The Houston Geological Society, which bills itself on its website as “the world’s largest local geological society” (and if Houston continues to hold its place among the five Texas cities in the top ten on the Men’s Health annual list of “America’s Fattest Cities", this may be literally true), held an Environmental and Engineering Dinner meeting on 14-Dec to discuss the technology behind risk mitigation for shale gas development. Anthony Gorody, president of Universal Geoscience Consulting, Inc., has been very involved in baseline groundwater sampling and forensic analysis of stray gas in shallow water wells. This was especially timely given the recent identification in Pavillion, Wyoming of compounds in two deep monitoring wells (see the draft report at: http://www.epa.gov/region8/superfund/wy/pavillion/EPA_ReportOnPavillion_Dec-8-2011.pdf) that the EPA described in their press release as “consistent with gas production”. Mr. Gorody repeated the industry’s stance that relatively few water wells are impacted by drilling operations and that to date there have been no unambiguously documented cases of groundwater contamination directly attributed to hydraulic fracturing itself. Instead, he showed that many issues have been with stray gas being released from insufficient cement jobs rather than completion operations (note even the EPA report references “gas production” first rather than hydraulic fracturing). Compounding the issue is the fact that drilling operations have now moved from areas like Wyoming, where a one mile radius of investigation around a gas well might encounter only two water wells, to populated lands in Pennsylvania, where the same footprint might include up to 60 privately drilled water wells. Gorody noted that hydraulic fracturing is not a new technology (it has been in use since 1947) and showed what may be the best image in the public domain to explain the relationship between the depth of water wells and the depth and extent of hydraulic fracturing, which should allow the general public to understand the physical inability of artificial fractures to propagate to groundwater levels in a play like the Barnett.
He used some basic physics to show that small shale pores are two orders of magnitude smaller than the molecular sizes of larger hydrocarbons, and that fractures must be vertically confined in order to create strain release, and slammed the recent EPA report for confusing “coincidence and collocation with cause and effect”. He gave a rule of thumb that the energy released in a typical fracture job is about the same as dropping a gallon of water from head height, while the audience tried to imagine that amount of energy fracturing over 3000 feet of consolidated rock. The high visibility and impact of shale gas drilling operations, however, with 3-5 million gallons of water being trucked in per well, and highly mobile rigs moving through what used to be rural countrysides, has led many community organizations to cast a skeptical eye on the industry. Gorody emphasized the impact on instrumentation and monitoring technology, showing that pressure plots and noise surveys do not show any evidence of fluid or gas release, that increased sampling and analysis of gas shows is providing a fossilized history of hydrocarbon expulsion in many basins, and that baseline water sampling is providing a boon in data density and data mining for forensic geochemists studying aquifers, paid for by risk-averse and litigation-wary operators. The voluntary and regulatory release of chemical information supports studies that show produced gases are not isotopically the same as gases found in water wells, and that buoyant hydrocarbons from depth escaping from failed casings, uncemented annuli, and compromised casing cement bonds can invade shallow aquifers and re-suspend colloidal complexes and sediments that have normally settled to the bottom of water wells. This creates a reducing environment in the well pump intake port, and the bacterial conversion of toxic sulfides that are then reported as odiferous and noxious. It only takes 87 psi of stray gas to overcome hydraulic head and invade water wells drilled to 200 feet, that is less than the pressure in a standard bicycle tire. Since around 85% of the population can detect sulfides such as H2S at levels of .03 ppm, the population quickly becomes aware of the degradation of their water supply, but Gorody noted that this process is completely independent of the hydraulic fracturing used to complete the well, and that maybe the term “hydraulic fracturing” should not even be used when describing vertical wells. Gorody pointed out that as soon as the annulus is squeezed, the problems with water contamination that occur in the first weeks to months after drilling go away, and that nearby monitoring wells may fail to intersect the tortuous paths used by the stray gas to migrate between the gas producing and water wells. His suggestions for reducing these impacts include monitoring of mud logs for gas shows during drilling, cementing off shallow gas shows to prevent leakage, sampling gas for its isotopic fingerprint during drilling to differentiate it from produced gas, running cement bond logs, and coproducing or venting casinghead gas. In the end, it was very enlightening to hear such a sober, scientific evaluation of the technology being used to track gas in shale plays, as opposed to the usual dialogue in places like mainstream media.
Thursday, January 19, 2012
Wednesday, December 21, 2011
Chevron at the SPE Digital Energy Study Group
Jim Crompton, Senior IT Advisor for Chevron, addressed the SPE Digital Energy Study Group in Houston on 16-November on the topic of the “Digital Oil Field IT Stack”. He announced that he wanted to address and be a bit provocative about what he described as two recognized barriers that came out of the panel discussions at the SPE ATCE in Denver a couple of weeks before. His experience comes from implementing what he described as “gifts” from the Chevron central organization in diverse business units for real world application. He felt the two unaddressed barriers were change management, and the need for a standard infrastructure and architecture, which he proposed to describe. His presentation started with some standard, but according to him, neglected trends in the expanding scope and role of IT, including increased digitization, a move into plants and fields, and the need to address the latest generation of IT consumers, which he described as the first generation of oilfield workers to have better IT infrastructure in their homes than at work. He acknowledged that in many cases, the “first kilometer” is still a problem, as where an entire offshore field may be instrumented with fibre optics, but the link to the onshore office is still via low bandwidth microwave links (he only half jokingly suggested lack of telcom coverage as a positively correlated indicator for oil occurrence). So how do we leverage the hundreds of thousands of sensors on a new greenfield platform and move from a “run to failure” mode to one of proactive failure detection and avoidance? Jim cited some examples of predictive analytics, Statoil’s experiements with injected nano sensors that report back on reservoir conditions, distributed sensors for real-time optimization, and new mobility platforms for field workers. But the most interesting new idea was that of borrowing sensor mesh architectures from agricultural and military applications to go beyond current de-bottlenecking workflows and address the advanced analytics used by electrical engineers in their instrumentation. He indicated such a robust and cheap architecture “pattern” might be one of maybe half a dozen that an IT group like Chevron’s might use to provide semi-customizable solutions. Part of the frustration he acknowledged was that at least at Chevron, his best Visual Basic programmers are petroleum engineers using Excel, and they are more in touch with MicroSoft development plans than his IT group and upset that the next version of Excel will remove Visual Basic and move it to the Sharepoint platform. Faced with Chevron now having over 20 million Gigabytes of digital data under management, he suggested treating the information pipeline in the same way we manage hydrocarbon pipelines, and trying to prevent “leaks” to unmanaged environments, like Excel. He showed some digital dashboards that could provide a balance between real time surveillance and advanced modeling, mix the needs of mapping and reporting services, and move organizations up the Business Intelligence maturity model. He finished with a quick nod to HADOOP solutions and a need to move away from “creative solutions that only solve when the creator is present”.
Saturday, February 19, 2011
A Once in a Thousand Year Event?
Some new work along the southeastern tip of India shows that the Boxing Day Tsunami was rare, but not unprecedented. Now that scientists know what the erosional remnants of a global tsunami event look like when preserved on the beaches of that coast, they can use Ground Penetrating Radar (GPR) and sediment cores to look for evidence of other events correlated around the Indian Ocean basin, and use optical methods to come up with dates for them. The latest round of work has identified two previous tsunami records at 1080 years ago (+/- 60 years) and 3710 years ago (+/- 200 years). So yes those of us who witnessed this event were indeed present for an event that starts to bridge the gap between human history and the geologic record.
See: (EOS, Transactions, American Geophysical Union, Vol. 91, No. 50, 14-Dec-2010, "Subsurface Images Shed Light on Past Tsunamis in India", Rajesh Nair, Dept. of Ocean Engineering, Indian Institute of Technology)
See: (EOS, Transactions, American Geophysical Union, Vol. 91, No. 50, 14-Dec-2010, "Subsurface Images Shed Light on Past Tsunamis in India", Rajesh Nair, Dept. of Ocean Engineering, Indian Institute of Technology)
In the News ... Again
In following up the scientific response to the BP Gulf of Mexico Oil Spill (yes the media tagged it and it will never be the "Cameron BOP spill" or the "Anadarko Joint Venture spill"), there is some real insight from those who deal every day with complex technological ventures. In a pretty good indication that, yes, scientists are the pragmatic lot that we expect and need them to be, I have now come across at least two admissions in technical and scientific and publications that when it comes to huge expensive undertakings like deep offshore drilling, the next spill is not a matter of if, but when.
When the National Oceanic and Atmospheric Administration(NOAA)stood up their GeoPlatform website in response to the spill, their CIO was quite candid in noting that they were already planning how the IT infrastructure would have to evolve in order to meet the "next crisis". See:
http://gcn.com/articles/2010/07/15/noaa-cio-kilmavicz.aspx
And Case Western Reserve University has received a grant from the National Science Foundation to study an aerogel material that can soak up eight times its weight in oil, and then be wrung out and re-used. The goal is to lower the cost of the gel so it can be used "during the next big spill".
Those who launch people into space, build high energy physics labs, or even integrate complex software suites, and do it under budgetary constraints, live with a harsh reality. The technicians who are even today, as Paul Carter describes in "This is Not a Drill", designing the "whole fleets of brand new sixth generation, fly by wire cyber rigs ... getting spat out of shipyards all over the world at the moment" ... they know it.
When you push the technology to its limits, sooner or later, something will go wrong.
When the National Oceanic and Atmospheric Administration(NOAA)stood up their GeoPlatform website in response to the spill, their CIO was quite candid in noting that they were already planning how the IT infrastructure would have to evolve in order to meet the "next crisis". See:
http://gcn.com/articles/2010/07/15/noaa-cio-kilmavicz.aspx
And Case Western Reserve University has received a grant from the National Science Foundation to study an aerogel material that can soak up eight times its weight in oil, and then be wrung out and re-used. The goal is to lower the cost of the gel so it can be used "during the next big spill".
Those who launch people into space, build high energy physics labs, or even integrate complex software suites, and do it under budgetary constraints, live with a harsh reality. The technicians who are even today, as Paul Carter describes in "This is Not a Drill", designing the "whole fleets of brand new sixth generation, fly by wire cyber rigs ... getting spat out of shipyards all over the world at the moment" ... they know it.
When you push the technology to its limits, sooner or later, something will go wrong.
Thursday, February 17, 2011
How did this trajectory start?
In the book that will eventually trace the course of this particular scientist through the global oilfields, speculatively titled "Hold My Beer and Watch This!", I will undoubtedly have to spend some time explaining how a short intellectual kid from Chicago ended up driving a 27-ton Litton Vibrator Truck in Pecos, Texas. In his book "This is Not a Drill: Just Another Glorious Day in the Oilfield", Paul Carter describes some of the motives that led him to join offshore rig crews; namely wanderlust, camaraderie, and lucrative contracts. Interestingly, these were among the same things listed by Frank "The Irishman" Sheerhan in the book "I Hear you Paint Houses" as reasons for him joining the Mob....
In my case it was not only the prospect of a lucrative job actually using my college degree when the mining business was collapsing around Upper Michigan in the early 1980's, the possibility to work in remote exotic locations (ok, but Pecos?) and knowing I would be working with geoscientists who I already knew to be a friendly and jovial lot, but the fact that at that time, oil companies were actually using some of the spiffiest technological equipment of the times. I mean, we had access to computers!
I could actually submit a seismic processing job from a teletype terminal in Midland, Texas, and have it checked and submitted by a computer operator in The Woodlands outside of Houston the same day. I knew I had picked the right industry when, in the mid 1980's, the U.S. government decided they could help fund the big government labs by finding commercial applications for some of the technology. When Los Alamos in New Mexico went looking for industry customers, one of the first segments they turned to was "Big Oil". I found myself on a trip from Dallas Texas to Albuquerque New Mexico with a delegation of oil and gas technologists to get a first look at what the weapons guys had been doing inside of the top secret walls that housed the Manhattan project in it's day. We didn't get "inside the wall" where they do the real crazy stuff, and our unfortunately Iranian-born Vice President didn't even get that far, his clearance was denied at the gate and he spent the day in the hotel and looking at "Fat Man" and "Little Boy" in the museum. But the conversations we had around the conference table that day were pretty interesting.
"Oh so you want a way to reduce engine noise on a ship so you can listen better to sonic waves? ... yeah we can do that"
"Oh so you would like to be able to run huge 3D process simulation using parallel processing and hierarchical storage of modeling data? ... yeah we can do that"
And when the previously cloistered government scientists from the weapons lab met the oilfield completion engineers working on downhole perforation guns for deep drilling, it got really interesting:
"Oh it would be good if you could direct a shaped explosive charge to blow a precisely oriented hole through thick steel casing from a few miles away? Hell Son, we do that every god-damned day around here! Wanna come out to the range and see it?"
Later in the day I got to walk through what was then one of the largest computers on the planet, the Thinking Machines CM-2 massively parallel hypercube array, and when I say walk through, that's exactly what I mean. You didn't stand and look at this computer, you walked into it! I knew it was big when I saw them wheeling in a standard workstation like the ones we were using at the time to run our 3D visualizations, on a cart, and start to use it to run a backup of just part of the array.
They also had a Cray-2 there, the same model I ran into in the Musée des Arts et Métiers in Paris when my wife and I visited for our 25th anniversary in 2006. I was later to find out it was not only the same model, but in fact the very same machine I had reverently laid my hand on to feel the chilled water cooling system when it was running simulated nuclear explosion models in New Mexico two decades earlier and an ocean away. Now where else but the oilfield could you make a connection like that?
In my case it was not only the prospect of a lucrative job actually using my college degree when the mining business was collapsing around Upper Michigan in the early 1980's, the possibility to work in remote exotic locations (ok, but Pecos?) and knowing I would be working with geoscientists who I already knew to be a friendly and jovial lot, but the fact that at that time, oil companies were actually using some of the spiffiest technological equipment of the times. I mean, we had access to computers!
I could actually submit a seismic processing job from a teletype terminal in Midland, Texas, and have it checked and submitted by a computer operator in The Woodlands outside of Houston the same day. I knew I had picked the right industry when, in the mid 1980's, the U.S. government decided they could help fund the big government labs by finding commercial applications for some of the technology. When Los Alamos in New Mexico went looking for industry customers, one of the first segments they turned to was "Big Oil". I found myself on a trip from Dallas Texas to Albuquerque New Mexico with a delegation of oil and gas technologists to get a first look at what the weapons guys had been doing inside of the top secret walls that housed the Manhattan project in it's day. We didn't get "inside the wall" where they do the real crazy stuff, and our unfortunately Iranian-born Vice President didn't even get that far, his clearance was denied at the gate and he spent the day in the hotel and looking at "Fat Man" and "Little Boy" in the museum. But the conversations we had around the conference table that day were pretty interesting.
"Oh so you want a way to reduce engine noise on a ship so you can listen better to sonic waves? ... yeah we can do that"
"Oh so you would like to be able to run huge 3D process simulation using parallel processing and hierarchical storage of modeling data? ... yeah we can do that"
And when the previously cloistered government scientists from the weapons lab met the oilfield completion engineers working on downhole perforation guns for deep drilling, it got really interesting:
"Oh it would be good if you could direct a shaped explosive charge to blow a precisely oriented hole through thick steel casing from a few miles away? Hell Son, we do that every god-damned day around here! Wanna come out to the range and see it?"
Later in the day I got to walk through what was then one of the largest computers on the planet, the Thinking Machines CM-2 massively parallel hypercube array, and when I say walk through, that's exactly what I mean. You didn't stand and look at this computer, you walked into it! I knew it was big when I saw them wheeling in a standard workstation like the ones we were using at the time to run our 3D visualizations, on a cart, and start to use it to run a backup of just part of the array.
They also had a Cray-2 there, the same model I ran into in the Musée des Arts et Métiers in Paris when my wife and I visited for our 25th anniversary in 2006. I was later to find out it was not only the same model, but in fact the very same machine I had reverently laid my hand on to feel the chilled water cooling system when it was running simulated nuclear explosion models in New Mexico two decades earlier and an ocean away. Now where else but the oilfield could you make a connection like that?
Monday, January 3, 2011
Those Pesky Rare Earths
So if the rare earth minerals are so rare, why all the fuss about them? Well actually, the rare earth minerals are named after the elements that they contain, which are primarily within the rare earth series on the periodic table, the lanthanides, elments 57-71, and numbers 21 and 39, Scandium and Yttrium. Despite the name, the elements are actually relatively plentiful in the earth's crust, but economically viable occurrences of the minerals are relatively rare compared to other mineable resources such as copper or iron ores. The real strategic value of the rare earth minerals is in the industrial uses of the elements they contain, which reads like a veritable Who's Who of the devices that allow us to continue as a high-tech society. Consider for example the following sampling of gadgets that depend on rare earth elements for their manufacture:
Aerospace components; mercury-vapor lamps; high-temperature superconductors; microwave filters; high refractive index glass; hydrogen storage; battery-electrodes; camera lenses; catalysts for oil refineries; chemical oxidizing agents; polishing powders; colorings in glass, ceramics and enamels; catalysts for self-cleaning ovens; rare-earth magnets; lasers; carbon arc lighting; glass used in welding goggles; ferrocerium firesteel (flint) products; ceramic capacitors; nuclear batteries; neutron capture materials; masers; phosphors; x-ray tubes; computer memories; fluorescent lamps; vanadium steel; portable X-ray machines; chemical reducing agents; PET Scan detectors.
Now you can understand why China's current 96% control of the export market for these minerals is of concern and why global mining companies are looking to open new sources.
Aerospace components; mercury-vapor lamps; high-temperature superconductors; microwave filters; high refractive index glass; hydrogen storage; battery-electrodes; camera lenses; catalysts for oil refineries; chemical oxidizing agents; polishing powders; colorings in glass, ceramics and enamels; catalysts for self-cleaning ovens; rare-earth magnets; lasers; carbon arc lighting; glass used in welding goggles; ferrocerium firesteel (flint) products; ceramic capacitors; nuclear batteries; neutron capture materials; masers; phosphors; x-ray tubes; computer memories; fluorescent lamps; vanadium steel; portable X-ray machines; chemical reducing agents; PET Scan detectors.
Now you can understand why China's current 96% control of the export market for these minerals is of concern and why global mining companies are looking to open new sources.
Tuesday, November 16, 2010
What were those languages?
Since posting my note about the languages used on the Western Australia bus system, TransPerth, I have had a lot of questions from people who didn't recognize several of them.
For those who are interested, here are some details on some of those that may not be familiar to our colleagues in the Western Hemisphere:
Amharic is a Semitic language spoken in North Central Ethiopia.
Dinka is a Nilotic language from Southern Sudan.
Karen is a group of tonal languages spoken by three million people in southern Burma, considered unusual among Tibeto-Burman dialects for not having any Chinese influence.
Kirundi is the Bantu language of 8.7 million Hutu and Tutsi in Burundi, Tanzania, Congo-Kinshasa and Uganda.
Dari is a variety of Persian spoken in Afghanistan.
So what we have here is not only an indication of some of the important groups immigrating to Perth over the centuries, but also in some cases the languages spoken by groups, who when they leave their homeland, march to the nearest ocean, and set sail in a perpendicular course away from the shore, the next significant piece of land they encounter happens to be Western Australia.
For those who are interested, here are some details on some of those that may not be familiar to our colleagues in the Western Hemisphere:
Amharic is a Semitic language spoken in North Central Ethiopia.
Dinka is a Nilotic language from Southern Sudan.
Karen is a group of tonal languages spoken by three million people in southern Burma, considered unusual among Tibeto-Burman dialects for not having any Chinese influence.
Kirundi is the Bantu language of 8.7 million Hutu and Tutsi in Burundi, Tanzania, Congo-Kinshasa and Uganda.
Dari is a variety of Persian spoken in Afghanistan.
So what we have here is not only an indication of some of the important groups immigrating to Perth over the centuries, but also in some cases the languages spoken by groups, who when they leave their homeland, march to the nearest ocean, and set sail in a perpendicular course away from the shore, the next significant piece of land they encounter happens to be Western Australia.
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