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Expo/Industry events for the next few months

DUG Eagle Ford
August 29-31, 2017
San Antonio, TX 
Shale Insight
September 27-28, 2017
David Lawrence Center
Pittsburgh, PA 
West Virginia Energy Expo
October 4, 2017
Morgantown, WV  
Utica Summit
October 11, 2017
Walsh University
North Canton, OH  
Midstream PA 2017
October 19, 2017
Penn Stater Conference Center
State College, PA 
For other events visit

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

Atlantic Sunrise Pipeline Buys the Farm.  In March, MDN told you about a small group of radical protesters who established a protest “camp” on a private farm along the path of the Williams $3 billion, 198-mile Atlantic Sunrise Pipeline in Lancaster County, PA (see Protesters Try to Resurrect Failed ND Pipeline Fight in Lancaster). Some of the so-called protesters had previously participated in illegal protests in Standing Rock, North Dakota, against the Dakota Access Pipeline being built there. Channeling that protest, the crazies in Lancaster stenciled “WELCOME TO THE STAND” across the side of the barn on the farm where they decided to form a new/illegal protest camp–hinting at what’s to come. The protesters were using the farm location to stash food, water, toilet paper, condoms…whatever. Hippie protesters need supplies, man. Well guess what? The farm’s owners, sympathetic to the protesters’ aim to block Atlantic Sunrise–just sold their farm to Atlantic Sunrise. How’s that for principled protest? Yep–gotta stop that evil pipeline from ruinin’ the pristine cornfields in Lancaster County–unless the price is right. And then it doesn’t matter…
Cabot 2nd Qtr. Update.  Cabot Oil & Gas on Friday reported a 14% increase in production in the second quarter from the year-ago quarter, Kallanish Energy reports.
Equivalent production for 2Q 2017 was 173.1 billion cubic feet-equivalent (Bcfe), the Texas-based company reported. That included 166.2 billion cubic feet (Bcf) of natural gas, 1.014 million barrels (MMBbl) of crude oil and condensate and 132,400 Bbl of natural gas liquids.
“Our second-quarter results demonstrate what our high-quality asset base can continue to deliver, highlighted by double-digit, year-over-year production growth while generating positive free cash flow for the fifth consecutive quarter,” said chairman, president and CEO Dan Dinges, in a statement.
The company said net income in Q2 was $21.5 million, which compares to a net loss of $62.9 million a year earlier. Net income for the latest quarter included the impact of an impairment charge of $43.2 million associated with non-core properties and pipeline assets in West Virginia, Virginia and Ohio that were classified as being held for sale.
Natural gas price realizations were $2.38 per thousand cubic feet, a 46% improvement over a year ago, the company said.
In Q2, Cabot drilled 13.7 net Marcellus Shale wells, completed eight net wells and placed six net wells into production. Cabot averaged 1.7 Bcf/d of net Marcellus production
 “The average cumulative production of the 26 fourth generation wells that we placed in production during the first half of 2017 continues to outperform our 4.4 Bcf per 1,000 lateral-foot type curve,” Dinges said.
The company is operating two rigs and one completion crew in the Marcellus Shale and it intends to remain at that level for the rest of the year.
Oil production in the Eagle Ford Shale in South Texas jumped 9% from the previous quarter, the company said.
It drilled 7.4 net wells and completed and placed into production 16.0 net wells.
Oil production in the quarter was 13,146 BOE. That was lower than expected because of operational delays and an extended cleanup period for longer laterals, the company said.
Gulfport Energy 2nd Qtr. Update.  Gulfport Energy, a major player in the Utica Shale, reported net production grew sharply in the second quarter, Kallanish Energy reports.
It said Q2 production averaged 1.04 billion cubic feet-equivalent per day, up 56% from Q2 2016. That production is 88% natural gas, 8% natural gas liquids and 4% oil.
The Oklahoma-based company raised its 2017 year-end production guidance to the range of 1.07 to 1.10 Bcfe/d.
Gulfport’s realized prices for Q2 were $31.6 per Mcf of natural gas, $57.86 per barrel of oil and 45 cents per gallon of natural gas liquids, resulting in a total equivalent price of $3.43 per Mcfe.
In Q2, Gulfport turned to sales 29 gross (26.7 net) operated wells in the Utica and two gross (1.2 net) wells in the SCOOP play in Oklahoma. That is the most wells that the company has turned to sales in a quarter since it began drilling in eastern Ohio in 2011, said CEO and President Michael Moore, in a statement.
The Oklahoma wells produced 14.4 and 17.3 MMcfe/d for the average 60-day peak production rate, the company said. That production from two wells in southern Grady County was 79% natural gas, 19% NGLs and 2% oil.
“Gulfport delivered another successful quarter during the second quarter of 2017, highlighted by 22% production growth over first quarter 2017 and a very active quarter operationally in both tour Utica Shake and SCOOP assets areas,” Moore said.
Gulfport will release its 2Q financial information on Aug. 9.
Range 2nd Qtr. Update.  Looking for more Marcellus Mergers.  Natural gas drillers in the Marcellus Shale would benefit if there were fewer companies competing in the country’s most prolific gas field, according to the CEO of Fort Worth-based Range Resources.
Consolidation would make gas drillers more efficient and smooth out the pace of development, said Jeff Ventura, Range’s chief executive officer. Supply gluts that weaken prices would be easier to manage as pipelines linking the region to high-demand markets are built, leading to more stable prices.
The Marcellus, centered in Pennsylvania and West Virginia, is changing rapidly as gas production there approaches a record. Deal interest is accelerating as new pipelines promise to end transportation bottlenecks and bring higher prices. Consolidation is seen by many as the key to unlocking the region’s full potential.
Fewer companies in the Marcellus “are probably a positive thing,” Ventura said on a conference call Wednesday after Range released its second-quarter earnings. Consolidation means “a more paced development, more prudent and more rational development.”
Range reported second-quarter earnings late Tuesday that missed estimates Wednesday, largely due to a hiccup in Louisiana where the company is experimenting with well-completion techniques, according to Chief Operating Officer Ray Walker. Net income totaled $69.6 million, or 6 cent a share adjusted for non-recurring gains, short of analysts’ estimates of 7 cents.
Shares (ticker: RRC) plunged nearly 12 percent to $17.90 a share, the biggest one-day decline since 2011.
Last year, Range expanded with its $3.3 billion purchase of Memorial Resource Development of Houston, which added significant natural gas resources in Louisiana.
The latest proposed merger in the Marcellus is EQT’s $6.7 billion bid to buy Rice Energy, which would create the largest gas driller in the U.S. EQT, noted an “accelerating trend of industry-wide consolidation in the Appalachian Basin” in a filing with the Securities and Exchange Commission.
Rice Energy bought Vantage Energy for $2.7 billion in 2016, just weeks after the target filed to go public. Alta Marcellus Development bought $1.24 billion of Marcellus acreage from Anadarko Petroleum this year. And Noble Energy sold its upstream operations in northern West Virginia and southern Pennsylvania for $1.23 billion in May to portfolio company Quantum Energy Partners.
Antero 2nd Qtr. Update.  Antero Resources (NYSE: AR) ("Antero" or the "Company") today announced estimated reserves as of June 30, 2017. 
  • Increased Marcellus wellhead type curves for 199 proved undeveloped and 398 probable locations from 1.7 Bcf/1,000' to approximately 2.0 Bcf/1,000' of lateral
  • Mid-year 2017 proved reserves increased by 7% to 16.5 Tcfe (41% liquids) from year-end 2017.
  • Pre-tax PV-10 of proved reserves at mid-year 2017 was $10.1 billion at 6/30/2017 strip pricing, including hedges
  • $0.48 per Mcfe all-in finding and development cost for proved reserve additions for the first half of 2017
  • 3P reserves increased by 14% to 53.0 Tcfe (29% liquids)
  • Pre-tax PV-10 of 3P reserves at mid-year 2017 was $17.0 billion at 6/30/2017 strip pricing, including hedges
Antero's estimated proved reserves at June 30, 2017 were 16.5 Tcfe, a 7% increase compared to estimated proved reserves at December 31, 2016.  Proved, probable and possible ("3P") reserves at mid-year 2017 totaled 53.0 Tcfe, which represents a 14% increase compared to year-end 2016.  Proved and probable reserves comprise over 96% of the total 3P reserves. 
Drill bit only finding and development cost, including revisions, was $0.47 per Mcfe for the first half of 2017.  All-in finding and development cost for estimated proved reserve additions was $0.48 per Mcfe for mid-year 2017. 
Paul Rady, Chairman and CEO, commented, "After announcing encouraging initial results for advanced completions in the Marcellus over the past year, our reserve engineers had the production history necessary to upgrade the type curve on almost 600 proved and probable undrilled locations from 1.7 previously to approximately 2.0 Bcf per 1,000' of lateral at mid-year 2017.  Once processed, these rich gas locations deliver gas equivalent reserves of approximately 2.6 Bcfe per 1,000' of lateral assuming ethane rejection.  As we expand our advanced completion footprint, we anticipate revising the type curve for a significant portion of our approximate 2,400 undeveloped locations that are still booked at 1.7 Bcf per 1,000' of lateral."
Antero's reserves at June 30, 2017 were prepared by the Company's internal reserve engineers and have not been reviewed or audited by its independent reserve engineers.   
Estimated Proved Reserves
As of June 30, 2017, the Company's 16.5 Tcfe of estimated proved reserves were comprised of 59% natural gas, 40% NGLs and 1% oil.  The Marcellus Shale accounted for 88% of estimated proved reserves and the Ohio Utica Shale accounted for 12%.  For the first half of 2017, Antero added 1.3 Tcfe of estimated proved reserves through the drill bit, which is reflective of the continued productivity gains from the use of advanced completion techniques and longer laterals.
Included in the mid-year 2017 reserves are 294 proved undeveloped locations, or 83% of the total proved undeveloped locations in the Marcellus, booked at an approximate 2.0 Bcf/1,000' type curve.  This includes an increase of 199 proved undeveloped locations that were previously booked at a 1.7 Bcf/1,000' type curve at year-end 2016 that have now been upgraded to an approximate 2.0 Bcf/1,000' type curve.  The remaining 60 Marcellus proved undeveloped locations are booked at a 1.7 Bcf/1,000' type curve and are generally outside of areas where advanced completions have been applied.
Approximately 29% of Antero's combined 636,000 net acre leasehold position was classified as proved at June 30, 2017 which was in line with year-end 2016.  Based on Antero's successful drilling results to date, as well as those of other operators in the vicinity of Antero's leasehold position, the Company believes that a substantial portion of its Marcellus and Ohio Utica Shale undeveloped acreage will be classified as proved over time as more wells are drilled.  Virtually no West Virginia Upper Devonian or Utica locations were classified as 3P reserves at June 30, 2017, with the exception of four proved developed producing Upper Devonian locations and one proved developed producing Utica location, due to the early stage of drilling and production in the play.
Estimated proved developed reserves increased by 20% from year-end 2016 to 8.3 Tcfe at June 30, 2017.  The Company added 76 Marcellus and 25 Ohio Utica wells to estimated proved developed reserves in the first half of 2017.  The percentage of estimated proved reserves classified as proved developed increased to 50% at June 30, 2017 from 45% at year-end 2016.  The average heating content of the Marcellus and Utica proved undeveloped locations is 1250 BTU and 1235 BTU, respectively, and the average lateral length is approximately 9,100 feet per location.  
Rice 2nd Qtr. Update.  Rice Midstream Partners LP (NYSE: RMP) ("RMP" or the "Partnership") today reported second quarter 2017 financial and operating results. Highlights include:
  • Gathering throughput averaged 1,360 MDth/d, a 10% increase from first quarter 2017
  • Freshwater delivery volumes were 424 MMGal, a 16% increase over first quarter 2017
  • Net income attributable to limited partners of $42.5 million, or $0.42 per unit
  • Adjusted EBITDA(1) of $55.6 million, a 14% increase relative to first quarter 2017
  • Distributable cash flow ("DCF")(1) of $49.3 million, resulting in DCF coverage ratio(1) of 1.68x
  • Raised second quarter distribution to $0.2711 per common unit, an increase of 21% over the second quarter 2016
  • Exited the quarter with low leverage(1) of 1.1x
  • Increased acreage dedication by approximately 15,000 acres consisting of approximately 12,000 acres through Rice Energy's announced Greene County, Pennsylvania land acquisition and approximately 3,000 acres through Rice Energy's organic leasing program
Commenting on the results, Daniel J. Rice IV, Chief Executive Officer, said, "We are pleased with our strong second quarter results, as gathering throughput continued to increase as a result of our sponsor's solid execution. Furthermore, we substantially increased our water volumes due to completing wells ahead of schedule. Our strong financial position allows for continued successful development across our increased footprint in Appalachia."
2017 Capital Budget Update
Based on results through the first half of 2017, we are updating our 2017 gathering and compression budget to reflect capital projects trending below prior expectations. We expect to invest $235 million in Washington and Greene counties, a reduction of 8% from our prior $255 million gathering and compression capital budget. Our $60 million water services budget is unchanged.
Proposed Merger of Rice Energy with EQT Corporation
In light of Rice Energy's previously announced merger with EQT, Rice Energy and RMP have discontinued providing guidance and long-term outlook information regarding results of operations and distribution growth through 2023. In addition, investors are cautioned not to rely on historical forward-looking statements regarding guidance and long-term outlook information, which forward-looking statements spoke only as of the date provided and were subject to the specific risks and uncertainties that accompanied such forward-looking statements.
In order to provide more clarity to our investors, we are providing the following analysis to demonstrate the impact of the elimination of the drop down opportunities for RMP on its previously published (and now discontinued) long-term outlook. Based upon Rice Energy's previously published development plan, the elimination of future drop down transactions would have resulted in an outlook that would have targeted 20% distribution growth, DCF coverage of approximately 1.4x and leverage of less than 2.5x through 2019.
As mentioned above, a significant number of factors that are outside of our control will ultimately determine the long-term distributions of RMP including, among other things, the development program to be adopted by EQT. As such, investors are cautioned that the above analysis should not be construed as guidance or relied upon as an expectation that such levels will be achieved.
Second quarter gathering throughput averaged 1,360 MDth/d, consisting of 1,144 MDth/d affiliate volumes and 216 MDth/d third party volumes. Increases in Adjusted EBITDA (1) to$55.6 million and DCF (1) to$49.3 million were driven by accelerated sponsor well completion activity and operational efficiencies.
As of June 30, 2017, RMP's concentrated gathering and compression acreage dedication in the Marcellus Shale core covered approximately 221,000 acres in Washington and Greene Counties with approximately 29,000 acres dedicated from high quality, third party customers.
On July 21, 2017, we declared a quarterly distribution of $0.2711 per unit for the second quarter 2017, an increase of $0.0103 per unit, or 4%, relative to first quarter 2017. The distribution will be payable on August 17, 2017 to unitholders of record as of August 8, 2017.
Consol 2nd Qtr. Update.  Consol Energy reported second-quarter net income of $174 million, compared to a loss of $469 million in Q2 2016, Kallanish Energy reports.
Net cash provided by operating activities was $89 million, compared to $95 million a year earlier.
After certain adjustments, the company reported net income attributable to Consol shareholders in Q2 2017 was $39 million. The company also received $326 million in proceeds from asset sales.
“We are at a pivotal point in our transformation as a company,” said president and CEO Nicholas DeIuliis, in a statement.
The company has been shifting from a coal mining company to a natural gas drilling and production company.
“The steady march of continuous improvement was sustained this past quarter in our E&P operations in all phases, including drilling and completions,” he said.
The company in Q2 sold 92.2 billion cubic feet-equivalent (Bcfe), a drop of 7% from the 99.3 Bcfe in Q2 2016.
Production was delayed on two Utica Shale pads in Ohio and the company sold off 3.0 Bcfe per day from assets in West Virginia’s Doddridge and Wetzel counties, the company said.
In Q2, Consol operated two rigs and drilled seven dry-gas Utica Shale wells: five in Ohio’s Monroe County and two in Pennsylvania’s Westmoreland County.
The company completed 15 wells in the quarter: five Marcellus and one Upper Devonian in Pennsylvania’s Greene County; three Marcellus wells in West Virginia’s Ritchie County; and six Utica wells in Monroe County.
The company turned-in-line six wells in Q2: five Marcellus wells in Ritchie County and one wet Marcellus well in Pennsylvania’s Allegheny County.
EOG Resources 2nd Qtr. Update.  EOG Resources reported its second consecutive quarterly profit and set a company quarterly crude oil production record.
The company reported second-quarter 2017 net income of $23.1 million, compared to a net loss of $292.6 million in Q2 2016. Revenue increased from $1.8 billion to $2.6 billion.
The additional revenue was linked to an increase in oil production and higher crude prices.
“Our permanent shift to premium drilling, driven by an organic exploration focus and best-in-class technology, is a sustainable competitive advantage,” said chairman and CEO William Thomas, in a statement.
Total crude volumes grew in the quarter by 25%, to 334,700 barrels per day (BPD) of oil, a company oil production record, Kallanish Energy reports.
The company increased its crude oil target in 2017 from 18% to 20% growth.
Natural gas liquids and natural gas production also exceeded production targets, contributing to 10% total company production growth compared to Q2 2016.
EOG said it still plans to complete 480 net wells in 2017 with capital spending between $3.7 billion and $4.1 billion. The company in the second quarter completed 47 wells in the Delaware Basin in West Texas and New Mexico.
In the Wolfcamp play, the company completed 25 wells with an average 30-day initial production rate per well of 3,010 barrels of oil-equivalent per day, 480 BPD of NGLs and 3.5 million cubic feet per day (MMcf/d) of natural gas.
EOG also completed 51 wells in the second quarter in the Eagle Ford Shale in South Texas and nine wells in the South Texas Austin Chalk.
It also completed 22 wells in the Bakken Shale in North Dakota, eight wells in the Powder River Basin in Wyoming, and 10 wells in the DJ Basin in Colorado.
Devon Energy 2nd Qtr. Update.  Independent U.S. producer Devon Energy reported that despite its second-quarter production of oil/bitumen, natural gas and natural gas liquids falling from a year ago, realized prices increased, while net earnings and revenue enjoyed a substantial jump.
For the quarter ended June 30, Oklahoma City-based Devon reported U.S. (Devon’s primary market) oil and bitumen production fell to 116,000 barrels per day (BPD), vs. 123,000 BPD one year ago.
Natural gas liquids production for the most recent quarter fell to 97,000 BPD, from 110,000 BPD one year ago, while natural gas production dropped to 1.19 billion cubic feet per day (Bcf/d), from 1.28 Bcf/d one year ago.
At the same time, realized prices to Devon for the above products all rose, including crude oil rising to $46.64 per barrel, from $41.56/Bbl. The price for NGLs jumped to $13.26/Bbl, from $10.14 in the year-ago quarter.
The realized price for gas climbed to $2.50 per thousand cubic feet (Mcf), up from $1.40/Mcf, Kallanish Energy reports.
“Devon achieved another high-quality operating performance in the second quarter, building operational momentum in our U.S. resource plays and accelerating efficiency gains across our portfolio,” said Dave Hager, president and CEO. “These successful efforts resulted in record-setting well results that drove our U.S. oil production above guidance expectations with a capital investment that was 17% below our budget year-to-date.”
Pioneer 2nd Qtr. Update.  Pioneer Natural Resources is scaling back its Permian Basin drilling in the second half of 2017, and is cutting its capital spending by $100 million, Kallanish Energy reports.
The company intends to push 30 well completions that had been scheduled for 2017 into 2018, said president and CEO Timothy L. Dove, in a statement. The company intends to begin production on 230 wells in 2017, not 260 wells.
Capital spending in 2017 will drop from $2.4 billion to $2.3 billion.
The changes will likely reduce 2017 production to the low end of the company’s guidance range of 15% to 16% growth, Love said.
“Operationally, we fell behind on our completions due to unforeseen drilling delays. To maintain efficient operations, we have chosen not to accelerate activity in order to catch up in the second half, especially in light of the current commodity price environment,” Love said.
Pioneer is the largest acreage holder in the Spraberry/Wolfcamp play, with roughly 800,000 acres in two areas. Pioneer intends to maintain its 18 rigs in the Spraberry/Wolfcamp. Of those rigs, 14 are in the northern area and four are in the southern joint venture area.
It placed 61 Spraberry/Wolfcamp wells in production in the quarter and expects to begin production on 55 to 60 wells in the third quarter.
The company reported Q2 2017 net income of $233 million. That compares to a loss of $268 million in Q2 2016.
Production during the quarter totaled 259,000 barrels of oil-equivalent per day (BOE/d), of which 57% was oil. Quarterly production grew by 10,000 BOE/d, or 4% from Q1 2017.
The independent producer shipped 1 million barrels (MMBbl) of Permian crude oil to Europe in the quarter and expects to export another 1 MMBbl to Europe and Asia in the third quarter.
Cove Point Almost Ready.  Dominion Energy’s Cove Point liquefaction project is 95% complete and the Maryland plant should be in operation in late 2017, the company announced Wednesday.
In July, the company received approval from the Federal Energy Regulatory Commission for hydrocarbon entry into four additional areas of the liquefied natural gas (LNG) facility, said chairman, president and CEO Thomas F. Farrell II.
More than 90% of the project’s systems are now in the commissioning phase, Kallanish Energy has learned.
TX May Production Numbers; Top 5 Counties.  Texas drillers produced nearly 76.4 million barrels (MMBbl) of crude oil and nearly 560.5 billion cubic feet (Bcf) of natural gas in May, according to the Railroad Commission of Texas.
Those are preliminary figures and will be updated later by drillers, said the state agency that oversees drilling in Texas.
Production reported in May 2016 was 73.1 MMBbl of crude, later updated to 84.5 MMBbl. Initial May 2016 natural gas production was 600.7 Bcf, later updated to 702.5 Bcf.
The commission reported production from June 2016 through May 2017 was 988 MMBbl of crude and 7.7 trillion cubic feet (Tcf) of total gas, Kallanish Energy reports.
Crude oil production does not include condensate which is reported separately by the commission.
According to the preliminary May data, Texas averaged 2.46 million barrels per day (MMBPD) of crude oil, compared to 2.36 MMBPD in May 2016.
Natural gas production in May 2017 averaged 18.1 billion cubic feet per day (Bcf/d), compared to 19.4 Bcf/d in May 2016.
Texas production in May 2017 came from 179,857 oil wells and 93,397 gas well
The Top 5 Texas counties for oil production in May were Midland, Karnes, Lasalle, Dewitt and Martin. The Top 5 counties for natural gas were Webb, Tarrant, Panola, Karnes and Dimmit. The Top 5 counties for condensate were Dimmit, Culberson, Karnes, Webb and Dewitt.
NatGas Volatility.  The price 60 days or so was hovering at about $3+; however an estimated 20 billion cubic feet of inventories plus cooler weather projected across most of the nation has temporarily lowered the price to $2.83+.  As the pipelines are completed, electric grids come on line and exports continue the price is expected to climb back to the $3+ range.
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Rig Count 

  • Baker Hughes Rig Count the week of July 28, 2017
  • PA
    • Marcellus 34 unchanged
  • Ohio 
    • Utica 28 up 1
  • WV 
    • Marcellus 14 up 1
  • TX
    • Eagle Ford 76 down 2
  • TX
    • Permian Basin – 379 up 5
  • ND
    • Williston – 54 unchanged
  • CO
    • Niobrara – 29 down 1
  • TOTAL U.S. Land Rig Count 931 up 7

PA Permits July 27, to August 2, 2017

           County                                   Township                                          E&P Companies


  1. Allegheny                                      Plum Boro                                         Huntley & Huntley
  2. Greene                                         Morgan                                              EQT
  3. Greene                                         Morgan                                              EQT
  4. Greene                                         Morgan                                              EQT
  5. Greene                                         Morgan                                              EQT
  6. Greene                                         Springhill                                           Rice
  7. Greene                                         Springhill                                           Rice
  8. Greene                                         Springhill                                           Rice
  9. Greene                                         Springhill                                           Rice
  10. Greene                                         Springhill                                           Rice
  11. Greene                                         Springhill                                           Rice
  12. Potter                                            Sweden                                             JKLM

OH Permits for week July 29, 2017


           County                                   Township                                          E&P Companies


  1. Carroll                                          Harrison                                             Rex
  2. Carroll                                          Harrison                                             Rex
  3. Carroll                                          Harrison                                             Rex
  4. Carroll                                          Harrison                                             Rex
  5. Carroll                                          Harrison                                             Rex
  6. Carroll                                          Harrison                                             Rex
  7. Harrison                                       Cadiz                                                  Hess
  8. Harrison                                       Cadiz                                                  Hess
  9. Harrison                                       Cadiz                                                  Hess
  10. Harrison                                       Cadiz                                                  Hess
  11. Harrison                                       Cadiz                                                  Hess
  12. Harrison                                       Athens                                               Hess
  13. Harrison                                       Athens                                               Hess
  14. Harrison                                       Athens                                               Hess
  15. Harrison                                       Athens                                               Hess
  16. Monroe                                        Switzerland                                       Statoil
  17. Monroe                                        Switzerland                                       Statoil
  18. Monroe                                        Switzerland                                       Statoil
  19. Monroe                                        Green                                                 Eclipse Resources
  20. Monroe                                        Green                                                 Eclipse Resources
  21. Monroe                                        Green                                                 Eclipse Resources
Joe Barone 610.764.1232
Vera Anderson 570.337.7149
Utica Summit 2019