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Expo/Industry events for the next few months

The New Upstream PA 2018
May 17, 2018
Penn Stater Conference Center
State College, PA
www.upstreampa.com

Appalachian Storage Hub Conference
June 7, 2018
Hilton Garden Inn, Southpointe
Canonsburg, PA
https://www.appastorage.com/

For other events visit http://www.shaledirectories.com/site/oil-and-gas-expo-information.html

Latest facts and a rumor from the Marcellus, Utica, Permian, Eagle Ford, Bakken and Niobrara Shale Plays

Ohio Valley Oil & Gas Expo Update.  Kudos to Natalie Brown and the MRP Supply Chain for another successful expo.  As always, these events are great sources of information.  Some the comments coming out of the expo are:

  • XTO is bringing two more rigs up to the Appalachian Basin
  • Paterson Universal has 31 rigs in the Appalachian Basin
  • Gulfport has two working rigs in the Utica and has six that have been laid down.
  • Ascent is certainly the most active E&P Company in the Utica.  It’s securing about five permits a week.

Gulfport Focusing on the SCOOP.  Gulfport Energy released an initial look at the company’s first quarter operations.   In 1Q18, when you role everything together (methane, NGLs and oil) converting it all to natural gas “equivalent,” Gulfport produced 92,772 million cubic feet equivalent (MMcfe), versus producing 67,559 MMcfe in 1Q17–a 37% increase year over year. However, what you can’t ignore in this update is that Gulfport has really turned up the activity in the Oklahoma SCOOP. In 1Q18 Gulfport brought online 3 Utica wells, but 7 SCOOP wells. In 1Q18 Gulfport produced 22,103 MMcfe in the SCOOP, versus producing just 7,398 MMcfe in the SCOOP a year ago in 1Q17–a 198% increase. The conclusion is inescapable: the SCOOP is ascending for Gulfport, occupying the company’s time, attention and money.

EQT 1st Qtr. Financial Update.  E QT Corporation announced financial and operational performance results for the first quarter 2018.

Highlights:

    Announced plan to separate midstream and upstream businesses

    Announced midstream streamlining transaction details

    Recorded $2.3 billion non-cash impairment charge for Huron and Permian Plays

    Increase in adjusted operating cash flow of 116%

    Decrease of 26% in Production’s per unit cash operating costs

Wells Drilled (spud)

                                    Marcellus                   Upper Devonian        Ohio Utica (net)

Q1 2018                          24                                      2                                   6

2018 Forecast               134                      16                                  25

Q2 2018 Forecast      35 – 40                            3 – 5                             8 – 10

 

    Q1 2018 average lateral lengths: Marcellus 14,000; Upper Devonian 16,800; Ohio Utica 11,700

    2018 forecasted average lateral lengths: Marcellus 12,600; Upper Devonian 15,800; Ohio Utica 11,000

Wells Turned-in-line (TIL)

                               Marcellus                        Upper Devonian        Ohio Utica (net)

Q1 2018                      25                                            5                                   4

2018 Forecast     160 – 170                             20 – 25                         20 – 25

Q2 2018 Forecast  48 – 53                                    3 – 5                          4 – 6

 

    Q1 2018 average lateral lengths: Marcellus 7,900; Upper Devonian 11,300; Ohio Utica 10,000

    2018 forecasted average lateral lengths: Marcellus 8,700; Upper Devonian 11,300; Ohio Utica 11,500

Cabot 1st Qtr. Financial Update.  Cabot Oil & Gas Corporation reported financial and operating results for the first-quarter of 2018.

First-Quarter 2018 Highlights

  • Daily equivalent production of 1,884 million cubic feet equivalent (Mmcfe) per day, exceeding the high-end of the Company's guidance range
  • Net income of $117.2 million (or $0.26 per share); adjusted net income (non-GAAP) of $128.5 million (or $0.28 per share)
  • Net cash provided by operating activities of $272.8 million; discretionary cash flow (non-GAAP) of $280.3 million
  • Free cash flow (non-GAAP) of $88.6 million, marking the eighth consecutive quarter of positive free cash flow
  • Returned $234.8 million of capital to shareholders through dividends and share repurchases
  • Improved operating expenses per unit by 21 percent relative to the prior-year comparable quarter
  • Completed the previously announced divestiture of the Company's Eagle Ford Shale assets

Marcellus Shale Operational Highlights

During the first-quarter of 2018, the Company averaged 1,822 million cubic feet (Mmcf) per day of net Marcellus production, an increase of three percent sequentially compared to the fourth-quarter of 2017 despite the Company not placing any wells on production during the quarter. During the second-quarter of 2018, the Company plans to place 20.0 net wells on production, of which 16.0 net wells have already been turned to sales. Cabot expects to place an additional 60.0 net wells on production during the second half of the year to allow for the anticipated increase in production volumes associated with the in-service of new infrastructure projects beginning in June.

Cabot is currently operating three rigs and two completion crews in the Marcellus Shale.

There was nothing in the report about the Ashland County, Ohio initiative.

Range 1st Qtr. Financial Update.  Production in the first quarter of 2018 for Range Resources averaged a record 2.19 billion cubic feet-equivalent per day (Bcfe/d), an increase of 13% compared to the first quarter of 2017, Kallanish Energy reports.

That includes 1.5 Bcf/d of natural gas, 103,000 barrels per day of natural gas liquids, and 11,816 BPD of oil and condensate.

The production makes Range one of the 10 largest natural gas producers in the U.S. and a Top 3 NGL producer, which provides leverage to improve pricing, the company said.

The Texas-based company during the quarter also drilled its two longest-ever laterals: at 18,129 feet and 17,875 feet, both in the Appalachian Basin.

The company said it drilled laterals in Q1 2018 that were 21% longer than laterals drilled in Q4 2017.

Range reported Q1 net income of $49.2 million, down considerably from $170.1 million in the year-ago quarter.

"The first quarter was a good start to the year, generating record quarterly cash flow while remaining on track to deliver our expected 11% growth within cash flow for 2018,” said CEO Jeff Ventura, in a statement.

“Operationally, Range is focused on translating our peer-leading inventory into shareholder value as efficiently as possible. This effort is led by the Marcellus, where record-long laterals and the utilization of existing pads and infrastructure are a tailwind for capital efficiencies, positioning us to deliver on the long-term growth within cash flow we demonstrated in our five-year outlook.”

Ventura added Range is focused on de-leveraging its balance sheet as swiftly and prudently as possible via asset sales. He said Range has "various processes underway and believe we can execute one or more successful sales in the current year, which would improve our balance sheet and corporate returns.”

Production in the first quarter in the Appalachian Basin averaged 1.81 Bcfe/d a 20% increase year-over-year, Range reported.

Production in southwest Pennsylvania averaged 1.68 net Bcfe/d during the quarter, a 25% increase over year-earlier quarter, it said.

Production in northeast Pennsylvania averaged 116 million cubic feet per day (MMcf/d), a 20% decrease from the prior-year quarter.

The company brought online nine Marcellus wells in the first quarter, two in the super-rich area and seven in the wet-gas area.

In 2018, Range plans to bring online 100 wells and is expecting to average five rigs in the Appalachian Basin this year.

It reported net natural gas production in Q1 exceeded 1.2 Bcf/d, a quarterly record. Net NGL production in Appalachia was 89,000 BPD. Overall NGL production was 103,000 BPD in Q1, a 9% increase over Q1 2017.

EQT 1ST Qtr. Financial Update.  EQT Corp. reported a $1.59 billion net loss in the first quarter of 2018, Kallanish Energy reports.

That compares to net income of $164 million in Q1 2017.

The net loss in the first quarter was due to an impairment charge of $2.3 billion associated with the Huron and Permian Basin plays, the company said.

The company said its adjusted net income was $268.3 million, compared to $75.9 million one year ago.

EQT's sales volume in Q1 was 357.0 billion cubic feet-equivalent (Bcfe), up from 189.9 Bcfe one year ago.

Operating revenue in Q1 was $1.35 billion, up from $828.7 million.

The company in Q2 expects to produce 360 to 370 Bcf of natural gas for sales, along with about 4.5 million barrels

(MMBbl) of liquids. It produced 329.4 Bcf of natural gas in Q1 2018.

In the quarter, the company spud 24 Marcellus wells, two Upper Devonian wells and six Ohio Utica wells. It turned in line 25 Marcellus wells, five Upper Devonian and four Utica wells, it reported.

EQT said it plans to spud 35 to 40 Marcellus wells in Q2, along with three to five Upper Devonian and six to 10 Ohio Utica wells.

For full-year 2018, the company said it plans to drill 134 Marcellus wells, 15 Upper Devonian and 25 Ohio Utica wells.

In Q1, the average lateral length was 14,000 feet in the Marcellus, 16,600 feet in the Upper Devonian, and 11,700 in the Ohio Utica, it said.

The lateral lengths for full-year 2018 are projected to be 12,000 feet in the Marcellus, 15,800 feet in the Upper Devonian and 11,000 feet in the Ohio Utica.

EQT said it's proceeding with plans to separate its upstream and midstream businesses, an effort that should be completed by the end of 2018's third quarter.

The company also announced it's selling its Permian Basin assets in West Texas and New Mexico for $64 million. The sale will reduce production by 5 Bcfe. The buyer was not identified.

Antero 1st Qtr. Financial Report.  Antero Resources reported net income of $15 million in the first quarter of 2018, down substantially from $268 million one year ago, Kallanish Energy reports.

Net daily gas-equivalent production averaged a record 2.38 billion cubic feet-equivalent per day (Bcfe/d) in Q1 2018, the Denver-based company reported. That was an 11% increase over Q1 2017, with 26% of production liquids, Antero said.

“We are off to a strong start in 2018, with record first-quarter results that delivered strong cash flow growth during the quarter,” said chairman and CEO Paul Rady, in a statement.

Results were boosted by strong Utica Shale production and a focus on liquids in the Marcellus Shale, he said.

Antero said its realized natural gas price averaged $3.14 per thousand cubic feet before hedging in the first quarter.

The company said liquids production averaged 102,798 barrels per day in Q1, a 4% increase from the year-ago quarter, while contributing 35% of total production revenue before hedging.

During the quarter, Antero completed and placed into service 16 Marcellus wells with an average lateral length of 9,100 feet and a 30-day production rate of 19.8 MMcfe/d.

It plans to operate five rigs and four completion crews in the Marcellus in 2018. The company reported it took 11.5 days to drill the typical Marcellus well, a 6% reduction from 2017.

Antero is getting ready to begin production on its two largest pads, each with 12 wells. They have 120,000 lateral feet and 106,000 lateral feet, respectively.

In the Utica Shale, Antero placed five horizontal wells into production in Q1, with an average lateral length of 9,200 feet. It took 15.5 days to drill, a 7% decrease in time from 2017. The company plans to operate one drilling rig and one completion crew in the Utica in 2018.

Antero is working to complete five Utica wells in Ohio, including four wells with an average lateral length of 17,400 feet. Those are the company’s longest wells drilled and completed to date. They are expected to begin production next month, the company said.

Last December, Antero placed 10 Ohio wells with an average lateral length of 10,200 into service. They were Antero’s first wells in the Utica’s dry gas window. Those wells have produced more than 24 Bcf of dry gas to date (20 MMcf/d average well) and show no signs of decline, it said.

Rover Update on FERC Approvals.   The Federal Energy Regulatory Commission on Wednesday gave Rover Pipeline approval to begin service at a compressor station and 51 miles of Mainline B pipeline between Crawford and Wayne counties in northern Ohio, Kallanish Energy reports.

The company’s request to begin service on the 100-mile-long Market Segment from Defiance in northwest Ohio to Michigan and other compressor and meter stations on the $4.2 billion project is still pending.

Rover Pipeline, a subsidiary of Energy Transfer Partners, had filed its request with FERC on April 13.

Much of Mainline A is already in service and the pipeline is moving Utica and Marcellus Shale natural gas from Ohio, West Virginia and Western Pennsylvania to markets in the Midwest, Ontario and the Gulf Coast, while work is continuing on Mainline B and some laterals.

The company says 99% of the pipeline is complete and 83% of 49 sites for horizontal directional drilling under streams and highways are done.

The project has encountered problems going under the Tuscarawas River in Ohio and drilling was halted for a time by FERC. The Ohio Environmental Protection Agency also got involved over spills to waterways. West Virginia has also halted pipeline work because of local problems.

The 713-mile twin pipeline will move up to 3.25 billion cubic feet per day.

PA PUC Not Responding on Mariner East 1.  Ethane and propane had been flowing through the converted Mariner East 1 (ME1) pipeline safely for more than year, hauling the two natural gas liquids (NGLs) from southwest PA all the way to the Marcus Hook refinery near Philadelphia. However, ME1 was suddenly switched off on March 3 by order of the Pennsylvania Public Utility Commission (PUC) after a sinkhole opened up under the pipeline in Chester County, exposing some of the bare steel to the open air. Sunoco Logistics Partners, the owner of ME1, is building a new set of pipelines called Mariner East 2 (ME2) close to the existing ME1. Construction work in the area on ME2 led to the sinkhole that exposed ME1. The PUC shut down ME1 until further notice, requiring Sunoco to conduct a study of the area and provide the PUC with evidence to reassure them that ME1 is OK and will not leak or explode. Sunoco conducted the study, provided its results, and has told the PUC it’s time to restart ME1. But the PUC is dragging its feet, taking its time to review Sunoco’s work, and in no particular hurry to restart ME1–even though the outage is impacting the drilling program at companies like Range Resources.

Russians Are Funding the Sierra Club and the State of NY.  New Yorkers who are missing out on the natural gas revolution could be victims of Russian spy operations that fund popular environmental groups, current and former U.S. government officials and experts on Russia worry.

Natural gas development of the celebrated Marcellus Shale deposits has spurred jobs and other economic growth in neighboring Pennsylvania. But not in New York, which nearly 10 years ago banned the process of hydraulic fracturing, also known as fracking, to produce natural gas.

Two environmental advocacy groups that successfully lobbied against fracking in New York each received more than $10 million in grants from a foundation in California that got financial support from Bermuda company congressional investigators linked to the Russians, public documents show.

The environmental groups Natural Resources Defense Council and the Sierra Club Foundation received millions of dollars in grants from the San Francisco-based Sea Change Foundation.

Most recently, the two environmental groups scored another victory when the Delaware River Basin Commission, an interstate regulatory agency that includes the governors of New York, New Jersey, Pennsylvania, and Delaware, proposed a ban on fracking within the Delaware River Basin cutting across all four states.

The Sierra Club and the Natural Resource Defense Council have pressed the regional commission to impose the ban, issuing statements (here and here) calling for  restrictions that are tighter than what the commission proposed.

PennEast Pipeline Co. is set to begin construction on a 120-mile-long pipeline to transport natural gas from the Marcellus Shale across Eastern Pennsylvania into New Jersey. In a new public relations campaign, PennEast asks New Jersey residents if they would rather obtain their energy from Pennsylvania or Russia.

PennEast cites media reports describing how anti-pipeline policies in Massachusetts forced the state into a position where it had to rely on Russian imports of liquefied natural gas during peak cold periods this past winter.

The Russian Money Trail

Government officials and environmental leaders have a responsibility to track the money, Stiles, the former CIA officer, told The Daily Signal in an interview.

“The Russians are very adept and skilled at making long-term investments,” Stiles said. “They sit back very patiently to see how their funding can pay off over a period of many years.”

Stiles added:

Whether these environmental groups realize it or not, they could be operating as what we [in the CIA] call ‘agents of influence.’ By working to block natural gas production, environmental activists are advancing policies that work to the advantage of Russia and to the disadvantage of America and America’s allies.

Blue Racer Keeps Growing.  The privately held company quietly goes about its business in the Appalachian Basin. The company operates the largest network of gathering pipelines in the Utica Shale with more than 700 miles of pipelines, its so-called “super system,” said spokesman Cory Gerken, at a recent Utica Midstream conference in North Canton, Ohio.

That includes 531 miles of rich gas lines, 39 miles of lean gas lines, 101 miles of liquids and 50 miles of condensate lines, he said.

Serving Utica and Marcellus

Its processing has grown from about 200 million cubic feet per day (MMcf/d) in March 2014, to 400 MMcf/d in March 2015, to 700 MMcf/d today, according to a Kallanish Energy review of company data.

It serves 20 customers in the Utica Shale in eastern Ohio and the nearby Marcellus Shale in West Virginia and western Pennsylvania.

Blue Racer must remove the heavy hydrocarbons from the wet or rich natural gas to create the most value for its producers, and those natural gas liquid volumes are increasing.

The system serves the lean Utica and the rich Utica and nearby rich Marcellus areas.

Returning to wet gas window

Drillers had shifted away from the wet gas window in 2015 and 2016 toward the dry gas areas to keep costs down, but they are starting to re-emerge in the rich gas areas of the Utica Shale, Gerken said.

The company’s flagship Natrium processing plant on the Ohio River at Natrium, W. Va., can handle 450 MMcf/d of natural gas processing, and 123,000 barrels per day (BPD) of fractionation, he said. It also features 2,500 BPD of onsite condensate stabilization, he said.

The fractionator can accommodate up to 1.1 billion cubic feet per day (Bcf/d) as currently configured, and the company is developing an expansion to 1.4 Bcf/d, he said.

Natrium also offers pipeline, rail, truck and barge options for natural gas liquids shipments, he said.

Room to grow

Gerken said the Natrium site can accommodate two additional processing plants as currently configured, and could potentially handle two additional plants with appropriate site work. No Natrium expansions have been announced.

There are two cryogenic gas processing plants that can together handle 420 MMcf/d, Gerken said. There is also a condensate stabilization facility that can handle 10,000 BPD.

The site could accommodate two additional processing plants, he said, but no expansions have been announced by the company.

The Utica and Marcellus shales “are very, very important to Blue Racer Midstream” and production is expected to grow, he said.

Production in the Utica and Marcellus, now about 22 Bcf/d, is projected to grow by 14 Bcf/d over the next five years, according to the U.S. Energy Information Administration.

Formed six years ago

Blue Racer was formed in 2012 by Caiman Energy II LLC and Dominion Energy, who remain 50-50 partners. The Dallas-based company has assets of $2.4 billion and 160 employees, according to Gerken.

It inherited 406 miles from Dominion Energy and has added 316 miles since its formation.

Ethane is “very plentiful…and creates a major opportunity in the Appalachian Basin,” he said. The company is well positioned for shipping Appalachian Basin ethane to markets.

Blue Racer, he said, is shipping ethane on the ATEX, Mariner West, Sunoco Mariner East 1 and Kinder Morgan Utopia pipelines. Those shipments amount to 300,000 BPD, with half going south to the Gulf of Mexico on the ATEX pipeline, he said.

Plans call for shipments on the Mariner East 1 to grow by 20,000 BPD, after the Mariner East 2 Pipeline goes into service, he said.

The volume of ethane being shipped via the ATEX Pipeline may also be increased in the near future, he said.

A big impact

Blue Racer (it is named after an Ohio snake) is also in good position for propane and butane connections, Gerken said. It is shipping 50,000 BPD via the TEPPCO Pipeline and plans to ship 275,000 BPD via the Sunoco Mariner East 2. Its construction was halted recently by Pennsylvania due to sinkholes opening up near the line in eastern Pennsylvania.

That pipeline is going to have a big impact because it will change NGL pricing in the Appalachian basin and beyond by adding new markets domestic and international, he said.

Permian Analysis and Future Projections.  The pace of inbound questions to BTU about the gas market has been up in recent months with callers interested in discussing gas market dynamics in Oklahoma, Northern Louisiana, Rockies and Appalachia.  Our response to each of these requests are, ‘yes we can talk about the play of interest, but we are going to have to talk about the Permian as well, which demonstrates the expanse and extent of the current levels of activity in the Permian and subsequent impacts to the U.S. gas market.  In this Energy Market Commentary we will show in three charts why what happens in the Permian reverberates throughout the industry.  These charts are 1) depth of inventory, 2) Permian’s capture of U.S E&P CapEx and 3) Permian gas growth vs. total U.S. demand growth.

             

First the geographic size advantage of the Permian is impressive, however on an aerial acreage basis it ranks up there with the Bakken and Eagle Ford.  But when multiple drilling horizons are considered, even by the most conservative estimates of horizons that could potentially be developed, this doubles the size of potential developed “horizon acres” for the region, putting it in a league of its own in relation to other major plays as shown above.  Extensive inventory based on aerial and horizon acreage, in addition to favorable Permian breakevens (which we have covered in a previous post) , means that capital for infrastructure and drilling flows more freely to the Permian, allowing it to continue to disrupt North American gas regional balances for the long-term.

             

Second, the Permian is increasingly consuming a larger slice of total U.S. E&P CapEx. BTU estimates that by 2020 the Permian will grow to represent 40% of U.S. E&P CapEx (based on BTU Analytics’ Cash Flow Tool looking at horizontal activity only).  More Permian CapEx means more activity and production growth relative to other plays.

             

Adding insult to injury, BTU’s forecast calls for Permian gas growth to outpace US Demand growth from 2020 – 2023.  This means that all else equal, other plays will need to decline to accommodate Permian gas growth. Baring a major WTI price correction, Permian associated gas is going to impact all gas basins for years to come.  To follow these trends more closely request more information about BTU Analytics’ Upstream Outlook.

Gov. Justice to Expedite Permitting.  Gov. Jim Justice signed an executive order Monday intended to streamline the permitting process for business and industry seeking to set up shop in the Mountain State.

“West Virginia has consistently been ranked at or near the bottom amongst all states for our regulatory environment by publications such as Forbes and CNBC,” Justice said in a press release. “This is an area where we need to improve.

Like our President, Donald J. Trump, I have been very focused on regulatory reform and will aggressively continue those efforts in our state,” Justice said in the release.

According to the governor’s staff, the executive order would require expedited permitting for all projects, as well as prioritization of permits for projects of critical economic concern.

U.S. Shale Companies Reach Self-Financing.  The US shale oil revolution has reached a landmark moment, with the sector’s top companies for the first time earning enough cash to cover the cost of new wells. Since the shale oil boom began a decade ago, exploration and production companies have needed a steady inflow of capital to pay for drilling and completing new wells but thanks to the rise in crude prices, many can now finance themselves. The leading producers, which were just about covering their capital spending from their operating cash flows in the final quarter of last year, are now generating significant free cash, according to Wood Mackenzie, the research company. “It’s quite a windfall for a lot of these companies,” said Andrew McConn, of Wood Mackenzie, who noted that the larger US shale oil companies needed a crude price of about $53 a barrel to generate free cash.

PA Has Another Record Production Year.  Our favorite government agency, the U.S. Energy Information Administration, yesterday took a close look at natural gas production in Pennsylvania and how it has grown. A few interesting factoids: PA averaged a record high 15 billion cubic feet per day (Bcf/d) of natural gas production in 2017–3% higher than 2016. Most of PA’s natural gas production comes from the Marcellus Shale. PA production accounted for 19% of total U.S. marketed natural gas production in 2017. PA produces more natural gas than any other state except Texas. Several key pipelines have helped move some of PA’s enormous production to other markets.

NY Kills Another Pipeline.  New York State regulators have denied a permit for a pipeline expansion designed to increase natural gas deliveries to New York City, The Associated Press reports.

The Northeast Supply Enhancement project proposes to expand the Transco pipeline system, which extends from Texas to the Northeast coast. It would include installation of 17 miles of 26-inch pipeline underwater from New Jersey to the Borough of Queens.

The New York State Department of Environmental Conservation (DEC) said the application for a state water quality permit shows "potentially significant environmental impacts."

A spokesman for Tulsa, Okla.-based Williams Partners told AP the company intends to resubmit its application and work with DEC to satisfy conditions for permit approval.

Food and Water Watch, an environmental group, told AP it will continue to fight the pipeline and other fossil fuel infrastructure.

U.S. Becoming a Factor in the Petrochemical Global Market.  The trend has been swift and surprising: The U.S., once a laggard in petrochemical production, is quickly outpacing the Middle East in capacity thanks to a surge in natural gas from shale fields in West Texas and elsewhere. This year, research firm IHS Markit expects the United States to add 5.2 million tons of production capacity of natural gas-derived chemicals including ethylene, propylene and methanol, all used to make a wide range of plastics, building materials and consumer goods. That’s more than triple the production capacity slated to come online in the Middle East. The dramatic shift in regional production is centered on the need for ethane, the natural gas liquid that is the feedstock of choice for petrochemicals. Ethane has become scarce in the Middle East, but plentiful in the U.S. as a result of the shale drilling boom. Domestic ethane production is projected to increase nearly 60 percent to 2 million barrels a day by 2021, up from 1.26 million barrels a day in 2016, according to IHS Markit.

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PA Permits April 19, to April 26, 2018

             County                                        Township                                          E&P Companies

  1. Tioga                                            Liberty                                                Rockdale Marcellus
  2. Tioga                                            Liberty                                                Rockdale Marcellus
  3. Tioga                                            Union                                                 Rockdale Marcellus
  4. Washington                                 Cecil                                                    Range

OH Permits for week ending April 21, 2018

             County                                   Township                                          E&P Companies

  1. Guernsey                                    Millwood                                            Eclipse
  2. Jefferson                                     Smithfield                                          Ascent
  3. Jefferson                                     Smithfield                                          Ascent
  4. Jefferson                                     Wayne                                               Ascent
  5. Jefferson                                     Wayne                                               Ascent
  6. Jefferson                                     Wayne                                               Ascent

Joe Barone jbarone@shaledirectories.com 610.764.1232
Vera Anderson vera@shaledirectories.com 570.337.7149

Midstream PA