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May 2015

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Table of Contents 4

ENERGY BRIEFS

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‘MORE IS GETTING DONE; THERE’S MORE TO DO’

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NEW REGULATIONS THREATEN ENERGY BOOM

EXECUTIVE EDITOR

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GAS/OIL WORKERS NEED TO PROTECT THEIR HEARING

Ray Booth RBooth@dixcom.com

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UTICA SHALE PRODUCING STRONG RESULTS

CONTRIBUTING EDITOR

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TENORM STUDY COULD INDICATE GOV. WOLF’S STANCE

PUBLISHER Andrew S. Dix ASDix@dixcom.com

Dan Alfaro Dan@pharosmediallc.com

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FEDERAL FRACKING RULES ROLLED OUT

ADVERTISING

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PENNSYLVANIA GAS & OIL: WHAT’S OLD IS NEW AGAIN

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THE UPPER DEVONIAN BURKET/GENESEO SHALE APPALACHIA’S LITTLE BROTHER TO THE UTICA AND MARCELLUS

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2ND MAJOR GAS PIPELINE WOULD LINK PENNSYLVANIA, NORTHEAST

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BELMONT COUNTY NAMED FINAL CANDIDATE FOR POSSIBLE PETROCHEMICAL FACILITY

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PROTECTING UTILITY LINES

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COVE POINT BREAKS GROUND: A NEW ERA IN AMERICAN ENERGY

Rhonda Geer RGeer@dixcom.com 330-287-1653 Christy Penland Account Executive CPenland@daily-jeff.com 330-287-1668 Ed Archibald Account Executive EArchibald@dixcom.com 740-439-3531 DIGITAL CONTENT MNGR Brad Tansey BTansey@dixcom.com

ART DIRECTOR Pete Kiko PKiko@the-daily-record.com

LAYOUT DESIGNER Elizabeth Horne Ehorne@the-daily-record.com

“Gas & Oil” is a monthly publication jointly produced by Dix Communication newspapers across Ohio & PA. Copyright 2015.

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Gas & Oil

Briefs

WOLF ADMINISTRATION EXPANDS PUBLIC INPUT ON DRILLING RULES ARRISBURG, Pa. (AP) — Pennsylvania state environmental regulators are broadening an effort to collect public response to their proposal to toughen regulations over the Marcellus Shale natural gas drilling industry.

The Department of Environmental Protection said it will allow a 45-day public comment period, rather than 30 days, and schedule three public hearings.

The public comment period ends May 19, and two of the yet-to-be-scheduled public hearings will happen in northern Pennsylvania and one in southwestern Pennsylvania.

The department hopes its plan will become regulation in 2016.

Agency officials want more stringent reviews of proposed drilling sites that are within 100 feet of streams or wetlands, tougher requirements over noise and waste storage and more analysis of how each new well could affect drinking water sources, schools and playgrounds.

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WILLIAMS PARTNERS TO BUY MAJORITY INTEREST IN UTICA EAST EW YORK (AP) — Williams Partners L.P. will expand its stake in Utica East Ohio Midstream to a majority interest for about $575 million.

The energy infrastructure company already owns a 49 percent stake in Utica East, which focuses on fracking in the Utica Shale formation in eastern Ohio. It is buying the 21 percent interest owned by EV Energy Partners L.P. "Acquiring these cash-generating assets supports our strategy to grow our natural gas midstream position in key basins," said Williams Partners CEO Alan Armstrong, in a statement.

Tulsa, Oklahoma-based Williams Partners agreed to waive about $43 million of general partner incentive distribution rights for the three-year period 2015 through 2017 as part of the deal with Houston-based EV Energy Partners. The deal is expected to close by the middle of July.

Williams Partners shares fell 76 cents to $48 in afternoon trading Monday. Its shares are down 11 percent over the past year.

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Pennsylvania Edition

May 2015

OIL SPILL AVOIDED AFTER DEADLY OFFSHORE BLAZE EXICO CITY (AP) — A huge blaze twisted and blackened an oil platform in the Gulf of Mexico, but the state-run Pemex oil company said it managed to avert any significant oil spill.

At least four workers died and two suffered life-threatening injuries in an explosion that engulfed the platform in flames Wednesday, forcing 300 people to abandon the facility.

Officials said environmental damage was avoided because the fire happened on a processing platform where the feeder lines could be turned off, rather than at an active oil well with a virtually unlimited amount of fuel flowing up from the seabed.

In a statement Wednesday night, Pemex said the accident "did not cause an oil spill into the sea, given that there was only a seepage, which is being taken care of by specialized vessels." It suggested the oil remaining in the pipelines was burning off.

The company's official Twitter account announced late Wednesday that fire had been extinguished after hours of being showered with water sprayed from 10 firefighting and emergency boats.

Pemex Director General Emilio Lozoya said the accident "would have a minimal impact on production, because this was a processing platform," not a producing well.

Production from nearby wells it normally serves could be rerouted to other processing platforms.

Lozoya said the explosion appeared to have been set off by some kind of mechanical problem but the precise cause was still under investigation.

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CONSOL ENERGY USING ENGINES TO CUT FRACKING PUMP EMISSIONS MPERIAL, Pa. (AP) — Consol Energy has begun using new, cleaner-burning engines to run its hydraulic fracturing pumps at natural gas well sites on Pittsburgh International Airport property.

The company says the diesel engines are supposed to cut harmful emissions by 36 percent.

They're developed jointly by Cummins Inc., which makes engines and fuel systems, and Halliburton, the oilfield services company.

Consol's chief operations officer of exploration and production, Tim Dugan, says the airport drilling sites are the company's "flagship project." The cleaner engines are being used on a six-well drilling site on the 9,000-acre airport site.

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May 2015

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‘More is getting done; there’s more to do’ John Molinaro, president and CEO of Appalachian Partnership for Economic Growth

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ELSONVILLE, OH — John Molinaro’s mission is to build prosperity in a 14,000 square mile region that stretches from Columbiana County in the northeast to Brown County in the southwest — the Appalachian Partnership for Economic Growth.

At his office in Nelsonville, Molinaro, president and CEO of APEG, reflected on its accomplishments and challenges. He’s proud and optimistic.

Companies are growing, wells are being drilled, and workers are learning new skills. And while more is getting done, there’s more to do.

Q: What’s the latest on the region’s shale development?

A: 2014 was a very good year for the industry. We had a lot of drilling activity. More wells are being completed and the new wells are doing substantially better than older ones in terms of output. The heart of the play is farther south than people had originally envisioned. The I-77 corridor south of I-70 has turned out to be more productive than the area north, where the play began. We’ve seen drilling activity happening as far south as Washington County.

Wells in Monroe County are some of the most productive seen anywhere ever, and I mean that in a global sense. The 2014 production numbers are pretty outstanding.

Q: You’ve called midstream capacity critical to shale development in eastern Ohio. Why is it so important?

A: The midstream is the part of the energy processing industry between the well and the end user. In the APEG region, firms like Mark West and Blue Racer complete major facilities that help separate out the natural gas components, ethane and propane, for example. We also saw a lot of pipeline infrastructure go in during the year. The reason infrastructure is so important is because nobody wants to put $10 million or more into drilling a hole in the ground and then cap it and wait to get their product to market.

Also, we had announcements about additional capacity that will be developed in the next few years. That should keep us on pace with or ahead of existing drilling activity.

Q: What does the late-2014 major decrease in oil prices mean?

A: We anticipate that 2015 will produce as much or more gas as 2014. Some will come from wells that have already been drilled but haven’t been completed. There will also be a lot of new drilling activity. So far the rig count in Ohio is down just slightly from what it was a year ago, less than

10%. Fortunately, the Utica shale play in eastern Ohio, and the Marcellus that’s being drilled here as well, is among the most profitable plays in the entire country. Because of that – despite very low oil and gas prices – the companies drilling here are able to make a profit in this market. Those that have announced cutbacks tend to be companies that are very heavily exposed to shale plays in America that mostly produce oil.

Q: Can you do anything to help the region’s shale development?

A: Yes. We’re adding another staff position that’s focused on mid-stream and down-stream opportunities created by the shale drilling. We’re trying to capture more of the industries that use the products coming out of the ground, that’s what the new, full-time person will do. We’re very, very excited about having more resources to work on attracting investment to the region because it means jobs in the mid-stream and down-stream shale activity.

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Pennsylvania Edition

May 2015

New Regulations Threaten Energy Boom Nicolas Loris and Katie Tubb The Heritage Foundation

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he Department of Interior missed an opportunity for real reform recently when it released new regulations on hydraulic fracturing, or fracking, on federal lands.

Since the onset of the Obama administration, the U.S. has undergone both an energy boom that was the bright spot in the great recession and a heated political battle over the Department of Interior’s lack of transparency that significantly slowed oil and gas production on federal lands. It also likely is not the last rule coming from the Obama administration to regulate fracking.

In typical “If it keeps moving, regulate it” fashion, Interior started a rule-making process in November 2010 in response to increased fracking activity and public concerns that were exacerbated by fallacious films such as Gasland and Matt Damon’s Promised Land.

The rule updates and expands regulation and will be revisited again in seven years. It is largely duplicative of what states already do to regulate fracking—adjusting construction standards to protect water resources and requiring disclosure of chemicals and advance public notice of fracking activity. Regulations apply to federal and Indian lands as well as private or state lands where the underground mineral rights belong to the federal government. States otherwise would regulate fracking on state and private lands as they have been. Unsurprisingly, extremist environmental groups did not think the Interior Department went far enough.

The Department of Interior should have taken the fracking boom as an opportunity to pivot away from one-sizefits-all regulation and turn management of fracking activity to the states. Regulation at the state and local level—as opposed to from Washington—has been a chief reason for the impressive economic results and environmental record of the new technology. Even the White House Council of Economic Adviser’s noted in its annual report to Congress that the regulatory structure that met local concerns regarding fracking was at the state and local level.

Instead, it has taken Interior five years to develop these new regulations, and politically driven management of federal lands has played a significant role in the loss of productivity on those lands. Meanwhile, states have effectively and efficiently managed the energy boom on state and private lands even as demand to develop oil and gas

resources has increased. In fact, states have been regulating fracking for decades. While federal regulators lose even more time putting these new regulations into practice, states already have policies in place that reflect the unique conditions of the state.

Federal management of energy resources also has had a chilling effect on productivity. According to the Congressional Research Service, roughly 43 percent of all proven crude oil reserves in the U.S. are on federal lands. And yet, since 2009, oil production on federal lands has fallen by 9 percent even as production on state and private lands has increased by 61 percent over the same period. In 2010, 36 percent of all domestic oil production came from federal lands; now only 23 percent does. A similar story can be told of coal and natural gas. This activity translated into more jobs and higher incomes.

States have also been more responsive to the unique interests and concerns of their communities, in contrast to Interior’s approach of stalling on granting permits to drill for oil and gas. Not a single case of water contamination has been caused by the process of fracking, and although there are best practices that must be followed, fracking has withstood the many myths demonizing the technology.

Some communities have elected to ban the use of fracking technology. Unfortunate and misguided as that is, good environmental policy puts the freedom to make decisions in the hands of the people who are affected most by management choices. Nevertheless, Interior’s rule prevents this local decision-making.

Congress and energy producers already have responded in kind. In recent days, 27 senators introduced legislation to block the regulation and the Independent Petroleum Association of America and Western Energy Alliance filed a lawsuit against the Department of Interior, calling the rule “a reaction to unsubstantiated concerns” that “lacks the factual, scientific or engineering evidence necessary to sustain the agency’s action.” Ultimately states, not Washington, should regulate fracking activities on federal lands.

They are more knowledgeable and adaptable to the conditions of each region.

Nicolas Loris, an economist, focuses on energy, environmental and regulatory issues as the Herbert and Joyce Morgan fellow at The Heritage Foundation.

Katie Tubb is a research assistant for the Thomas A. Roe Institute for Economic Policy Studies at The Heritage Foundation.

Gas & Oil

www.GasandOilMag.com

May 2015

7

Gas/oil workers need to

protect their hearing

Employees working in the oil and gas industry should avoid or protect themselves from excessive noise exposure on the job. The need for properly fitted earplugs or earmuffs to block loud sounds is essential to protecting your hearing. This need is all too often recognized only in hindsight by workers.

Occupational hearing conservation programs alert employees to the possibility of permanent damage caused by excessive noise. Annual hearing testing for employees is conducted for the purpose of identifying early stages of hearing loss and educating workers on prevention.

At home or recreationally, earplugs or muffs should also be worn during activities involving excessive noise. This includes using lawn tractors, snow blowers, gasoline-powered string trimmers, chain saws, circular saws, shop vacuums, and firearms, to name only a few examples, as well as attending rock concerts.

Earplugs and earmuffs work well, are inexpensive, and are readily available at most home improvement centers. An alternative is to have custom earplugs made that exactly match the contours of the user’s ears. Regardless of whether hearing protection is over-the-counter or custom, the key is to actually use it.

Difficulty understanding speech is the most frequently reported problem resulting from hearing loss. Especially problematic is understanding in noisy settings. Hearing loss can take away the ability to hear and distinguish between consonant sounds which makes it sound like people are mumbling or running their words together.

For more information regarding noise induced hearing loss, to schedule a hearing evaluation or to schedule your company's annual hearing testing contact Davison Audiology at (740) 695-1058. Choose from one of our 5 convenient locations or request onsite company testing.

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Gas & Oil

May 2015

Pennsylvania Edition

Utica Shale Producing

Strong Results Joe Massaro - Energy In Depth

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ennsylvania’s Marcellus Shale broke production records last year when operators were able to pump four trillion cubic feet of natural gas from the formation. The continued success of Marcellus Shale development now has operators looking a few thousand feet deeper at Pennsylvania’s Utica Shale.

Some of the first wells developed in Pennsylvania’s Utica Shale were Shell’s Gee and Neal wells located in Tioga County. The Neal well was brought online in February of last year and at peak was producing 26.5 million cubic feet of natural gas per day. According to a company release: “The Gee well was drilled over 100 miles to the northeast of the nearest horizontal Utica producer, and had an initial flowback rate of 11.2 million cubic feet of natural gas per day. Gee has been on production for nearly one year. Shell began production of the Neal well in February, with observed peak flowback rates of 26.5 million cubic feet of natural gas per day.”

Other companies have also had good results tapping into the play as well. Range Resources developed its Utica shale well in the Southwestern part of the state where it achieved an average 24-hour rate of 59 million cubic feet of natural gas per day. Range’s well, the Sportsman’s Club #11H, is recorded as having the strongest 24-hour rate reported in the entire Marcellus/Utica area and is one of the most prolific onshore gas wells (based on the 24-hour production test) ever drilled in North America. According to Range Resources CEO Jeffrey Ventura: “Given our 400,000 net acre acreage position in the area, coupled with existing well control and 3-D seismic, we believe this translates into significant potential. Being able to drill additional Utica wells on the same locations as our Marcellus wells should further enhance our capital efficiency for many years to come.”

One of the more recent wells developed in Pennsylvania’s Utica shale was by Seneca Resources an exploration and production subsidiary of National Fuel Gas Company.

The Tioga County well is located on state forest land and produces 22.7 million cubic feet of natural gas per day. According to Ronald J. Tanski, CEO of National Fuel Gas Company: “We are very pleased with the initial production results from our first Utica Shale well in Tioga County, Pa. This well, along with wells drilled by other operators in the area, have de-risked the Utica potential of our 10,000 acres on DCNR Tract 007. We estimate resource potential on this tract alone of approximately 1 trillion cubic feet. With these strong results in hand our team is evaluating options to develop this acreage in the next few years, depending on local gas prices and pipeline take-away capacity. We have additional Utica potential not only in Tioga County, but across much of our large Pennsylvania acreage position.

Our next Utica exploration well is planned for fiscal 2016.”

With the success of Pennsylvania’s Utica shale so far, other companies are looking to tap into the formation in the near future. One such company is Rice Energy which recently announced it would begin developing a well in the formation. During their earnings conference call, the company stated that the well would be about 2.5 miles deep and run horizontally for about 6,000 feet. According to the CEO, Daniel Rice IV: “While we expect the well to be pretty expensive, it’s going to be pretty exciting to see what we can do with this formation at these depths and pressures, and the best time to test an expensive deep well like this one is in the deflationary cost service environment like the one we’re in.”

Production results for Rice Energy’s first Pennsylvania Utica Shale well are expected during the fourth quarter of 2015.

Because of Pennsylvania’s incredible geology, operators have the ability to tap into multiple carbon-bearing formations, and it will continue to propel the United States towards energy independence for years to come.

Joe Massaro is a spokesman for Energy in Depth.

www.GasandOilMag.com

Gas & Oil

May 2015

9

TENORM study could indicate Gov. Wolf’s stance Joe Kuklis

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he Pennsylvania Department of Environmental Protection sanctioned a study during the Governor Corbett administration on technically enhanced naturally occurring radioactive material, or TENORM. The purpose of the study was to identify and understand how hydraulic fracturing affects groundwater in Pennsylvania.

Naturally occurring radiation exists as part of all geologic formations but the concern was shale gas drilling may artificially increase normal radiation levels, thus potentially polluting groundwater and nearby environs.

The study which began in January of 2013 was hailed as one of the first of its kind and did a deeper dive into the potential impacts to the general environment of Pennsylvania. The results of the study were closely watched by both sides of the legislative aisle in Harrisburg and of course among interested trade associations and their membership. The outcome of the study was expected to impact shale drilling in the Commonwealth for better or worse.

The industry's eyes were focused on the Capitol in January of 2015 when the results were released to the public.

The study proved to be relatively benign to the shale gas industry when the report revealed that TENORM from fracking only had limited impact on the potential for radiation exposure to the public or the shale gas workforce. This possible exposure to the workforce was studied globally, accounting for workers in all phases of shale gas drilling and transmission including in treating the contaminated water and waste. Overall it was discovered that there was little potential for negative exposure to radiation for each of these labor clusters.

However, the perception was that the study was completed at the tail end of a shale friendly Governor's term which to many smacked of its own political ramifications.

And although it is early in Governor Wolf's new administration, the shale gas community will watch to see how the first year governor and his environmental team treat the TENORM study and implement its findings.

Many of the governor's senior staff have backgrounds in conservation and environmental protection, dictating that there may be a stronger levels of scrutiny to the study and it's results. The Governor's Chief of Staff, his policy director and his new DEP secretary all have served under former Governor Ed Rendell and helped to implement his Growing Greener programs, perhaps signaling a cautionary tale for those in the fracking community in general.

Coupled with an early public stance proposing to tax shale gas extraction in Pennsylvania, Governor Wolf has already raised the eyebrows of the Marcellus Shale Coalition and its related allies. It is not a far of a leap of faith to expect the DEP study will be read differently by a Wolf official as opposed to a Corbett appointee.

In the end, Governor Wolf's influence of Department of Environmental Protection could lead to the study being used to add new regulations or perhaps make changes to internal policies for spill protection, the treatment of waste and further studies for the adoption of specific TENORM best practices and protocols. Expect both sides of this important environmental issue to continue to vigilantly "watch dog" the progress and utilization of the TENORM report.

Gas & Oil

May 2015

Pennsylvania Edition

Federal fracking rules

rolled out

Sophie Kruse Dix Communications n March 20, the Obama administration unveiled the first major federal regulations on fracking that have been in the works for four years.

These regulations are expected to be the first in a series governing safety in fracking. It’s expected that the administration will also issue regulations to cut the release of methane from fracking wells.

The regulations will take affect in June and allow governmental workers to inspect and validate the safety of concrete barriers that line fracking wells. The regulations will also set standards of safety for how companies can store used chemicals around well sites from fracking, as well as requiring companies to submit information to the Bureau of Land Management on well geography. The Bureau is part of the Interior Department.

It will also require companies to disclose publicly the chemicals that are used in the fracking process within 30 days of completing operations on an industry-run website called FracFocus. The site also allows anyone to log on and see where sites have been drilled and the chemicals that were used.

The new regulations are designed mainly to protect groundwater.

The new federal rules will cover nearly 100,000 gas and oil wells on public lands. Before these regulations were released, the states had jurisdiction over state-owned and private land in the United States. Federal land produces 5 percent of oil and 11 percent of natural gas that is consumed in the US. Private and state-owned land won’t be required to follow the new federal standards. More than 90 percent of new land wells in the United States use fracking.

According to the Interior Department, the agency worked closely with oil and gas companies, environment groups and state authorizes to develop the new regulations — along with reviewing more than 1.5 million public comments.

The Independent Petroleum Association of America has filed a lawsuit to challenge the regulations. They call them

O

“a reaction to unsubstantiated concerns.” The Association claims that fracking has been a vital part in recovering the economy in America and that the regulations will negatively affect the growth.

For states that regulate fracking, rules like this have already been in place and companies have been complying.

Estimates say that new regulations would add $11,400 to the cost of fracking for each well. That ends up being less than one percent of the cost of drilling. Industry wide, the cost would be $32 million.

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Gas & Oil

Historic photos courtesy of the Ohio History Connection & EnergyFromShale.org

May 2015

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Gas & Oil

Pennsylvania Edition

May 2015

E

dwin Drake is known as the father of the modern oil industry giving rise to drilling operations in Pennsylvania in the 1850s, but he may not have been in a position to make such a monumental contribution to the business if not for his years of employment as a railroad conductor.

Drake is credited with constructing the first oil well, “Drake Well,” after oil collections from “seeps” — a spot where oil naturally seeped from the ground — and whaling efforts failed to meet the growing demand for oil to lubricate new types of machinery.

That well was located in Titusville, Pa. Born in New York in 1819, Drake worked a variety of jobs before joining the railroad in 1850 as a conductor.

But after only seven years, Drake was forced to retire from the railroad due to his ill health. He could no longer carry out the duties of a conductor, but his retirement came with a benefit that would serve him well in his next employment for the Seneca Oil Company.

In search of someone to inspect their new operations in rural Pennsylvania where oil was collected from seeps, Seneca Oil’s George H. Bissell and Jonathan G. Eveleth came across Drake, who was looking for employment after his career with the railroad came to a sudden end.

www.GasandOilMag.com

It was a perfect match as one benefit afforded to Drake upon his retirement was free railroad travel. Given they would have far fewer travel expenses with Drake, Bissell and Eveleth hired him for the job.

Faced with the growing demand for oil, Drake began to seek ways to improve the production from the rural seeps, which produced only small amounts of oil at a given time.

The answer was logical — dig into the ground to get the oil — but not practical, as nobody had invented a way to get the oil from deep in the earth.

Drake’s initial attempt to dig into the ground was a mine, but that ended in failure when the mine shaft flooded.

Drake then focused his efforts on drilling into the ground to obtain the oil.

Basing his efforts on drilled salt mines, Drake created the oil well nicknamed by locals as “Drake’s Folly” in 1859 with the help of blacksmith William “Uncle Billy” Smith, a local resident.

The first efforts were slow at best, drilling just three feet per day, but the men were persistent.

Each day they continued to drill deeper into the ground and on Aug. 27, they reached a depth of 69 feet before stopping for the day.

When Smith arrived for work the next day, he made a star-

Gas & Oil

May 2015

13

tling discovery — the oil had risen to the ground through the well. The design created by Drake and the hard work of both men had paid off in the form of a steady supply of oil.

The well, known locally as Drake’s Folly, was named Drake Well and became the first producing oil well.

The oil was funneled into whiskey barrels with an estimated 400 gallons of oil being produced daily. The productivity far exceeded the small amounts collected from the seeps.

The Drake Well paved the way for more oil wells to be constructed by Seneca Oil Company and its competitors, as Drake never patented his methods.

The result was an oil boom in western Pennsylvania, with wells capable of producing thousands of barrels of oil daily.

The boom resulted in oil prices dropping to such a low that Drake and Seneca Oil Company were forced out of business. Reports say Drake only drilled two more wells before living most of his remaining live in poverty.

Drake’s invention made drilling oil wells a practical part of the oil business and laid his claim to history.

The State of Pennsylvania and its legislators awarded Drake a pension in 1870 for his efforts in the oil business — a pension he only collected for 10 years before his death in 1880.

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Gas & Oil

May 2015

Pennsylvania Edition

The Upper Devonian Burket/Geneseo Shale Appalachia’s Little Brother to the Utica and Marcellus Gregory Wrightstone - Wrightstone Energy Consulting WrightstoneEnergy.com

T

he Marcellus Shale has dominated the energy headlines for news coming out of the Appalachian Basin for the last 8 years or so and for good reason – its vast natural gas resources and production have almost singlehandedly transformed the entire energy marketplace in North America. The Utica Shale has also garnered a lot of attention for continuing consistent success in the wet gas window and some recent eye-popping initial production rates in the dry gas window.

Flying under the radar is Appalachia’s 3rd resource shale play, the Burket/Geneseo Shale. Less flashy, with lower initial production numbers, the shale is unlikely to challenge the other “Big 2” shales for size of resource potential, although total reserves may be significant. It is likely that the play will benefit from its “stacked pay” potential that allow companies to decrease drilling and production costs through utilization of existing well pads and infrastructure, liquids-rich production in some areas and possible flat decline rates. As of mid-April, 2015 a total of 85 Burket/Geneseo horizontal wells have been completed as productive in Pennsylvania (64) and West Virginia (21).

Geology – The Upper Devonian Burket/Geneseo Shale is the organic-rich mudstone that lies immediately above the Tully Limestone (figure 1). The correct scientific name for this shale is Burket (with one “t”) across all of West Virginia and most of Pennsylvania, while Geneseo is accepted terminology in northwest Pennsylvania and New York. The thickness of the shale expands from only a few feet in western West Virginia to

more than 150’ in its depo-center in central Pennsylvania. Drilling depths increase from less than 4,500’ in NW PA to more than 7,500’ in the center of the Basin.

Figure 2 utilizes Gamma Ray Foot (GRFT) mapping to combine thickness of the unit with quality as measured by Total Organic Carbon (TOC). Two “sweet spots” of better quality are mapped, with most of the current productive wells located within these southwest and northern pods of increased reservoir quality.

The key geologic controls on production are projected to be similar to that controlling the Marcellus Shale including thickness and rock quality as mapped by the GRFT mapping. Little hard data is available on pressure gradients, but early indications and personal communication indicate that the unit is significantly over-pressured, enhancing production capabilities. As with the Marcellus, structural complexity is a key negative to production performance and complicates geo-steering. Additionally, since the Burket/Geneseo is significantly thinner than the Marcellus, additional geo-steering challenges are presented to the operator to stay in the sweet zone of high TOC and rotary steerable drilling may be the optimal solution.

Production – A relatively small database of wells have long term production data available via state reporting agencies, but provide enough information that some early projections can be advanced. Analysis of the available production, combined with geologic mapping allow us to identify the Northern and Southwestern Core Areas within which the highest performing

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Burket/Geneseo wells are located (figure 3). A total of 27 wells have at least one full year of production available.

The Southwest Core Area encompasses an area of 1.4 million acres and is the better of the two areas based on limited data.

Five wells have at least one year of production data and average 1.5 BCFe in their first twelve months on line. Additional analysis of peak daily production confirms the general outline of this area. Wells surrounding the Southwest Core Area have significantly reduced production volumes and average just 470 MMCFe in 12 months.

The Northwest Core Area covers an area of about 800,000 acres, but is less proven and may not reach the production potential of the Southwest Area. Six (6) wells on production had average first year production of ~700 MMCF. Wells surrounding this Core Area produced only 225 MMCF during the time period.

Economics and Resource Potential – Production rates from the Burket/Geneseo, while strong, lag significantly when compared to the Marcellus and Utica results. Economic analysis using a well cost of $6.0 million (4,800’ lateral), Marcellus type decline and gas price of $3.00/MCF (dry gas) indicate that only the “Southwest Core of the Core” is economic in today’s depressed market conditions.

Some significant upside potential exists that may increase economic viability for the reservoir.

• Flat decline - Analysis of Burket/Geneseo wells in the Southwest Core Area show production declines to be much flatter than published Marcellus decline rates. In a recent presentation, Consol reported that their first Burket/Geneseo well, located in Washington County, PA had an EUR of 9 BCFe (1.8 BCFe/1000’) based on actual production, compared to predicted type decline curve estimates of 5.8 BCFe (1.2 BCF/1,000’).

• Lower AFE Costs - Drilling and completion costs can likely be reduced via utilization of existing drilling pads and infrastructure • Liquids/Wet Gas – Much of the Southwest Core Area has wet to very-rich wet gas and the economics of these wells can by significantly enhanced through liquids production and increased BTU. Technically recoverable re-

Gas & Oil

May 2015

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serves in the Southwest Core of the Core are projected to be 29 TCFe with another possible 52 TCFe if the remaining core areas prove viable. These numbers are likely to expand if the flatter decline is confirmed, leading to increases in EURs. It is likely that most companies will continue to focus the bulk of their precious CAPEX on the more lucrative Marcellus and Utica reservoirs to get their best “bang for the buck” in the short term, but the Burket/Geneseo holds good potential for substantial future development.

16

Gas & Oil

May 2015

Pennsylvania Edition

2nd major gas pipeline

would link Pennsylvania, Northeast S

Mary Esch - Associated Press CHOHARIE, N.Y. (AP) — New York landowners along the planned 124-mile Constitution Pipeline are getting details of a second major natural gas pipeline proposed to cut through their property, this one a 325-mile link from Pennsylvania to New England.

Construction workers in economically distressed southern New York are ecstatic about the job possibilities, but landowners who have been fighting the first pipeline for three years are dismayed at the prospect of going through the whole process a second time.

“You think about the worst things that can happen to you in a life and I’ve had some things happen to me in life, but this is right up on the scale,” landowner Dan Brignoli said this week at the first open house held in New York for the $4 billion Northeast Energy Direct project planned by Houston-based Kinder Morgan.

A right of way through the property where Brignoli and his wife built their home 40 years ago in Davenport was taken by eminent domain two weeks ago for the Constitution Pipeline, the furthest-along of a slew of projects planned to pipe cheap gas from the massive Marcellus Shale region in Pennsylvania to gas-hungry New York City and New England. A federal court will determine the Brignolis’ compensation.

Constitution plans to break ground this summer if a critical state permit is issued. Northeast Energy Direct, which would have to obtain a second right of way if it’s routed across Brignoli’s land, is scheduled to file a formal application with the Federal Energy Regulatory Commission this fall and break ground in January 2017. The exact route is still being fine-tuned.

“Eminent domain is a very touchy subject, but in this country a lot of things were taken for the greater good, for the interstate highways and other projects,” said Josh Shaul, a member of the New York State Laborers’ Union who was among a large contingent of orange-shirted union members at the pipeline meeting in Schoharie. “This project is good for jobs, good for the community.”

Union spokesman Frank Marchese Jr. said Kinder Morgan has agreed to use union labor and local workers, noting that pipeline workers typically earn $27 an hour and work 60 hours a week for nine months to a year.

“Everybody prospers when a pipeline comes through an area,” Marchese said.

The latest proposal, a 36-inch high-pressure pipeline that would be part of the extensive Tennessee Gas Pipeline network that already includes 849 miles of pipeline in New York, would run about 325 miles from Pennsylvania through New York, Massachusetts and New Hampshire.

Strenuous opposition in Massachusetts led it to shift much of its route to New Hampshire, where it would follow the route of an existing power line.

In New York, most of the Northeast Energy Direct Pipeline would follow the same route as the Constitution Pipeline northeast to an interconnect station in Schoharie County, and from there would be co-located with Tennessee Gas Pipeline’s existing system and a utility corridor.

Open houses on the pipeline are scheduled for Monday in Schodack and Tuesday in Richmondville. Two others are planned in Pennsylvania: Wednesday in New Milford and Thursday in Towanda.

Opponents say the pipelines will reduce property values, pose safety risks and environmental harms, and prolong dependence on fossil fuels rather than investment in renewable energy.

Many opponents also maintain that the real goal of the pipeline build-out in the Northeast is intended to sell the gas at higher prices overseas via export terminals proposed in Nova Scotia and northern Maine.

“This is not local gas for local people,” said Loddie Marsh of Sidney, whose neighbor’s land was taken by eminent domain for the Constitution Pipeline.

Kinder Morgan says the Northeast Energy Direct pipeline is being built to serve Northeast customers, including local distribution companies, electric utilities, and industries.

But it says four proposed liquid natural gas export projects in Atlantic Canada and one in Maine could find the Northeast Energy Direct project useful, and the pipeline company can’t discriminate against customers based on ultimate use or destination of the gas.

The company said it has commitments so far from National Grid, Liberty Utilities, Columbia Gas of Massachusetts, Connecticut Natural Gas Corp. and other anchor shippers to transport about 500 million cubic feet of natural gas per day. The pipeline’s capacity is from 1.2 billion to 2.2 billion cubic feet of gas per day.

Gas & Oil

www.GasandOilMag.com

May 2015

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Photo: Tennessee Gas Pipeline representatives Curtis Cole, left, and Jay Pugh listen to pipeline opponent Loddie Marsh at an open house with landowners along the proposed Northeast Energy Direct pipeline on Monday, April 6, 2015 in Schoharie, N.Y. The project’s proposed route from Pennsylvania’s gas fields to New England will cross the property of many New York landowners who have waged a losing battle against the Constitution Pipeline for three years. (AP Photo/Mary Esch)

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Gas & Oil

Pennsylvania Edition

May 2015

BELMONT COUNTY NAMED FINAL CANDIDATE FOR POSSIBLE PETROCHEMICAL FACILITY

C

OLUMBUS — Today Governor John R. Kasich announced that PTT Global Chemical(PTTGC), Thailand’s largest integrated petrochemical and refining company, and its project partner, Marubeni Corporation, a Japan-based company, have selected a site in Belmont County, Ohio for the possible construction of a world-scale petrochemical complex, also known in the industry as an ethane cracker. With a site now selected, PTTGC and Marubeni will take the next 12-to-16 months to complete the detailed engineering design and permitting at the Ohio site.

For nearly two years, PTTGC and Marubeni have considered project sites across the Utica and Marcellus shale region. JobsOhio, the private, non-profit corporation designed to drive job creation and capital investment in Ohio, has worked with the companies throughout this time and led the effort to move this project forward in Ohio.

“Ohio is at the center of America’s new energy industry, and the smart companies want to come here to be part of the great things that are happening. We are one step closer to landing a new, multi-billion dollar investment in eastern Ohio, and that’s exciting news for our state, the region and Belmont County,” said Kasich. “There is more work ahead before final decisions on this project are made, but I know our Ohio team will do everything we can to bring it fruition. We are excited about the possibility of working with companies of the caliber of PTTGC Global and Marubeni.

A project of this size can help lift the region forever.”

If constructed, the ethane cracker would utilize ethane extracted from the region’s Marcellus and Utica Shale formations. The facility would then “crack” the ethane into ethylene, which is used as a basis for plastics and resins contained in everyday items such as food and product packaging, textiles and pharmaceuticals.

“Working with JobsOhio and the state over the past two years has been a positive experience and we look forward to moving this project into the next phase,” said Dr. Kongkrapan Intarajang, Executive Vice President of International Business Relations for PTTGC. “While we have not yet made final decisions on this investment, we will continue to work with Governor Kasich, JobsOhio and all of the local partners in an effort to make our vision a reality.”

John Minor, President and Chief Investment Officer of JobsOhio, added, “This project has been a truly collaborative effort, resulting in this good news for eastern Ohio and the state. JobsOhio’s David Mustine and Matt Cybulski played leading roles working with PTTGC and Marubeni

along with our regional partner Appalachian Partnership for Economic Growth and local development partners. I thank them for playing such integral roles in advancing the project to this point. An ethane cracker in Belmont would facilitate additional investments in the growing shale and petrochemical industries, and with greater investments come more job opportunities for Ohioans.

PTTGC and Marubeni are expected to make a final investment decision in 2016. Should the project move forward, construction of the ethane cracker facility would take an estimated three and a half years to complete

About PTT Global Chemical

PTT Global Chemical PCL conducts its business in the Petrochemical and Chemical Sectors. It was ranked in the Top 10 of the Dow Jones Sustainability Indices (DJSI) for the second consecutive year and was ranked twenty-second among world-leading petrochemical companies on the ICIS Top 100 Chemical Companies listing. The company has seven main business lines and currently has the production capacity of chemical and petrochemical products of 8.8 million ton/year and the refinery capacity of crude oil and condensates of 280,000 Bbl/Day. In addition, it places high value on making investment to expand to specialties chemical products and green chemicals.

About Marubeni Corporation

Marubeni Corporation was founded in 1858 and is headquartered in Tokyo, Japan. Through its local and international network, Marubeni Corporation provides products and services in a broad range of sectors, encompassing import and export as well as transactions in the Japanese market, related to food materials, food products, textiles, materials, pulp and paper, chemicals, energy, metals, machinery, finance logistics, information technology, infrastructure development and a range of other fields, including resources development and investments on a global level.

About JobsOhio

JobsOhio is a private, non-profit corporation designed to drive job creation and new capital investment in Ohio through business attraction, retention, and expansion efforts. Learn more at jobs-ohio.com.

About APEG

The Appalachian Partnership for Economic Growth (APEG) is one of six JobsOhio Regional Network Partners. APEG works to accelerate sustainable business growth, job creation and advancing the economy of Southeast Ohio.

Gas & Oil

www.GasandOilMag.com

May 2015

Protecting utility lines

Linda Hall - Dix Communications OOSTER — With the arrival of spring and excavation projects – large and small – get underway, underground utility line safety must be a priority.

“Any time you’re putting a shovel in the ground,” the utility lines must first be marked, said Lee Richards, public awareness & education supervisor for Ohio Utilities Protection Service, emphasizing that the rule is actually a state law.

There is no depth measurement in the protocol, according to Richards. Anyone digging below the surface of the ground, even if it seems to be a shallow amount, must make the call.

But the simple way to contact officials before digging is to merely dial 8-1-1.

A person calling 8-1-1- in Pennsylvania will get a Pennsylvania contact; the same is true for Ohio or any other state.

The 8-1-1 call center operates nationwide, Richards said.

“Any time you do any digging in the state of Ohio,” she said, the person excavating on a large or small scale for a big project or a little one is required to call 48 hours ahead of time to get the utility lines marked.

The Ohio Utilities Protection Service takes the information and notifies utility companies that are members, she said. Sub

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sequently, the owner of the lines “does the marking of the lines.”

It is a common misconception, according to Richards, that the Ohio Utilities Protection Service is responsible for marking the lines, but this is not accurate. Rather, the Protection Service is a link.

“The owners of the utility lines mark their own lines,” after being contacted, she stressed.

Information about the importance of making the 8-1-1 call is available on the Northeast Gas Association website, which urges homeowners against making “risky assumptions about whether or not they should get their utility lines marked.”

Every digging job demands marking lines, “even small projects like planting trees and shrubs,” the website says, noting, “The depth of utility lines varies and there may be multiple utility lines in a common area.”

Marking of lines is free and prevents disrupting service to entire neighborhoods or dangerous consequences such as injury from occurring.

The “Call Before You Dig” 8-1-1 campaign has been spearheaded by Common Ground Alliance (CGA), an organization working with the industry to protect underground utility infrastructure and to promote public safety and the environment.

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Gas & Oil

Pennsylvania Edition

May 2015

Cove Point Breaks Ground:

A New Era in American Energy M

Joe Massaro - Energy in Depth aryland Governor Larry Hogan recently participated in the groundbreaking event for the expansion of the Cove Point LNG facility.

This is an important milestone, considering the Cove Point facility was originally constructed to import liquefied natural gas (LNG) from foreign countries to the United States during a period of energy scarcity.

Now, thanks to abundant supplies of natural gas unlocked through hydraulic fracturing, the Cove Point facility is being expanded into an export facility.

Pennsylvania’s Marcellus Shale now produces 14.4 billion cubic feet of natural gas per day and accounts for 36 percent of U.S. shale gas production. Without the success of this shale play, the Cove Point facility likely would have remained an import facility.

The Cove Point facility also goes to show how far-reaching the economic benefits of shale development are. As EID previously noted, the $3.8 billion project will create three thousand shovel ready jobs during the three years it will take to construct the facility and then 75 new permanent jobs once it’s running. The facility will also provide a long term revenue stream for Calvert County to the tune of $40 million a year on average. According to Governor Hogan: “The Cove Point expansion is one of largest private investments ever in Maryland and designed to bring both economic and environmental benefits to Maryland.

Through this project, Maryland will have the ability to share some of America’s new found energy production capabilities with overseas markets – in places like Japan and India.”

Because of Japan’s geology they aren’t as natural resource-rich as the United States. This has created the opportunity for the United States to strengthen relations with one of our key allies by providing them with cheap abundant energy produced here, in America.

Further, thanks to the increased use of natural gas from hydraulic fracturing, the United States has been able to significantly reduce greenhouse gas emissions. We now have the opportunity to help our allies lower their emissions and greenhouse gases on a global scale through LNG

exports. As a recent peer reviewed study from Carnegie Mellon University concludes: “From a global emissions perspective, this study has shown that exporting LNG can help to reduce life cycle GHG emissions from electricity generation and industrial heating.”

Governor Hogan will soon be making a decision on whether to proceed with hydraulic fracturing in Maryland.

With part of the Marcellus Shale underlying two Maryland counties and the groundbreaking of the Cove Point facility it just doesn’t make sense to continue stalling the development that would bring huge economic and environmental benefits to the state.

Joe Massaro is a spokesman for Energy In Depth – Marcellus.

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