Monday, May 20, 2019

Welcome to!  As severe weather pounds the plains of Oklahoma and Texas again today, spot natural gas prices are rebounding slightly in advance of June’s NYMEX close. 

Today, we’ll also review the latest interstate pipeline company critical notices plus provide an update on latest energy news and give you the latest National Weather Service temperature forecast for the month of June, too.


At the New York Mercantile Exchange (Nymex) today, the price of the June 2019 contract increased by nearly four cents to about $2.67/MMBtu on Monday.  The price of the 12-month strip averaging June 2019 through May 2020 futures contracts has gained about six cents the past week to nearly $2.81/MMBtu. 

From the US Energy Information Administration’s “Natural Gas Weekly Update” publication…

Net injections to working gas totaled 106 billion cubic feet (Bcf) for the week ending May 10. Working natural gas stocks are 1.653 Tcf, which is 15% lower than the five-year (2014–18) average for this week.

The natural gas plant liquids composite price at Mont Belvieu, Texas, rose by five cents, averaging $5.73/MMBtu for the week ending May 15. The price of ethane and natural gasoline fell by 2% and 1%, respectively. The price of propane, isobutane, and butane rose by 3%, 2%, and 1%, respectively.

According to Baker Hughes, for the week ending Tuesday, May 7, the natural gas rig count remained flat at 183. The number of oil-directed rigs fell by 2 to 805. The total rig count decreased by 2, and it now stands at 988.


Global investment firm KKR and Western Natural Resources, LLC (“Western”) today announced a new partnership to acquire producing and undeveloped oil and gas assets in the Williston Basin.

Western’s CEO Heath Mireles and his team bring extensive operating experience to the partnership, having drilled, completed and operated thousands of wells over the Williston Basin’s long history. The Western team will leverage their collective experiences from time spent at large public operators as well as other private companies to acquire, manage and develop producing wells and drilling locations throughout the play.

Ben Conner, Director on KKR’s Energy Real Assets team, said, “The Williston continues to be a core area of focus for us as we see a significant opportunity to acquire high quality producing assets with attractive long-term value creation opportunities to be delivered through superior technical and operational execution. We have known Heath and members of his team for years and believe our partnership is well positioned to acquire and manage assets in the Williston for the long run.”

Western is a private company focused on the acquisition and exploitation of upstream oil and gas assets. Headquartered in Oklahoma City, Oklahoma, its primary objective is to build and operate a large-scale portfolio of producing oil and gas wells and drilling locations in the Williston Basin.


Today, NRG Energy, Inc. agreed to acquire Dallas-based Stream Energy’s retail electricity and natural gas business for $300 million plus working capital in an all-cash transaction.

“This transaction will strengthen NRG’s position as a growing, customer-driven energy company. It represents another step in perfecting our integrated business model,” said Mauricio Gutierrez, president and chief executive officer, NRG Energy. “Stream Energy’s retail energy business provides NRG an attractive opportunity to increase our national retail leadership position and potential for growth.”

Stream Energy, one of the largest direct selling companies in the energy market and one of the nation’s fastest growing retailers, serves more than 600,000 Residential Customer Equivalents (RCEs) in nine states and the District of Columbia. The transaction is expected to increase NRG’s market share in Texas, Pennsylvania and a number of other markets in the Eastern U.S., accelerating the pace of growth in these markets. The combination will also enhance NRG’s multi-brand strategy.

The transaction is expected to close in the third quarter of 2019 and is subject to various customary closing conditions, approvals and consents, including the Federal Energy Regulatory Commission (FERC), Georgia Public Service Commission, and antitrust review under Hart-Scott-Rodino.


Late last week, Freeport LNG announced that it has received approval from the U.S. Federal Energy Regulatory Commission (FERC) to site, construct and operate its fourth natural gas liquefaction train, to be integrated into its existing natural gas liquefaction and LNG export facility on Quintana Island near Freeport, Texas. Approval from the U.S. Department of Energy for the export of Train 4 volumes to non-Free Trade Agreement countries is anticipated later this quarter.

Freeport LNG’s Train 4 is expected to add over 5 million tonnes per annum (mtpa) of LNG production to its existing project, increasing the total export capability of the 4-train facility to over 20 mtpa. Approximately 13.5 mtpa of this capacity has been contracted under 20-year tolling agreements to Osaka Gas Trading & Export, LLC, JERA Energy America, LLC, BP Energy Company, Toshiba America LNG Corporation, and SK E&S LNG, LLC, and approximately 0.5 mtpa has been contracted to Trafigura PTE LTD under a 3-year sale and purchase agreement commencing in 2020.

Train 4 operations are anticipated to commence in 2023.


Now, let’s check the latest critical notices from the interstate natural gas pipeline grid:

Columbia Gas Transmission:

Columbia Gas Transmission, LLC (TCO) continues to work with upstream operators due to the operational event experienced by Markwest at the originally referenced Salem Plant.  Markwest has since clarified that the outage was on a line feeding the Hopedale Fractionation Plant in Salem, WV. 

TCO encourages customers to coordinate with its upstream operator regarding scheduled volumes for Gas Days Monday, May 20, 2019 and Tuesday, May 21, 2019. 

At this time, the operational event is anticipated to be resolved later today, May 20, 2019.  TCO will provide an update as soon as information becomes available.  Please contact your Customer Services Representative with any questions.

***Previous Posting***

Columbia Gas Transmission, LLC (TCO) has been notified of an operational event at the Markwest Salem Plant that is impacting scheduled deliveries into TCO.  TCO is working closely with Markwest and upstream operators to assess the impact, as well as a timeline for repairs. The Markwest Salem Plant impacts deliveries into TCO at the following points: 

642452 – CMG Majorsville

643053 – Gibraltar III

643106 – Majorsville-LXP

642645 – Sherwood1

642824 – Smithfield-Mobley

643185 – Sherwood-MXP

842867 – Braxton 

The current estimated impact is a reduction in supply on the TCO system of approximately 2.1 MMDth, necessitating a curtailment of scheduled volumes by the upstream point operators effective ID1 Cycle for Gas Day Sunday, May 19, 2019 and Timely Cycle for Gas Day Monday, May 20, 2019.  

El Paso Natural Gas:

EPNG remains concerned about delivery point operators taking their gas according to their scheduled quantities as a result of the forecast below average temperatures in the Desert Southwest. The SOC Warning for a high linepack condition issued on May 17, 2019 (Notice No. 605375) remains in effect.  

Washington Ranch is on maximum injection. 

Delivery point operators are encouraged to continue to take gas according to their scheduled quantities.  If the situation fails to improve EPNG will declare an SOC for a PACK condition. 

Supply operators are encouraged to reduce and/or maintain their deliveries into the EPNG system at their scheduled rates.   

Payback to the system, such as Payback (Imbalance Payback to TSP), may be limited or denied due to operational concerns related to the potential for a high linepack condition.  For scheduling questions, please call your scheduling representative at (800) 238-3764.

Also from El Paso:

EPNG will be conducting bottom hole surveys at the Washington Ranch Storage Facility starting Monday, June 10, through Friday, June 14. During this scheduled maintenance, operational flexibility will be extremely limited as no injection or withdrawal from the storage facility will be possible.   

Shippers are strongly encouraged to closely monitor their receipts and deliveries to ensure that their transportation is balanced during this time frame. If significant and persistent imbalances are experienced, EPNG may need to issue an SOC or COC, and/or take the necessary action to limit excess receipts into the system. 

Northern Natural Gas:

The results of the recent in-line inspections for sections of Northern’s pipeline system between the Beaver, Oklahoma and Mullinville, Kansas compressor stations have come back favorable and no additional reduction in operating capacity for Beaver North (Group 1025) is necessary.

The outage capacity will remain at 820,000 Dth for the group. As a result, Northern is willing to sell incremental capacity up to 62,259 Dth through Beaver North for Gas Day May 21, 2019.

Northwest Pipeline:

Due to high inventory levels at the Jackson Prairie storage facility (JP), Northwest is no longer accepting IT storage injections at JP beginning gas day Wednesday, May 22, 2019.

Northwest is not currently requesting SGS-2I storage customers vacate the facility.  Northwest will provide notice to begin the interruptible service vacate process when the Jackson Prairie facility balance is approximately 90 percent full. Discretion will be used to determine the percentage each interruptible storage customer will be required to vacate allowing Northwest to meet its firm obligations at the facility. Upon said notice, SGS-2I shippers will have seven (7) days to comply.

Northwest would also like to remind its shippers that the storage inventory levels as well as Park and Loan availability is posted each morning on Northwest’s website at

Please contact your Marketing Services Representative or the Northwest Pipeline Hotline at (801) 584-7301 if you have any questions.

Southern Natural Gas:

On Tuesday May 21, 2019, Southern will post the May/June/July and other 2019 Maintenance projects.

On Wednesday, May 22, 2019 at 1:30 PM (Central Time) Southern will conduct a conference call/WebEx meeting and review the posted information.  For more information on how to participate in the conference call/WebEx, please review the Southern Natural Gas EBB posting dated May 20, 2019.


The National Weather Service has published their initial temperature forecast for the upcoming month of June.  Temperatures are expected to be warmer than average along the Atlantic coast as well as along the Pacific coast.   Meanwhile, several states in the midsection of the country from the Dakotas and Nebraska down to Texas are shown with cooler than seasonal weather for June. 

That’s all for this Monday edition of  Please let your friends in the natural gas scheduling and transportation business know about us! 

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Thursday, May 2, 2019

Welcome to!  We always review the country’s interstate natural gas pipeline companies for their most recent critical postings and bring you information about changes in pipeline operating conditions. 

Plus, we will update you on the latest publicly released news from major energy companies and, with golf weather covering most of the country, provide the extended temperature forecast for the next few weeks from the National Weather Service, too.  


According to the US Energy Information Administration, working gas in storage was 1.462 Tcf as of Friday, April 26, 2019. This represents a net increase of 123 Bcf from the previous week.

Natural gas in storage is now 316 Bcf (approximately 18%) below the five-year average.


NRG Energy, Inc. expects to return to service its inactive 385 MW Gregory natural gas plant in Corpus Christi, Texas. The Gregory plant ceased operations in late 2016 when its cogeneration partner, Sherwin Alumina, filed for bankruptcy and discontinued operations. Following resolution of certain issues resulting from the Sherwin Alumina bankruptcy, the Gregory plant is expected to return to service as a combined cycle facility in early June 2019.

“I am pleased to announce the return to service of this highly efficient natural gas plant,” said Mauricio Gutierrez, President and CEO of NRG. “The Public Utility Commission of Texas’ recent actions to further strengthen the ERCOT market reinforced our decision to return Gregory to service ahead of summer, providing additional reliability to our customers and Texas’ growing economy.”

At full power, the Gregory plant can meet the needs of approximately 77,000 homes on the hottest days of the year.


Despite warmer weather across much of the United States, there are still several critical postings coming from the electronic bulletin boards of the major interstate natural gas pipeline transporters. Let’s review the latest news:

Algonquin Gas Transmission:

In order to maintain the operational integrity of the system, Algonquin Gas Transmission, LLC (AGT) is issuing an Operational Flow Order (OFO) pursuant to Section 26 of the General Terms and Conditions of AGT’s FERC Gas Tariff effective 9:00 AM CCT, May 2, 2019, to all parties, with the exception of those Operational Balancing Agreements required by FERC regulations, on the AGT system.

This OFO does not affect the ability of AGT to receive or deliver quantities of gas for scheduled nominations to any customer or pipeline.

During the effectiveness of this OFO, all parties must be balanced such that actual deliveries of gas out of the system must be equal to or less than scheduled deliveries. The penalty shall apply to each dekatherm of actual delivery quantities that exceeds the greater of 4,000 Dth or 104% of scheduled delivery quantities. The penalty will be equal to three times the daily Platts Gas Daily “Daily Price Survey” posting for the High Common price for “Algonquin, city-gates” for the day on which such violation occurred as indicated in AGT’s General Terms and Conditions Section 26.8. In addition, AGT will not permit retroactive nominations to avoid an OFO penalty.

AGT may be required to issue an hourly OFO pursuant to General Terms and Conditions Section 26.7(d) to impose further restrictions in order to maintain the operational integrity of the system.

As previously posted AGT, requests that customers/point operators on AGT be aware of the impact non-ratable hourly takes from the system may have in causing delivery pressures reaching lower than desired levels. As a reminder, AGT’s system is not designed to sustain delivery pressures above contract levels while making non-ratable/accelerated deliveries above scheduled quantities for more than 6 consecutive hours, to be followed by flows below scheduled quantity for the balance of any 24 hour period.

Furthermore, if customers/point operators don’t manage hourly takes from the system, 1) delivery pressures will be impacted and /or 2) AGT may be required to impose further restrictions or courses of action in order to maintain the operational integrity of the system.

This OFO will remain in effect until further notice.

ANR Pipeline:

Bridgman Northbound Capacity Reduction (Updated 05/01/19)

ANR will continue planned pipeline and compressor maintenance along its Michigan Leg North Segment located in the Northern Fuel Segment (Zone 7). This will reduce the total Bridgman Northbound (Loc ID #226632) capacity by the following:

Bridgman Northbound (LOC #226632):

375-MMcf/d – (leaving 1,226 – MMcf/d available) 5/1 – 5/3
65-MMcf/d – (leaving 1,536 – MMcf/d available) 5/4 – 5/6
375-MMcf/d – (leaving 1,226 – MMcf/d available) 5/7 – 5/20
40-MMcf/d – (leaving 1,561 – MMcf/d available) 5/21 – 6/2
325-MMcf/d – (leaving 1,276 – MMcf/d available) 6/3 – 8/12

Since the last posting, the end date of the first maintenance period has been extended from 5/2 to 5/3, and each subsequent outage period has been adjusted accordingly.

Based on current nominations through Bridgman Northbound, it is anticipated that this posting may result in the capacity allocation reduction of IT and Firm Secondary. This posting will be updated as more information becomes available.

Colorado Interstate Gas (CIG):

Effective May 5, 2019, Colorado Interstate Gas Company, L.L.C. (CIG) is removing the limitation on Transportation Service (NNT) requests for NNT authorized withdrawals declared in Notice Number 118466.

No limit is currently placed on requests for NNT authorized injections or withdrawals. 

Dominion Energy Transmission:

Due to integrity issues affecting LN-24 and LN-541 (Notice ID 213991), effective ID1 cycle for gas day May 2, 2019, Dominion Energy Transmission, Inc (DETI) will not accept any increases in Secondary or IT transport for delivery to the following meters:


Effective gas day May 3, 2019 the above meters will be limited to Primary Only deliveries until further notice. Please note that “Unauthorized Overrun Charges – Daily” rate of $10.00/dth will apply to deliveries made in excess of FT and FTNN entitlements while these restrictions are in place.

Gulf South Pipeline:

Hall Summit Expansion Compressor Station Maintenance: 

Begins:  May 19, 2019            Ends:  May 27, 2019

Expansion Receipts Upstream Vixen Scheduling Group – Capacity could be impacted by up to 300,000 dth/d for the duration of the maintenance.  Please contact your customer service representative if you have any questions.

Natural Gas Pipeline Company of America (NGPL):

Natural has experienced horsepower issues at Compressor Station 167 (CS 167), located in Lea County, New Mexico that require Natural to shut-in CS 167 for the duration of this restriction.  This is a Force Majeure event that will limit Natural’s throughput capacity from receipts south of CS 167 and just north of CS 167 (from LOC 908135 Targa Saunders Plt). 

The scheduling constraint will be north of CS 167; therefore, any gas received south of CS 167 from either Segment 7 or Segment 9 receipt points for delivery north of CS 167 will be impacted for the duration of the restriction.  Additionally, transports associated with storage injections will be impacted.  The Permian Pool (LOC 25077) is located south of the constraint. 

As such, effective for gas day Thursday, May 2, 2019, Intraday 1 Cycle, and continuing until further notice, Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 74% of contract MDQ through CS 167.  Actual nomination levels and changes in pipeline conditions could result in changes to the percentages scheduled (lower or higher) on subsequent gas days.  AOR/ITS and Secondary out-of-path Firm transports continue to not be available for the duration of this restriction.

Southern Natural Gas:

Based on current milder temperatures and resulting lower demand on Southern’s system, SNG is currently experiencing high line pack on the system.  SNG encourages all shippers to manage their system requirements to maintain balance between actual receipts and deliveries.  An Operational Flow Order for long imbalances could be required to help ensure system integrity as Southern’s Tariff provides that a Type 6 OFO can be implemented on four hours’ notice or less prior to the start of the gas day.

Deliveries with actual flows less than scheduled daily volumes are subject to reductions of nominations to demonstrated daily volumes.  Receipts should not exceed scheduled daily volumes.

We request that all Shippers/Poolers monitor the balance between actual receipts and deliveries to ensure that a daily out-of-balance situation does not occur.  Additionally, SNG requests all payback be nominated. 


The latest six-to-ten day temperature forecast from the National Weather Service for May 8 – 12 reveals that warmer than average May temperatures will be seen along both the East and West coasts of the US.  For the midsection of the country, though, cooler than average temperatures will prevail from Texas northward into the Northern Plains during the second week of the month.

Thanks for joining us at  We’ll be back on Monday to bring you the publicly sourced natural gas pipeline and energy news for you along with an updated weather outlook for the coming week. 

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