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The Play: The Sahara

Under Western Skies
by Cheryl Hudak

More than a hundred years after the Land Run, Oklahoma’s Cherokee Strip continues to present new opportunities to people with a pioneering spirit. Today Chesapeake’s land, geology, drilling and production teams are bringing those opportunities to the surface.

Northwestern Oklahoma looks like the backdrop of a John Wayne movie, with endless skies and a terrain punctuated by ancient rock formations. A closer look, however, reveals state-of-the-art drilling rigs among the mesas. The plains are dotted with white Chesapeake storage tanks marking the locations of more than 2,000 natural gas wells that produce approximately 230 million cubic feet of natural gas equivalent per day (mmcfe/d).

The company entered the vast Sahara Play in 1998, when it acquired Hugoton Energy Corporation and DLB Energy, Inc., and valuable acreage in Woods, Woodward, Major, Alfalfa and Blaine counties. Despite the fact that the region had been a strong gas producer for decades, Chesapeake geologists believed it still held untapped potential. They reasoned that earlier developers who drilled primarily in the Tonkawa, Cottage Grove Sands and uppermost part of the Chester Lime between 6,000 and 7,000 feet deep, lacked a full understanding of the Chester's reservoir characteristics, drainage patterns and pay intervals.

Chesapeake started with two rigs and ramped up the pace as they encountered good results. Today the company is the dominant player in the region, employing 11 rigs, 10 of which are owned by Nomac, Chesapeake’s drilling subsidiary.

“This play worked in 1998, with natural gas selling for about $2 per thousand cubic feet (mcfe), because drilling costs were about $300,000 per well,” said David Craycraft, Northwest Oklahoma District Manager. “Today it still works, with natural gas selling for almost $10 and drilling costs about $800,000 to $900,000 per well.”

White Chesapeake storage tanks
mark the locations of more than
2,000 natural gas wells in the area.

Sahara is called an “unconventional” play because the natural gas is distributed throughout the rock rather than occurring in discrete traps as in a conventional play. Sahara had also been considered fully developed before Chesapeake recognized its potential.

Infill drilling has been a key to unlocking that potential. In 1998, the area had spacing of one well per section (640 acres). Since then, the company proved to the Oklahoma Corporation Commission that full development would require tighter well spacing and increased density authority. Today, there are as many as 16 wells per section. Most of those are 7,000- to 8,000-foot vertical wells completed in the Chester and Mississippi formations.

“You could say the Chester is our bread and butter formation,” Craycraft said. “It is a tight, highly stratified formation that contains individual reservoirs with low porosity and low permeability. The deeper you drill in Sahara, the more unconventional it is. Sahara is also unconventional in the kind of thought processes required to evaluate and tap its potential.”

Chesapeake was among the first companies in Sahara to use slick-water fracturing, which combines water with a friction-reducing additive that allows the water to be pumped faster into the formation. Water fracs do not require the use of polymers to thicken them, and the amount of proppant (sand-like particles forced into the fractures to prop open the breaks) used is significantly less than that of gels.  Slick-water fracs help control costs while opening different pay intervals, allowing more gas to migrate to the wellbore.

Chesapeake production crews claim it’s more than a full-time job,
bringing up natural gas in Sahara. Tail lights glow as a pumper is
up before the sun to travel country roads.

Since 2006, Chesapeake has deployed several drilling rigs to develop unconventional dewatering plays in the Hunton and Simpson Dolomite formations. These natural gas plays contain significant water and at one time would have been considered uneconomical due to the cost of removing the water. Today, horizontal drilling technology enables dewatering plays to produce greater quantities of gas relative to the amount of water produced, which makes them economic.

“Even with a long history of drilling and production, something new and different often pops up in this area,” said Bob Campbell, Geoscience Manager – Sahara. “Inevitably, these surprises encourage us – a formation we expected to produce performs better than anticipated, or we encounter a gas-producing formation we didn’t expect at all.”

Many of these surprises are revealed by the extensive use of 3-D seismic, which helps find new formations as well as the “sweet spots” of known formations. The effective use of seismic data has played an important role in the company’s success in Sahara, where drillers have encountered only four or five dry holes in a 1,400-well drilling program.

“Management supports us in shooting many large-scale seismic surveys here,” Campbell continued. “Our geological team also benefits from the help of the employees in Chesapeake’s Waynoka and Kingfisher field offices,” he said. “They’re top notch.”

A drilling rig runs 24/7, with two crews working 12-hour
shifts to bring in a well within deadline.

As in every area where it operates, Chesapeake is conscientious about protecting the unique high plains environment of Sahara Play. The company purchases surface water from landowners for fracing activities and disposes of wastewater by injecting it into disposal wells drilled about 9,000 feet deep into the Arbuckle formation – more than 8,000 feet deeper than usable water sources in the region.

“There’s plenty of gas left out here to find,” Campbell said of northwestern Oklahoma. And with some 800,000 acres of leasehold in the area, Chesapeake’s exploration and production teams believe there is room for further growth beneath the western skies.

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The Play: Barnett Shale

Big Town in the Barnett

Sophisticated drilling techniques invigorate the economy while maintaining the unique urban environment of Fort Worth

Natural gas occurs deep beneath the earth’s surface, regardless of whether the ground above is empty or the center of a bustling metropolis.

Today, almost 80% of Americans live in towns or cities with populations exceeding 2,500. Each of those communities provides an environment for the people who live there, and most people cherish the place where they dwell. Whether it is a quiet, tree-lined suburb or a fast-paced, heart-of-the-city street, it’s home.

Because some of the nation’s most important natural gas resources lie beneath urban settings, the concept of environmentally friendly operations is no longer limited to nature preserves or national parks. Today, the commitment to environmentally friendly exploration and production methods in urban areas is of paramount importance, because the environments they protect are the environments of people’s lives.

The metropolitan area of Fort Worth, Texas, is a prime example.

Neither an inning of baseball nor a round of golf was
lost when Chesapeake drilled at Hidden Creek Golf
Course in the Fort Worth suburb of Burleson, Texas.
Today the site contains a Chesapeake natural gas
well behind a screen of landscaping.

Citizens of this sprawling, historic city play golf at Hidden Creek in suburban Burleson while their offspring practice in one of the four adjacent baseball diamonds. They jog the shady paths of Trinity Trails. They are passionate about their city and consider it the quintessential American hometown.

Located in the heart of the Barnett Shale, the nation’s largest gas field, Fort Worth and its rapidly expanding suburbs are home to an estimated 3 million people. Beneath their homes and workplaces lie an estimated 50 trillion cubic feet of natural gas – enough energy to supply all the gas-heated homes in the nation for more than five years.

A report of The Perryman Group projects that the Barnett Shale’s economic output will generate over $10 billion through 2015. It will create more than 108,000 permanent jobs, put millions of dollars in royalty payments into the hands of mineral rights owners and provide a significant new source of funding for municipal and environmental improvements throughout the area.

Chesapeake is committed to bringing up that Barnett Shale natural gas in the most unobtrusive manner possible, lessening its environmental footprint by using the newest drilling and completion technologies, the most advanced noise control systems and the most stringent safety and quality controls ever seen in the exploration and production industry.

All operators in the Barnett Shale are regulated by the Texas Railroad Commission as well as by city ordinances when drilling in city limits, and are monitored by the Texas Commission on Environmental Quality, but Chesapeake goes the extra mile to ensure the quality of life in urban Fort Worth. The company’s expertise in horizontal drilling techniques allows wells to be situated at a distance from dwellings and businesses. Electrically powered rigs and sound-baffling equipment are employed to maintain noise at appropriate levels. Gas gathering pipelines, similar to the utility pipelines that deliver gas to homes, are installed within strict standards and pose no elevated safety risks.

The company goes above and beyond to treat essential greenspace and groundwater resources with the utmost care, and whenever possible, to leave every site in better condition than it was found.

Chesapeake’s innovative drilling and production techniques are providing a solution for the nation’s growing demands for more and cleaner energy – while maintaining the unique urban environment of Fort Worth, America’s hometown.

Trinity Trails

Joe Piazza

One example of Chesapeake’s environmental commitment can be seen at an area near Trinity Trails. Although the site’s previous owners planned to clear its trees to build an office park, there was vocal concern when Chesapeake bought the property to produce natural gas. During the drilling process, the company reduced the size of the pad from a planned five acres to 1.4 acres to maximize canopy coverage, planted an additional 268 trees and installed irrigation to guarantee a greener outcome than the office park planned by the property’s previous owners would have given.

“As long as they’re planting other trees and keeping the environment here – with the price of fuel, it’d be a good idea to tap into those resources,” said runner Joe Piazza, who along with other Fort Worth inhabitants still enjoys his exercise along Trinity Trails.

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The Play: The Technology

Finding the sweet spot
by Cheryl Hudak

One of the most valuable items in the natural gas toolbox is a unique method of exploration geophysics called 3-D reflection seismology. In the past 20 years, seismic vibrations have shaken up the natural gas industry, changed the exploration paradigm and opened new doors of opportunity to aggressive, unconventional operators like Cheseapeake Energy.

3-D seismic helps geoscientists explore layers of rock formations beneath the earth’s surface, seeking out structural traps that could contain hydrocarbons. By its most common definition, seismic data is a road map that leads explorers to the “sweet spot” which holds the highest potential for finding natural gas. Equally important, it helps avoid subsurface hazards and has greatly reduced the risk of drilling dry holes.

The 18-foot-wide stereo screen in Chesapeake’s
3-D Seismic Visualization room turns scientific
information into a giant virtual game board for
geoscientists.

Chesapeake’s 250-person geoscience team uses continually improving seismic data gathering systems and superior data interpretation skills to help the company attain an impressive 98% drilling success rate.

“The company is widely recognized as the nation’s most active driller for natural gas, with more than twice as many active rigs as the second company on that list,” said Larry Lunardi, Vice President – Geophysics, “But Chesapeake is even more weighted seismically, with 3-D seismic data covering more than 19 million acres – three to four times the seismic inventory of our closest competitor.

“That is extremely important to our success,” Lunardi said.  “Because almost every time we look at a 3-D map of the earth, we discover something we did not expect – sometimes something we never dreamed was there. That’s pretty amazing.”

Vibrator trucks shoot sound waves deep into the earth.

Chesapeake has budgeted more than $300 million for seismic data in 2008. Most of this data will be acquired as proprietary 3-D surveys. “That means we pay for the survey and we have exclusive use of the findings,” Lunardi explained.  “About 90% of our proprietary surveys are on properties that have never been shot before. Occasionally, we resurvey over an area where seismic was done some time ago. The difference is the improvement in technology.

“Today’s high-resolution seismic is much better defined and easier to interpret. It’s like the difference between conventional and high-definition television. Now we actually refer to some of our data as HD because its pixilation is analagous to that of HD-TV.”

3-D glasses enable scientists like Kurt
Schrantz, Senior Geophysicist, to envision
geologic formations miles below the surface.

Those high-definition images can be viewed most effectively in the company’s 3-D Seismic Visualization Room. In this unique facility, 3-D stereo eyeglasses turn natural science into what resembles a video gamer’s paradise on 18-foot-wide stereo screens: fault lines come to life, underground formations float like space stations, intersected by yellow poles representing possible drilling sites. It looks likes a virtual game board for natural gas exploration.

For anyone who might consider wildcatting a game, the ante is high. 3-D seismic helps even the odds.

“It tells us where to poke the $7 million hole,” Lunardi said with a smile.

The technology will continue to evolve. In some of the company’s earlier surveys, recordings were made using 400 channels of six geophones each.

“Nowadays we have 4,000 to 5,000 channels. Instead of a narrow swath of phones, we have an active patch 12 miles long and four to five miles wide. There is a huge difference in what you can see,” he added. “In the early days of 3-D, each pixel was equal to one seismic trace and we might have 30,000 to 40,000 traces in a square mile. Now we are recording more than a million traces in a square mile.”

Today’s seismic survey is not only more detailed than its predecessors, it is far more expensive. Terrain is a factor in the cost. In the wide-open spaces of West Texas and Oklahoma, where vibrator trucks can be hauled in to produce sound waves, costs are less than in locations with rough or mountainous terrain such as Appalachia, where shothole drilling equipment must be transported entirely by helicopter.

“We make surveys as large as possible because it’s more economical to survey per square mile,” said Lunardi. “Our average survey today is about 200 square miles. The per-unit cost is better with larger surveys, and you have a greater opportunity to find things you really didn’t know were there.”

Properly interpreted, such information is a roadmap to success in the natural gas exploration industry.

There is no doubt that 3-D seismic technology has enabled the company to create value in some of the nation’s hottest unconventional natural gas plays like the Barnett Shale of North Texas and the Fayetteville Shale in Arkansas.

Now the 3-D seismic road map is again expanding, as Chesapeake recently revealed important new unconventional natural gas discoveries in the Haynesville Shale of Lousiana and the Marcellus and Lower Huron Shales in Kentucky, West Virginia, Pennsylvania and New York.

How does seismic work?

Sound waves are shot deep into the earth by the use of vibrator trucks (vibroseis) or explosives. Magnetic recorders then note the length of time it takes for those waves to reflect back up to geophone receivers on the surface. This data is processed by specialized computer software, resulting in 2-D seismic profiles that can be interpreted to provide a cross section of the rock layers that form the earth’s crust.

Today, most seismic surveys use a two-dimensional arrangement of geophones and a two-dimensional grid of energy sources. This results in a three-dimensional image of the geology being surveyed – and it is called 3-D seismic.

History of seismic

Early seismic equipment was often mounted
on the bed of a pickup truck, such as this
one in the 1920s.

The concept of seismic is not new – Ludger Mintrop, a German mine surveyor, first proposed seismological methods for exploration and received a patent in 1916.  The following year, a Canadian inventor named Reginald Fessenden was working on methods of detecting submarines during World War I, and he filed patents on a method to use reflected seismic waves to infer geology.

In 1920, John Clarence Karcher incorporated the Geological Engineering Company in Oklahoma, after he and colleagues from the University of Oklahoma came up with the idea that sound reflections Karcher had used to detect artillery might aid in hydrocarbon exploration. This technique was, in fact, originally referred to as the “Oklahoma” method for acquiring 2-D reflection seismic data.

After many decades of refinement, the use of seismology, which became more commonplace in the 1990s, is a prerequisite for the development of unconventional natural gas plays.

Heliportable seismic in Appalachia

Hovering over an imaginary grid, a
helicopter prepares to lower a shothole
drill over a seismic survey area in
Appalachia.

The rugged terrain of the Appalachian Basin makes it difficult to transport and position vibrator trucks to conduct seismic surveys. Steep mountain ridges and deep hollows provide uneven purchase for vibroseis trucks. In many forest areas, there are no roads to bring heavy equipment through the dense woods.

For two years, Chesapeake has literally risen above these problems by using heliportable equipment when it conducts seismic surveys in the challenging West Virginia environments.

“Because of the mountain terrain here, this is an environmentally friendlier way to accomplish seismic data gathering,” said B.J. Carney, Senior Geophysicist – Appalachia. “It leaves a smaller footprint because we don’t cut roads or haul in heavy trucks or equipment. Instead, we surgically drop drills between the trees with no loss or damage. There is no long-term effect on wildlife or farm animals.”

Heliportable seismic works this way:

First, a small shothole drilling rig is delivered by helicopter, attached to the end of a 160-foot cable. The 12- by 4-foot drill is carefully lowered into position and untethered from the hovering helicopter. 

Second, a 20- to 40-foot bore is drilled and a small charge of explosives is set in the borehole. The helicopter then picks up the drill and moves it to the next drilling position. This is repeated until the area being surveyed is filled with a grid-like pattern of charge-filled bores – often 50 per square mile.

Next, a grid of geophone receivers is set over the entire survey area to record the reflection of sound waves. Fourth, radio signals trigger the explosive charges deep in the earth, to create the sound waves required for measurement.

“From this point, the process is the same as using vibroseis,” said Carney. “It is a very expensive process – about four times the cost of conventional seismic. Chesapeake is willing to push the edge of the envelope, taking more risk for higher rewards.  And here in the Eastern Division, that is starting to pay off.”

 

Shaking things up, six years ago 3-D seismic
indicated the Buffalo Creek 1-17 might be a
success. To date, the well has produced more
than 50 billion cubic feet of natural gas.

A Success Story: Wildcatting at Buffalo Creek

The story of the Buffalo Creek 1-17 in Beckham County, Oklahoma, is a love song to seismic. Located in an area with no proven production, Chesapeake had access to nonproprietary seismic that indicated the location might have hydrocarbon potential. The well, spud May 14, 2002, was drilled to more than 21,000 feet in the Springer formation. Buffalo Creek 1-17 came out strong – at 45 million cubic feet per day (mmcf/d). Six years later, it is still producing 10 mmcf/d, with total production thus far of 51 billion cubic feet (bcf), one of the highest revenue-generating wells in the state’s history.

“One of the highlights of my career was being given the opportunity to design the completion of the Buffalo Creek 1-17,” said Michael Park, District Manager – Anadarko. “The Buffalo Creek 1-17 has just become one of 11 elite Oklahoma gas wells to have surpassed the 50 bcf production mark – and the only Springer well in Oklahoma to have done so.”

Park gives credit for the well’s success to many team members such as Richard Green, Geology Manager – Anadarko, and Geophysicist Tom Sharp – as well as to the availability of seismic data.

The company recently finished drilling a 22,000-foot wildcat near the location, using proprietary seismic from a new survey they fondly call “East Buffalo Creek.”

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The Play: The Company

Chesapeake Energy Named to the 2008

FORTUNE 100 Best Companies to Work For® List

Chesapeake’s unconventional strategies extend beyond its drilling techniques in the field to all aspects of the company’s operations, resulting in high job satisfaction among its 6,400 employees. The company was recently recognized by FORTUNE magazine as one of the 100 best companies to work for in the nation.

The company debuted at number 61 on the 2008 list, which is determined in large part from responses given in the most extensive employee survey in corporate America. Nearly 100,000 employees from 446 different companies were polled by the Great Place to Work Institute, and asked to rate their companies’ management credibility, job satisfaction and camaraderie. Rankings are also based on the company’s responses to the Institute’s Culture Audit, which evaluates pay and benefit programs, as well as hiring practices, management philosophy, methods of internal communications, training, recognition programs and diversity efforts.

“It’s a tremendous honor to make the list,” said Martha Burger, Senior Vice President – Human and Corporate Resources. “It’s exciting to know that we’ve created an environment that fosters community and employee development and has been recognized as a top place to work in the U.S.”

Julie Barron, Data Analyst, and McClendon share a
high five at the company’s celebration party.

An important part of being a great company to work for is community involvement. In 2007, Chesapeake contributed and committed more than $20 million to support a host of educational initiatives and nonprofit organizations involved in community development and preserving the environment. Employees took the company’s commitment a step further, volunteering their time and talents to a broad range of activities from building homes for Habitat for Humanity to running in Relay for Life.

Chesapeake Chairman and CEO Aubrey McClendon called the company’s inclusion in the FORTUNE list a great achievement.

“As we continue to grow, being one of the best workplaces also helps Chesapeake attract and retain a quality work force, which can be a challenge in the competitive energy industry. We place a premium on creating a challenging and rewarding work environment where our employees can excel.”

A different kind of company

Chesapeake prides itself on having a creative and progressive culture. As noted in FORTUNE, the company provides “unusual perks” for employees, which vary by location to include scuba-diving lessons, cooking classes, movie screenings and company time to tutor at local elementary schools.

“We continually evaluate and determine which benefits matter to our employees and how these benefits provide a better work-life balance,” said Martha Burger. “Satisfied, happy employees produce better work and improve the company’s bottom line.”

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The Play: South Texas

Gas Machine on the Rio Grande

Zapata County, Texas, is full of surprises. One of those surprises is the fact that this remote region is the number one natural gas producing county in the state, quite a feat in a state so rich in hydrocarbon resources. Last year, Zapata County’s 3,600 producing gas wells brought up more than 314 billion cubic feet of natural gas.

Chesapeake entered South Texas in 2003, acquiring operations from Laredo Energy and Legend Energy in Zapata County focused on the Wilcox Lobo trend, a highly compartmentalized formation riddled with faults. This overpressured, low-permeability sandstone formation is far from exhausted despite a long history of natural gas production.

In 2006 the company acquired additional assets in the Vicksburg play in nearby Hidalgo County from Sierra Resources – which as the state’s fifth-highest natural gas producing county presents another significant opportunity.

“Although the first commercial wells were drilled in South Texas in the 1920s, there is still strong upside potential to this region,” said Tim Newville, District Manager – Gulf Coast. “It is not necessarily the ultimate recovery of the wells that is so attractive,” he explained. “It is the high initial production that makes for a fast return on our investment.”

A bright orange marker indicates future
drilling at this multiwell pad in Zapata,
Texas.

Today, the company operates 450 wells in the South Texas region, producing approximately 150 million cubic feet equivalent (mmcfe) net per day.  Chesapeake has been Zapata county’s number one producing operator for the past two years, with more than 60 billion cubic feet equivalent (bcfe) of production in 2006 and 52 bcfe in 2007.

A six-rig drilling program is developing additional resources from the Wilcox Lobo, the Deep Wilcox and the Vicksburg trends.  Considered a conventional play, most of the wells are drilled vertically or directionally to a depth of 11,000 – 12,000 feet.  Improved fracture stimulation techniques play a role in maintaining the area’s strong production rates.

This year Chesapeake is doing some deep-well wildcatting on the Rio Grande.

“We’re exploring deeper horizons with four wildcat wells in 2008,” said Eric Ashmore, Drilling Superintendent – Gulf Coast District. “We’re drilling the Ramirez #1 well to more than 19,000 feet. It has a good looking seismic event in the deeper Wilcox of the Fandango Field, and we are pretty excited about it.”

As in most of its operations, Chesapeake analyzes South Texas prospects through the use of 3-D seismic surveys. An exception is the area under nearby Falcon Reservoir, an 87,000-acre lake along the Rio Grande River which forms the boundary between the U.S. and Mexico. There, issues of international law preclude seismic testing beneath the lake.

Zapata County is located about as far south in Texas as one can travel without a passport. Its remote landscape is dotted with historic ranches – and natural gas wells. The area has a rich, close-knit culture that blends American and Hispanic traditions, so establishing positive relationships with its residents has been a key element of Chesapeake’s success.

A cow and calf wander through the field,
unconcerned by natural gas drilling activity.
Zapata County has a ranching heritage
going back hundreds of years.

Landmen Ron Kendrick and Jim Fansher work closely with Zapata residents as they negotiate leases for mineral rights in the area. That process can be complicated in South Texas, where many families have owned property since the days of Spanish land grants. Many of these properties, called “porciones,” were configured to give each landowner equal access to the precious water of the Rio Grande, so they are extremely long and narrow – which can create additional challenges for leasing and accessing wellsites.

According to Mike Laue, Production Superintendent – Gulf Coast District, success is all about having the right people in place.

“Our biggest challenge in Zapata County is growing from a handful of people with disparate backgrounds and experiences into a leading producer,” Laue said. “We have accomplished this by having good employees who understand what Chesapeake is about, people who know what they are doing and pay attention to details. They get great support from Oklahoma City and the Gulf Coast office in College Station, Texas, as well.”

That carefully built trust has led to one of the company’s greatest accomplishments in the region.

“I think one of the company’s greatest achievements here has been our ability to drill within the town of Zapata,” said Ashmore. “We were the first company to do that, and now we have nearly 100 wells in and very near the town. We’ve had our hurdles, but we believe in-town drilling was an important barrier to break. Basically, we did it by doing what’s right.”

The use of directional drilling has been critical to that success, because it allows wells to be located at a distance from their targets. The first well in town was drilled in 2004 between the old high school and baseball field. Now Chesapeake wells are located on the school grounds, fairgrounds, residential districts, vacation resorts, at the local airport – even on the golf course.

The use of multiwell pad drilling techniques also increases the company’s acceptance and ability to operate in the town. An example of that can be found on a padsite that could soon be home to 13 potential wells. Located near a boat ramp on Falcon Lake, a major recreation source in the region, the site is also adjacent to an upscale residential area.

A pleased audience of parents and educators applauds
as Production Superintendent Mike Laue awards
outstanding young people at the Discovering Tomorrow’s
Leaders awards dinner.

“We are making every effort to accomplish this drilling project as a good neighbor,” said Newville. “We are respectful of peoples’ homes and streets. We even hired site security people to direct contractor traffic, watching every detail and making sure large trucks don’t meet up at the same time or get off the road into yards.”

The quiet little town on the Rio Grande is home to most of Chesapeake’s 30-person Zapata field office staff. Their community pride is combining with company pride as the group moves into a pristine new field office and yard.

“This move is thrilling to our team in Zapata,” Laue said. “This is a small, close-knit town where our Chesapeake people live, as well as where they work. That makes a big difference in how they work and how they are received in the community. I think we can be proud of how our Zapata employees do their jobs – and the kind of citizens they are in the community.”

That community commitment can be seen in Chesapeake employees’ direct involvement with the Zapata Chamber of Commerce, local schools and projects such as 4-H Club, Discovering Tomorrow’s Leaders and county fairs. They also have spearheaded efforts to raise significant funds for local chapters of the American Cancer Society, Boys and Girls Club and other charities.