NEWS

1

Engineering and Business News from Fekete Associates Inc. Spring 2008

35 Years of Technical Excellence - p1 | Acid Gas Injection and Geological Storage of CO2 - p2-3 | Update on Fekete Software Interoperability - p4INSIDE THIS ISSUE

4

Fekete Associates Inc. | Phone: 403.213.4200 | Toll Free: 1.800.625.2488 | Fax: 403.213.4298 | Email: fast@fekete.com | Website: fekete.com

 

Celebrating 35 Years of Technical Excellence

AU

THO

R Kevin Dunn is the Manager of Technical Sales at Fekete

About two years ago, I had a discussion with our sales manager, and a senior engineer. The topic could be summed up as follows, “What is the one thing we need to do to make our software better?” That discussion has always stayed with me, because it was the first time the concept of interoperability was really vocalized and stressed as a priority in software development. Since Fekete thrives on technology and innovation, we are always thinking about the next big technical “nut” to crack for our software developers. Truthfully, our developers have also quietly been working towards interoperability for years; but it was not until that discussion that I realized just how important it is.

Why is interoperability so important? Simply put, it increases the ease and efficiency with which our software may be applied by our users. Let me give you an example: Let’s say you are using F.A.S.T. RTA™ to analyze the production data for a well that has continuous surveillance. When the well is periodically

shut-in, build-up data is collected as part of the surveillance. Interoperability means that you can use F.A.S.T WellTest™ to analyze the build-ups in the same data-file without having to re-enter the same input parameters or reload data. That example represents just the beginning (and indeed, F.A.S.T. RTA™ and F.A.S.T. WellTest™ can already share data that way). The long-term goal of our software developers is to achieve full interoperability among all our software. The two main categories of interoperability are as follows:

Sharing and exchanging of common data among programs: our developers have designed a common data model for all of our software called an “interchange,” which ensures that all of our programs can access and write data to a common location, using consistent rules.

Developing and using common interface components within our programs: some examples of these are common GIS / mapping (look for this in the next release of F.A.S.T. Piper™), common ASCII import (look for this in the current versions of F.A.S.T RTA™ and F.A.S.T CBM™) and common Wellbore Tool (coming soon).

Look for more interoperability in future versions of Fekete software.

1.

2.

SPE ATCE ANAHEIM NOVEMBER 11- 14, 2007

to ensure that we are providing the best value to our clients.

Looking to the FutureIn the past, you have challenged us — we have responded. As a result, Fekete is built on a solid foundation of technical excellence and service. We ask that you continue to challenge us and we will, with your support, continue to serve you and meet your needs. Together, we will grow and succeed. We have a healthy mix of experienced personnel and young staff. We continuously encourage the young’ns to adopt and improve our formula for success. We’re excited about what the future holds at Fekete. We are continuously adding new staff to meet the demands for engineering/geological projects and software products.

Going GreenWe are reducing the amount of paper products we use. If you would like to receive this newsletter electronically, just send us an e-mail(fast@fekete.com) and we will provide future editions in PDF format to your e-mail inbox. In addition, we now complete paperless software transactions; for more information, talk to your software account manager, the next time you license software.

An Update on Fekete Software Interoperability

To receive an electronic copy of Fekete’s newsletter, please contact us at fast@fekete.com

This year, we at Fekete are celebrating 35 years of service to the oil and gas industry. Thank you for challenging us, supporting us, and working beside us for so many years!

Founded in 1973, Fekete has grown to become a leader in the industry in reservoir engineering and software. Our success can be attributed to our staff’s commitment to operate from our core values.

Value #1 – Technical ExcellenceWhatever we do is done to the highest technical standards. Our morning training “boot-camps” start at 6:45AM. They are tailored to our staff’s varied experience levels, from basic concepts in reservoir engineering, through to advanced analysis and modeling theory. This, together with our senior staff mentoring new employees, ensures the technical excellence that we are committed to.

Value #2 – Taking Care of Our ClientsWe value the relationships we have with each of our clients, and this means getting your project done to your satisfaction, on time, and on budget. It is common to see staff working through a weekend to get a project completed on short timelines, or putting extra effort into a report to ensure you understand

the results of the work we have done. We are committed to doing anything we can to support our clients.

Value #3 – Taking Care of Our StaffWe treat our staff as family. Many team- building events, and family-oriented activities take place every year, often organized by the Fekete Social Club, to nurture the “family” atmosphere that each Fekete employee is a part of. Last year, we modified our work schedule to a 4 ½ day work week, to give our staff more time to spend with family and friends.

Value #4 – Entrepreneurial SpiritWe encourage every one in the company to find ways to expand the services we provide, develop new products, or find a more efficient way to complete a project. This represents how Fekete has grown from two people in 1973 to 150 engineers, geologists, technologists and support staff today. Someone took on a challenge, found a solution and built a new service or product to offer to our clients.

Value #5 – EfficiencyOur success in business is built on providing cost-efficient solutions for our clients. We are always looking for ways to improve our efficiency and resources,

We’re Hiring!Are you a talented individual looking for an exciting new career path? Would you like the opportunity to work on a wide variety of challenging and interesting projects? Does working with world-renowned industry leaders and being a part of a dynamic team of dedicated people interest you? If you answer yes to these questions, then you may be the person we are looking for.

Fekete gives you the flexibility to create your own career and opportunities are only limited by your ability, motivation and imagination. We encourage all our staff to engage in life-long learning and we assist them in their professional development through mentoring by senior staff. We believe corporate culture plays a large role in job satisfaction and have worked hard to create an atmosphere where everyone feels welcome. We have many more reasons why Fekete is a great place to work and we believe our staff say it best!

Fekete continues to grow! We currently have openings for programmers, engineers, technologists, geologists and technical sales. Go to the career section of our website to apply.

Casey O’Shea – Project Engineer“The main things are the people, technical excellence, project diversity, travel opportunities, and very open opportunities for growth.”

Margaret Laffin – Junior Programmer“It’s amazing how well we are treated and how fun of an environment it is.”

Lisa Dean – Manager of Geology“Projects are varied and each day is different. It is fast-paced, new and exciting, and you get a chance to see the world. It is an extremely dynamic and integrated company to work for.”

AU

THO

R

David Anderson is the Lead Technical Advisor at Fekete

Acid Gas Injection and Geological Storage of CO2 Acid Gas Injection and Geological Storage of CO2

3

AUTH

ORS

2

studies show that, as the gas front becomes more diffuse (as opposed sharp), there is increased separation of H2S from the gas stream, and the difference between the H2S and CO2 breakthrough times increases.

Effect of Water SaturationThe chromatographic separation is more significant in the case of injection of impure CO2 in aquifers (water saturation=100%). To illustrate the effect of increased water saturation, a simulation was conducted where the water saturation in the Long Coulee reservoir was increased by 10%. The results indicate that the higher saturation of the aqueous phase led to a delay in the breakthrough of both components. While CO2 breakthrough was delayed by about six months, the H2S breakthrough was delayed by more than one year. It is expected that a 100% aqueous saturation would have led to an even longer delay.

CO2 capture and storage in geological formations is considered to be one of the practical options for reducing “Green House Gas” emissions. A number of operators in Alberta have implemented injection into depleted gas and oil pools, as a means of disposal and storage of acid gas. In the risk assessment of geological sequestration of CO2, it is important to understand the characteristics of the injected fluid and its mixing with and displacement of in-situ fluids.

Given the interest in CO2 geological storage and acid gas disposal, Natural Resource Canada (NRCan) provided funding to the Energy Resources Conservation Board (ERCB) to study, in collaboration with Fekete Associates Inc., five acid gas injection sites in Alberta. Our study of the Long Coulee Glauconite F pool in southeast Alberta, where acid gas broke through at the producing wells, has recently been completed, and some of its findings are reported in this article.

The operator of this reservoir, where acid gas (98% CO2 and 2% H2S) has been injected since 2002, reported that breakthrough of the H2S in the producing wells occurred after the breakthrough of CO2. In geological storage, the separation of H2S from CO2 is of importance, because leakage of the more dangerous H2S component may occur long after CO2 has been detected.

Detailed laboratory flow experiments that confirmed delayed breakthrough of H2S as compared with CO2 were performed by Hycal Energy Research Laboratories Ltd. In our study, we numerically modeled these experiments, and conducted a detailed reservoir characterization and simulation of the Long Coulee acid gas injection operation. In this article, we review the reservoir simulation study, with special emphasis on the issue of the separation of H2S from CO2 as the acid gas flows through the reservoir.

HistoryThe gas cap of this reservoir that produces from the Upper Mannville Glauconite was discovered in 1967, and the much smaller oil leg in 1984. At peak production, there were eight gas and six oil wells producing. By the end of 2006, the pool had produced nearly 1.9x109 m3 (68 Bcf) of gas and 139x103 m3 (875 MSTB) of oil. At the time of the start of acid gas injection in 2002, the reservoir pressure had declined from an initial value of 13,000 kPa (1,900 psi) to 1,000 kPa (150 psi). Breakthrough of acid gas at the producing wells was observed between 2003 and 2005.

Static CharacterizationA detailed geological study was conducted to generate maps of reservoir structure, gross and net pay, porosity, permeability and water saturation. The reservoir is characterized by high permeability sands of 10s to 100s of mD, porosity of 12 to 22% (average 18%), net pay thickness of up to 6 m, and average water saturation of 20%. The native gas is characterized by a gravity of 0.75 with up to 20% CO2 and trace amounts of H2S.

Reservoir Simulation and Sensitivity StudiesSome adjustment to the porosity and permeability, especially in the oil zone was necessary to match the historical pool performance. Figure 1 below shows a comparison between simulated (solid line) and historical values (open symbols) of gas, oil and acid gas production volumes and reservoir pressure.

Figure 2 shows the simulated spread of the injected gas. The results clearly indicate significant spread of the acid gas and breakthrough in a number of producing wells. This is illustrated in Figure 3, where the streamlines originating from the two injectors in the middle of the reservoir have broken through at a gas producing well in the bottom right corner and two of the oil producing wells (the other producing gas wells to the north of the injectors have already been shut-in because of excessive acid gas production). Results in Figures 2 and 3 indicate that by 2007, when the injected acid gas is equivalent to only 9% of the original-gas-in-place (OGIP), most of the gas cap is contaminated by the injected acid gas and breakthrough has occurred in all producing wells.

Differential Solubility of H2S and CO2

Experiments were conducted at Hycal to characterize the solubility of the CO2 and H2S in the formation brine. The results showed that the solubility of H2S is roughly two times that of CO2 at reservoir conditions. The solubility experiments were then modeled using the Peng-Robinson equation of state and incorporated through

the use of Henry’s law in the CMG compositional simulator, GEM. The in-situ and injected fluids including the formation brine were modeled using six pseudo-components.

Chromatographic Separation of H2S and CO2

The difference in the solubility of H2S and CO2 in water gives rise to chromatographic separation of these two components as they advance in the reservoir, thereby causing these gases to breakthrough at different times. Figure 4 shows a comparison between the measured and simulated CO2 and H2S concentration in the separator gas at the 06-23 well. The results show that H2S breakthrough occurred about one year after CO2 breakthrough (2006 vs. 2005). A similar effect is observed in other producing wells.

To better understand the separation between H2S and CO2, Figure 5 shows the calculated concentration profiles of H2S and CO2 in the reservoir at two different times. These profiles demonstrate that, at the displacement front, CO2 advances faster than H2S due to the preferential solubility of H2S over CO2, so that less and less H2S remains in the advancing gas front. Furthermore, the results show that the separation between the CO2 and H2S fronts becomes wider as the gas sees more reservoir water and more of its H2S component is preferentially dissolved. A number of sensitivity

AU

THO

R

Mehran Pooladi-Darvish, Ph.D., P.Eng., is a Senior Technical Advisor at Fekete

Figure 2: Simulated distribution of injected gas in the Long Coulee Glauconite F pool on 01.07.2007

Figure 3: Simulated acid gas flow streamlines in the Long Coulee Glauconite F pool on 01.07.2007

0

0.2

0.4

0.6

0.8

1

2003-03 2003-09 2004-03 2004-09 2005-04 2005-10 2006-04 2006-10 2007-04 2007-10

DateC

O2

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Fra

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on

0

0.001

0.002

0.003

0.004

H2

S M

ole

Fra

ctio

n

Simulated - CO2

Measured - CO2

Simulated H2s

Measured H2S

H2S breakthrough: Jan 2006

CO2 breakthrough: Jan 2005

Figure 4: Breakthrough of CO2 (top) and of H2S (bottom) in well 06-23

0

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0 400 800 1200 1600 2000

Distance from the injector (m)

CO

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0.008

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0.016

0.020

H2S

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le Fractio

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Jan  2005

CO2

H2S

CO2

H2S

Jan  2003

Figure 5: Composition of H2S and CO2 in the gaseous phase versus distance from well 09-25 at two different times.

Figure 1: Comparison of the historical data and simulation results (counter clockwise from top left: gas production, oil production, acid gas production and reservoir pressure)

SummaryIn the acid gas injection reservoir of this study, H2S breakthrough in some producing wells occurred approximately one year after the breakthrough of CO2.

Solubility measurements showed that H2S solubility in the aqueous phase is more than twice that of CO2.

Simulation studies indicated that the H2S is preferentially stripped by the formation water, resulting in a CO2 gas front that moves (and break-through) ahead of the H2S.

The observed time difference (one year) between the CO2 and H2S breakthrough was successfully simulated.

Sensitivity studies showed that with a higher aqueous saturation (such as that in aquifers), the delay in H2S breakthrough would be increased. This is of significance, particularly for monitoring of impure CO2 storage in deep saline aquifers, where the impurity may consist of H2S.

This study illustrates that injection of acid gas in depleted reservoirs can be modeled successfully, including the chromatographic separation of H2S and CO2, and that the appearance of CO2 at monitoring wells precedes the subsequent arrival of H2S.

•

•

•

•

•

•

AcknowledgementsWe acknowledge the contribution of Dr. Bachu (AGS), Ms. Hong, Ms. Theys, and Dr. Stocker (all of Fekete), Dr. Dashtgard (Simon Fraser University), and Mr. Alan (Conoco-Philips).

CO2

CO2

H2S

H2S

Acid Gas Injection and Geological Storage of CO2 Acid Gas Injection and Geological Storage of CO2

3

AUTH

ORS

2

studies show that, as the gas front becomes more diffuse (as opposed sharp), there is increased separation of H2S from the gas stream, and the difference between the H2S and CO2 breakthrough times increases.

Effect of Water SaturationThe chromatographic separation is more significant in the case of injection of impure CO2 in aquifers (water saturation=100%). To illustrate the effect of increased water saturation, a simulation was conducted where the water saturation in the Long Coulee reservoir was increased by 10%. The results indicate that the higher saturation of the aqueous phase led to a delay in the breakthrough of both components. While CO2 breakthrough was delayed by about six months, the H2S breakthrough was delayed by more than one year. It is expected that a 100% aqueous saturation would have led to an even longer delay.

CO2 capture and storage in geological formations is considered to be one of the practical options for reducing “Green House Gas” emissions. A number of operators in Alberta have implemented injection into depleted gas and oil pools, as a means of disposal and storage of acid gas. In the risk assessment of geological sequestration of CO2, it is important to understand the characteristics of the injected fluid and its mixing with and displacement of in-situ fluids.

Given the interest in CO2 geological storage and acid gas disposal, Natural Resource Canada (NRCan) provided funding to the Energy Resources Conservation Board (ERCB) to study, in collaboration with Fekete Associates Inc., five acid gas injection sites in Alberta. Our study of the Long Coulee Glauconite F pool in southeast Alberta, where acid gas broke through at the producing wells, has recently been completed, and some of its findings are reported in this article.

The operator of this reservoir, where acid gas (98% CO2 and 2% H2S) has been injected since 2002, reported that breakthrough of the H2S in the producing wells occurred after the breakthrough of CO2. In geological storage, the separation of H2S from CO2 is of importance, because leakage of the more dangerous H2S component may occur long after CO2 has been detected.

Detailed laboratory flow experiments that confirmed delayed breakthrough of H2S as compared with CO2 were performed by Hycal Energy Research Laboratories Ltd. In our study, we numerically modeled these experiments, and conducted a detailed reservoir characterization and simulation of the Long Coulee acid gas injection operation. In this article, we review the reservoir simulation study, with special emphasis on the issue of the separation of H2S from CO2 as the acid gas flows through the reservoir.

HistoryThe gas cap of this reservoir that produces from the Upper Mannville Glauconite was discovered in 1967, and the much smaller oil leg in 1984. At peak production, there were eight gas and six oil wells producing. By the end of 2006, the pool had produced nearly 1.9x109 m3 (68 Bcf) of gas and 139x103 m3 (875 MSTB) of oil. At the time of the start of acid gas injection in 2002, the reservoir pressure had declined from an initial value of 13,000 kPa (1,900 psi) to 1,000 kPa (150 psi). Breakthrough of acid gas at the producing wells was observed between 2003 and 2005.

Static CharacterizationA detailed geological study was conducted to generate maps of reservoir structure, gross and net pay, porosity, permeability and water saturation. The reservoir is characterized by high permeability sands of 10s to 100s of mD, porosity of 12 to 22% (average 18%), net pay thickness of up to 6 m, and average water saturation of 20%. The native gas is characterized by a gravity of 0.75 with up to 20% CO2 and trace amounts of H2S.

Reservoir Simulation and Sensitivity StudiesSome adjustment to the porosity and permeability, especially in the oil zone was necessary to match the historical pool performance. Figure 1 below shows a comparison between simulated (solid line) and historical values (open symbols) of gas, oil and acid gas production volumes and reservoir pressure.

Figure 2 shows the simulated spread of the injected gas. The results clearly indicate significant spread of the acid gas and breakthrough in a number of producing wells. This is illustrated in Figure 3, where the streamlines originating from the two injectors in the middle of the reservoir have broken through at a gas producing well in the bottom right corner and two of the oil producing wells (the other producing gas wells to the north of the injectors have already been shut-in because of excessive acid gas production). Results in Figures 2 and 3 indicate that by 2007, when the injected acid gas is equivalent to only 9% of the original-gas-in-place (OGIP), most of the gas cap is contaminated by the injected acid gas and breakthrough has occurred in all producing wells.

Differential Solubility of H2S and CO2

Experiments were conducted at Hycal to characterize the solubility of the CO2 and H2S in the formation brine. The results showed that the solubility of H2S is roughly two times that of CO2 at reservoir conditions. The solubility experiments were then modeled using the Peng-Robinson equation of state and incorporated through

the use of Henry’s law in the CMG compositional simulator, GEM. The in-situ and injected fluids including the formation brine were modeled using six pseudo-components.

Chromatographic Separation of H2S and CO2

The difference in the solubility of H2S and CO2 in water gives rise to chromatographic separation of these two components as they advance in the reservoir, thereby causing these gases to breakthrough at different times. Figure 4 shows a comparison between the measured and simulated CO2 and H2S concentration in the separator gas at the 06-23 well. The results show that H2S breakthrough occurred about one year after CO2 breakthrough (2006 vs. 2005). A similar effect is observed in other producing wells.

To better understand the separation between H2S and CO2, Figure 5 shows the calculated concentration profiles of H2S and CO2 in the reservoir at two different times. These profiles demonstrate that, at the displacement front, CO2 advances faster than H2S due to the preferential solubility of H2S over CO2, so that less and less H2S remains in the advancing gas front. Furthermore, the results show that the separation between the CO2 and H2S fronts becomes wider as the gas sees more reservoir water and more of its H2S component is preferentially dissolved. A number of sensitivity

AU

THO

R

Mehran Pooladi-Darvish, Ph.D., P.Eng., is a Senior Technical Advisor at Fekete

Figure 2: Simulated distribution of injected gas in the Long Coulee Glauconite F pool on 01.07.2007

Figure 3: Simulated acid gas flow streamlines in the Long Coulee Glauconite F pool on 01.07.2007

0

0.2

0.4

0.6

0.8

1

2003-03 2003-09 2004-03 2004-09 2005-04 2005-10 2006-04 2006-10 2007-04 2007-10

Date

CO

2

Mo

le F

ra

cti

on

0

0.001

0.002

0.003

0.004

H2

S M

ole

Fra

ctio

n

Simulated - CO2

Measured - CO2

Simulated H2s

Measured H2S

H2S breakthrough: Jan 2006

CO2 breakthrough: Jan 2005

Figure 4: Breakthrough of CO2 (top) and of H2S (bottom) in well 06-23

0

0.2

0.4

0.6

0.8

1

0 400 800 1200 1600 2000

Distance from the injector (m)

CO

2 M

ole

 Fra

ctio

n

0.000

0.004

0.008

0.012

0.016

0.020

H2S

 Mo

le Fractio

n

Jan  2005

CO2

H2S

CO2

H2S

Jan  2003

Figure 5: Composition of H2S and CO2 in the gaseous phase versus distance from well 09-25 at two different times.

Figure 1: Comparison of the historical data and simulation results (counter clockwise from top left: gas production, oil production, acid gas production and reservoir pressure)

SummaryIn the acid gas injection reservoir of this study, H2S breakthrough in some producing wells occurred approximately one year after the breakthrough of CO2.

Solubility measurements showed that H2S solubility in the aqueous phase is more than twice that of CO2.

Simulation studies indicated that the H2S is preferentially stripped by the formation water, resulting in a CO2 gas front that moves (and break-through) ahead of the H2S.

The observed time difference (one year) between the CO2 and H2S breakthrough was successfully simulated.

Sensitivity studies showed that with a higher aqueous saturation (such as that in aquifers), the delay in H2S breakthrough would be increased. This is of significance, particularly for monitoring of impure CO2 storage in deep saline aquifers, where the impurity may consist of H2S.

This study illustrates that injection of acid gas in depleted reservoirs can be modeled successfully, including the chromatographic separation of H2S and CO2, and that the appearance of CO2 at monitoring wells precedes the subsequent arrival of H2S.

•

•

•

•

•

•

AcknowledgementsWe acknowledge the contribution of Dr. Bachu (AGS), Ms. Hong, Ms. Theys, and Dr. Stocker (all of Fekete), Dr. Dashtgard (Simon Fraser University), and Mr. Alan (Conoco-Philips).

CO2

CO2

H2S

H2S

NEWS

1

Engineering and Business News from Fekete Associates Inc. Spring 2008

35 Years of Technical Excellence - p1 | Acid Gas Injection and Geological Storage of CO2 - p2-3 | Update on Fekete Software Interoperability - p4INSIDE THIS ISSUE

4

Fekete Associates Inc. | Phone: 403.213.4200 | Toll Free: 1.800.625.2488 | Fax: 403.213.4298 | Email: fast@fekete.com | Website: fekete.com

 

Celebrating 35 Years of Technical Excellence

AU

THO

R Kevin Dunn is the Manager of Technical Sales at Fekete

About two years ago, I had a discussion with our sales manager, and a senior engineer. The topic could be summed up as follows, “What is the one thing we need to do to make our software better?” That discussion has always stayed with me, because it was the first time the concept of interoperability was really vocalized and stressed as a priority in software development. Since Fekete thrives on technology and innovation, we are always thinking about the next big technical “nut” to crack for our software developers. Truthfully, our developers have also quietly been working towards interoperability for years; but it was not until that discussion that I realized just how important it is.

Why is interoperability so important? Simply put, it increases the ease and efficiency with which our software may be applied by our users. Let me give you an example: Let’s say you are using F.A.S.T. RTA™ to analyze the production data for a well that has continuous surveillance. When the well is periodically

shut-in, build-up data is collected as part of the surveillance. Interoperability means that you can use F.A.S.T WellTest™ to analyze the build-ups in the same data-file without having to re-enter the same input parameters or reload data. That example represents just the beginning (and indeed, F.A.S.T. RTA™ and F.A.S.T. WellTest™ can already share data that way). The long-term goal of our software developers is to achieve full interoperability among all our software. The two main categories of interoperability are as follows:

Sharing and exchanging of common data among programs: our developers have designed a common data model for all of our software called an “interchange,” which ensures that all of our programs can access and write data to a common location, using consistent rules.

Developing and using common interface components within our programs: some examples of these are common GIS / mapping (look for this in the next release of F.A.S.T. Piper™), common ASCII import (look for this in the current versions of F.A.S.T RTA™ and F.A.S.T CBM™) and common Wellbore Tool (coming soon).

Look for more interoperability in future versions of Fekete software.

1.

2.

SPE ATCE ANAHEIM NOVEMBER 11- 14, 2007

to ensure that we are providing the best value to our clients.

Looking to the FutureIn the past, you have challenged us — we have responded. As a result, Fekete is built on a solid foundation of technical excellence and service. We ask that you continue to challenge us and we will, with your support, continue to serve you and meet your needs. Together, we will grow and succeed. We have a healthy mix of experienced personnel and young staff. We continuously encourage the young’ns to adopt and improve our formula for success. We’re excited about what the future holds at Fekete. We are continuously adding new staff to meet the demands for engineering/geological projects and software products.

Going GreenWe are reducing the amount of paper products we use. If you would like to receive this newsletter electronically, just send us an e-mail(fast@fekete.com) and we will provide future editions in PDF format to your e-mail inbox. In addition, we now complete paperless software transactions; for more information, talk to your software account manager, the next time you license software.

An Update on Fekete Software Interoperability

To receive an electronic copy of Fekete’s newsletter, please contact us at fast@fekete.com

This year, we at Fekete are celebrating 35 years of service to the oil and gas industry. Thank you for challenging us, supporting us, and working beside us for so many years!

Founded in 1973, Fekete has grown to become a leader in the industry in reservoir engineering and software. Our success can be attributed to our staff’s commitment to operate from our core values.

Value #1 – Technical ExcellenceWhatever we do is done to the highest technical standards. Our morning training “boot-camps” start at 6:45AM. They are tailored to our staff’s varied experience levels, from basic concepts in reservoir engineering, through to advanced analysis and modeling theory. This, together with our senior staff mentoring new employees, ensures the technical excellence that we are committed to.

Value #2 – Taking Care of Our ClientsWe value the relationships we have with each of our clients, and this means getting your project done to your satisfaction, on time, and on budget. It is common to see staff working through a weekend to get a project completed on short timelines, or putting extra effort into a report to ensure you understand

the results of the work we have done. We are committed to doing anything we can to support our clients.

Value #3 – Taking Care of Our StaffWe treat our staff as family. Many team- building events, and family-oriented activities take place every year, often organized by the Fekete Social Club, to nurture the “family” atmosphere that each Fekete employee is a part of. Last year, we modified our work schedule to a 4 ½ day work week, to give our staff more time to spend with family and friends.

Value #4 – Entrepreneurial SpiritWe encourage every one in the company to find ways to expand the services we provide, develop new products, or find a more efficient way to complete a project. This represents how Fekete has grown from two people in 1973 to 150 engineers, geologists, technologists and support staff today. Someone took on a challenge, found a solution and built a new service or product to offer to our clients.

Value #5 – EfficiencyOur success in business is built on providing cost-efficient solutions for our clients. We are always looking for ways to improve our efficiency and resources,

We’re Hiring!Are you a talented individual looking for an exciting new career path? Would you like the opportunity to work on a wide variety of challenging and interesting projects? Does working with world-renowned industry leaders and being a part of a dynamic team of dedicated people interest you? If you answer yes to these questions, then you may be the person we are looking for.

Fekete gives you the flexibility to create your own career and opportunities are only limited by your ability, motivation and imagination. We encourage all our staff to engage in life-long learning and we assist them in their professional development through mentoring by senior staff. We believe corporate culture plays a large role in job satisfaction and have worked hard to create an atmosphere where everyone feels welcome. We have many more reasons why Fekete is a great place to work and we believe our staff say it best!

Fekete continues to grow! We currently have openings for programmers, engineers, technologists, geologists and technical sales. Go to the career section of our website to apply.

Casey O’Shea – Project Engineer“The main things are the people, technical excellence, project diversity, travel opportunities, and very open opportunities for growth.”

Margaret Laffin – Junior Programmer“It’s amazing how well we are treated and how fun of an environment it is.”

Lisa Dean – Manager of Geology“Projects are varied and each day is different. It is fast-paced, new and exciting, and you get a chance to see the world. It is an extremely dynamic and integrated company to work for.”

AU

THO

R

David Anderson is the Lead Technical Advisor at Fekete