Oil & Gas Network - February 2009

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February 2009 Volume 10, Number 1

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Volume 10, Number 1

Contents 5 7 7 8

Celebrating 15 Years of Keeping STARS in the Sky Annual Reports 101 Help Keep STARS in the Sky Frac-Point™ Isolates Fracs in Tight Gas Wells to Increase Productivity and Accelerate Return on Investment 10 Fossil Fuels to Play Key Role in Ending Recession 11 Wood Group launches Chair of Arctic Engineering at the Memorial University of Newfoundland, Canada 11 What’s in store for 2009? 12 geoLOGIC systems ltd. Attains Gold Certified Partner Status in Microsoft Partner Program 14 Remote Gas Monitoring Systems 16 Driller Friendly GatorBACK Casing Running Tool 18 UBD Hybrid Benefits Environment and Budget 18 Garlock Adds Custom Flue Duct Expansion Joints 18 Chevron Canada launches award-winning educational program in partnership with Fort McMurray Historical Society 18 Launch of Turcon® Varilip® PDR seals from Trelleborg Sealing Solutions 19 GE Expands Award Winning Telematics Solution to Canada 19 AVEVA PDMS: Setting the Standard in Cost Reduction and Productivity for Plant Operations 19 Garlock Valve Stem Packing Tested to API 622 Fugitive Emissions Standard 20 CobraMax® stimulation service delivers increased production and efficiency in the Montney 22 Piping without Welding 23 Human Process Management Helps Oil and Gas Organizations Deal with Information Overload 23 Canada Energy Partners Announces Commencement of Gas Sales From the First Commercial Coalbed 24 geoLOGIC buys Calgary-based Whitehot Innovations, adds QFind Document Management module to geoSCOUT 24 North Rig Catwalk Technologies Ltd. 27 Schlumberger Opens Technology Center in Calgary 27 Brochures for Oil and Gas Drilling Operations Now Available from Automation Products Group 27 CygNet Invests for Growth as Oil & Gas Industry Demands Software to Increase Operational Efficiency 28 SMU Professor Got It Right 28 Control Microsystems Announces the SCADAPack 330E and 334E Controllers 29 Experion Process Knowledge System R310 29 OneWireless 29 UOP Master Simulation Models 30 Safety Manager 30 Uniformance Process Studio

Photo courtesy of Halliburton Oil & Gas Network, February 2009 3

Celebrating 15 Years of Keeping STARS in the Sky The PSAC Perspective Rob Gray, Manager Communications & Member Relations afety is a key issue for PSAC and its members. Despite our best efforts, accidents can happen – and most often occur in very remote locations, far from emergency medical services. While we hope that none of our workers will need the service – it’s comforting to know that a STARS air rescue team is only a phone-call away. That’s something industry worker Aldean Sehlstrom knows all too well. His wife Maureen was driving to the Eckville Public Health Unit, where she worked as a nurse, when her car hit black ice. Her vehicle rolled violently three times before crashing into a post.The impact broke her neck and back, fractured her pelvis in three places and fractured one of her legs. Aldean, an employee of Lonkar Inc., was working at a remote site when he got the news. His wife was in bad shape and needed medical attention quickly. Maureen had been airlifted by STARS to Edmonton. Her condition was dire, but thanks to the quick efforts of STARS, she would be okay. After several weeks in rehabilitation she returned home, and eventually recovered, shortly thereafter becoming a mom. The Sehlstrom’s story serves as a vivid reminder that at any moment your phone could ring with news of an incident where one of your field employees or a family member is critically injured. It’s a call that no one wants to get, but when it happens, chances are that the Alberta Shock Trauma Air Rescue Society (STARS) already has one of their shiny red choppers on the way. Often, these bright red beacons of hope and the emergency medical response team they carry can mean the difference between life and death, especially in a remote location. That’s why PSAC is proud to support the Shock Trauma Air Rescue Service (STARS) Foundation to ensure that their emergency medical transport helicopters are able to stay in the air. What began 15 years ago as an industry/community partnership to support safety has grown into the PSAC STARS & SPURS Gala, renowned as one of the longest running and most successful single-night fundraising events in Alberta. Each year, the event delivers a night to remember, with chart-topping country music performers, a delightful dinner and dance, and an array of indulgent activities and treats. The Gala brings together more than 1,000 individuals from the service/supply sector, the E&P sector, government, and otherwise, all in an effort to support this important community cause. This year’s Gala, held January 24, 2009, marks the 15th year of this partnership, through which PSAC has become STARS’ largest corporate supporter – having now well surpassed the $3 million mark. In honour of this ongoing partnership, the PSAC logo is proudly displayed on the STARS helicopters as a symbol of the role that the Association and its members have played in supporting this tremendous cause. In honour of the 15th Anniversary, PSAC would like to thank all the organizations and individuals who have contributed to the success of the Gala over the years. While the organizations and individuals who have supported this event are too numerous to recognize individually, PSAC does wish to acknowledge those companies recognized as a part of the Anniversary Gala for their long-term and significant support of the event.This includes Benefactors: Trican Well Service Ltd.; EnCana Corporation; and FirstEnergy Capital Corporation, along with the following Honorary Patrons: JuneWarren Publishing/Nickle’s Energy Group, Canadian Mountain Holidays, and Cargill Foods. Even in times of economic uncertainty, industry has remained steadfast in its support of this event, and for that we are both proud and grateful.Throughout industry’s ups and downs, this event has continued to grow, and so on this – our crystal anniversary year, PSAC felt it appropriate to thank everyone who has supported the Gala – both past and present, for being a part of something great.

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Oil & Gas Network, February 2009 5

Coll’s Corner By David Coll

Annual Reports 101

Help Keep STARS in the Sky

What to look for in this year’s crop of annual reports

he sixteenth annual STARS lottery launched this month with 3,030 prizes worth over $4.9 million. Every ticket sold will help keep STARS in the sky including the new AW139 helicopter arriving later this year. “It is an exciting time as we anticipate the arrival of the new helicopter. It will fly farther and faster and help save lives through an advanced medical interior as well as the capacity to carry two critical patients,” STARS President and CEO Dr. Greg Powell said at the lottery launch. The lottery is offering five grand prizes worth over $3.3 million retail, including four beautiful showhomes in Calgary, Red Deer, Edmonton and Lethbridge. The fifth prize is a ‘home away from home’ truck and trailer worth $116,000.

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THE COVER In a feeble attempt to underscore fiscal austerity, I fear we are going to see a slew of reports with nothing but the company name on the cover. After all, none of the simple bromides about growth, performance and value are going to fly in these tough times. But I would argue they don’t fly in good times either. It’s even more important, then, to craft a message that truly differentiates your company from the thundering wolf pack. Highly challenging for a communicator, but one tricky way around this dilemma is to find a tough quote from your CEO that puts a personal stamp on the report and establishes the theme. Image-wise, it’s all about focus. Avoid the ubiquitous collage that attempts to show the diversity of your operations. Pick a winner, the best single image that supports what you’re trying to get across thematically. If you’re going to be laying off 500 employees, you might favor a facility shot, for instance. FORMAT An unorthodox size may make your book stand out, but functionality is king. This year, you will look flaky if you produce anything horizontal or smaller than the standard 8 X 10. PRESIDENT’S MESSAGE We are going to be treated to hundreds of views about the poor economic conditions, how companies are coping and how “well” they are positioned moving forward. One way to improve your letter is to move the employee message front and centre, instead of tacking it on at the end of (presumably) more weighty matters.You need to at least create the illusion that people come first. Graphic pullquotes and photos of people on the job are two other effective ways to reinforce this concept.

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Photo by Mark Mennie

ith the Recession in full swing, cratered commodity prices and the general mood of doom and gloom said to pervade Canada’s oilpatch, I must confess I am rather looking forward to this years’ crop of annual reports and AGMs. Having “authored” five annual reports for a “major Canadian energy producer” almost a decade ago, I still delight in these staples of spring. For an investor and even the casual observer, there’s no better way to learn how a company truly sees itself than by reading their AR and attending their AGM. As early as the late 90s, pundits were predicting the demise of the printed annual report; securities regulations continue to evolve but it hasn’t happened yet. If anything, today’s AR is even more important – meeting a regulatory requirement but, for many, also serving as a company’s central marketing piece. It’s an urban myth, perhaps, that PR & corporate communications is one of the first disciplines to suffer during a downturn.That may be true, but on the flipside, it’s never been more important for companies to project a positive, professional image in light on the economic challenges that lie ahead both short and long term. So if you’ve already toasted your communications department, here’s some free advice – the things I’ll be looking for when this year’s reports hit the street.

There are also two exceptional early bird packages to be won including a MercedesBenz and travel package worth over $86,000 retail and a 2009 Porsche Boxter and Las Vegas trip for four plus $5,000 cash prize. In addition to the grand and early bird prizes, there are 13 vehicles, 41 vacations, 2,329 electronic prizes, 339 cash prizes and 594 other prizes including jewellery and luggage. STARS is a non-profit, charitable organization and relies on the lottery to fund approximately 50 per cent of mission operations.“Although there is global economic uncertainty, we hope that Albertans will continue to generously support our largest fundraiser as they have in the past,” said Dr. Powell. STARS provides airborne intensive care to the critically ill and injured 24 hours a day, seven days a week with the familiar red BK117 helicopters from bases in Calgary, Edmonton and Grande Prairie. STARS has flown over 17,300 missions since 1985 and currently serves 94 per cent of Alberta’s population.

OPERATIONS REVIEW For many, this has been replaced with the oftenpedantic MD&A. No reason this can’t be spiced up with photograpahs, pullquotes and a painstaking Plain English edit or two. FINANCIALS Ask yourself if anyone, beyond your CFO, controller and legal counsel can understand the notes to your financials. Ask again and follow the above advice on the MD&A. BACK PAGES Here’s another opportunity to enhance governance discussion by providing short bios of your board of directors and company officers. Consider scrapping the chronological litany of achievements for a more personal summation of what specific expertise a given director brings to your company (i.e. hatchet man). Consider replacing static mugshots with a photojournalistic shot of the board in action or, at least, interacting. Roll up those sleeves. BACK COVER Valuable real estate, often wasted. You’re paying handsomely for the cover stock and the back cover is often displayed on someone’s desktop when they put the book down – why not use this space to leave the reader with a simple closing message? And don’t forget the recycled logo – David Suzuki is watching.

Oil & Gas Network, February 2009 7

Frac-Point™ Isolates Fracs in Tight Oil & Gas Wells to Increase Productivity and Accelerate Return on Investment Quick and to the Point roducing gas in tight shale formations often requires major pumping investments. Traditionally, An operator didn’t have many good choices when fracturing a tight gas or oil well. One option was to simply pump frac fluid into the open hole and hope for the best, which resulted in frac fluid flowing mainly to the area of least resistance, reducing production along the rest of the wellbore. Another choice was to isolate each zone along a horizontal wellbore by repeatedly cementing, plugging, perforating, and fracturing. That meant multiple trips downhole, the expense and risk of perforating, and the cost of having pumping trucks on standby for days at a time. Baker Oil Tools has developed a better option. The Baker Oil Tools Frac-Point Open-Hole Fracture Completion System allows you to pinpoint fracture placements without cementing. That means improved initial productivity, accelerated reservoir drainage, and a faster return on your investment. Baker Oil Tools sets the standard for innovation, performance, and reliability in completion technology. With the FracPoint™ Open-Hole Fracture Completion System, Baker Oil Tools delivers a solution that can improve production in tight shale reservoirs and turn otherwise unprofitable projects into moneymakers.

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Frac-Point™ Open-Hole Frac System The Frac-Point system uses specially designed short-radius, open-hole packers and frac sleeves to isolate intervals of a horizontal section and pinpoint fracture treatment placement.The result is greater control of the frac treatment and the assurance of fracturing the entire length of the lateral and increasing production. By eliminating the costly cycle of cementing, plugging, and perforating, the Frac-Point system delivers three important advantages to operators drilling in tight shale formations. • No cementing. Open-hole packers provide isolation along the length of the liner. This eliminates the need to cement the liner in the lateral section and increases formation interface. • No perforating. The sleeves provide access to the zone of completion for both fracturing and production. • No wasted time. Frac-Point is a one-trip system, so fracture treatments for each section can be pumped on the same day–eliminating the expense of mobilization and demobilization of pumping equipment.

Frac-Point™–How it Works The Frac-Point™ Open-Hole Fracture Completion System consists of four primary components: the liner top packer, open-hole packers, frac sleeves, and pressure-actuated sleeves (P-Sleeves).

S-3™ Liner Top Packer The liner top packer is a hydraulic set permanent production packer with a tie-back sleeve.The packer is designed to carry up to 200,000 lb of liner assembly.

Frac Sleeves The frac sleeves include ball seats sized accordingly. The sleeves are then actuated open sequentially by deploying balls from the surface.This also isolates the already-treated lower intervals. The balls and seats are designed to be milled up to allow for a full opening production ID to be maintained throughout the system if needed.

Getting Through the Tight Spots One major challenge in completing high-angle wells in open hole is simply getting the tools through doglegs and other restrictions to total depth. Baker Oil Tools uses its design expertise and operational excellence to meet this challenge. Because Frac-Point packers are shorter than competing tools, they can navigate better through tight spots. Baker Oil Tools’ proprietary torque and drag software estimates the probability of reaching total depth and helps eliminate wasted trips and wasted money. The Frac-Point™ Open-Hole Fracture Completion System consists of four primary components: the liner top packer, open-hole packers, frac sleeves, and pressure-actuated sleeves (P-Sleeves).

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Short Radius Open-Hole Packer The open-hole hydraulic set packers feature Baker’s patented antiextrusion packing element system and require no mandrel movement during setting.

P-Sleeves The pressure-actuated sleeve is similar to the frac sleeve, but does not contain a ball seat. The operator may choose to open the P-Sleeve at installation or have it remain closed until the frac crew is on site and rigged up.

Key Frac-Point™ Advantages • Eliminates perforating and liner cementing operations • One-trip installation saves rig time • Improves fracture extension control over nonselective hydraulic fracturing • Reduces fracturing costs with smaller, selective treatments • Treats up to twelve intervals /stages

See the Effect of Frac-Point™ on the Value of Your Well Baker Oil Tools’ Houston-based reservoir analysis team can model different completion scenarios and estimate well deliverability for specific well parameters.Taking into account factors like reservoir size, temperature, pressure and permeability, fracture properties, and projected gas prices, the team can determine whether it’s economically feasible to use FracPoint™ on a particular well. The cases below model two tight gas wells in Texas, one in a charged reservoir and another in a depleted reservoir. In each case, three scenarios were modeled: 1) Base Scenario: Completed as a vertical well and fractured 2) Frac-Point Scenario A: Completed as a horizontal well (1,500 ft) (457.2 m) and fractured in three zones using Frac-Point 3) Frac-Point Scenario B: Completed as a horizontal well and fractured in four zones using Frac-Point

Model Well #1

Model Well #1: Frac-Point™ Super-Charges Returns This reservoir has a drainage area of 2,109 ft (643 m), an average permeability of 0.3 md, an average reservoir thickness of 38 ft (11.58 m), and an initial pressure of 1,500 psi (103.42 bar), and 3,032 MMscf gas in place. In this scenario, the operator could shave four months off the payback time by using a four-zone Frac-Point completion.

Model Well #2: Frac-Point™ Squeezes Out Profits In depleted reservoirs, the effect of Frac-Point can be even more dramatic. In this scenario, with a reservoir with an initial pressure of just 600 psi (41.37 bar) and 800 MMscf gas in place, a driller would never break even using a traditional vertical, hydraulically fractured completion. The four-zone Frac-Point completion could pay for itself in four years.

Model Well #2

Oil & Gas Network, February 2009 9

Fossil Fuels to Play Key Role in Ending Recession AJM Releases First Quarter Oil and Gas Price Forecast JM Petroleum Consultants released its first oil and gas price forecast for 2009 with the prediction that short-term prices will remain volatile as fossil fuels play a key role in helping the world climb out of recession. “While we’ve seen a drop in demand for fossil fuels, Americans are being lured back to the roads with gasoline sitting at US$1.70

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or lower per gallon,” observed Ralph Glass, AJM’s Vice President of Operations. “If President-elect Obama’s plans to put America back to work through infrastructure revitalization begin to materialize, fossil fuels will be the engine driving the Americans to prosperity. Factors like these suggest that crude oil is currently at its bottom average price, and a climb is soon to begin.”

Mr. Glass believes that while external forces will continue to cause near-term volatility and oscillation in prices, basic supply and demand and the cost to bring on new production, will provide a truer picture of oil and natural gas pricing for forecast purposes. AJM’s Q1 2009 price forecast, established effective December 31, 2008, shows crude oil prices in constant dollars based on a WTI forecast of US$55.00/bbl for 2009, rising to US$75.00/bbl in 2010, then reaching US$100.00/bbl by 2013 and holding at this level for the balance of the forecast. The AECO US NYMEX natural gas price in constant dollars is expected to average US$6.50/Mcf in 2009, rising with oil to a long-term price in 2013 of US$9.50/Mcf. The Canadian priced AECO forecast is expected to average C$7.00/Mcf in 2009 rising to C$9.00/Mcf in 2013, corresponding with the expected recovery of the Canadian dollar over the same period. Complete forecast tables, commentary and documentation for AJM’s December 31 Price Forecast are available for download on the AJM Petroleum Consultants website at www.ajmpetroleumconsultants.com. AJM Petroleum Consultants, a privately owned Calgary-based company, has extensive experience in corporate reserve evaluations, acquisition and divestiture evaluations, and evaluations of unconventional reserves such as coal bed methane, tight gas, shale gas and bitumen/heavy oil. Diverse engineering and geological capabilities combined with a forward-thinking approach to technology have allowed AJM to provide innovative solutions to clients in the upstream sector of the oil and gas industry in Western Canada, North America and internationally. Over time, the company’s price forecasts have proved to be more realistic than others in the industry.

Upcoming Event The Canadian Energy Research Institute is holding the following conference in the spring of 2009.

CERI 2009 NATURAL GAS CONFERENCE Navigating a Clear Path in a Sea of Uncertainty

February 23-24, 2009 Calgary TELUS Convention Centre The last 12 months has seen the natural gas market change from a healthy, positive environment to one of turmoil, unknowns, tight credit and general unease. This conference will explore the events that led us to this point and the potential changes in conventional and unconventional gas developments that could set a path out of this turmoil.

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Wood Group launches Chair of Arctic Engineering at the Memorial University of Newfoundland, Canada nternational energy services company, John Wood Group PLC (“Wood Group”), has launched its sponsorship of a professorial chair in arctic engineering at the Memorial University of Newfoundland (MUN) in St John’s, Canada. Mike Straughen, Group director & chief executive of Wood Group’s Engineering activities, said, “I am delighted to announce that, over a five-year period, we are investing C$500,000 to sponsor a new academic Chair at MUN, which will be known as the ‘Wood Group Chair in Arctic and Cold Region Engineering’. We already collaborate with the university through J P Kenny and IMV, our engineering company based in St Johns. Our goal is to develop leading edge technology so we can source new engineering solutions for our clients operating in these emerging, strategic regions. MUN is a recognised leader in this area, with a track record for research into the unique challenges of ocean and ice engineering such as seabed ice gouging and ice loads on ships. “The combination of MUN’s expertise with Wood Group’s experience working in the cold regions of Canada,Alaska and Russia, through our IMV, Mustang and J P Kenny engineering companies, will enable us to jointly find safe, cost-effective solutions for these untapped reserves,” added Mike Straughen. “Exploration in the Arctic is still in its infancy and surveys produced by the US Geological Agency suggest that the area may contain as much as one fifth of the world’s yet-to-be discovered oil & gas reserves. It is estimated that the Arctic may hold as much as 90 billion barrels of undiscovered oil reserves and 1,670 trillion cubic feet of natural gas.” The professorial chair will be associated with MUN’s Ocean Engineering Research Centre in the Faculty of Engineering & Applied Science and will benefit both undergraduate and post- graduate engineering students. At MUN, Wood Group plans to invest in research projects focusing on topics including ice mechanics, arctic pipeline design and arctic structures to advance technology for engineering in arctic and cold regions for the oil & gas industry. “We are extremely pleased about this collaboration with Wood Group,” said Eddy Campbell, acting president and vice-chancellor, Memorial University, “It is very important for an engineering school to have strong links with industry as this exposes students to a world outside the university. Our staff within the faculty will also benefit from similar exposure, especially when working in frontier regions.” Given MUN’s geographic location and current academic research & development programmes, there is an opportunity for Wood Group to raise its profile by collaborating with the University. Wood Group companies IMV and J P Kenny already collaborate with MUN on the Co-Operative Engineering programme, in which engineering undergraduates combine academic terms with extensive industrial internships in the oil & gas industry. This sponsorship is the latest in a series of similar arrangements Wood Group has made with universities in Aberdeen, Australia, Dubai and Kazakhstan, to invest in the future of the next generation of engineers and contribute to advances in technology and industry sustainability.

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What’s in store for 2009? he year ahead won’t be the worst the petroleum industry has experienced, but the downward slide is expected to continue. Don Herring, president of the Canadian Association of Drilling Contractors (CAODC), said drilling numbers in 2009 are already proving to be falling from 2008 levels.“It will be essentially a continuation in the decrease in activity we experienced in 2007 and 2008, following peak rates in 2005 and 2006,” he said. The last time the industry experienced such a slowdown, it lasted seven years. “We went through seven very tough years starting in 1986 with 36 per cent utilization. We didn’t see utilization levels go to 55 per cent until 1993,” said Herring. In the first week of 2009, utilization levels were at 36 per cent in Alberta. Herring said 50 to 55 per cent utilization is considered a break-even point for industry, so that puts it in sub-economic conditions. “Our current forecast calls for about 14,000 wells drilled in 2009. We’re suggesting utilization will be around 39 or 40 per cent and that may be slightly optimistic because the numbers we just got for 2008 show utilization at 40 per cent.” This year will see a continuation in the trend for higher days per well because of the focus on deeper natural gas wells, the CAODC reported. The estimate for slightly more than 14,000 well completions in 2009 is down six per cent from 2008 and 25 per cent from 2007. In 2005, utilization was a healthy 69 per cent and wells drilled were 22,000. This year is going to be quite different. Greg Stringham, vice president of markets and fiscal policy for the Canadian Association of Petroleum Producers (CAPP), said 2009 is going to be a year of “a great deal of uncertainty. Planning has been very, very difficult.” While everyone believes commodity prices will eventually go back up, the big question is when, he said. Calgar y-based Tristone Capital released a forecast in December predicting that oil will average $50.30 US per barrel in 2009.

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“I’ve never seen oil prices drop over $100 a barrel over five months,” said Stringham. “It would be nice to see some stability to return to the market.” The course of action he has heard from companies is that they are tightening their belts for 2009.“They have to go back and live within their means and being prudent enough to be resilient for when commodity prices bounce back,” he said. Stringham said it’s likely that mergers and acquisitions won’t be as common in 2009 because banks are not as open to approving credit.“The equity is not there.” The opening months will tell the true tale of where 2009 is headed because the first quarter is usually the busiest drilling season, he added. Back in the fall, CAPP predicted a 20 per cent expenditure drop for 2009, but that may have to updated as things play out. The slowdown in the petroleum industry has hit Alberta the hardest, according to statistics compiled by the Petroleum Services Association of Canada (PSAC). Once a leader in drilling activity, Alberta has slipped to third, with the highest drilling numbers for 2009 expected to come from unconventional gas plays in British Columbia, followed by the Bakken play in Saskatchewan. PSACs 2009 Canadian Drilling Activity Forecast shows a four per cent decrease in total wells drilled compared to 2008. In Alberta though, that decrease is expected to be 11 per cent. “Alberta will see a drop of 1,350 wells, due in large part to the province’s new royalty regime.The new regime simply makes it more attractive for companies to diversify into places like B.C. and Saskatchewan that are now seen as being more competitive,” said Roger Soucy, PSAC president. In the pipeline side of the industry, things will be slightly more level than the drilling side because the projects take so long to be pulled together, explained Brenda Kenny, president of the Canadian Energy Pipeline Association (CEPA). “It’s somewhat steady as she goes,” she said. “It’s too early to tell, but there may be a year of two of pushing back some projects.”

Oil & Gas Network, February 2009 11

geoLOGIC systems ltd. Attains Gold Certified Partner Status in Microsoft Partner Program geoLOGIC Further Distinguishes Itself by Earning a Microsoft Competency in ISV/Software Solutions eoLOGIC systems ltd. announced it has attained Gold Certified Partner status in the Microsoft Partner Program with a competency in Independent Software Vendor/Software Solutions recognizing geoLOGIC’s expertise and impact in the technology marketplace. As a Gold Certified Partner, geoLOGIC has demonstrated expertise with Microsoft technologies and a proven ability to meet customers’ needs. Microsoft Gold Certified Partners receive a rich set of benefits including access, training and support, giving them a competitive advantage in the channel. A recognized leader with 25 years of experience supplying knowledge management services to the oil and gas industry, geoLOGIC is a leading provider of value-added oil and gas data and decision support tools based on Microsoft technologies. “Achieving Gold Certified Partner status in the Microsoft Partner Program is just one more way we are demonstrating our commitment to provide single-source solutions that can be reliably and effectively integrated company-wide,” said geoLOGIC Vice President of Operations and Technology, Sean Udell,. “The benefits provided through our Gold Certified Partner status will allow us to continue to enhance the offerings that we provide for customers.”

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“We congratulate geoLOGIC systems ltd. for achieving Microsoft Gold Certified Partner status, demonstrating their commitment to delivering innovation and value to customers,” said Lora Gernon, Director, Partner Group, Microsoft Canada Co.“The Microsoft Partner Program delivers tools and resources to help technology providers such as geoLOGIC succeed and make an impact on the marketplace.” As one of the requirements for attaining Gold Certified Partner status, geoLOGIC had to declare a Microsoft Competency. Microsoft Competencies are designed to help differentiate a partner’s capabilities with specific Microsoft technologies to customers looking for a particular type of solution. Each Competency has a unique set of requirements and benefits, formulated to accurately represent the specific skills and services that partners bring to the technology industry.Within select Competencies, there are Specializations that focus on specific solution areas that recognize deeper expertise within that Competency. Serving as a specialized path to earning those Competencies, Specializations give direct access to the tools and resources that support that specific area of focus. The ISV/Software Solutions Competency recognizes the skill

and focus partners bring to a particular solution set. Microsoft Gold Certified Partners that have obtained this competency have a successful record of developing and marketing packed software based on Microsoft technologies. “Solutions competencies are an important way for Microsoft to better enable ISVs to meet customer needs,” said Sanjay Parthasarathy, corporate vice president of the Developer and Platform Evangelism Group at Microsoft Corp.“They allow ISVs to keep and win customers through their deep knowledge of solutions-based Microsoft platform technologies. Microsoft has a long history of working closely with ISV partners to help them deliver compelling solutions and applications to our mutual customers, and the Microsoft Competencies are an important step in continuing to enhance vital relationships with ISVs worldwide.” The Microsoft Partner Program was launched in October 2003 and represents Microsoft’s ongoing commitment to the success of partners worldwide. The program offers a single, integrated partnering framework that recognizes partner expertise, rewards the total impact that partners have in the technology marketplace, and delivers more value to help partners’ businesses be successful.

Remote Gas Monitoring Systems Intelligent Solutions for the Oil & Gas Industry here are many facilities that need to monitor for hazardous gas leaks in areas where it is not possible to install cabling for power or signal. In these scenarios, the products must operate independently. They must have self-contained power supplies and methods of sending out alarm messages when gas concentrations reach alarm levels. This becomes essential when detecting gas in areas surrounded by residential communities. Lately, more exploration and production is occurring in areas that were never considered. Exploratory drilling is occurring in backyards, school yards and community parks. In many communities, well heads or pumping units are being installed within or very close to residential communities. It is important that the members of these communities feel Permanent pole mount safe and not threatened by gas exposure. To protect these areas, remote monitoring systems can be easily deployed while drilling occurs, or placed permanently while the wells are producing oil and gas. These units require no cabling and can be powered by battery packs and solar arrays. Gas detectors are used to detect hazardous levels of either toxic or combustible gases. When alarm conditions are met, the units will dial out via an internal modem and report the alarm condition via e-mail and cellular phone to emergency response personnel.These systems can also be equipped with GPS or other sensors to measure and report wind speed, or wind direction. With this information, responders can see where the release is heading, and plan any necessary evacuations. Industrial Scientific is able to offer such a system for monitoring several gas wells in North America. Each location required both combustible as well as toxic monitoring at remote locations within their facilities. The detector (iTrans) carries a Class 1, Division 1 explosion proof approval, and can be located in classified areas.

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Sample architecture: The gas detectors were connected via a 4-20 mA signal to a small control device that was used for remotely monitoring gas levels. The control device has 4 inputs and can monitor gas concentrations, level, flow, pressure, temperature, or any 4-20 mA transmitter. A unique GSM interface allows the control systems to upload information at pre-determined intervals. It can

14 Oil & Gas Network, February 2009

also upload concentrations or levels for each channel during alarm events.A Web interface allows key managers to view the information from any computer. Reports can be generated as well as automatic e-mail and telephone notifications when an alarm condition occurs.These systems will operate as long as there is GSM cellular coverage in the area. The entire system (gas detector and controller) can be powered directly by any 12-24 VDC. If local power is not available, an optional battery pack and solar panel can be used to power the entire system. Industrial Scientific has installed a variety of options to meet this need including permanent pole mount installations, and mobile push cart systems.

Notifications Example: The Web site also allows the user to set up notifications. This option will dictate what types of events will trigger notifications.These events can include power failures, gas alarms, or any type of level of flow alarm.When an event occurs, notifications can be sent by e-mail and phone. Multiple e-mail addresses and multiple phone numbers can be entered to receive these alerts each time an alarm occurs.

Hardware needed: Controller: The hardware required for this system is a four-channel controller with GSM interface. The controller operates off of 12 VDC, has one output relay for local alarming and can take any 4-20 mA input (gas detector, anemometer, pressure, etc. The iTrans gas detector has internal relays that can be used for additional alarm relays. If more relays are required, alternate solutions can be provided.

Gas detector and housing: In addition to selecting a gas detector with the proper sensor configuration, the equipment can be housed in non-classified stainless steel (or NEMA 4X rate) enclosures. It can also be placed in Class 1, Division 1 rated enclosures. Power supply: Based on customer needs, various power supplies are available. These supplies include direct DC power sources, AC/DC power sources, batteries, and solar panels. Confidence and assurance: All these options can be selected to meet the needs of the facility and to ensure easy integration into an existing gas monitoring program. Regardless of the options chosen, the most important thing to remember is that these systems are designed with one purpose, to protect human life. Selecting a manufacturer that can to provide quality equipment and service will also ensure the highest possible levels of safety in, around and near a facility.

About Industrial Scientific Corporation Industrial Scientific Corporation is a global leader in gas detection equipment, software and services to protect human life in the most demanding work environments. With continuous improvements in lean manufacturing operations, engineering, and R&D, Industrial Scientific is dedicated to eliminating workplace fatalities.To achieve this goal, Industrial Scientific combines the highest quality products, the breakthrough iNet™ service to keep them in perfect working condition, and a focus on anticipating and addressing problems before they happen. Employing over 850 people, Industrial Scientific has manufacturing operations based in Pittsburgh (USA),Arras (France), Dortmund (Germany) and Shanghai (China).The company provides technical services to customers from local service centers around the world, and has additional offices in Australia, Brazil, Canada, Czech Republic, Dubai, Mexico, The Netherlands, Qatar, Singapore, Switzerland and the United Kingdom.

Oil & Gas Network, February 2009 15

Driller Friendly GatorBACK Casing Running Tool fter three years of field trials, along with extensive engineering and testing, the GatorBACK™ Casing Running Tool internal, CRTi has proven itself. These tools are being manufactured by Volant Products 2008 Inc. and now offered for sale. Until recently, Volant Tubular Services Inc. was the only Canadian source of casing running services using CRTi technology. “Continuous evolution of tool design has yielded numerous refinements and improvements, maximizing the range of casing sizes and weights that can be serviced by a single tool.” The design objective had been to create and develop “driller friendly” casing running tools. To that end, the following objectives have been met: • Efficient for use in top drive casing handling • Reduction of physically demanding tasks encountered in conventional casing running • Reduce the necessity to have specialized technical personnel onsite for casing running operations, improving utilization of drilling personnel • Very fast rig-in and rig-out operations with no hydraulic connections • Compact, reliable, robust tools that are fully mechanical • Can be used in conjunction with controlled connection make-up and torque-turns monitoring • Reduce the exposure of drilling personnel to hazardous overhead and pinch point locations, and elimination of power tongs • Capable of immediate fluid circulation and cementing • Capable of full string handling in vertical and deviated wells – hoisting, rotating, and reciprocating the casing Our vision has always been to make these tools widely available for use in drilling and completion operations, and now with the solidification of the design we are moving forward. The tools are available for purchase by drilling companies and casing running service providers. Over the past few months, we have experienced strong uptake in key markets in the USA and abroad. There is also strong interest coming from major drilling contactors operating in the Western Canadian Sedimentary Basin, and particularly in the heavy oil belt. One driller has purchased tools to equip multiple rigs which are destined for the Middle East. We have recently sold tools to Australian drilling contractors. We are looking forward to strong growth of sales for this product line in 2009.

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Upcoming Event The Canadian Energy Research Institute is holding the following conference in the spring of 2009.

CERI 2009 OIL CONFERENCE The Economy and Oil Demand: Where are they Taking the Oil Market

April 5-7, 2009 Calgary TELUS Convention Centre Most of the OECD economies went into recession late last year and the growth in the overall world GDP is expected to be minimal this year. The oil demand is going through a similar path and the future outlook does not seem promising. The 29th Annual CERI Oil Conference has invited prominent experts to address important issues affecting the global oil markets. 16 Oil & Gas Network, February 2009

UBD Hybrid Benefits Environment and Budget

Chevron Canada launches award-winning educational program in partnership with Fort McMurray Historical Society

Gas lost to venting is now making its way to the gas line, using an asset capture system developed from underbalanced drilling technology.

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hen venting from coalbed methane (CBM) wells in southwestern Colorado became a community issue, Weatherford’s local Controlled Pressure Drilling & Testing (CPD&T) team knew they had an answer. It just required some ingenuity, a bit of retooling and a client that was willing to come onboard. Some viewed venting as a visual pollutant in the more populated areas and as a fire concern in the dry western environment. For beleaguered operators, the venting also meant lost gas sales revenue potential. They all needed a solution; so a process that eliminated the venting and captured the gas for sale looked like a win-win situation to the Weatherford engineers.

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Reducing Methane Emissions Methane gas flowed back after hydraulic fracture stimulation poses a potential environmental risk. Produced by the well, the gas mixes in the wellbore with sand and fluid remaining from the stimulation treatment. The wellbore cleaning or flowback removal process, typically used in conjunction with compressed air, gas and foam techniques, results in venting the returned gas. Vented to the atmosphere, this greenhouse gas is potentially a serious enough pollutant to warrant an ongoing industry-wide emissions reduction program. In addition, dangerous gas build-up in the venting area or in low-lying areas may increase the chance of a fire or explosion. Venting the gas during the short-term cleanout operations typically takes care of methane emission concerns. But burning was not the solution favored by many residents living atop the Fruitland formation, source of the world’s largest CBM field— with about 55 trillion cubic feet of original gas in place—and the target of abundant drilling and stimulation activity in the prolific San Juan Basin since the early 1950s.

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® ® Launch of Turcon Varilip aves PDR seals from Trelleborg on cre Sealing Solutions

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sealing on the shaft, leading to excellent performance at high rotary speeds. Characterized by low friction and stickslip-free running, the seal reduces temperature generation, permits higher peripheral speeds and lowers power consumption. This results in a long-service life, with maximized mean time between planned maintenance and greater productivity. “Currently there is a big push by industry in general to reduce power consumption and our carbon footprint,” says Dave Cummings, Product Manager for Trelleborg Sealing Solutions Broomfield, CO, one location where Turcon® Varilip® PDR is manufactured. “Apart from showing responsibility for the environment, it has the benefit of lowering ever-increasing energy bills.” Go to www.trelleborg.com/news

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relleborg Sealing Solutions announces the launch of its new Turcon® Varilip® PDR range for the oil & gas industry. These industrial seals are the optimum solution for high-speed rotating applications, as this range has exceptional low-friction characteristics, reducing torque.This in turn cuts power consumption, which can contribute to lower equipment running costs and ultimately decreased energy bills. Turcon ® Varilip ® PDR (Performance, Durability, Reliability) rotary shaft seals are constructed from one or multiple Turcon® PTFE based sealing elements which are mechanically retained in a precision machined metal body. The metal body gives a robust static seal against the housing, preventing thermal cycling, while the Turcon® sealing element provides positive dynamic

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arlock Sealing Technologies, a leader in fluid sealing technology for more than 100 years, adds the custom-engineered 8400-HT style expansion joint to its existing line of flue duct products. Available in a variety of configurations and material combinations, each component is designed and fabricated to meet specific system requirements. Ideal for low-pressure, lightweight piping and ductwork applications, the 8400-HT expansion joint can also withstand temperature excursions from -75oF to +2,200 oF (-60 oC to +1200 oC). Reflecting environmental focus on emissions control, the 8400-HT can be constructed with a proprietary blend of fluoropolymers and reinforcing materials that provide high resistance to corrosive gases such as SO2 and H2SO4, making the expansion joint suitable for most operating conditions in flue gas desulphurization systems. To assure safe operation and optimal performance, it is imperative that accurate application and dimensional information is provided. A Garlock application data submittal sheet can be provided to insure that the expansion joints are engineered specifically and correctly. [email protected].

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Garlock Adds Custom Flue Duct Expansion Joints

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hevron Canada has announced it has entered into a partnership with the Fort McMurray Historical Society to bring an award-winning educational program to elementary school students and teachers in the Wood Buffalo Region. Under a multi-year funding agreement, Chevron will contribute more than $180,000 over four years to establish the Chevron Open Minds Program at Heritage Park, a unique educational, cultural and social venue operated by the Fort McMurray Historical Society. Chevron Open Minds is an internationally recognized educational initiative that advances student learning by moving students out of regular school classrooms into enriching community environments for a full one-week period. Heritage Park now joins other Chevron Canada Open Minds Programs in southern Alberta, including the Calgary Zoo and Glenbow Museum, as well as a new site being launched at The Rooms in St. John’s, Newfoundland and Labrador. “Chevron Canada is delighted to partner with the Fort McMurray Historical Society to give students in the Wood Buffalo Region a wonderful opportunity to immerse themselves in the diverse history of northern Alberta,” said Mark Nelson, president of Chevron Canada. “By following the proven educational model of Open Minds, participants will gain hands-on experiences that will help them to develop vital critical thinking, problem solving and writing skills.” “We appreciate Chevron’s generosity which has enabled Heritage Park to implement this exceptional education program,” said Roseann Davidson, executive director of Heritage Park. “The Open Minds Program will provide students with the opportunity to discover our community’s rich history and culture. Our museum site, exhibits and collections will enlighten and connect the students to the natural and social history of our region.” From January 19-23, Heritage Park will welcome its first Open Minds class, comprising 20 students in Grade 3 from Good Shepherd School. During their week-long stint, the students and their teacher will study artifacts, experience the life of a trapper and learn about the skill of weaving and spinning wool. It’s anticipated that a total of five classes will participate in the 2009 pilot year, with an equal number of classes participating in 2010 and 2011. The Chevron Open Minds Program began in 1993 with the introduction of the first school at the Calgary Zoo. It has since expanded to three other facilities in the Calgary area, including the Glenbow Museum, TELUS World of Science and the Cross Conservation Area, and has won over 30 national and international awards. For additional information on the program, please visit http://chevronopenminds.ca

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GE Expands Award Winning Telematics Solution to Canada

AVEVA PDMS: Setting the Standard in Cost Reduction and Productivity for Plant Operations

Analytics and Consultancy Helps Companies Dramatically Reduce Costs, Increase Productivity & Green Fleet Operations

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arlock Sealing Technologies, a leader in fluid sealing technology for more than 100 years, has successfully tested its Style 1303-FEP valve stem packing for compliance with the newly adopted API 622 Fugitive Emissions Standard. Measured leakage confirmed the packing meets the requirements of the most stringent U.S. state air quality laws and consent decrees. Yarmouth Laboratories, an independent testing facility in Yarmouth, Maine, conducted two iterations of the test. The new API 622 standard reflects the unique operating environment in today’s hydrocarbon processing facilities. Using methane as the medium, the test subjected the Garlock Style 1303-FEP packing to three thermal cycles, from ambient to 500o F (260o C) and back again, simulating the real-world challenge of processing different grades of crude oil through the same equipment. To model the minimum desired packing life in difficult refinery environments, Yarmouth Laboratories also conducted 1,500 actuation cycles at 600 psig (41 bar). The 5-ring Garlock Style 1303-FEP packing sets exhibited exceptionally low leakage rates, averaging just 41 PPMv and 53 PPMv in the two iterations of the test. Refineries can obtain engineered set performance from this fire-safe, spooled braided packing without the time and expense of having to measure the valves. As such, it shortens turnaround windows by providing a more timely and cost-effective “build-in-place” repacking solution.Additionally, 1303-FEP carries a five-year warranty, assuring continued compliance from turnaround-to-turnaround and eliminating the costs associated with on-line leak sealing, environmental penalties and valve replacement.

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On average, customers have realized double-digit percentage improvements in worker productivity, expanded business capacity, fuel consumption, carbon emissions, accident rates, and overtime costs. Moreover, because delivery, sales and service calls are completed more efficiently, businesses using telematics are better able to meet their customer service level agreements. This strengthens customer loyalty and drives more revenue.

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eneral Electric is expanding its award winning telematics solution to Canada, the company announced today. The offering, which was rolled out in the United States in 2006, gives companies with fleets of vehicles the critical line of sight into how their assets are performing in real time. “Now more than ever, businesses are looking for smart, efficient ways to reduce operating costs while simultaneously increasing productivity. Our solution provides an answer, offering a powerful suite of back-office fleet support services with robust analytics all on one easy to use integrated platform,” says Stephen Ulanoski, General Manager, GE Capital Solutions Telematics program. Visibility, Knowledge, Competitive Advantage GE’s comprehensive telematics solution provides web-based access to vehicle asset performance metrics including CO2 emissions as well as related alerts, trend charts, exception reports, and customizable mapping. The integrated solution not only allows customers to see in real time where their assets are; it offers clear strategies for improving performance and puts them on their way to greening their fleet operations. GE’s six-sigma trained fleet telematics experts compile more than 100 customized reports.These allow businesses to take into account stop frequency, stop duration, and drive time, along with many other critical data elements demanded by diverse fleet types.The reports and analysis helps customers understand the impact of each on their business. “For example, if it takes 30 minutes to visit one customer and 60 minutes another, the data and our analysis helps our clients understand what’s behind that. Once that’s captured and the costs are understood, we help our clients take proactive steps—whether it is better route planning or more strategic resource allocation and pricing—to optimize the operation. The results are immediate and significant, delivering the competitive advantage our customers want and need, especially now,”Amit Jain, Product Manager, GE Capital Solutions Telematics program. Big Results Augmented with additional current fleet data, actionable recommendations provided by dedicated telematics consultants enable significant operational improvement in a fleet’s performance and cost management.

VEVA’s unique, proven and object-based technology has provided our clients with unrivalled flexibility in the execution of complex global process plant projects. AVEVA has taken this technology platform to new heights of productivity enhancements across the whole project, offering further fabrication and construction savings by extending the scope and ability to control, manage and share project information globally. AVEVA Plant Design Management System (PDMS) is part of the AVEVA Plant portfolio, which enables companies to make immediate and substantial productivity gains on their projects from capabilities delivered on a proven design platform. A snapshot regarding some of the benefits in using PDMS is outlined as follows: Reduced Site Rework These can be explained further such as reduced site rework improved higher quality design through the ability to perform multiple design checks therefore eliminating errors.Accurate materials information eliminates over-ordering and delays on site due to a lack of required materials or information. Effective Globally Dispersed Design Teams PDMS allows geographically separate design teams to work together although they were in a single office. The environment offers the designer centralised administration, control, and protection from communication limitations or failures. Project teams can be quickly assembled and mobilized. Higher Design Efficiency High levels of automation, intelligent behaviour and rule-based features deliver increased productivity across all disciplines. The ability to share component information and to reuse design data between projects reduces man-hours and schedule time. Improved Quality 3D multi-discipline working environment improves communication between teams and facilitates “right-first-time” design. Clash checking, integrity checking and rule-based checking tools ensure higher quality designs and less work. Database driven drawing production achieves consistency between drawings, reports and design data. Reduced Schedule Times Reduced site work, concurrent multi-location engineering, higher design efficiency and higher quality all combine to reduce schedule time. Greater ability to react to major project changes, including the capability to change the project structure during project execution and to dynamically add in new locations or remove existing ones, all protect he project schedule. All these features lead to even more accurate, complete and clash free designs thereby ensuring reduced project costs.AVEVA PDMS delivers major innovations to our customers, ranging from improved productivity for individual designers through to increased overall project savings that result from significant improvements in data management and control.

Oil & Gas Network, February 2009 19

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CobraMax® stimulation service delivers increased production and efficiency in the Montney Halliburton Canada shale gas team lead By Eric Schmelzl ong horizontal sections and the maximum number of high-volume fracs per section are the keys to operators’ success in the Montney shale gas play. This lesson has been driven home since the first horizontal Montney well was drilled in 2005 and completed with Halliburton’s CobraMax® pinpoint stimulation service. On that first horizontal well, the CobraMax service fractured five intervals. The result: production 600 percent higher than the operator’s offset vertical well. Since then, with over 50 successful wells, the advantages of using the CobraMax service have become even more compelling for operators in the Montney. CobraMax technology is well suited for fracturing multiple-interval horizontal sections completed with unperforated, cemented casings. It perforates and fracs in the same trip, without using mechanical plugs that must be removed later. Instead, it uses gel/sand based plugs to isolate intervals, and these can be circulated out of the hole with the coiled tubing. And it uses a long-life bottomhole assembly that can perforate 22 sections before change-out. These features make CobraMax ideal for an environment that needs precise, high-volume fracs in minimum time.

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Wells stimulated with CobraMax service produce more gas Montney horizontal wells fractured using CobraMax service are out-producing wells stimulated in other ways by a substantial margin. In an area of about 3,000 square kilometers with homogeneous lithology, these wells averaged 40 percent more production in the first year when compared to other techniques. At current gas prices, that translates into about $4.6 million in additional production per well in the first year alone – results that are attracting attention from more operators every day.

The safety record of Halliburton’s CobraMax service crews in the Montney is also outstanding – there has not been a single recordable incident in 2008.

CobraMax treatment yields greater conductivity CobraMax service allows placement of very large concentrations of proppant, as much as 1500 kg/m3 vs. 800 kg/m3 for competitive treatments. This dense near-wellbore proppant pack creates superior conductivity, which is one of the primary sources of increased production from these treated wells. Higher proppant concentration also means less frac fluid pumped, and this means quicker, more effective clean-up.

CobraMax frac operations are fast and efficient Data from actual Montney CobraMax service jobs show nine zones fractured in 57 hours, from pumps-in to pumps-out; seven zones in 45 hours; and seven zones in 41 hours. Overall, experience shows an average of 6 hours per interval, compared to about 24 hours per interval from perf-and-plug techniques. These efficiency gains come from a combination of technology and the operational efficiency Halliburton has achieved through systematic crew training with the organization’s Montney playbook and the logistical support that keeps the equipment working 24 hours a day.

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CobraMax service reduces risk and lowers stimulation costs Perf-and-plug techniques run a high risk of premature plug setting, resulting in up to six days of NPT to remedy. Openhole packers also risk screenouts when combined with high proppant concentrations, which can result in significant cost and downtime.The CobraMax service reduces or entirely eliminates these risks. Its sand plug is reliably circulated out of the hole with the coiled tubing. Reliable performance without NPT is the key to the CobraMax service cost advantage over alternative technologies. The safety record of Halliburton’s CobraMax service crews in the Montney is also outstanding – there has not been a single recordable incident in 2008.

Fifty wells stimulated with CobraMax service help build reservoir understanding Shale gas plays are complex geological and technical challenges, and Montney is an especially difficult and heterogeneous basin. Halliburton’s CobraMax team now has the experience of stimulating over 50 Montney wells and has captured a significant amount of reservoir understanding. The team is also fortunate to be part of Halliburton’s continent-wide network of shale gas tech teams that share experiences and accelerate learning. Halliburton’s accumulated experience in other basins has contributed to the CobraMax service team’s success in the Montney.The combination of local experience and knowledge gained in shale plays all over North America enables the CobraMax service team to contribute to the well completion plan at a level beyond the stimulation process alone.

Montney horizontal wells benefit from an integrated solution The experience and reservoir understanding gained with by stimulating 50 wells with the CobraMax service is benefiting customers over the full well construction process. This experience has created the ability to link all well construction and completion services into a seamless, integrated process based on superior understanding. Montney horizontal wells are especially well suited to a holistic approach, and with the experience provided by the CobraMax service team, Halliburton customers will benefit in the Montney over the life of the field.

Oil & Gas Network, February 2009 21

Piping without Welding S-Hydro is the world’s leading supplier of non-welded piping technology – “Piping without Welding”. GS-Hydro has experience over 35 years of hydraulic systems and nonwelded connection technology. As a continuum of development work GS-Hydro brings now out the latest development of non-welded connection technology. GS-Hydro’s new innovative GS-HP Retain Ring™ pipe connecting method allows piping systems with workings pressures up to 400–420 bar to be assembled without welding. The GS-HP Retain Ring™ system provides fast and easy method to connect pipes with the highest possible quality and reliability, completely leak–free with high levels of joint integrity in the most efficient manner. GS-Hydro’s in-house developed GS-HP Retain Ring™ technology – continues the success of “Piping without Welding” technology and provides now even improved features with numerous benefits: • Proven, leak-free technology - which is simple, reliable and safe • Highest level of fatigue resistance • Intrinsically clean joint • Small space requirement • Easy and fast to install • No hot-work needed • Environmentally friendly

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Connection techno The GS-HP Retain Ring™ system provides compact, high pressure joint, in which the flanges are held to the pipe by a solid retain ring halves which are sitting in a machined groove on the pipe end.This new system has been subject for rigorous burst and impulse testing.The pipe ends are pressed against the seal/each other when tightening the screws. The HP-retain rings, flanges and screws absorb the axial forces and shocks. The combination of retain rings and flanges

strengthens the pipe (at the location of the groove) in such a manner that connection is stronger than the pipe itself! GS-Hydro provides various alternatives where new GS-HP Retain Ring™ system can be used. This flange system corresponds to ISO 6162-2 SAE J618 bore pattern (6000 psi) for nominal sizes 24–32 and ISO 6164 (350–400 bar) bore pattern for nominal sizes 40–48. • Pipe to pipe connections • Flange to port connections • Pipe to block connections • Hose fitting connections • Male / female thread connections • Welding hub connections (in the case of connecting to welded systems) • Reducer connections • Vibra- bulkhead connections The unique characteristics of the GS-HP Retain Ring™ connection The excellent sealing performance and very high mechanical strength of new HP-invention has been proven by external testing laboratories. New form of connection technology has unique resistance against external loads. GS-Hydro’s GS-HP Retain Ring™ connection is the right solution when the final customer application is using thick wall pipes (wt > 8 mm) , high working pressures (up to 400–420 bar) in the application where the pipe connections are under specific stress caused by external load, dynamic impulses and vibration. Because of freely rotating flange connection and self-centering sealing element, the GS-HP Retain Ring™ connection is easy to install and certainly leak proof.

Extensive testing completed Comprehensive fatigue strength test range accomplished by external test labs by using servo hydraulic test systems. All tests were made under load control and also using constant amplitude controlling. In each case the fatigue test was continued until at least 2 million cycles were reached. Using this approach it is apparent that the new HP-construction has superior mechanical characteristics under pulsating load and also in the case where the maximum working pressure (400–420 bar) occurs. Extensive testing has shown the suitability of the GS-HP Retain Ring™ System for high pressure piping systems in a wide range of different materials ranging from mild and stainless steel to duplex and titanium pipe materials with an elongation above 20%. Numerous Benefits to Customers Worldwide The GS-HP Retain Ring™ system can be used in a broad range of high pressure piping applications in a wide variety of industries ranging from offshore and marine to various industrial piping systems.The new retain ring system is suitable for various media e.g. high pressure hydraulic oil, lubricating oil, fuel oil, sea water and fresh water. Especially this new invention will provide benefits in the most demanding applications like with pipe and hose connections where hydraulic system and its components are effected by pulsating load, shocks and constant vibration. The GS-HP Retain Ring™ system provides a proven, reliable and leak-free piping solution. New design and improved characteristics lead to a minimised need for maintenance, repair or replacement of piping components. The new innovation is widely patented in several countries.

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Human Process Management Helps Oil and Gas Organizations Deal with Information Overload By Jacob Ukelson, D.Sc., chief technology officer of ActionBase tructured processes account for less than 20 percent of all work performed today in most organizations. The other 80 percent of work is completely tacit and therefore dynamic. Human Process Management (HPMS) focuses on the human side of business processes – managing the human interactions that take place as part of an implied, dynamic or unstructured business process where humans play the key role. The role of a Human Process Management Solutions (HPMS) are to help an organization effectively manage the 80 percent of business processes not handled by Business Process Management (BPM) or other automated systems (e.g. ERP). E.ON is a subsidiary of E.ON AG, the largest privately owned power and gas company in the world, active in markets across Europe, Russia and the U.S. The company needed a way to track all business critical actions in order to gain full control over audit and compliance management. This initiative supports E.ON’s corporate strategy of creating an integrated business and centralized corporate knowledgebase. E.ON generates and distributes electricity, and retails power and gas to millions of customers. E.ON needed an off-the-shelf action tracking solution that supported a collaborative approach to corporate accountability and responsibility for achieving operational excellence. ActionBase, a provider of HPMS, was deployed as a part of E.ON’s Action Tracking initiative in an effort to seamlessly integrate organizational processes within E.ON’s operations and regulations. Working in a complex environment in the oil and gas industry causes actions to come from many different cross organizational processes such as operations and regulations, internal and external audit reviews, HSE, incident management, etc. The HPMS integrated with Microsoft

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Office follows the audit trail on all assigned action items and creates a central repository for assigning, tracking and resolving all of E.ON’s actions. E.ON is using the HPMS as a way to focus on business processes when dealing with compliance and regulations. Businesses spend resources in making sure they are compliant with health, safety, environmental and financial regulations standards, procedures, directives and regulations. A HPMS is designed for the auditor, compliance officer, CFO and the process owners involved in the organizational process of adhering to industry standards or regulations. The HPMS enable managers to initiate and engage in human business processes that are usually handled through documents, Microsoft Excel check lists and e-mail correspondence. It provides managers with real-time status and full visibility over the whole process, optimizing resources and enhancing communication and collaboration with effective reporting, alerting and syndication. With a HPMS, managers and process owners have the process visibility needed to make informative decisions and react in time, not when it is too late. The organization gains a system of record for all of its business critical human processes, and can be driven by best practices and benchmarks for its human processes. Solutions like HPMS provide workplace software that understands human work patterns and supports the inherent spontaneity of human interaction. It does not focus on “straight-through” business processes, but rather on the way people really work - via interactions, which lead to commitments, which in turn lead to actions. The key to managing human processes is to harness those human interactions and give people the collaborative framework they need to interact and work on a process, but in a manageable way.

Canada Energy Partners Announces Commencement of Gas Sales From the First Commercial Coalbed anada Energy Partners Inc. has commencement of gas sales from eight wells on its 50,788acre Peace River Coalbed Methane Project Canada Energy owns a 50 per cent working interest in the Project and GeoMet, Inc. through its wholly-owned subsidiary Hudson’s Hope Gas, Ltd., owns the other 50 per cent and is the Operator. This significant achievement is the first commercial CBM project in British Columbia and is a result of eight years and more than $45 million cash invested by the Company and its partners into acquisition of lands, exploration and development. In conjunction with the announcement, Honourable Richard Neufeld, Minister of Energy, Mines and Petroleum Resources of British Columbia, commented: “I would like to congratulate you and your entire exploration and production team for reaching this significant milestone.This event signifies the first commercial production of coalbed gas in the Province of British Columbia and, as such, it is especially noteworthy. Unconventional gas development plays an important role in British Columbia’s future energy security. Investment in coalbed gas development and the realization of gas royalties and taxes from coalbed gas production and sales will help fuel the Province’s economy.The Ministry of Energy, Mines and Petroleum Resources acknowledges your accomplishment in coalbed gas development and looks forward to continuing to work with industry to allow the sector to succeed, while balancing economic and social priorities and protecting our environment and quality of life.” Ben Jones, Canada Energy President and Chief Executive Officer, commented: “After eight years of tremendous collaborative effort, it is a distinct pleasure to see this milestone achieved. I believe this project will be of a great value to our shareholders and will benefit the community, region and the Province of British Columbia. We look forward to its continuing development.” Darby Ser?, GeoMet President and Chief Executive Officer, commented: “We are excited to achieve the first coalbed methane gas deliveries in British Columbia.We expect to increase gas sales from the Peace River Project for many years as we continue the development of the project.” Canada Energy also holds a 50 per cent interest in the gas treating and compression facilities installed on the Project. The facilities are scalable and modular and can be expanded with an increasing production base. The Company believes that in addition to the processing of the CBM these mid-stream facilities will be strategic in the commercialization of the Moosebar Shale, the Montney Shale, and other deeper formations. Exploration programs on Moosebar Shale and Montney/Doig formations are currently underway on the lands covered by the Project. The current eight wells on production represent the first phase of a scalable project with 315 potential well locations (based on 160 acre spacing). The Company expects to have an updated independent reserve report including the recent activities completed on the CBM Project later this February 2009. The 2009 CBM development program will be finalized with the joint venture partner in Q1 2009 and the Company anticipates an additional multi-well production drilling program to start in July 2009.

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geoLOGIC buys Calgary-based Whitehot Innovations, adds QFind Document Management module to geoSCOUT sers of geoSCOUT, the cutting-edge, easy-to-use E&P decision support system from geoLOGIC systems ltd., will soon be able to augment their mapping and analysis capabilities with point-and-click access to all relevant, available documentation for oil and gas properties – without ever having to leave the map they are viewing. Under an agreement announced this past month, geoLOGIC systems ltd. has purchased the assets of Whitehot Innovations Corporation. The purchase includes all proprietary technology and surrounding assets. Four Whitehot staff, including company president Lori Adams, have already made the transition to geoLOGIC and are working on the team responsible for the integration of Whitehot’s QFind Document Management asset with geoLOGIC’s signature product, geoSCOUT. Ms. Adams has some 20 years of industry experience, including 10 years in management roles and extensive

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experience in new product line development. In 2001, she joined Rapid Technology to oversee product development and large-scale technology projects specifically in oil and gas. Ms. Adams was instrumental in the building and subsequent sale of Rapid Technology’s RapiDataTM product. She started Whitehot Innovations in 2007 after purchasing the newly commercial QFind asset from Rapid Technology. “The completion of this purchase is a vision realized for me, and for the Whitehot team,” said Ms. Adams. “QFind’s smart indexing allows it to sift through any available documentation more accurately and quickly so you only get the most relevant documentation. But the real power comes in the fact that you will be able to access all this information directly through a map within geoSCOUT. The implications for efficiency and workflow enhancement are tremendous.” With many industry experts predicting a rise in M&A activity in Canada, geoLOGIC sees the acquisition of Whitehot and the addition of QFind functionality to geoSCOUT as an opportunity to help companies address the challenge of keeping up with documentation, as well as merging existing documentation from different sources. “Recent reports have indicated that Canadian oil and gas assets are already the most actively traded in the world,” said geoLOGIC President David Hood. “So it is more important than ever that oil and gas companies are able to easily and intuitively make use of the data that is available to them. As much as we can, we are trying to offer our customers cost-effective choices that support enhanced workflows. The addition of the QFind module to geoSCOUT will allow us to offer document management capabilities that are fully integrated into their enterprise-wide decision support tool.”

North Rig Catwalk Technologies Ltd. “The Power Catwalk People” s of November 24, 2008, North Rig Catwalk Technologies Ltd. is the proud owner of the Power Catwalk designs of Hunterwood Technologies Ltd. Former General Manager and Vice President of Hunterwood, Adrian Prudden, is the principal of the new catwalk company. North Rig will continue to build on the strong fifteen year reputation of Hunterwood by providing first class power catwalks (pipe handling equipment) to the Oil & Gas Industry. North Rig Power Catwalks differ significantly in three distinct areas from most other catwalks being built today. • The open belly design of North Rig’s catwalks allows the catwalk to move over existing well heads as the rig moves from hole to hole on location. Expensive, time consuming teardown/set-up of the catwalk, separate from the rig, is unnecessary. • Built into the V-door is a lift-up system (patent pending) for optimal pipe presentation to the drilling floor. Available on the C22 and the C26, the hydraulic lift extends up from the V-door, bringing the pipe to a comfortable working height as predetermined by the operator and programmed into the PLC for convenient remote operation. • The self contained power pack houses an electric motor and hydraulic pump combination which makes up the “Hydraulic Load Sense System”, unique to very few manufacturers. This system allows the hydraulic system to run in a low pressure mode, saving power, until a demand is sensed and the system kicks into high gear to accomplish the task at hand.

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North Rig will provide their clients with the ultimate in safety and performance designed systems to achieve production targets in a competitive market. All products are designed using 3D CAD modelling systems and are manufactured with the highest production standards.

Schlumberger Opens Technology Center in Calgary Facility to focus on efficient heavy oil recovery in Alberta and Alaska chlumberger has inaugurated a new oilfield technology center in Calgary, Alberta. The state-of-the-art center will work directly with oilfield technical teams and regional research facilities to help customers increase heavy oil production, reduce technical risk and minimize environmental footprint. The Heavy Oil Regional Technology Center (RTC) will provide a working environment where clients can work hand-in-hand with Schlumberger geoscientists and petroleum engineers to solve key technical challenges associated with heavy oil recovery. These research projects include, but are not limited to, innovative geological and geophysical services, advanced well placement strategies, new formation evaluation and characterization techniques, and novel integrated completions and monitoring programs. “The Heavy Oil RTC will act as a focal point for scientific and technological advancement in Canada by communicating regional customer needs to the worldwide research and development organization of Schlumberger,” said Ken Havlinek, RTC center manager, Schlumberger. “Client-specific problems can be fast-tracked to the right global experts, and solutions developed within a framework of local, integrated knowledge of heavy oil exploration and production processes.” The Heavy Oil center features a 3D visualization center, a high-performance computing cluster, a multi-use conference

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center, and an interactive collaboration space designed to accommodate locally based scientists and engineers as well as short- and long-term visiting experts and clients. This is the seventh Schlumberger RTC to open and the second to focus on heavy oil. Located around the world,

Brochures for Oil and Gas Drilling Operations Now Available from Automation Products Group utomation Products Group, Inc. (APG) has available a brochure on Sensor Solutions for Oil and Gas Drilling Operations, including mud pressure, mud tank level, liquid level sensing, general purpose monitoring and pressure calibration equipment. The brochure reviews potential oil and gas sensing solutions, including APG’s HU intrinsically safe Hammer Union pressure transmitter, PT-400 pressure sensor, PT-500 hydrostatic pressure level transmitter, PG-7 digital pressure gauge, LPU-2428 ultrasonic level sensor, LPU-2127 ultrasonic sensor, KA Kari cable suspended f loat switch, PC-10K hydraulic pressure comparator/calibrator and the RPM resistive chain level sensor. The depth and breadth of APG’s sensing solutions enables them to provide an unbiased technology recommendation in oil and gas applications. www.apgsensors.com .

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Schlumberger RTCs specialize in addressing key issues in the drilling and production industry such as unconventional gas, gas condensates, carbonates and sub-basalt imaging. For further information about the Schlumberger commitment to heavy oil, please visit www.heavyoilinfo.com.

CygNet Invests for Growth as Oil & Gas Industry Demands Software to Increase Operational Efficiency Company Expands U.S. Headquarters; Opens Calgary Office ygNet Software www.cygnetscada.com, a leading provider of enterprise operations software and solutions for the oil and gas industry, has announced it has expanded the size of its headquarters in San Luis Obispo, Calif. and opened a new office in Calgary, Alberta, Canada. The company’s growth includes the recent commissioning of CygNet software on an additional 6,000 miles of gas pipeline operated by CygNet clients and a more than 30 percent increase in employee headcount during the past year. This expansion is a direct result of strong demand for its enterprise operations software, which drives market responsiveness and operational efficiency. As energy companies face mounting pressure to maintain profit profiles in a volatile market environment, they have increased their focus on investments in improving operational efficiency and productivity. “The momentum that CygNet experienced during better economic times has only accelerated as the oil and gas industry struggles with recessionary forces,” said Chris Smith, president and CEO, CygNet Software.“The ability to collect, manage and distribute large volumes of vital real-time production and contract information across the entire enterprise means our customers are able to work more efficiently and accomplish more with fewer resources. By investing in the most talented technologists, engineers and professional services experts, we will ensure the continued delivery of breakthrough solutions that help our customers increase their competitiveness despite the tighter environment.” CygNet’s new Calgary office is located at 525 Eleventh Avenue SW, Suite 410 in Calgary, Alberta, Canada. The sales and professional services personnel at the new facility will support CygNet’s installed base and its targeted areas of growth.

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SMU Professor Got It Right: Pulling Geothermal Energy from Oil and Gas Wells hen Ormat Technologies recently demonstrated how it is generating geothermal energy from a producing oil well in Wyoming, the company had Southern Methodist University geothermal expert Dr. David Blackwell to thank for it. Blackwell and fellow SMU researcher Jason McKenna published a paper in Sept. 2005 proposing that the hot water gushing as a byproduct from many oil and gas wells could be harnessed to produce electricity. Pass the nuisance hot water through a small, specially designed binary power plant, he wrote, and producers ought to be able to generate enough electricity to draw oil and gas to the surface – nearly for free. Hook up a field full of these special geothermal mini-plants, he concluded, and geothermal energy would produce enough electricity to light up nearby homes, business and schools. “Blackwell’s work to identify the potential of co-production from oil and gas wells dramatically expands the scope and potential of geothermal energy in the US and around the world, said Karl Gawell, executive director of the Geothermal Energy Association.“It is important for decision makers to understand that geothermal energy is an enormous resource with widespread potential to help address our environmental and national security needs. Dr. Blackwell has been instrumental in delivering that message.” Most people associate geothermal energy with extremely high heat – think geysers. But the Geothermal Map of North America produced by Blackwell and SMU researcher Maria Richards for the American Association of Petroleum Geologists in 2004 revealed locations all over the United States where subsurface temperatures are high enough to drive a small, binary power plant and generate electricity. This kind of power plant is similar to an air conditioning unit run backwards, using heat to generate electricity. The hot water that runs through one chamber in the pump heats fluid with a lower boiling point in an adjacent chamber, which expands into high-pressure vapor and drives a turbine. Blackwell’s “light bulb” moment came when he realized that oil and gas wells all over the country were spewing moderately hot wastewater, but petroleum company executives were unaware of the resource they were pumping back into the ground. Deep drilling through hard rock is expensive: that’s one reason traditional geothermal energy development has lagged behind green technologies like wind and solar power. But Blackwell’s mapping has proven that many existing oil and gas wells in Texas, Louisiana, Mississippi, Alabama and some mid-continent states reach shallower depths where temperatures still range from 200-300 degrees Fahrenheit. That’s hot enough for a binary power plant to do its job. “This was just a flash of light,” Blackwell says. “It seemed to me it ought to work.” Blackwell is not trying to convince anyone that piggybacking geothermal pumps onto existing oil and gas wells is the answer to all of America’s energy needs. But the technology could generate enough electricity to power as many as 4.5 million homes, and make it possible for petroleum producers to continue pumping low-producing wells that the high cost of purchased electricity might otherwise force them to shut down. “What is important about this work is its sense of vision of what is possible from geothermal energy,” Gawell said.

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Control Microsystems Announces the SCADAPack 330E and 334E Controllers ontrol Microsystems, global developer of advanced SCADA products, has announced the release of the SCADAPack 330E and 334E, two exciting additions to the SCADAPack family of telemetry and control devices. These cost-effective controllers are based on the popular SCADAPack 330/334 hardware platform and address the growing demand for secure and authenticated data. The SCADAPack 330E and 334E provide multi-vendor interoperability and reliable communications through native DNP3 and IEC 60870-5. Data integrity for billable applications or critical operations is supported with AGA12 encryption. “The popularity of E-Series features has driven the growth of the product line”, said Dale Symington, VP Product Strategy. “DNP3 and IEC 60870-5 allow the slave controller to store a time-stamped event whenever data points change and continuous recording means there are never holes in the data, even when communication links go down.” The E-Series controllers support a full-featured FAT32 (PC compatible) file system and command line, which is accessible over FTP, Telnet, DNP3 or local serial port. The command line provides direct access to the file system and configuration commands. An IEC 61131-3 programming environment provides support for two logic applications running simultaneously. This allows system integrators to introduce password-protected applications that offer value-added functionality in their chosen industry, all while leaving the second application open for the end-user to add custom control if required.

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Experion Process Knowledge System R310 oneywell’s Experion® Process Knowledge System (PKS) R310 is an enhanced version of Honeywell’s award-winning process automation and control system that improves safety by allowing plant operators to carefully coordinate process control, safety shutdown and fire and gas mitigation steps. Through the unique safety instrumented system (SIS) integration, Experion provides crucial safety and fire and gas information, such as pre-shutdown alerts, directly to operators. Operators can easily access plant-wide SIS point data, diagnostics and system information, as well as alarms and events, operator displays and sequence-of-event information. It also decreases overall system and maintenance costs by reducing the amount of installed field sensor equipment. Additionally, Experion R310 helps improve plant operations through embedded simulation capabilities used for training operators and validating controls, displays and procedures.The system feeds data from critical plant subsystems directly to operators to help improve decision making in the control room. The system also includes new integrated batch functionality that can significantly increase production as well as reliability for chemical and life sciences companies. The embedded batch functionality allows chemical and life sciences customers to execute batches at the control level, versus using a separate server, which makes the system more reliable, less complex and easier to maintain. Another key capability of Experion is a unique alarm shelving utility that allows operators to better manage and prioritize alarms on their displays.This capability is based on several years of collaboration between Honeywell and the Abnormal Situation Management® consortium in the interest of improving operator effectiveness during abnormal situations that can lead to process upsets. Experion R310 more easily integrates with simulation tools and safety systems. It features data exchange and control

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UOP Master Simulation Models he UOP Master Simulation Models are an exclusive series of UOP process technology-based operator training systems (OTS) delivered through Honeywell’s UniSim® family of process modeling and simulation technology. The UOP Master Simulation Models contain embedded UOP mathematics and kinetics in the UniSim framework, so the simulation environment is as close to real-life refining operations as you can possibly get. UniSim improves plant safety and efficiency by allowing manufacturers to design and test processes before they are implemented in their plants, as well as train operators to use those processes and reduce errors that could lead to plant incidents. Because the UOP Master Simulation Models have the UOP intellectual property embedded in the software, they are as close as a plant operator can possibly get to a reallife refining operation. The UOP Master Simulation Models are based upon UOP’s proprietary process design package which includes engineering specifications for the process streams, equipment, reactors and instrumentation. They are a high fidelity representation of UOP’s process design. While they are not customized to the customer’s actual production capacity and tag naming conventions, the general process configuration and operating conditions are similar to the customer’s actual installation.

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communication protocol that allow safety engineers to design and build plant-wide safety strategies while providing plant operators with crucial system information. Experion R310 is the most efficient system of its kind, and that efficiency translates to safer, more reliable and more profitable plants. Experion R310 provides crucial safety information directly to operators using a common display. Experion R310 continues to deliver on Honeywell’s commitment to enhance safety by minimizing the impact of incidents, keeping plants online longer and reducing the total cost of ownership. For more information about Honeywell’s Experion solution, visit http://hpsweb.honeywell.com/Cultures/en-US/Products /Systems/ExperionPKS/default.htm.

OneWireless oneywell’s updated version of its OneWireless™ industrial wireless network equipment is designed to be compatible with the end-user driven ISA100.11a industrial wireless communication standard. The latest OneWireless release is the process industries’ first mesh network with ISA100-ready hardware. The network can be easily upgraded to the ISA100.11a standard, when it is completed, through an over-the-air software update.

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Manufacturers have been asking for a secure and reliable multi-functional wireless network that can handle the thousands of devices they use within their plants. Until now, the only way to do so was with proprietary systems. The ISA100.11a standard will allow OneWireless users to achieve this vision using a standards-based network. The new version also extends Honeywell’s product line of transmitters with a new XYR™ 6000 Digital Input wireless transmitter. OneWireless supports a broad range of both wired and wireless transmitters, including corrosion, gauge pressure, differential pressure, high-level analog input and temperature transmitters. As a single network supporting both sensors and IEEE 802.11-based applications, OneWireless also supports mobile worker devices, such as Honeywell’s IntelaTrac PKS and Experion Mobile Station, and can improve plant safety by helping customers quickly locate employees. In addition, the latest OneWireless release expands the interface capabilities of the system, supporting the HART protocol. HART is commonly used by asset management applications such as Honeywell’s Field Device Manager. OneWireless system management software makes any XYR 6000 transmitter communicate to existing HART-enabled applications in the same manner as to a wired HART device.This continuous evolution of the OneWireless platform highlights the multi-protocol capabilities of the Honeywell system. For more information about Honeywell’s OneWireless solution, visit http://hpsweb.honeywell.com/Cultures/en-US/ Products/wireless/default.htm.

The regulatory control and safety systems integrated with the process model are based upon UOP’s standard control strategies. The control package is used to interface the trainee with the plant simulation through the operator station graphics, trends and alarm configurations. UniSim has proven an effective tool for improving operator performance, which ultimately leads to a more efficient workforce and better business results. Because it captures UOP’s extensive process knowledge within UniSim, the UOP Master Simulation Models provide an even more realistic simulation environment. Manufacturers from a wide range of industries use UniSim to train operators before new process units are commissioned, or before new processes are implemented in existing plants. Operators also practice start-up and shutdown sequences for plant processes and learn how to sustain unit operation at peak performance levels.The results include safer and more efficient operation and less unplanned downtime. For more information about Honeywell’s UOP Master Simulation Models solution, visit http://hpsweb. honeywell.com/Cultures/enUS/Products/ControlApplications /simulation/default.htm. Oil & Gas Network, February 2009 29

Safety Manager oneywell’s Safety Manager helps lower the cost of safety and improves plant performance by reducing the risk of safety incidents, maximizing production up-time, reducing the cost of compliance, and providing productivity tools that help you manage safety in your plant. The latest version of Safety Manager, integrated with Honeywell’s Experion® Process Knowledge System (PKS), allows safety and process controllers to directly communicate with each other without depending on intermediate interfaces such as PCs, and without compromising operations security or data integrity. Safety Manager aligns a plant’s goals for increased safety, reliability and maximum operability with proven solutions that integrate process safety data, applications, system diagnostics and critical control strategies.As a component of Experion PKS, Safety Manager features tight integration with Experion alarm and events capabilities for smooth plant operation and easy post-mortem analysis with a single window access on the Experion human machine interface (HMI). In sharing critical information between Safety Manager and the Experion C300 process controller, the system can provide plant-wide SIS point data, diagnostics and system information, as well as alarms and events, operator displays and sequence of event information to any Experion station located in a plant. This integration allows plants to improve production by minimizing intervention and shutdowns, and recover more easily from process upsets. It also reduces hardware and installation costs. Additionally, operators are not required to learn different systems for process control and SIS.

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Safety Manager is designed for a wide range of industries including hydrocarbon processing, bulk and fine chemicals, oil and gas, and energy production. The solution helps improve process-safeguarding practices such as process and emergency shutdowns, equipment protection, fire and gas monitoring and critical control. Built on the proven Quadruple Modular Redundant (QMR®) technology, Safety Manager is Honeywell’s next generation safety system platform. QMR is a diagnostic-based technology that enhances system flexibility, increases diagnostic messaging capabilities and improves system fault tolerance for critical applications. For more information about Honeywell’s Safety Manager solution, visit http://hpsweb.honeywell.com/Cultures/en-US/ Products/Systems/SafetySystems/SafetyManager/default.htm

A LAWSUIT WAS FILED BY FISHER CONTROLS INTERNATIONAL LLC IN THE UNITED STATES DISTRICT COURT FOR THE OUTHERN DISTRICT OF IOWA AGAINST DYNAFLO CONTROL VALVE SERVICES, LTD., AND AMICABLY SETTLED. As part of the settlement, Dyna-Flo has removed the DF1 and DF2400 Control Valves from the marketplace in view of Fisher’s United States Patents Nos. 4,986,300, 5,791,629, 6,866,244, 6,991,218, and 7,185,672. Dyna-Flo acknowledges the validity, and does not contest its infringement, of these patents.

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directory of advertisers ABB Inc. www.abb.com/oilandgas ASCOValve Canada www.asco.ca Axia NetMedia Corporation

North Rig Catwalk Technologies www.northrig.com Oil Patch Challenge www.maplejt.com/opc

Baker Hughes Canada

PETROLEUM HUMAN RESOURCES COUNCIL OF CANADA

www.bakerhughes.com

www.petrohrsc.ca

Camoplast Track Vehicles

R & M Energy Systems

www.camoplast.com

www.rmenergy.com

Dyna-Flo Control Valve

Rogers Wireless

Services Ltd.

www.rogers.com

www.dyna-flo.com

Singletouch Canada Inc

Flexpipe Systems

www.singletouch.com

www.flexpipesystems.com

SMi Group

FLIR Systems Ltd.

www.smi-online.co.uk

www.flir.ca

Telus Business Solutions

Halliburton Energy Services

www.telus.com

www.halliburton.com

Volant Products

ICOM Canada

www.volantproducts.ca

www.icomcanada.com

Wainbee

Inmarsat

www.wainbee.com

www.inmarsat.com/oilgas

Wellstream Canada Limited

INNOVENG

www.wellstream.com

www.INNOVENG.com

West Coast Resorts

Langara Fishing Adventures

www.westcoastresort.com

www.langara.com

Wood Group ESP, Inc.

Mattracks Inc.

www.woodgroup-esp.com

www.axia.com

www.mattracks.com

Uniformance Process Studio oneywell’s Uniformance Process Studio is a desktop software package that allows plant engineers to improve overall plant efficiency by more easily analyzing process performance. The user-friendly interface includes workflow management applications that enable engineers to build trend graphs and graphics with minimal training or manual configuration. Uniformance Process Studio is designed for use with Honeywell’s Uniformance Plant History Database, which gathers critical data from equipment and instrumentation located throughout a plant. In the event of a plant upset, for instance, users can pull historical data to examine how a certain unit functioned in the moments leading up to the incident and use that information to avoid future upsets. For engineers, using Uniformance Process Studio for trend analysis is as easy as selecting tags from additional information management systems and using a drag-anddrop function to insert them into a trend graph or table. Many commonly used options, such as selecting trend times and sampling methods, are also available through simple drop-down menus. Uniformance Process Studio also provides a variety of trend styles. A multi-trend view allows engineers to view the status of numerous trends, making it easy to monitor the status of several processes or pieces of equipment at once. The Uniformance desktop includes powerful graphics based on Honeywell’s HMIWeb technology. Such graphics may be used to review current operating conditions

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or users may scroll back in time to view historical process conditions. The HMIWeb graphics builder comes with a comprehensive graphics library. Existing graphics may also be copied and converted from a Honeywell’s Experion® system, saving the cost of building special graphics for engineers and other business data users. Uniformance Process Studio increases overall plant efficiency by making the engineer’s job easier. Uniformance allows users to organize information in personal and shared workspaces, making it easier for users to find relevant process trend information.These workspaces are not limited to plant historian information; users can include Web page links, applications and a variety of documents. With this approach, engineers aren’t required to constantly switch between Uniformance and Internet browsers. Having a keen understanding of how a plant has performed in the past is critical to maximizing business results and improving safety, reliability and efficiency. Uniformance Process Studio was designed to help engineers make sense of relevant data faster and easier. Engineers can perform basic functions with only a few mouse clicks so that their time is spent analyzing the process, not manipulating the tool. For more information about Honeywell’s Uniformance Process Studio solution, visit http://hpsweb. honeywell. com/Cultures/enUS/Products/OperationsApplications/I nformationManagement/UniformanceProcessStudio/d efault.htm.