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NewsLetters

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

PTTGC and Daelim Purchase.  500 acres on the Dilly’s Bottom site have been purchased by PTTGC.  While this is a positive step forward, it’s not the “Final Investment Decision (FID).”   We are still waiting for the FID.  The champagne will start popping then.

ETP Hopes to Start Mariner East 2.   Energy Transfer Partners LP (ETP) said it filed with Pennsylvania Utility Regulators on Friday to restart its Sunoco Mariner East 1 natural gas liquids pipeline and hopes the line will return to service this week.

The Pennsylvania Public Utility Commission suspended operations on the Mariner East 1 pipeline on March 7 after sinkholes were discovered near the project.

“Our integrity testing for (Mariner East 1) is complete and has demonstrated that the line has been and will continue to be safely operated, as we have previously stated,” Lisa Dillinger, a spokeswoman for ETP, said in an email.

The shutdown forced shippers, including U.S. gas producers Range Resources Corp and Antero Resources Corp, to find another route for their liquids and is likely causing more ethane to be injected into the region’s natural gas pipelines, according to analysts.

One other route for the liquids is Enterprise Products Partners LP’s ATEX pipeline, which delivers liquids from the Marcellus and Utica shale formations in Pennsylvania, West Virginia and Ohio to the Mont Belvieu storage facility in Texas, according to analysts.

Mariner East 1 can transport up to 70,000 bpd of propane and ethane from the Marcellus and Utica basins in western Pennsylvania to customers in the state and elsewhere, including ETP’s Marcus Hook industrial complex near Philadelphia.

Separately, ETP is building the $2.5 billion Mariner East 2 pipeline, which will boost total capacity of the Mariner East project to 345,000 bpd and open the pipe to suppliers in Ohio and West Virginia.

Since May 2017, Mariner East 2 has received 51 notices of violation from Pennsylvania regulators due in part to inadvertent returns or spills.

Delays related to those spills, among other things, have pushed the expected startup of Mariner East 2 from the third quarter of 2017 to the end of the second quarter of 2018. Some analysts, however, do not expect Mariner East 2 to enter service until the third quarter.

In an analyst call following the release of its earnings in April, Antero said if Mariner East 2 does not come online when expected and is delayed until the end of the year; it would cost the company about $30 million in cash flow.

FERC Approves Rover Facilities.  Energy Transfer Partners said that Rover Pipeline has secured approval from the US Federal Energy Regulatory Commission (FERC) to commission additional phase 2 facilities of the Rover pipeline project.

Last week, FERC granted Rover permission to place a segment of Phase 2, which included Mainline Compressor Station 3 located in Crawford County, Ohio, and a section of the line between Mainline Compressor Station 2, in Wayne County, Ohio, and Mainline Compressor Station 3, in service for additional throughput opportunity.

The approval from FERC granted today allows for the full commercial operation capability of the Market Zone North Segment.

Phase 1 of the project was also placed into service in segments, with the first portion going into service August 31, 2017, and the remaining segment of Phase 1 going into service in December of 2017.

Since December 2017, Rover has been capable of transporting up to 1.7 billion cubic feet per day of natural gas.

Rover will transport natural gas from the Marcellus and Utica Shale production areas to markets across the United States as well as into the Union Gas Dawn Storage Hub in Ontario, Canada. Construction of the entire project is anticipated to be completed later this quarter.

Hess 1st Qtr. Financial Update.  Hess Corp. on Wednesday posted a smaller quarterly loss due to increasing crude oil prices and cost reductions made by the company.

It reported a net loss of $106 million in the first quarter 2018, compared to a net loss of $324 million in the first quarter of 2017.

On an adjusted basis, the company reported an after-tax net loss of $72 million in Q1 2018.

The improved after-tax adjusted results reflect higher realized crude oil selling prices, lower operating costs and depreciation, depletion and amortization expense, partially offset by lower production volumes, primarily due to asset sales, the company said.

“Our focus for 2018 is on execution, and we believe we are off to a very strong start to the year,” CEO John Hess said, in a statement.

In the first quarter, the company increased cash returns to shareholders, reduced debt, exceeded production guidance, continued to lower costs and announced two offshore Guyana discoveries: Ranger and Pacora, he said.

Net production in the Bakken Shale in North Dakota and Montana increased 12%, from 99,000 barrels of oil-equivalent per day (BOE/d) in Q1 2017, to 111,000 BOE/d in Q1 2018, Hess reported.

The company operated four rigs in the Bakken in the first quarter. It drilled 23 wells and brought 13 new wells online. It plans to add a fifth rig in the third quarter and a sixth rig in the fourth quarter.

SWN 1st. Qtr. Update.  Southwestern Energy reported an 11% increase in overall production in first quarter 2018 in the Appalachian Basin and in the Fayetteville Shale, Kallanish Energy reports.

Net production was 226 billion cubic feet (Bcf) and was 87% natural gas. Production in Q1 2017 was 204 Bcf and was 90% natural gas.

First-quarter production increased in northeast and southwest Pennsylvania, and dipped in the Fayetteville Shale.

Q1 production included a 37% increase in liquids from the year-ago quarter, Southwestern said. Oil production jumped from 519,000 barrels to 613,000 Bbls, year-over-year. Natural gas liquids grew from 3 million barrels (MMBbl) in 1Q 2017, to 4.2 MMBbl in Q1 2018.

“Momentum from growing liquids production and relentless delivery of operational and technical excellence, combined with our new credit facility, will improve margins in 2018 and into the future,” said president and CEO Bill Way, in a statement.

Appalachian Basin net production in Q1 was 159 billion cubic feet-equivalent (Bcfe), or 1.77 billion cubic feet equivalent per day (Bcfe/d), Southwestern said. That is an increase of 29% from a year ago.

The company reported Q1 net income of $205 million, down from $281 million in Q1 2017. It reported Q1 2018 adjusted net income of $162 million, up from $87 million one year ago.

Total capital investments in the quarter were $338 million. Net cash provided by operating activities was $364 million and net cash flow was $358 million.

The company drilled 32 wells in Q1, completed 29 wells and began sales on 33 wells.

The typical well in northeast Appalachia costs $6.2 million with an average lateral of 7,360 feet. The average well in southwest Appalachia costs $8.8 million with an average lateral of 6,790 feet.

Southwestern reported new record-level completion performance, increasing the number of staged pumped per day using zipper fracks to more than six stages, a 55% improvement compared to historic completion operations, it said.

It also made cycle time reductions with record facility performance in southwest Appalachia, reducing the average facility installations by 45% vs. the 2017 average, it said.

It is also working to boost the water infrastructure in Tioga County, PA, to reduce drilling costs, along with drilling longer laterals.

Chesapeake 1st Qtr. Financial Update.  Higher commodity prices helped produce Chesapeake Energy’s best quarterly financial report in more than three years, Kallanish Energy reports.

The Oklahoma-based company reported first quarter net income of $268 million. That compares to $75 million in Q1 2017. The company reported Q1 adjusted net income of $361 million.

Net cash provided by operating activities in Q1 increased $557 million from Q1 2017, to $609 million, it said. The company reduced its long-term debt by $581 million in Q1.

The company’s Q1 production averaged 554,000 barrels of oil-equivalent per day (BOE/d), up 11% compared to 1Q 2017 results, adjusted for asset sales.

Production in Q1 2017 was roughly 528,000 BOE.

Average oil production in Q1 2018 was 92,000 BPD, up 16% compared to one year ago, and adjusted again for asset sales. Oil production in Q1 2017 was 84,000 BPD.

“The strength of our operations and improved cost structure, coupled with higher realized prices, resulted on our best quarterly financial performance in over three years,” said CEO Doug Lawler, in a statement.

Higher prices helped, but the improvement was largely driven by strong oil production and a lower cost structure, he said.

Chesapeake reported in the first quarter of 2018 it had 15 rigs drilling wells working and it spud 77 gross wells, completed 76 gross wells and connected 57 gross wells.

It spent $611 million on capital projects in Q1. Production came from the Marcellus and Haynesville shales, followed by the Utica and Eagle Ford shales.

Production increased slightly in the Marcellus in the Appalachian Basin and dropped in the other three plays, compared to Q1 2017.

It expects to place into service up to 150 wells in the Eagle Ford Shale in Texas in 2018. It is projecting 50 wells in the Marcellus in 2018, 35 wells in the Utica in Ohio, 35 wells in the Mid-Continent in Oklahoma, 35 wells in the Powder River Basin in Wyoming, and 25 in the Haynesville in Louisiana.

Continental 1st Qtr. Financial Update.  The Bakken Shale in North Dakota and Montana remains a big oil producer and is breaking records for Oklahoma-based Continental Resources, Kallanish Energy reports.

Three of the company’s top five all-time, 30-day initial production rates are Bakken wells completed in the first quarter 2018, the company said Wednesday. They are averaging 2,305 barrels of oil-equivalent per day (BOE/d), it said.

The top eight, 30-day rate Bakken wells in the company’s history have been completed in the last two quarters, the company said.

Continental said 31 operated wells in the Bakken completed flowing at an average 24-hour initial production (IP) rate of 2,079 BOE/d.

Its Bakken production averaged 161,356 BOE/d in Q1 2018, up 48% from Q1 2017. It said 80% of that production was oil.

The company said it has completed 164 optimized Bakken wells in Dunn, McKenzie, Mountrail and Williams counties in North Dakota.

“We are clearly seeing a structural uplift in well performance across the Bakken field,” said President Jack Stark, in a statement.

The company is operating six rigs in the Bakken and it intends to maintain that level of drilling through year-end 2018. It is also operating eight stimulation crews in the play.

“Our first quarter results show our 2018 breakout year is off to a strong start,” said chairman and CEO Harold Hamm, in a statement.

Total production in Q1 2018 was 25.9 million barrels of oil equivalent (MMBOE), or 287,410 BOE/d, Continental said. That is up 34% from a year ago.

Oil production grew 37% from Q1 2017 to Q1 2018, it said.

Continental said it's expecting Q2 2018 production will be in the range of 285,000 to 290,000 BOE/d.

Total Q1 2018 production included 163,837 barrels of oil per day, which equaled 57% of production, plus 741.4 million cubic feet per day (MMcf/d) of natural gas (43% of production).

The company completed 18 gross (14 net) wells in Q1 2018 in the SCOOP play in Oklahoma. SCOOP production averaged 62,012 BOE/d (26% oil). It has eight rigs working in the SCOOP area.

The company announced plans for its Project SpringBoard in the SCOOP play in Oklahoma. It calls for 100 Springer wells and up to 250 Woodford and/or Sycamore wells on 70 square miles or 31,000 net acres. It could hold 400 MMBOE, the company said.

The project marks the company’s first full-scale development in the SCOOP play.

Continental said that updated well designs and improved drilling performances have reduced completed well costs in the Woodford oil window by $1 million to $11.7 million per well.

The company said it intends to shift its rigs in the SCOOP play to focus on oil and liquids-rich assets.

It reported first-quarter 2018 net income of $233.9 million, compared to $469,000 one year ago. It had adjusted net income of $255.1 million, and cash flow from operations of $886 million in Q1.

Eclipse Resources 1st Qtr. Financial Update announced its first quarter 2018 financial and operational results, along with updated guidance for the second quarter and full year 2018.

First Quarter 2018 Highlights:

  • Average net daily production was 315.2 MMcfe per day, consisting of 72% natural gas and 28% liquids.
  • Realized an average natural gas price, before the impact of cash settled derivatives and firm transportation expenses, of $2.87 per Mcf, a $0.13 per Mcf discount to the average monthly NYMEX settled natural gas price during the quarter.
  • Realized an average oil price, before the impact of cash settled derivatives, of $56.52 per barrel, a $6.39 per barrel discount to the average daily NYMEX WTI oil price during the quarter.
  • Realized an average natural gas liquids (“NGL”) price, before the impact of cash settled derivatives, of $25.55 per barrel, or approximately 41% of the average daily NYMEX WTI oil price during the quarter.
  • Per unit cash production costs (including lease operating, transportation, gathering and compression, production and ad valorem taxes) were $1.39 per Mcfe, including $0.27 per Mcfe in firm transportation expenses.
  • Net loss for the first quarter of 2018 was ($2.6) million; and Adjusted EBITDAX1 for the first quarter of 2018 was $63.0 million.
  • Established second quarter 2018 guidance and updated full year 2018 guidance including the reduction in the capital expenditure budget by approximately $60 million to now reflect approximately $250 million in estimated capital expenditures for the full year 2018.

Benjamin W. Hulburt, Chairman, President and CEO, commented on the Company’s first quarter 2018 results, “This was another solid quarter for the Company and the execution of our 2018 plan is off to a strong start as we exceeded our production and cash flow expectations while expanding our margins by keeping our operating expenses and our general and administrative expenses low.

As was detailed during our analyst day presentation, we continue to focus on liquids development during 2018, with all 5 gross (3.7 net) wells that were turned to sales during the first quarter 2018 generating a significant liquids production. These wells included our first two operated Marcellus wells and three Utica Condensate wells. Our production on a per Mcfe basis was 28% liquids for the first quarter 2018, and given the current commodity pricing environment, this liquids production aided in an increase in our year over year liquids revenue of approximately 36% and equating to approximately 47% of our total unhedged revenue.

We have recently completed drilling our first Utica Shale well in Pennsylvania in our “Flat Castle” project area. This well was drilled to 25,017 feet of total measured depth with a horizontal lateral of 13,857 feet. Additionally, during the first quarter of 2018, we brought on our second completions crew to accelerate completions on our backlog of wells created by our two rig drilling program. The completions team has had a highly productive quarter averaging over 6.5 stages per day with minimal downtime despite the harsh winter environment.

As we continue to analyze our capital plan for the full year 2018, the Company intends on taking a disciplined and financially prudent approach designed to preserve our financial strength. As part of this effort, and in light of current outlook for natural gas prices, we are lowering our capital expenditure forecast for 2018 by approximately 20% reflecting our plan to reduce our net capital expenditures in the second half of the year. This plan will be executed through one of two approaches currently under consideration. As we near completion of our first two drilling programs in our Utica Shale drilling joint venture with Sequel Energy Group, LLC we are actively discussing the optional third program with our partner. As an alternative to continuing the drilling joint venture, we are also reviewing the merits of releasing one of our rigs in the third quarter. With either of these options the Company will continue to fund a one net rig program as we are today. As such, we are revising our guidance on our full year 2018 capital expenditures plan to approximately $250 million, materially below the Company’s initial 2018 guidance of $300-$320 million.

Consol 1st Qtr. Financial Update.  CNX Resources on Thursday reported first-quarter sales of natural gas and liquids jumped 36% from a year ago, to 129.5 billion cubic feet-equivalent (Bcfe), from 95.0 Bcfe, driven primarily from Utica Shale play volumes.

Utica Shale volumes, including liquids, in the quarter were 43.5 Bcfe, roughly 184% higher than the 15.3 Bcfe in the year-earlier quarter, consistent with the company's previously stated expectations Utica Shale volumes would ramp in the fourth quarter of 2017 and the first quarter of 2018, driven primarily from activity in Monroe County, Ohio.

 

In addition to the production, the ramp in Monroe County volumes also benefited overall Utica Shale total production costs, which were $1.60 per thousand cubic feet-equivalent (Mcfe) in the just-ended quarter, or a $0.56 per Mcfe improvement from the year-ago quarter.

"Our first full quarter ... was a successful quarter highlighted by strong operational execution; cash flows growing materially; approximately $102 million in asset sales; closing on the previously announced acquisition of the remaining 50% membership interest in CNX Gathering; selling the West Virginia Shirley-Pennsboro gathering system to CNXM for $265 million; additional stacked pay delineation; and the continuation of the share repurchase program," said Nicholas J. DeIuliis, CNX president and CEO.

During the quarter, CNX received roughly $102 million from asset sales, which included approximately $88 million for the sale of CNX's shallow oil and gas (SOG) assets, as well as proceeds for the sale of scattered acreage and other miscellaneous assets. In connection with the SOG sale, the buyer assumed approximately $200 million of liabilities primarily associated with asset retirement obligations, which CNX had on its balance sheet.

In the first quarter, CNX operated three horizontal rigs and drilled 19 wells: two Utica Shale wells in Monroe County, Ohio; seven Marcellus Shale wells in Greene County, Pa.; and 10 Marcellus Shale wells in Washington County, Pa.

CNX in the first quarter of 2018 recorded net income of $527.56 million, on revenue of $495.73 million, compared to a year-ago net loss of $38.97 million, on revenue of $319.93 million.

The independent producer's net income was greater than revenue primarily was due to a $623.66 million gain on a previously-held equity interest.

Eclipse Resources 1st Qtr. Financial Update.  Eclipse Resources reported its first-quarter 2018 production in the Appalachian Basin was 315.2 million cubic feet-equivalent per day (MMcfe/d), up 8.7% from 290 MMCfe/d one year ago.

The company also announced it is reducing its 2018 capital spending and making other cuts, Kallanish Energy reports. Eclipse said it is cutting its 2018 CAPEX by 20% -- $60 million -- to reduce costs in the second half of the year.

It intends to spend roughly $250 million on capital projects, not the $300 million to $320 million that had been publicly released earlier.

It has been operating two rigs but that could be reduced to one rig, the company said. And it's accelerating its well completions in the Appalachian Basin by adding a second crew.

The company said it is also revising its cash general and administrative expense guidance downward by 8% for full-year 2018.

It turned to sales five gross (3.7 net) wells in Q1, including three Utica condensate wells and its first two operated Marcellus wells.

The company that is looking at future financial and organizational options said it is trying to focus on liquid-rich wells. That strategic review is continuing.

Hulburt added, “This was another solid quarter for the company and the execution of our 2018 plan is off to a strong start as we exceeded our production and cash flow expectations, while expanding our margins by keeping our operating expenses and our general and administrative expenses low.”

The company is drilling its first Utica Shale well in north-central Pennsylvania. The Flat Castle well was drilled to 25,017 feet of total measured depth with a horizontal lateral of 13,857 feet, the company said.

The company reported a Q1 2018 net loss of $2.6 million, compared to net income of $26.8 million in the year-ago quarter. Revenue in Q1 was $110.2 million, up from $101.86 million.

MPLX 1st Qtr. Financial Update.   MPLX, the Marathon Petroleum-sponsored midstream company, reported positive operations, leading to strong earnings for the quarter ended March 31.

The Ohio-based midstreamer, who is expected to benefit from the $23 billion buy of independent refiner Andeavor by Marathon Petroleum, reported gathered volumes jumped 31%, to 4.17 billion cubic feet per day (Bcf/d), from 3.18 Bcf/d, and processed volume rose 8%, to 6.63 Bcf/d, from 6.13 Bcf/d from one year ago.

Total fractionated barrels year-over-year climbed 15%, to 367,000 barrels, to 423,000 Bbls, Kallanish Energy reports.

Gathering and processing revenue jumped 13.3%, to $350 million, from $309 million in the year-ago quarter.

Total quarterly revenue for MPLX was $1.42 billion, from $886 million for the quarter ended March 31, 2017.

Profit for the recent quarter jumped more than 180%, to $421 million, from $150 million in the year-earlier quarter.

"Our record financial results reflect MPLX's significant transformation into one of the largest diversified master limited partnerships in the energy sector," said Gary R. Heminger, chairman and CEO. "The dropdowns (from Marathon Petroleum) of the past year have nearly doubled the partnership's earnings base, and the elimination of incentive distribution rights improves the partnership's cost of capital."

Williams 1st Qtr. Financial Update.  Williams reported unaudited first-quarter 2018 net income attributable to Williams of $152 million, a decrease of $221 million from first-quarter 2017. The unfavorable change was driven primarily by the absence of a $269 million gain in first-quarter 2017 associated with a transaction involving certain joint-venture interests in the Permian basin and Marcellus shale. Commodity margins were $59 million lower due primarily to the absence of margins from the Geismar olefins (chemical) facility, which was sold July 6, 2017. The unfavorable change also reflects the absence of $43 million of gains on early retirement of debt and contract settlements and terminations, and $25 million lower equity earnings due primarily to lower earnings at Discovery Producer Services. Partially offsetting the decreases were $90 million increased service revenues due primarily to Williams Partners' Transco expansions and higher gathered volumes in the Williams Partners' West business segment and $43 million lower operating and maintenance (O&M) and selling, general and administrative (SG&A) expenses. The year-over-year change also includes a modest increase in income tax expense reflecting the absence of a $127 million prior-year benefit from the expected utilization of a capital loss carryover and a reduction in income attributable to noncontrolling interests.

Williams reported first-quarter 2018 Adjusted EBITDA of $1.135 billion, a $10 million decrease from first-quarter 2017. Williams Partners' current business segments improved by $53 million over the same period in 2017, driven by $58 million increased revenues from Williams Partners' Transco expansion projects being placed into service in 2017 and 2018 and a $14 million increase in natural gas liquids margins. Partially offsetting the increases was a $23 million decrease in proportional EBITDA from joint ventures due primarily to a significant decline in volumes on the Discovery system. The improvement from Williams Partners' current business segments was partially offset by the absence of $49 million Adjusted EBITDA earned in first-quarter 2017 from Williams Partners' former NGL & Petchem Services business segment primarily as a result of the sale of the Geismar olefins facility on July 6, 2017.

CEO Perspective

Alan Armstrong, president and chief executive officer, made the following comments:

“The organization utilized our stable foundation of advantaged positions to deliver another impressive quarter of steady growth driven once again by our consistent fee-based revenue growth as all three of our current business segments demonstrated year-over-year improvement in Adjusted EBITDA.

“The demand for low-cost U.S. natural gas continues to increase as reflected in the year-over-year growth in fee-based revenues that occurred thanks in large part to our ‘Big 5’ Transco expansions being placed into service last year. And that demand continues as we recently filed our application with FERC for our Southeastern Trail expansion project, another fully-subscribed Transco expansion.

“I’m extremely pleased with our project execution and operational performance in 2018. Already this year, we have set one- and three-day delivery records on Transco, established three new volume records on our Susquehanna Supply Hub, started construction on the Gulf Connector’s 475 MMcf/d Gulf Coast LNG delivery expansion, reached several key milestones on the 1,700 MMcf/d Atlantic Sunrise project, placed Phase 2 of the Garden State Transco expansion into service, and also placed additional gathering expansions into service on our Susquehanna Supply Hub in Pennsylvania and Wamsutter Gathering System in Wyoming.

“No one is as well positioned as Williams to capture the ongoing demand growth of natural gas in the U.S., and we look forward to updating investors about our significant achievements and plans for the future at our Analyst Day event May 17.”

Supreme Court Kills Constitution Pipeline.  The U.S. Supreme Court on Monday rejected Constitution Pipeline Co’s effort to challenge New York state’s refusal to issue a needed water permit for the project.

The high court left in place an August 2017 ruling by the New York-based 2nd U.S. Circuit Court of Appeals in favor of the state.

Partners in the 125-mile pipeline project from Pennsylvania into New York state include Williams Cos., Duke Energy, WGL Holdings, and Cabot Oil & Gas.

Cabot spokesman George Stark referred all questions from Kallanish Energy to Williams; Williams could not be reached to comment.

The Federal Energy Regulatory Commission first approved construction of the project in 2014, then again in 2016, conditioned on other approvals.

Constitution separately sought water quality certification with the New York Department of Environmental Conservation in August 2013.

The state denied the application in April 2016, saying the company failed to provide sufficient information to determine whether the project would comply with the state’s water quality standards.

Constitution appealed that decision to the 2nd Circuit, but lost. The Supreme Court’s refusal to hear the company’s appeal of the 2nd Circuit’s ruling does not necessarily kill the project. The company has separately petitioned FERC to overturn the state agency’s decision. In March, the federal regulator gave itself more time to consider the issue.

If built, the pipeline would transport 650 million cubic feet per day (MMcf/d) of Marcellus Shale natural gas from Pennsylvania, into New York State.

More NatGas-Fired Plants Coming.  Dominion Energy Virginia said that it plans to build at least eight new natural gas-fired plants during the next 15 years, cementing its shift away from coal, while depending on renewables for less than 10 percent of its energy capacity. Virginia’s largest utility described how it will generate power to comply with regulations and meet customer needs between 2019 and 2033 in a regulatory filing called an integrated resource plan. Dominion plans to increase solar generation by nearly 50 percent over last year’s forecast, a change made possible in part because of the technology’s increasing affordability, company executives said in an Associated Press interview. A number of coal- and oil-fired power plants will likely be retired, and while Virginia’s four existing nuclear units will remain in use, plans for a fifth reactor remain shelved, for now. Altogether, this plan puts the utility on an “environmentally responsible, sustainable path” for the long term, said Paul Koonce, president and CEO of parent company Dominion Energy’s power generation group.

Pipelines Coming to the Bakken.  ONEOK has won approval from North Dakota regulators for a $1.8 million liquids pipeline project, Kallanish Energy reports.

The North Dakota Public Service Commission on Monday approved the Cherry Creek Pipeline in northwest North Dakota. The agency said the pipeline would be a safer transportation option for natural gas liquids and help reduce the wasteful flaring of natural gas in the Bakken Shale.

The project, being developed by ONEOK Rockies Midstream, will convert roughly 45 miles of an existing gas-gathering pipeline and a portion of another gas-gathering line into a transmission pipeline for natural gas liquids.

The pipeline will move up to 50,000 barrels per day (BPD) of NGLs from the Lonesome Creek gas-processing plant in McKenzie County, to the Stateline Gas Plant in Williams County where it will go into the Bakken Pipeline.

ONEOK is currently constructing a separate NGL pipeline in the Bakken Shale. The $1.4 billion Elk Creek Pipeline will run 900 miles from eastern Montana to Bushton, Kan., where it will connect with the company’s Mid-Continent NGL facilities.

The 20-inch line will initially transport 240,000 barrels a day (BPD) with expansion possible to 400,000 BPD. It is projected to be in-service by late 2019.

It will complement the company’s existing Bakken NGL Pipeline and the Overland Pass Pipeline of which ONEOK owns 50%.

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PA Permits April 26, to May 3, 2018

            County                                   Township                                          E&P Companies

  1. Elk                                                Jones                                                 Seneca
  2. Susquehanna                            Harford                                               Cabot
  3. Susquehanna                            Harford                                               Cabot
  4. Susquehanna                            Harford                                               Cabot
  5. Tioga                                            Delmar                                               Seneca
  6. Tioga                                            Delmar                                               Seneca
  7. Tioga                                            Delmar                                               Seneca
  8. Tioga                                            Liberty                                                Reposol
  9. Tioga                                            Liberty                                                Reposol
  10. Tioga                                            Liberty                                                Reposol
  11. Tioga                                            Liberty                                                Reposol
  12. Tioga                                            Liberty                                                Reposol

OH Permits for week ending April 28, 2018

             County                                   Township                                          E&P Companies

  1. Jefferson                                     Cross Creek                                      Ascent
  2. Jefferson                                     Cross Creek                                      Ascent
  3. Jefferson                                     Cross Creek                                      Ascent
  4. Jefferson                                     Cross Creek                                      Ascent
  5. Jefferson                                     Cross Creek                                      Ascent

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

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