It is good to see someone fighting Obama's EPA Gestapo. They are worse than a runaway BP oil well.
P
Friday, May 28, 2010, 12:06pm CDT
Gov. Perry pushes back against EPA, Obama administration
Dallas Business Journal - by Kerri Panchuk Web Reporter source
Texas Gov. Rick Perry is firing back at the Obama administration over a recent federal initiative to quash a Texas program that deals with air emissions. Perry said switching to a federally mandated program puts the state at risk of killing jobs.
He defended the emissions control program that Texas has in place now, saying it went into effect under Gov. Ann Richards and was approved by then President Bill Clinton.
“Since then, the EPA’s unelected bureaucrats haven’t ruled on it once, yet, with the arrival of a new administration in Washington, they have put a bulls-eye on the backs of hardworking Texans,” Perry said.
Perry said the feds decision to trade the Texas air permitting policy for a new federal plan ignores the fact that Texas has seen a 22 percent reduction in ozone and a 46 percent drop in emissions. He added that the EPA’s program is an overreach and violates the state’s rights under the 10th Amendment.
kerripanchuk@bizjournals.com
Showing posts with label North Texas. Show all posts
Showing posts with label North Texas. Show all posts
Friday, May 28, 2010
Wednesday, August 13, 2008
Barnett Shale Gas
The gas being produced from the Barnett Shale represents one of the most exciting developments in the oil and gas industry in decades.
Peter
source
Barnett Boom Ignites Hunt for Unconventional Gas Resources
January 2007
The global hunt for unconventional gas reserves recently turned to an unlikely spot—a patch of north central Texas that already seemed tapped out after 50 years of intense oil and gas drilling.
Technology, economics and one man’s persistence transformed the Barnett Shale formation of the Fort Worth Basin into a booming new frontier.
As conventional petroleum reserves dwindle in the U.S., public pressure mounts to reduce the country’s dependence on foreign energy, and the price of oil and gas rises, energy companies are setting their sights on “unconventional” domestic sources. These include oil sands, coal beds and shales.
In less than a decade, the Barnett Shale play has become the largest natural gas play in the state of Texas and, as new wells sprout like bluebonnets across the Fort Worth region, it might soon become the largest in the nation.
“This play already covers parts of 15 or more counties,” says Eric Potter, associate director of the Bureau of Economic Geology at the University of Texas at Austin. “It compares favorably with the biggest of the old oil booms of the early 20th century.”
Of course this boom is different. The concrete-like shale gives up its gas grudgingly. So individual wells tend to be smaller and more expensive to operate.
Peter
source
Barnett Boom Ignites Hunt for Unconventional Gas Resources
January 2007
The global hunt for unconventional gas reserves recently turned to an unlikely spot—a patch of north central Texas that already seemed tapped out after 50 years of intense oil and gas drilling.
Technology, economics and one man’s persistence transformed the Barnett Shale formation of the Fort Worth Basin into a booming new frontier.
As conventional petroleum reserves dwindle in the U.S., public pressure mounts to reduce the country’s dependence on foreign energy, and the price of oil and gas rises, energy companies are setting their sights on “unconventional” domestic sources. These include oil sands, coal beds and shales.
In less than a decade, the Barnett Shale play has become the largest natural gas play in the state of Texas and, as new wells sprout like bluebonnets across the Fort Worth region, it might soon become the largest in the nation.
“This play already covers parts of 15 or more counties,” says Eric Potter, associate director of the Bureau of Economic Geology at the University of Texas at Austin. “It compares favorably with the biggest of the old oil booms of the early 20th century.”
Of course this boom is different. The concrete-like shale gives up its gas grudgingly. So individual wells tend to be smaller and more expensive to operate.
In less than a decade, the Barnett Shale play has become the largest natural gas play in the state of Texas and, as new wells sprout like bluebonnets across the Fort Worth region, it might soon become the largest in the nation.
“The East Texas gushers would win out hands down,” says Potter. “But there are so many [Barnett] wells that even though they are modest, the total output is going to be huge.“
This play is also different because much of the untapped gas lies under the highly populated Fort Worth metropolitan area. Oil and gas companies are finding new challenges drilling in an urban setting.
Now, some experts are wondering if the boom can go global. The search is on for similar shale formations around the world, including the Fayetteville Shale in Arkansas.
Going to the Source
The fact that there is a Barnett boom at all reflects a tectonic shift in thinking. In the past, drillers bypassed the source rock that generated the oil and gas and focused on the reservoir rock, where the resources were easier to extract. Typically, oil or gas exits from the source rock and migrates to places where it is trapped. And those traps—conventional fields—typically do not cover a large area.
“There would be a field here and then a lot of blank space and then a few miles over there would be another field,” says Potter. “But this kind of play, it just covers county after county. You’re looking at thousands and thousands of wells covering the land.”
According to Eric Potter, the 5,500 wells currently pumping gas in the Barnett Shale play will ultimately generate on the order of $35 billion for their owners and through an economic ripple effect, $100 billion for the Texas economy.
With new technologies for coaxing gas out of shales, drillers see the Barnett as both source and reservoir. One such technology is artificial fracturing—in which operators pump water and sand down a well to create fractures that liberate more gas from the rock.
Potter and his colleagues at the Bureau are analyzing the properties of shales across the state. Ultimately, they hope to apply their work to similar rock formations anywhere in the world.
“Now any kind of mudrock or shale that’s black, organic rich, reasonably thick, and reasonably deep we’re interested in,” says Potter. “The question is, all shales are not alike, so what makes a shale prospective as opposed to one that is not prospective? We don’t really know that yet.”
Wise Investment
Before he died in 2003, oilman and philanthropist John Jackson donated to The University of Texas at Austin royalty interests in roughly a thousand wells in the Fort Worth Basin, part of the bequest that led to the formation of the Jackson School of Geosciences. These wells were producing oil and gas from the younger Bend Conglomerate formation just above the Barnett.
The Bend Conglomerate was formed during the Pennsylvanian age, meaning it was laid down about 290 to 320 million years ago. The Barnett Shale, a marine basinal deposit of middle to late Mississippian age, was laid down about 320 to 360 million years ago.
Could the same wells produce significant amounts of gas from the older, deeper Barnett shale? Potter and his colleagues at the Bureau helped the University assess the long-term potential of the University’s royalty interests.
Royalty interests on about a thousand wells donated by John Jackson, mostly in Wise County, Texas help build one of the world’s premier geoscience programs at the Jackson School.
“The short answer is that we think that most of that acreage has quite good potential in the Barnett,” says Potter. “Eight of the top ten Jackson School royalty wells are producing from the Barnett Shale. We are forecasting that most of these holdings will produce from the Barnett.”
The University receives on average about two percent of the gross revenue from wells it holds royalty interests on. That money is being used to build one of the world’s premier geosciences programs at the new Jackson School. Because the money goes into general funds, it supports all of the activities of the school, including dean Eric Barron’s priorities: to create the world’s most student-centered earth science program, to attract and retain the best research talent, to increase the breadth and depth of the faculty and research community and to establish the “fabric of a great school.”
Researchers at the Bureau are providing technical analysis to help stimulate additional drilling and production in Wise County, where most of the University’s royalty interests are located. Emphasis so far has been on mapping the basic stratigraphic and structural framework, tracking successful drilling in the less developed southern part of the play, mapping similar conditions in Wise County, and remapping the thermal maturity of the formation. The maturity seems to relate directly to the gas to oil ratio, one of the key factors controlling gas flow rates.
According to Potter, the 5,500 wells currently pumping gas in the Barnett Shale play will ultimately generate on the order of $35 billion for their owners. As those companies pay taxes and wages, and as their employees and contractors in turn spend their money, there is an economic ripple effect, creating an overall value of about $100 billion to the Texas economy.
Of course, that is only counting current wells. Potter predicts that if gas prices stay relatively high, tens of thousands of new wells will be drilled in the coming decades.
“It’s a ubiquitous reservoir,” says Larry Brogdon, partner and chief geologist for Ft. Worth based Four Sevens Oil Company. “It’s everywhere. You can not drill a well without hitting the Barnett, and the gas is always there. The question is can you get it out or not.“
So far, operators have extracted 2 trillion cubic feet of gas from the Barnett Shale play. At about 1.5 billion cubic feet a day, that’s about 2 percent of the daily natural gas consumption of the U.S.
“When you can go from nothing to the second largest producing gas field in the country in a matter of just a few years, that makes a statement,” says Rich Pollastro, a geologist with the U.S. Geological Survey in Lakewood, Colorado. “That’s huge. And it could potentially become the largest producing field in the country. That was a real awakening for the country and now because of its success, industry and nations are looking at it worldwide.”
The Next Barnett?
In the summer of 2004, Southwestern Energy announced that the Fayetteville Shale formation in the Arkoma Basin had many of the same characteristics that made the Barnett Shale formation so desirable for gas production. Before the announcement, the company had quietly acquired mineral leases on nearly a half million acres of land.
The announcement set off another gas boom. Oil and gas operators familiar with the Barnett Shale rushed to Arkansas to get in on the action.
“The analog would be like a 19th century gold rush,” says Ed Ratchford, geology supervisor for the Arkansas Geological Commission in Little Rock. “Everyone stakes a claim. You don’t say this place is going to be better than this place. You don’t have time. People were leasing thousands of acres a day.”
Ratchford and his team maintain a well log library, a collection of well cuttings and cores from oil and gas wells across Arkansas. They used these to conduct geochemical tests on samples from the Fayetteville Shale and produce a regional picture of where good gas prospects were likely to be.
“We had companies all over us waiting for us to get this stuff done,” says Ratchford. “They were sitting out in the parking lot before we opened up. We were the only ones that had this information. It was critical for helping the operators know where to lease.”
In the excitement, many companies took a gamble on mineral leases.
Locations of the Barnett Formation. Source: USGS.
“We had a lot of companies that had leased before the report came out,” says Ratchford. “Then they had a big golf ball in their throats saying, ‘I wish I hadn’t leased here.’ That’s the risk you run when you lease big tracts of land in a boom without having the luxury of doing the science first.”
“Some of those companies are going to make a lot of money,” notes Ratchford, “some are going to be doing tax write offs. That’s the nature of exploration. In a situation like this, where there’s a frenzy, there are going to be winners and losers.“
It’s too early to tell how much gas will ultimately be recoverable from the Fayetteville Shale. Southwestern Energy, still the largest lease holder in the play, estimates that they will recover 17 trillion cubic feet of gas.
The future looks good for the Fayetteville play. Ratchford expects the number of wells producing in the area to rise from the current 80 to a couple hundred and that gas will be extracted for at least 15 or 20 years.
He also notes that oilfield services provider Schlumberger has recently built a 30,000 square foot facility in Conway, Arkansas and will employ approximately 100 employees at that facility. “They would not do this if they didn’t believe this would be a long term venture,” says Ratchford.
Other areas that have generated interest for possible large shale gas plays are the Caney and Woodford formations in Oklahoma, the Floyd formation in the Black Warrior Basin of northwest Alabama, and the Barnett and Woodford formations in the Permian Basin of Texas.
It remains to be seen if the rising star of the Barnett Shale play will be eclipsed by other gas plays.
“The Barnett might be as good as it gets,” says Pollastro. “No one knows for sure.”
He produced the U.S. Geological Survey’s assessment of the Fort Worth Barnett shale play in 2003. At the time, he estimated that it held a remaining volume of 26 trillion cubic feet of recoverable unconventional gas. Now he’s evaluating the Barnett and Woodford formations in the Permian Basin, where drillers have experienced mixed results.
“It’s a different animal,” he says. “The Barnett in the Delaware Basin part of the Permian Basin is deeper and is more clay rich, so at present it’s not working like everybody thought it would. It’s not as rich in organic material as the Fort Worth Basin. I think there’s good potential, but I think there will be a steep learning curve.”
by Marc Airhart
Tuesday, April 8, 2008
Natural Gas, Marcellus Shale Play in Pennsylvania
The following article about a new natural gas exploration and production "play" in Pennsylvania and neighboring States, is a good example of how rising prices can increase the amount of oil and gas found and produced. Apparently there is a real boom going on. One of the reasons why producing gas from shale is economically attractive is because the layer of shale in the subsurface is often thick and widespread. This means it is easy to find. The rock also tends to be very impermeable and lacking in porosity (that is open space between rock particles). 
“It’s a modern-day gold rush in our own backyard,” Mr. Gregoire said.
Not just his backyard either — a frenzy unlike any seen in decades is unfolding here in rural Pennsylvania, and it eventually could encompass a huge chunk of the East, stretching from upstate New York to eastern Ohio and as far south as West Virginia. Companies are risking big money on a bet that this area could produce billions of dollars worth of natural gas.
A layer of rock here called the Marcellus Shale has been known for more than a century to contain gas, but it was generally not seen as economical to extract. Now, improved recovery technology, sharply higher natural gas prices and strong drilling results in a similar shale formation in north Texas are changing the calculus. A result is that a part of the country where energy supplies were long thought to be largely tapped out is suddenly ripe for gas prospecting.
Pennsylvania, where the Marcellus Shale appears to be thickest, is the heart of the action so far. Leasing agents from Texas and Oklahoma are knocking on doors, leaving voice mail messages and playing host at catered buffets to woo dairy farmers and retirees. They are rifling through stacks of dusty deeds in courthouse basements to see who has underground mineral rights to the deepest gas formations.
Thomas B. Murphy, a Pennsylvania State University educator who runs a program to instruct landowners on their rights, estimated that more than 20 oil and gas companies will invest $700 million this year developing the Marcellus Shale. Up to one half of that will be invested in Pennsylvania, he estimated.
The cost to companies for leasing mineral rights jumped from $300 an acre in mid-February to $2,100 now. “It shows you the pace this is going,” Mr. Murphy said. “I would call it breakneck.”
Dale A. Tice, a lawyer representing landowners in lease negotiations, said companies were on a “feeding frenzy.
A natural gas drilling site on a farm in Hickory, outside Pittsburgh, that seeks to extract gas from 600 feet below the surface.
Industry experts say in the last three years companies like Anadarko Petroleum, Chesapeake Energy and Cabot Oil and Gas have leased up to two million acres for drilling in the region, half of that in the last nine months.
Whether their bets will pay off is by no means a sure thing.
Researchers at Penn State and the State University of New York at Fredonia estimate that the Marcellus has 50 trillion cubic feet of recoverable natural gas, roughly twice the amount of natural gas consumed in the United States last year. But government estimates of the amount of gas recoverable from the Marcellus are relatively modest.
Early test results have encouraged companies to keep drilling, but most are holding details of their test wells close to the vest.
The company that has done the most work is Range Resources of Fort Worth, which says it plans to invest at least $426 million in the Appalachia region this year.
The company has reported promising results from the first 12 wells that it has drilled horizontally, the technique considered by most experts to be the most effective in the Marcellus. The most recent six have each produced more than three million cubic feet of production a day in recent months, and company executives say that is better than the average for wells recovering natural gas in the Barnett Shale in north Texas.
“The Marcellus is important to Range and it could be important to the country but it really is still early,” said Rodney L. Waller, a senior vice president at Range. “I can build you a scenario where it can be significantly better than the Barnett but it’s a function of economics.”
Energy experts say the Marcellus, along with other smaller shale formations being developed around the country, is coming under scrutiny at an opportune moment, just when conventional domestic natural gas production and imports from Canada are diminishing. With easy-to-find gas fields in decline, the country will need to explore in deeper waters in the Gulf of Mexico and penetrate deeper under the surface on land.
If all goes well, the Marcellus could help moderate the steep climb in natural gas prices and reduce possible future dependence on natural gas from the Middle East, which is beginning to arrive at coastal terminals in liquefied form.
Natural gas in the Marcellus and other shale formations is sometimes found as deep as 9,000 feet below the ground, a geological and engineering challenge not to be underestimated. The shales are sedimentary rock deposits formed from the mud of shallow seas several hundred million years ago. Gas can be found trapped within shale deposits, although it is too early to know exactly how much gas will be retrievable.
The gas from all the shales combined “is a game changer,” said Robert W. Esser, an oil and gas expert at Cambridge Energy Research Associates. He estimated that shale produced four billion cubic feet of gas a day on average last year, or about 7 percent of national production, and that shale gas production would increase to nine billion cubic feet a day by 2012, or about 15 percent of expected national production.
The New York State Energy Research and Development Authority estimates that developing New York’s portion of the Marcellus could roughly double the amount of natural gas now produced in New York. Currently that is about 55 billion cubic feet a year, providing for 5 percent of the state’s needs.
The Marcellus has suddenly become attractive in large part because natural gas prices have spiked in the last several years and the geologically similar Barnett Shale has been an industry sensation.
By using horizontal drilling techniques, oil and gas companies have been able to draw natural gas from underneath the city of Fort Worth, even from below schools, churches and airports. The companies have perfected hydraulic fracturing techniques, pumping water and sand into well bores to fracture shale and release gas from its pores.
Production in the Barnett has exploded from a trickle five years ago to over three billion cubic feet a day, and energy experts say that number could more than double by 2015. Shale gas development in other parts of Texas, Louisiana and Arkansas has also shown promise.
But no formation compares in size to the Marcellus. It is deeply entrenched in wooded and mountainous countryside and expensive to reach. But the reserve is also within short pipeline distance from some of the nation’s most energy-hungry cities.
Still, not everyone here is happy about all the leasing and drilling. At meetings with the companies, landowners have asked questions about potential hazards to water and woodlands.
Keith Eckel, 61, a grain farmer with 700 acres in northeastern Pennsylvania, said he had not decided whether to let the companies drill on his property. “Farmers have taken care of this land all their lives and don’t want to see it destroyed,” he said.
But many farmers and retirees in rural Pennsylvania appear excited that their lives are about to change.
“Now I can retire,” said Robert Deiseroth, a 63-year-old farmer and auctioneer from the town of Hickory, who recently received a $16,000 royalty check from Range Resources that he hopes will be repeated month after month. “This was a godsend for me. If it weren’t for this I would have to sell off some of my land to get some money for retirement.”
Mr. Deiseroth has put new windows in his house, bought a new fishing boat and plans to build a new garage. His 89-year-old father and 90-year-old mother, who live nearby, just got a $20,000 monthly check. His father has replaced the golf cart he drove around his farm with a Kubota utility vehicle, while his mother has bought a flat-screen television.
“When Range came in a lot of people didn’t like it,” Mr. Deiseroth said, “But things changed when they started getting their checks.”
Engineers have solved those problems primarily through the processes of "horizontal drilling" and "fracing" or fracturing the rock under ground by pumping fluid down the well bore and into the rock formation under high pressure. This is immediately followed with "sand" grains suspended in the fluid that goes into the induced fractures and keeps them open. This creates artificial porosity and permeability. It is an expensive and highly technical operation, but once perfected, as it seems to be, the results and the accompanying high value of the gas produced make it all worthwhile. This is a major development which can be very good for the area, and America's economy in general. It is a good time to be a working petroleum geologist and engineer.
Peter
April 8, 2008
There’s Gas in Those Hills
By CLIFFORD KRAUSS
HUGHESVILLE, Pa. — At first, Raymond Gregoire did not want to listen to the raspy voice on his answering machine offering him money for rights to drill on his land. They want to ruin my land, he thought. But he called back anyway a week later to hear more.
By the end of February, he had a contract in hand for $62,000, and he pulled together a group of 75 neighbors who signed $3 million in deals.
There’s Gas in Those Hills
By CLIFFORD KRAUSS
HUGHESVILLE, Pa. — At first, Raymond Gregoire did not want to listen to the raspy voice on his answering machine offering him money for rights to drill on his land. They want to ruin my land, he thought. But he called back anyway a week later to hear more.
By the end of February, he had a contract in hand for $62,000, and he pulled together a group of 75 neighbors who signed $3 million in deals.
“It’s a modern-day gold rush in our own backyard,” Mr. Gregoire said.
Not just his backyard either — a frenzy unlike any seen in decades is unfolding here in rural Pennsylvania, and it eventually could encompass a huge chunk of the East, stretching from upstate New York to eastern Ohio and as far south as West Virginia. Companies are risking big money on a bet that this area could produce billions of dollars worth of natural gas.
A layer of rock here called the Marcellus Shale has been known for more than a century to contain gas, but it was generally not seen as economical to extract. Now, improved recovery technology, sharply higher natural gas prices and strong drilling results in a similar shale formation in north Texas are changing the calculus. A result is that a part of the country where energy supplies were long thought to be largely tapped out is suddenly ripe for gas prospecting.
Pennsylvania, where the Marcellus Shale appears to be thickest, is the heart of the action so far. Leasing agents from Texas and Oklahoma are knocking on doors, leaving voice mail messages and playing host at catered buffets to woo dairy farmers and retirees. They are rifling through stacks of dusty deeds in courthouse basements to see who has underground mineral rights to the deepest gas formations.
Thomas B. Murphy, a Pennsylvania State University educator who runs a program to instruct landowners on their rights, estimated that more than 20 oil and gas companies will invest $700 million this year developing the Marcellus Shale. Up to one half of that will be invested in Pennsylvania, he estimated.
The cost to companies for leasing mineral rights jumped from $300 an acre in mid-February to $2,100 now. “It shows you the pace this is going,” Mr. Murphy said. “I would call it breakneck.”
Dale A. Tice, a lawyer representing landowners in lease negotiations, said companies were on a “feeding frenzy.
A natural gas drilling site on a farm in Hickory, outside Pittsburgh, that seeks to extract gas from 600 feet below the surface.Industry experts say in the last three years companies like Anadarko Petroleum, Chesapeake Energy and Cabot Oil and Gas have leased up to two million acres for drilling in the region, half of that in the last nine months.
Whether their bets will pay off is by no means a sure thing.
Researchers at Penn State and the State University of New York at Fredonia estimate that the Marcellus has 50 trillion cubic feet of recoverable natural gas, roughly twice the amount of natural gas consumed in the United States last year. But government estimates of the amount of gas recoverable from the Marcellus are relatively modest.
Early test results have encouraged companies to keep drilling, but most are holding details of their test wells close to the vest.
The company that has done the most work is Range Resources of Fort Worth, which says it plans to invest at least $426 million in the Appalachia region this year.
The company has reported promising results from the first 12 wells that it has drilled horizontally, the technique considered by most experts to be the most effective in the Marcellus. The most recent six have each produced more than three million cubic feet of production a day in recent months, and company executives say that is better than the average for wells recovering natural gas in the Barnett Shale in north Texas.
“The Marcellus is important to Range and it could be important to the country but it really is still early,” said Rodney L. Waller, a senior vice president at Range. “I can build you a scenario where it can be significantly better than the Barnett but it’s a function of economics.”
Energy experts say the Marcellus, along with other smaller shale formations being developed around the country, is coming under scrutiny at an opportune moment, just when conventional domestic natural gas production and imports from Canada are diminishing. With easy-to-find gas fields in decline, the country will need to explore in deeper waters in the Gulf of Mexico and penetrate deeper under the surface on land.
If all goes well, the Marcellus could help moderate the steep climb in natural gas prices and reduce possible future dependence on natural gas from the Middle East, which is beginning to arrive at coastal terminals in liquefied form.
Natural gas in the Marcellus and other shale formations is sometimes found as deep as 9,000 feet below the ground, a geological and engineering challenge not to be underestimated. The shales are sedimentary rock deposits formed from the mud of shallow seas several hundred million years ago. Gas can be found trapped within shale deposits, although it is too early to know exactly how much gas will be retrievable.
The gas from all the shales combined “is a game changer,” said Robert W. Esser, an oil and gas expert at Cambridge Energy Research Associates. He estimated that shale produced four billion cubic feet of gas a day on average last year, or about 7 percent of national production, and that shale gas production would increase to nine billion cubic feet a day by 2012, or about 15 percent of expected national production.
The New York State Energy Research and Development Authority estimates that developing New York’s portion of the Marcellus could roughly double the amount of natural gas now produced in New York. Currently that is about 55 billion cubic feet a year, providing for 5 percent of the state’s needs.
The Marcellus has suddenly become attractive in large part because natural gas prices have spiked in the last several years and the geologically similar Barnett Shale has been an industry sensation.
By using horizontal drilling techniques, oil and gas companies have been able to draw natural gas from underneath the city of Fort Worth, even from below schools, churches and airports. The companies have perfected hydraulic fracturing techniques, pumping water and sand into well bores to fracture shale and release gas from its pores.
Production in the Barnett has exploded from a trickle five years ago to over three billion cubic feet a day, and energy experts say that number could more than double by 2015. Shale gas development in other parts of Texas, Louisiana and Arkansas has also shown promise.
But no formation compares in size to the Marcellus. It is deeply entrenched in wooded and mountainous countryside and expensive to reach. But the reserve is also within short pipeline distance from some of the nation’s most energy-hungry cities.
Still, not everyone here is happy about all the leasing and drilling. At meetings with the companies, landowners have asked questions about potential hazards to water and woodlands.
Keith Eckel, 61, a grain farmer with 700 acres in northeastern Pennsylvania, said he had not decided whether to let the companies drill on his property. “Farmers have taken care of this land all their lives and don’t want to see it destroyed,” he said.
But many farmers and retirees in rural Pennsylvania appear excited that their lives are about to change.
“Now I can retire,” said Robert Deiseroth, a 63-year-old farmer and auctioneer from the town of Hickory, who recently received a $16,000 royalty check from Range Resources that he hopes will be repeated month after month. “This was a godsend for me. If it weren’t for this I would have to sell off some of my land to get some money for retirement.”
Mr. Deiseroth has put new windows in his house, bought a new fishing boat and plans to build a new garage. His 89-year-old father and 90-year-old mother, who live nearby, just got a $20,000 monthly check. His father has replaced the golf cart he drove around his farm with a Kubota utility vehicle, while his mother has bought a flat-screen television.
“When Range came in a lot of people didn’t like it,” Mr. Deiseroth said, “But things changed when they started getting their checks.”
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