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Expo/Industry events for the next few months

Utica Midstream
April 4, 2018
Walsh University
North Canton, OH

The New Upstream PA 2018
May 17, 2018
Penn Stater Conference Center
State College, PA

Appalachian Storage Hub Conference
June 7, 2018
Hilton Garden Inn, Southpointe
Canonsburg, PA

For other events visit

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

PTTGC Is Getting Pressured to Make a Decision.  Some of the companies working with PTTGC are pressing them to make the final investment decision (FID) sooner rather than later. 

It also looks like Fluor may get nod over Bechtel.  As you know, Bechtel is the prime on the Shell cracker which may be why Fluor will get the nod from PTTGC.  However, Shell is controlling all the union workers in the Ohio River Valley now. 

We’ll certainly be tracking this.  (RUMOR)

Emerging Opportunities Ohio River Valley Conference. (Thank you, Bob Dowling, Kallanish Reports)

The Thrasher Group partnered with Shale Directories to present the Emerging Opportunities Ohio River Valley Conference which was a great conference to start the year.  It was very informative and below are the highlights of the conference.

One of the biggest problems blocking the potential expansion of petrochemical and plastics industries in the Appalachian Basin in the wake of shale drilling is a bias toward competing states on the Gulf of Mexico, Kallanish Energy reports.

Petrochemical companies would rather build in Texas and Louisiana, not in Pennsylvania, Ohio and West Virginia, said Mike Jacoby, vice president for business development with the Appalachian Partnership for Economic Growth (APEG), part of JobsOhio, Ohio’s private economic development agency.

Bias is real

That industry bias is a real issue and is perhaps the major hurdle for the newest economic development efforts in the Appalachian Basin, he said Thursday at the Emerging Opportunities Ohio River Valley Conference at Oglebay Resort, outside Wheeling, W.V.

The day-long conference on economic options facing the Appalachian Basin from shale drilling in the Marcellus and Utica shales was sponsored by the Thrasher Group, a West Virginia-based architecture-engineering-field services company, in cooperation with

What is envisioned to happen in the Appalachian Basin is a “transformative“ happening, said Chad Riley, CEO of the Thrasher Group.

“This is a life-changer,” said George Stark, director of external affairs for Cabot Oil & Gas, a major Marcellus producer.

The “Gulf bias is real,” not imagined, said Joshua Jarrell, secretary-legal counsel for the West Virginia Department of Commerce. “It’s the Appalachian Basin against the Gulf. It’s us against the world.”

Familiar with Gulf infrastructure

Petrochemical and plastics companies are more familiar with the Gulf states where an infrastructure has been developed, and that works against the Appalachian Basin, he said.

The Appalachian Basin has to work harder to get companies to consider taking advantage of shale-drilling opportunities because of the Gulf bias, he said.

The Appalachian Basin is also shipping product to the Gulf Coast and that doesn't help efforts to compete with Gulf Coast states, the pair said.

The Ohio River Valley will benefit from the three states working together, although there will “always be politics and competition,” Jarrell said. “For the good of the valley, it’s all good.”

Marcellus, Utica gas boom to continue

The natural gas boom in the Marcellus and Utica shales in the Appalachian Basin will continue, said Frank King of Williams, a major midstream operator.

The Appalachian Basin is expected to generate 75% of the U.S. natural gas production increase from 2017 to 2022, he said. That growth is projected to be an additional 17 billion cubic feet per day (Bcf/d) by 2022, he said.

A lot of that growth will be in the Appalachian Basin’s rich plays which are more capital intensive, with costly processing and fractionation facilities needed, he said.

Natural gas production in the Appalachian Basin has grown from 7.8 billion cubic feet per day in 2012 to 23.8 billion cubic feet per day in 2017. It is also producing nearly 1 million barrels of natural gas liquids, he said.

There is potential for even more growth after 2022, King said.

Ten years ago, Williams was not a player in the Appalachian Basin. Today it moves one-third of the natural gas in the basin. It is the largest gatherer in the basin and No. 2 in processing, according to King.

His company has operations in Pennsylvania, Ohio and West Virginia.

Petchem, plastics industries can thrive in Appalachia

The petrochemical and plastics industries in the Appalachian Basin could really take off with cheap ethane as a feedstock, said chief economist Kevin Swift, of the American Chemical Council.

The U.S. produces 25% of the world’s ethane and the Appalachian Basin produces 25% of that total, he said.

U.S. NGL production is expected to grow by 1.1 MMBPD to 1.3 MMBPD by 2022, enough ethane to supply up to seven new ethane crackers in the Appalachian Basin, Swift said. One is under construction and another has been proposed.

Foreign companies interested in U.S.

The shale impacts on the U.S. chemical industry will be sweeping with investments of $35.8 billion and 100,000 new jobs, he said.

Foreign companies are very interested in investing in the Appalachian Basin chemicals, Swift said. “The U.S. is the place to be. We’ve re-invented ourselves.”

In other conference news, West Virginia’s Jarrell, in response to a question, said plans for another ethane cracker near Parkersburg are technically still alive.

The plan was halted by “a corporate pause,” he said.

Brazil-based Odebrecht and subsidiary Braskem had proposed building the plant.

His office is still in touch with the companies, Jarrell said. “It’s still alive. It’s just kind of stalled,” he said.

Mountain NGL Storage to Looking for Final Approval.  David Hooker, president of Mountaineer NGL Storage, said Thursday he expects his company in March to submit paperwork for final state permits for an underground liquids storage facility in the Appalachian Basin.

He said he is optimistic Ohio regulators and Gov. John Kasich will approve the project in eastern Ohio by this summer. Construction could begin shortly after that, Hooker said at the Emerging Opportunities Ohio Valley Conference at Oglebay Resort, outside of Wheeling, WV.

The day-long conference drew roughly 200 attendees and was sponsored by the Thrasher Group, a West Virginia-based architecture-engineering-field services company, in cooperation with ShaleDirectories.

Good News from the Bakken.  Continental Resources announced last week it expects its net production to grow by 17% to 24% in 2018.

The company said it looks to spend $2.3 billion in capital expenditures in 2018, with the bulk of that money being spent in the Bakken Shale in North Dakota and Montana, and the SCOOP and STACK plays in Oklahoma.

The Oklahoma-based independent producer is expecting to produce 285,000 to 300,000 barrels oil-equivalent per day (BOE/d) in 2018, with a year-end exit rate between 305,000 and 315,000 BOE/d, Kallanish Energy reports.

The company also is projecting 2019 production growth of 15% to 20%, with a capital budget of $2.5 billion to $2.8 billion.

The preliminary 2017 results and 2018 plans were released in advance of the company issuing its quarterly and full-year results later this week.

The company said it expects to generate cash flow from operations of $3 billion to $3.2 billion, and $800 million to $900 million of free cash flow (non-GAAP) at $60 per barrel West Texas Intermediate crude, and $3 per thousand cubic feet (Mcf) of natural gas at Henry Hub.

The budget is expected to be cash neutral with WTI prices in the low to mid $40s. The producer is projecting a return of 10% to 15% on capital employed (ROCE), Kallanish Energy reports.

In 2017, Continental reported total production of 242,637 BOE/d, up 12% from full-year 2016, the company said.

Oil production represented 59% of 2017 production, compared to 55% in Q4 2016, it said.

In the final quarter of 2017, Continental produced 286,985 BOE/d, up 37% from the year-ago quarter.

Continental said it plans to employ on average six rigs in the Bakken, to drill roughly 142 gross operated wells, and 15 rigs in Oklahoma where it expects to complete 118 gross wells in 2018.

The company also said it reduced its debt by $261 million in Q4 and by an additional $95 million in January 2018.

EQT 4th Qtr. and Annual Report.  Yesterday the biggest natural gas producing company in the U.S., EQT, released its fourth quarter and full year 2017 update. As we pointed out in our lead story today, the 800-pound gorilla in the room was talking about an impending announcement to split EQT into two companies. However, there was plenty of other news coming out of the 2017 update and accompanying analyst phone call. Of course the big news for EQT in 2017 was closing on the deal to buy Rice Energy.  Sadly, about half of Rice’s employees were fired as a result. EQT kept 275 out of the roughly 500 employees employed at Rice at the time of the merger. EQT reported a net income of $1.5 billion in 2017, which is up from a loss of $453 million in 2016 (a nearly $2 billion swing in one year!). Contrary to the naysayers, the Trump tax cut is having a huge impact on shale companies. EQT will be $1.2 billion richer this year due to “deferred tax liability”–taxes it expected to pay at the old rate of 35% rather than at the new rate of 21%. That’s money not going into the black hole of Washington politicians’ hands but instead getting reinvested right here in the Marcellus/Utica. In 2017, EQT picked up an *additional* 110,000 acres in the West Virginia Marcellus/Utica region–and that’s without including the acreage picked up in the Rice Energy deal. How about some hard numbers for drilling?

In 2017, EQT drilled 144 Marcellus wells, 49 Upper Devonian wells, and 4 Utica wells (197 wells drilled, total). In 2018 they plan to drill 134 Marcellus wells, 16 Upper Devonian wells, and 25 Utica wells (175 total). So, their drilling program will slightly decrease, and they will drill less Marcellus/UD wells and more Utica wells.

EQT also issued an announcement about proved reserves–the amount of gas (and equivalents) in the ground, under their leased acreage, that they could extract using today’s technology at today’s prices. EQT reports total proved reserves at the end of 2017 were a stupendously high 21.4 trillion cubic feet equivalent of natural gas–59% higher than 2016.

EQT Spinning Off Pipeline Business.  EQT, the nation's biggest natural gas producer, will spin off its pipeline business into a new publicly traded company, the Pittsburgh-based driller announced Wednesday.

The transaction represents something of a consolation prize to investors who objected to EQT's purchase of Rice Energy last year. Opponents led by activist investor Barry Rosenstein's Jana Partners had contended that splitting EQT's natural gas production and transportation businesses would better reward EQT shareholders.

Shares of EQT were up more than 1 percent Wednesday to about $52, after popping about 5 percent in premarket trading.

Chesapeake 4th Qtr. and Full Year Results.  Chesapeake Energy Corporation on February 22 reported financial and operational results for the 2017 full year and fourth quarter plus other recent developments. Highlights include:

Average 2017 production of approximately 547,800 barrels of oil equivalent (boe) per day, up 3 percent compared to 2016 levels, adjusted for asset sales; oil production up 11 percent in 2017 fourth quarter compared to 2016 fourth quarter, adjusted for asset sales

Projected 2018 capital expenditures program of approximately $1.975 - $2.375 billion, down 12 percent compared to 2017 levels, using midpoint

Total 2018 production, adjusted for asset sales, expected to grow approximately 3 percent year-over-year, using midpoint; oil volumes adjusted for asset sales, expected to grow by approximately 5 percent compared to 2017 levels, using midpoint

Doug Lawler, Chesapeake's Chief Executive Officer, commented, "I am very pleased with our fourth quarter and full year 2017 performance, as we made significant progress toward our goals of reducing our debt, increasing cash flow generation and margin enhancement. Fiscal year 2017 was a pivotal year for Chesapeake, as we restored our production and increased net cash provided by operations, increased our oil production, adjusted for asset sales, and significantly improved our cost structure by reducing our combined production, general and administrative and gathering, processing, and transportation expenses by approximately $510 million. We further demonstrated the depth of our portfolio by closing on approximately $1.3 billion in asset and property sales and signed additional asset sales for approximately $575 million that we expect to close by the end of the 2018 second quarter. We reduced our outstanding secured term debt by approximately $1.3 billion, or 32 percent, continued to remove legal obligations and recorded the best environmental and safety performance in our company's history.

"We are well-positioned to build on our 2017 accomplishments and progress our strategic goals, with our 2018 guidance highlighting improvements in our cost structure, increased oil production, adjusted for asset sales, and increased net cash and margins provided by operations. We expect to deliver production growth, adjusted for asset sales, of 1 percent to 5 percent on reduced capital expenditures. The expected improvements in our cost structure, as well as improved basis pricing differentials and higher NYMEX pricing, result in higher forecasted year-over-year cash flows.

2017 Full Year Results

For the 2017 full year, Chesapeake reported net income of $953 million and net income available to common stockholders of $813 million, or $0.90 per diluted share. The company's EBITDA for the 2017 full year was $2.376 billion. Adjusting items that are typically excluded by securities analysts, the 2017 full year adjusted net income attributable to Chesapeake was $742 million, or $0.82 per diluted share, while the company's adjusted EBITDA was $2.160 billion. Reconciliations of financial measures calculated in accordance with GAAP to non-GAAP measures are provided on pages 12 - 16 of this release.

2017 Fourth Quarter Results

For the 2017 fourth quarter, Chesapeake reported net income of $334 million and net income available to common stockholders of $309 million, or $0.33 per diluted share. The company's EBITDA for the 2017 fourth quarter was $764 million. Adjusting for items that are typically excluded by securities analysts, the 2017 fourth quarter adjusted net income attributable to Chesapeake was $314 million, or $0.30 per diluted share, while the company's adjusted EBITDA was $706 million. Reconciliations of financial measures calculated in accordance with GAAP to non-GAAP measures are provided on pages 12 - 16 of this release.

Operations Update

Chesapeake's average daily production for the 2017 full year was approximately 547,800 boe compared to approximately 635,400 boe in the 2016 full year. A summary of the company's 2017 average daily production and average daily sales prices received by the company's operating divisions can be found in the company's Form 10-K.]

Chesapeake's average daily production for the 2017 fourth quarter was approximately 593,200 boe compared to approximately 574,500 boe in the 2016 fourth quarter. The following tables show average daily production and average daily sales prices received by the company's operating divisions for the 2017 fourth quarter.

In the Powder River Basin (PRB), strong results from Chesapeake's latest well placed on production in the Turner formation provides additional confirmation of the PRB's potential resource. In December 2017, the LEBAR 15-34-69 A TR 22H well was placed on production in the gas condensate window of the Turner with a lateral length of approximately 10,100 feet. This well reached a peak rate of 2,600 boe per day (50% oil) and has cumulatively produced 115,000 boe (50% oil) in its first 60 days of production. The LEBAR well is currently producing approximately 2,000 boe per day (45% oil) with a flowing tubing pressure of 2,600 psi after approximately 80 days on production. Chesapeake's seventh producing well targeting the Turner formation, the BB 35-35-72 USA A TR 21H, was completed with a 9,677-foot lateral and is scheduled to be placed on production next week. In January 2018, Chesapeake placed three wells on production from the Sussex formation, averaging approximately 6,895 feet in lateral length, and achieving an average peak rate of 880 boe per day (90% oil), while still cleaning up. Chesapeake added a third rig in October 2017 and expects to add a fourth rig in April 2018. Chesapeake expects to place on production up to 33 wells in 2018, compared to 25 wells in 2017.

In the Eagle Ford Shale in south Texas, Chesapeake is currently utilizing five drilling rigs and expects to place on production up to 140 wells in 2018, compared to 166 wells in 2017.

In the Marcellus Shale in northeast Pennsylvania, Chesapeake is currently utilizing one drilling rig and expects to place on production up to 55 wells in 2018, compared to 43 wells in 2017. Chesapeake expects to keep its total gross operated production from the region effectively flat compared to 2017 at approximately 2.1 bcf per day.

In the Utica Shale in northeast Ohio, Chesapeake is currently utilizing two drilling rigs and expects to place on production up to 40 wells in 2018, compared to 67 wells in 2017.

In the company's Mid-Continent operating area in Oklahoma, Chesapeake is currently utilizing one drilling rig an

Another Example of Chemical Boom Coming to the Appalachian Basin.  The announcement by LyondellBasell Industries that it is acquiring rival A. Schulman Inc. for $2.25 billion is another in a long line of positive indicators on how affordable prices for natural gas are helping to grow the U.S. economy. LyondellBasell has focused its business on the manufacture of polymers targeting the automotive industry, and now believes the acquisition of A. Schulman will allow it to diversify its business into what it calls "high-growth end markets" like agriculture, electronics and appliances and building and construction. As the U.S. economy continues to grow at an increasingly rapid pace, LyondellBasell hopes to take advantage as a supplier to these high-growth sectors. Few sectors of the U.S. economy have been on a more high-growth trajectory than the chemicals and plastics industry has been over the last half-decade. This is an industry that saw a very high degree of flight capital investment overseas during the 1990s and 2000s, as tight supplies and high prices for natural gas - the industry's major feed stock - made it far cheaper to invest in new plant and equipment in other countries. But with the discovery of massive natural gas shale plays like the Haynesville in Louisiana and the gigantic Marcellus in Pennsylvania/Ohio/West Virginia, the concerns about high prices or lack of adequate domestic supplies have dissipated.

Marathon to Focus on Four Shale Plays.  Marathon Oil Thursday announced plans to spend $2.3 billion in its capital budget in 2018, with 90% of the money to be spent in four U.S. shale plays, where production is expected to jump 20% to 25%, Kallanish Energy reports.

That returns-driven budget will be self-funding at a $50 average West Texas Intermediate crude price, said the company.

Roughly 60% of the capital budget will be spent in the Eagle Ford in South Texas and in the Bakken Shale in North Dakota and Montana.

Those assets have “demonstrated step-change performance improvements while operating at scale,” the company said.

About one-third of the budget is earmarked for the company’s assets in the northern Delaware Basin in West Texas and also in Oklahoma.

The company spent $2.2 billion on its capital budget in 2017.

Marathon Oil reported U.S. plays will increase to about 70% of the company’s total production mix in 2018.

“We finished 2017 with another quarter of outstanding operational execution across all four resource plays,” said president and CEO Lee Tillman, in a statement.

The company, he said, had delivered “some of the most productive unconventional wells in our company’s history” in the Eagle Ford and the Bakken.

U.S. resource production averaged 249,000 net barrels of oil-equivalent per day (BOE/d), up 10% from Q3 2017, the company said.

Production jumped 4% in the Eagle Ford, 17% in the Bakken and 10% in Oklahoma from Q3 to Q4, the company said. Overall U.S. production jumped 31% in 2017 from the year-ago quarter.

For full-year 2017, net production, excluding Libya, was 358,000 net BOE/d, up 9% from 2016 on a divestiture-adjusted basis.

For full-year 2018, the company is forecasting total production (excluding Libya) to average 390,000 to 410,000 net BOE/d. That would be a 12% increase at the midpoint compared to 2017 on a divestiture-adjusted basis.

The company reported a fourth-quarter 2017 net loss of $28 million, compared with a net loss of $1.3 billion in Q4 2016.

For full-year 2017, the company had a net loss of $5.7 billion, compared to a loss of $2.1 billion for full-year 2016.

WV Gas-Fired Plant Coming to WV.  West Virginia regulators on Tuesday issued a siting certificate for the planned Brooke County Power plant, an $884 million gas-fired power plant, Kallanish Energy learns.

The project may receive funding from the planned $83.7 billion investment China Energy has said it will invest in energy-related projects in West Virginia, according to West Virginia Secretary of Commerce Woody Thrasher.

During a visit to China in November, Thrasher signed a memorandum of understanding agreement with the company in the presence of President Trump and Chinese President Xi Jinping.

“Just getting that application approved is something that lets us move forward. You can’t line up financing until you get a permit,” said Pat Ford, executive director of the Business Development Corp. of the Northern Panhandle. “This was a major hurdle that needed to be overcome.”

Original plans called for the Brooke County power plant to be built at the former Wheeling Corrugating plant at Beech Bottom, W.V., but the new site is in a portion of the West Virginia Division of Natural Resources Cross Creek Wildlife Management Area.

GE Holding on to Baker Hughes.  General Electric announced Wednesday it intends to retain its holdings in oilfield services firm Baker Hughes, before the expiration of a two-year lockup period.

GE last November said it was considering selling its Baker Hughes holdings to refocus its business and boost cash flow, Kallanish Energy reports.

The announcement came just months after the conglomerate had purchased a 63% stake in the firm under a deal that combined its oil and gas services and equipment business with Baker Hughes to create the second largest oilfield services company.

Continental Resources 4th Qtr. Update.  Continental Resources reported fourth-quarter 2017 net income of $841.9 million, due largely to record production in the Bakken Shale in North Dakota and Montana, Kallanish Energy reports.

That includes $128.2 million from operations and $713.7 million from federal income tax changes. The company had a net income of $27.6 million.

The company reported full-year 2017 income of $789.4 million, with $75.7 million from operations and $713.7 million from federal tax changes. In 2016, the company had a net loss off $399.7 million.

“Continental’s fourth-quarter performance was a fitting completion to a standout year,” said chairman and CEO Harold Hamm, in a statement.

The company is expecting significant production growth and "robust free cash flow” in 2018, he said.

Continental reported Q4 Bakken production was up 58% over Q4 2016, setting an all-time production high. It averaged 165,598 barrels of oil-equivalent per day (BOE/d).

In the 4Q, the company completed 97 gross (37 net) operated and non-operated Bakken wells with first production. Thirty-nine of those wells averaged 24-hour initial production of 2,180 BOE/d.

Petrochemical Industry to Drive Increases in U.S. Ethane Growth.  U.S. ethane consumption in the petrochemical industry in 2018-2020, will exceed increases in consumption of all other petroleum and liquids products, such as motor gasoline, distillate, and jet fuel — combined – the Energy Information Administration projects.

EIA also projects ethane exports will continue increasing, as ethane is exported both by pipeline to Canada and by tanker to more distant destinations, Kallanish Energy reports.

Ethane, the primary product separated from raw natural gas at processing plants primarily is used as a petrochemical feedstock for the production of ethylene, which is a building block for plastics, resins, and other industrial products, according to EIA.

“As U.S. natural gas production has increased, the amount of ethane contained in raw natural gas production streams has exceeded domestic demand or the ability to export it abroad,” EIA reported. “This situation has led producers to leave some of the ethane in the natural gas stream, up to allowable limits set by natural gas pipelines and distribution systems, and to sell it as natural gas, rather than recover and market ethane as a separate product.”

Nonetheless, ethane is increasingly being recovered from the natural gas stream, and U.S. ethane consumption is increasing as existing ethane crackers have expanded and new plants have begun operating.

In addition, expanding pipeline networks and two new ethane export terminals have allowed U.S. ethane exports to increase.

Sierra Club’s Losing in Court.  After years of fever-pitched opposition to liquefied natural gas exports, the Sierra Club quietly pulled its last LNG lawsuit from federal court last month. The withdrawal followed a series of losses in similar cases, a subdued end to environmentalists' chief legal campaign against shipping U.S. natural gas around the world. The Sierra Club considers LNG exports too risky for the climate, but federal judges repeatedly found that the government had sufficiently considered impacts. Many in the natural gas industry are now breathing a sigh of relief, satisfied that the U.S. Court of Appeals for the District of Columbia Circuit spoke clearly on the climate issue and glad that the Sierra Club got the message. But while environmentalists may have abandoned the specific approach used in the failed LNG challenges, they're positioning themselves for a second wave of combat that could prove every bit as bothersome to the industry and the Trump administration.

Carbon Emissions Fall Again.  The U.S. Energy Information Administration (EIA) last week reported that U.S. energy-related carbon dioxide emissions fell one percent from 2016 levels in 2017, continuing the downward trajectory that began about a decade ago. the U.S. has reduced energy-related carbon emissions 14 percent since 2005, and the EIA has once again affirmed that these reductions are “mainly” attributable to increased natural gas use for electricity generation. From the EIA report: “The underlying energy consumption trends that resulted in these changes—mainly because more electricity has been generated from natural gas than from other fossil fuels—have helped to lower the U.S. emissions level since 2005 because natural gas is a less carbon-intensive fuel than either coal or petroleum.”


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PA Permits February 15, to February 22, 2018

County                                   Township                                          E&P Companies

  1. Fayette                                         Luzerne                                             Chevron
  2. Fayette                                         Luzerne                                             Chevron
  3. Lycoming                                     McNett                                                Chief
  4. Lycoming                                     McNett                                                Chief
  5. Susquehanna                            Auburn                                              Chesapeake
  6. Susquehanna                            Auburn                                              Chesapeake
  7. Susquehanna                            Springville                                         Cabot
  8. Susquehanna                            Springville                                         Cabot
  9. Susquehanna                            Springville                                         Cabot
  10. Susquehanna                            Springville                                         Cabot
  11. Susquehanna                            Springville                                         Cabot
  12. Susquehanna                            Springville                                         Cabot
  13. Susquehanna                            Springville                                         Cabot
  14. Susquehanna                            Springville                                         Cabot
  15. Susquehanna                            Springville                                         Cabot
  16. Susquehanna                            Springville                                         Cabot
  17. Susquehanna                            Springville                                         Cabot
  18. Susquehanna                            Springville                                         Cabot
  19. Westmoreland                            Allegheny                                          Huntley & Huntley
  20. Westmoreland                            Allegheny                                          Huntley & Huntley
  21. Westmoreland                            Allegheny                                          Huntley & Huntley
  22. Westmoreland                            Allegheny                                          Huntley & Huntley
  23. Westmoreland                            Allegheny                                          Huntley & Huntley
  24. Westmoreland                            Allegheny                                          Huntley & Huntley  

OH Permits for week ending February 17, 2018


County                                   Township                                          E&P Companies

  1. Belmont                                       York                                                    XTO
  2. Jefferson                                     Mt. Pleasant                                      Ascent
  3. Jefferson                                     Mt. Pleasant                                      Ascent                                                     

Joe Barone 610.764.1232
Vera Anderson 570.337.7149

Northeast Supply Enhancement