 barrels of heavy oil from Canada into a branch of the Kalamazoo River, boosted its estimate of cleanup costs to nearly $1 billion earlier this year, a figure that doesn’t include fines.
Adding Cable
Keystone XL would carry crude from the oil sands to supply U.S. Gulf Coast refineries. TransCanada requires a presidential permit to build the $5.3 billion northern portion of the line because it crosses an international border.
It would cost TransCanada an additional $705,000 to add a fiber-optic cable to the parts of Keystone XL that may affect ecologically sensitive areas, drinking water, or populated regions, according to figures compiled by Bloomberg. The line has 141 miles in high consequence areas, according to the State Department, and the cable costs about $5,000 a mile, the December Transportation Department report estimates.
“This will be the safest pipeline that has ever been built in the United States,” Russ Girling, TransCanada’s CEO, said in an interview with Bloomberg Television that aired June 2.
Among sensitive new technologies to test for leaks is a 200-pound (90-kilogram) device the size of a garbage can that’s mounted on the outside of a helicopter. The sensor, made by Synodon Inc (SYD). in Edmonton, Canada, detects oil vapors in the infrared rays of sunlight to find leaks flowing at rates below 10 barrels a day, according to the company.
Aluminum Balls
Pipeline operators also are considering using aluminum balls that flow along the conduit with oil or gas, listening for leaks. Pure Technologies Ltd (PUR). of Calgary, which makes the balls, says their acoustic systems can spot leaks as small as 0.03 gallons a minute.
In its original comments on a State Department assessment of Keystone XL, the EPA recommended TransCanada install some of the latest leak detection technology. In a later report, the State Department questioned the reliability of the gear for the entire length of the line, noting its high cost and variable effectiveness.
Project Complexity
“Many of the technologies out there haven’t been deployed on that scale of system with the complexities that the type of project presents,” TransCanada’s Meier said.
The Association of Oil Pipe Lines has warned that any new rules inspired by the study may force the adoption of unproven technologies. It cited flaws in the report, which it said was based on vendor claims and not operator experience.
Several external leak detection technologies produce false alarms, said John Stoody, a spokesman for the association.
“People start tuning out false positives until the one time in 100 that it’s real,” Stoody said.
Internal systems such as the one planned for Keystone XL have a spotty record catching leaks, according to the Transportation Department’s report, prepared by the engineering firm Kiefner & Associates Inc., of Worthington, Ohio. Members of the public reported 23 percent of the 197 oil and liquids pipeline leaks between January 2010 and July 2012, according to the study, compared to 17 percent identified by the pipeline companies.
No Alarm
Oil identified last week on the surface of the Trans Mountain pipeline in British Columbia was detected during maintenance work, according to operator Kinder Morgan Energy Partners LP (KMP) of Houston, the biggest U.S. pipeline company. The leak, estimated at less than 6 barrels by Kinder Morgan two days after it was discovered, was missed by the line’s internal systems.
“It likely was a very slow leak, so we didn’t have any alarms going off to suggest there was a problem,” said Andy Galarnyk, a Kinder Morgan spokesman. Galarnyk couldn’t immediately say whether external tools would have caught it earlier.
The average pipeline company would probably save as much as $1.1 million a year by using external monitors in heavily populated or environmentally sensitive “high consequence areas,” making it cost effective to install systems in those places, the Transportation Department report concluded.
Even the most expensive systems could make sense at river crossings or in towns, the study found. Liquid-sensing cables can cost as much as $50,000 a mile, or $20 million for an average 400-mile line, compared with $100,000 for an internal computer-based system.
New regulations may be needed to force operators to adopt additional tools, according to the study.
Old Pipelines
Even without the most technologically sensitive tools to detect leaks, the risk of a spill on Keystone XL will be far less than on existing pipelines that lack leak detection systems, automated valves and good quality steel and coatings, Weimer of the Pipeline Safety Trust said.
“Clearly we’ve got millions of miles of old pipelines in the ground that are riskier than these new ones they’re putting in,” Weimer said. “What they’re doing now is better than what’s been in the ground for 50 years.”
Emily Mir, Kinder Morgan’s manager of corporate communications, deferred comment on leak detection to the Association of Oil Pipe Lines.
Rule Review
Enbridge, Canada’s largest transporter of crude, is testing performance claims on new technology before considering its adoption, said Ray Philipenko, senior manager for leak detection at the company. Enbridge is building a research center in Edmonton, Alberta, that will simulate leaks on a 40-foot-long pipeline to test how well external tools, including fiber-optic cables and vapor sensing tubes, detect the oil, Philipenko said.
The Transportation Department must give Congress a one-year review period following its December report before moving forward on new rules. Leak detection is “crucial to pipeline safety,” Cynthia Quarterman, head of the department’s Pipeline and Hazardous Materials Safety Administration, said in an e-mailed statement.
Any regulations should focus on the most environmentally sensitive areas along pipelines, where spill cleanup costs are the highest, said Richard Kuprewicz, president of the consulting engineering company Accufacts Inc. in Redmond, Washington.
A billion dollars used to seem like a lot of money, Kuprewicz said. “If you have a rupture in the wrong place, you can go through that in a heartbeat.”
Dental Front/Back Office (Culver City)
Posting ID: 3648313496Posted: 2013-02-27, 5:00PM PSTEdited: 2013-02-27, 5:00PM PSTemail to a friendSorry, I could not read the content fromt this page.
Colleges plan training for gas drilling jobs
Workers move a section of well casing into place at a Chesapeake Energy natural gas well site near Burlington, Pa. (AP Photo/Ralph Wilson, File)HARRISBURG, Ill. — Two colleges in southern Illinois have announced a cooperative agreement to provide training in the emerging field of high-volume oil and gas drilling.
Officials from Southeastern Illinois College in Harrisburg and Rend Lake College in Ina announced the plan Monday after Gov. Pat Quinn signed a new law establishing rules companies must follow during hydraulic fracturing, or “fracking.”
Both colleges plan to provide a safety program and other training needed by the industry. Southeastern Illinois College has submitted a custom training certificate program to the state for approval. Rend Lake College plans to establish an associate degree program in oil and natural gas.
Fracking uses high-pressure mixtures of water, sand or gravel and chemicals to crack underground rock formations and release oil and natural gas.
Rig Helper Oil and Gas Exploration and Development - The RIDGE Project - Tuscarawas, OH
Ideal candidates should be willing to
Learn about gas well operation
Take direction well
Ability to work outside in all kinds of weather
A swab rig helper will assist operator in rigging up and working on gas wells.
Cleaning out the well
Repairing the well
Plumbing gas lines
Cleaning up around the rig and well site
Rig helpers will also be doing the same duties on the service rig as well as helping to run pipe in and out of wells.
Experience in construction or heavy industrial maintenance preferred. Apply today for an immediate interview.
Nancy 330-456-8040
EVENT REPRESENTATIVES (Los Angeles area)
Duties Include:
? Ensuring display area is clean, safe and appealing
? Greeting and speaking with tour participants
? Being knowledgeable in our products and services
? Generating interest for our services
? Capturing contact information from potential buyers
? Representing our business in a professional and friendly manner
Qualifications and Requirements:
? Friendly and out-going with good communication skills
? Business-casual appearance
? Punctual and dependable
? In some locations there will be no seating, must be physically able to comfortably stand outside for long periods
Applicants please submit resume and cover letter. Please also visit our website at www.pacificoutdoorliving.com.
Posting ID: 3648305160
Service Rig Derrick Hand Oil and Gas Field Operati - The RIDGE Project - Tuscarawas, OH
Have you wanted to join the exciting gas and oilfield exploration in Ohio.
Our ideal candidate will assist the operator in all aspects of service rig operations, including maintaining the rig and all related equipment. Also rigging up, moving, rigging down, completing new gas wells as well as repairing and maintaining existing wells. Must be physically fit and able to climb and work at heights in all types of weather.
If you want an entry level position into the exciting field of oil and gas please call us or send a resume today for an immediate interview.
Our ideal candidate will assist the operator in all aspects of service rig operations, including maintaining the rig and all related equipment. Also rigging up, moving, rigging down, completing new gas wells as well as repairing and maintaining existing wells. Must be physically fit and able to climb and work at heights in all types of weather.
If you want an entry level position into the exciting field of oil and gas please call us or send a resume today for an immediate interview.
Call Nancy @ 330-456-8040
CareerMarketplace.com - 8 hours ago - save job - block
Alberta’s oil sands raise flaring emissions as rules lag
Emissions from flaring, or burning of natural gas, methane and hydrogen sulphide associated with oil production, have risen in each of the last three years. Lucas Schifres/BloombergIn the farming country of northwest Alberta, heavy oil wells are becoming more common than cattle and combines. Along with money and jobs, the boom has brought smells and fumes that are adding to the greenhouse gas emissions from Canada’s oil sands.
Emissions from flaring, or burning of natural gas, methane and hydrogen sulphide associated with oil production, have risen in each of the last three years as drillers increased activity and the government failed to implement new industry targets.
“There’s no new absolute target to reduce flare or vent emissions,” said James Vaughan, who works at the Alberta Energy Conservation Board’s surveillance branch, in an interview. “The economics for conserving gas just doesn’t seem to be there” because of a decline in natural gas prices.
Flaring by companies including Husky Energy Inc. (HSE) is rising even as the Canadian government touts the country’s efforts to limit emissions to win support for TransCanada Corp. (TRP)’s Keystone XL pipeline. Prime Minister Stephen Harper met his European counterparts last week in Paris and London, appealing for them to stop EU plans to single out Alberta as a source of high-polluting energy.
Environmental groups such as 350.org and the Sierra Club have lobbied President Barack Obama to reject the Keystone XL pipeline, which would carry crude from Alberta to U.S. Gulf Coast refineries, saying that oil-sands production has a larger climate-change impact. Globally, about 5.3 trillion cubic feet of gas is flared annually, the equivalent of 25 percent of U.S. consumption of the fuel, according to the World Bank.
Surging Production
With bitumen production expected to surge to 6.7 million barrels a day by 2030, flaring and venting will continue to rise without new regulations, said Chris Severson-Baker, managing director of the Pembina Institute, a Calgary-based environmental research group and consultancy.
Flaring and vented gas from crude oil and bitumen production increased 66 percent between 2009 and 2011, the most recent figures available, according to ERCB data. The upward trend continued last year, according to preliminary data from the regulator.
Previous declines from 1996 to 2009 resulted from the implementation of recommendations from an alliance of non-governmental groups, industry, the public and government, known as the Clean Air Strategic Alliance, helping Alberta achieve the most “comprehensive” enforcement rules to manage flaring globally, according to a 2004 World Bank report.
Negative Impacts
Emissions from flaring in Nigeria have “negative impacts” on lung function, according to a report in the Research Journal of Environmental Earth Sciences published on March 8, 2012. Inhaling vapors associated with heavy-oil production may result in nose and throat irritation, headaches and nausea, Baytex Energy Corp. (BTE), a Calgary-based producer, said on its website.
A 2005 report by the Environmental Rights Action and Climate Justice determined gas flaring in Nigeria’s Bayelsa State likely causes 49 premature deaths and respiratory illnesses in 5,000 children annually.
Alberta, home to Canada’s oil and gas industry, relies on companies to determine whether capturing, burning or releasing gas, known as venting, is “economically viable,” said the ERCB’s Vaughn. A combination of measures, including a previous emissions target for the industry, allowed Alberta regulators to slash flaring emissions by 80 percent between 1996 and 2009.
Progress Imperiled
That progress is at risk without stiffer regulations and targets, said Severson-Baker.
“We knew because of industry trends that flaring and venting was likely to start climbing upwards,” he said in an interview. “When it came right down to it, industry wasn’t able to spend more money on flaring and venting abatement and the government wasn’t prepared to push any further.”
Canadian Natural Resources Ltd. (CNQ) was responsible for the largest volume of flared and vented gas in the province in 2011, followed by Husky, according to regulatory data. Smaller companies including Manitok Energy Inc. (MEI) flared more gas as a proportion of their production.
Massimo Geremia, chief executive officer of Manitok, didn’t respond to a request for comment. Husky spokeswoman Kim Guttormson declined to comment. Canadian Natural Resources declined to comment.
Alberta’s energy regulator is tabling new rules, expected by the end of the year. An increase in operators drilling oil wells with small volumes of associated gas, which is difficult and expensive to capture, has also contributed to the rising flaring and carbon dioxide emissions, said Vaughn.
Open Wounds
“We are looking at expanding the test to look at other parameters to take into account something outside of economics,” he said. “When the public comes to us and asks why isn’t this facility conserving and we go back to them and say the economics aren’t there, that’s a hard pill for the public to swallow.”
Those issues have surfaced in the Peace River district in an area called Three Creeks. For Thera Breau, the increased heavy oil production and flaring has coincided with open wounds and eye problems for her four sons, all under the age of seven.
“My baby had a red spot behind his knee and by the end of March the blotch spread to the other leg,” Breau, a 36 year-old physiotherapist, said in an interview. “All the gas is free-vented and free-flared. The regulations are lagging.”
Leaving Home
Breau is among half a dozen families who have left their homes in the Peace River area to get away from the fumes and bad smells, she said. Neighbors Marcel and Vivianne Laliberte in October left their farm where family members have grown grains since 1928 after suffering from bleeding noses, headaches and swollen glands.
“It’s a heart-breaking situation,” said Vivianne Laliberte, in a phone interview. “Proper monitoring is not being done and people’s concerns are being disregarded.”
Baytex voluntarily halted its drilling program in the area near Three Creeks about a year ago and added equipment to capture gas and a pipeline system to use or sell about 1 million cubic feet of gas daily that would have previously been vented, said Brian Ector, a Baytex spokesman.
“We’ve put a lot of time and effort into reducing the amount of venting and reducing the emissions and reducing the odors up at Peace River,” he said.
Baytex captured almost 95 percent of the gas produced during oil extraction at its operations across Alberta, better than the industry average, according to ERCB data from 2011.
“We have always been fully compliant with the ERCB regulations, but we want to go above and beyond that,” Ector said.
North Dakota
Alberta isn’t the only jurisdiction in North America wrestling with rising flaring and venting emissions.
Oil production in North Dakota has tripled since 2010 to 718,790 barrels a day in March and companies are flaring about 30 percent of the associated gases, said Ryan Salmon, director of the oil & gas program at Ceres, a network of investors that promotes sustainability through the adoption of environmentally friendly business practices.
“You can’t underestimate how much is going up in flames– $1 million a day alone in North Dakota,” he said. “Reluctance on the part of companies comes down to near-term economics of getting infrastructure in place. You need to have both voluntary actions and regulation.” Ceres represents investors with $11 trillion worth of assets.
Oil producers can reduce flaring by connecting the produced gas to pipelines and selling or using the gas. If that’s not economic or practical, the “next best” option is to make sure the waste gas is combusted at the well site using high-efficiency gas incineration equipment to destroy volatile organic chemicals, said Audrey Mascarenhas, chief executive officer of Calgary-based Questor Technology Inc. (QST), which manufacturers gas-incineration equipment.
“Many will see the waste gas as still being combusted, however, when combusted at high efficiency the waste gases are being reduced to benign elements,” she said. “That is not happening now.”
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