Welcome to GasNewsOnline.com! 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 provide the extended temperature forecast for the next few weeks from the National Weather Service, too.
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From the US Energy Information Administration, working gas in storage was estimated at 1,653 Bcf as of Friday, May 10, 2019. This represents a net increase of 106 Bcf from the previous week.
Stocks were 130 Bcf higher than last year at this time and 286 Bcf below the five-year average of 1,939 Bcf. At 1,653 Bcf, total working gas is within the five-year historical range.
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OG& E Chairman, President and CEO Sean Trauschke today told the company’s shareholders that the company is “strong and built for the long term.” Speaking at the company’s annual meeting, Trauschke said he was pleased with the performance of OG&E, Oklahoma’s largest investor-owned utility, and Enable Midstream, in which the company owns interest, as both had contributed to the company’s ability to invest in its customers, and maintain utility rates that are 31 percent below the national average.
“2018
will be the benchmark the company uses to gauge future performance. OG&E completed its largest
ever investment program, wrapping up more than $6 billion of infrastructure
investment since 2011, on time, under budget and while receiving recognition as
the safest utility in the Southeastern Electric Exchange,” Trauschke said.
“At Enable, we’re seeing continued solid operational and financial results, while volumes
are increasing across all of their business segments.”
Looking
ahead, he said the company will continue to focus on growing the business
through an enhanced customer experience at affordable rates. “The new
assets we’ve put into operation have increased fleet resiliency for customer
benefit. We will continue to leverage our smart meters and technology that
increases reliability and reduces outage response and restoration times.”
OGE Energy is the parent company of Oklahoma Gas and Electric Company, a regulated electric utility serving approximately 852,000 customers in Oklahoma and western Arkansas. In addition, OGE holds a 25.5 percent limited partner interest and a 50 percent general partner interest of Enable Midstream Partners, LP.
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On Tuesday, Sempra Energy celebrated the completion of construction of Train 1 of the Cameron LNG export project in Hackberry, La., with a group of international, federal, state and local officials, including the U.S. president and members of the U.S. administration. The celebratory visit coincided with today’s announcement that Cameron LNG is producing liquefied natural gas (LNG) from the first liquefaction train of the three-train facility, a major commissioning milestone.
Sempra Energy set a goal in 2018 to
become the largest developer of North American LNG export infrastructure,
targeting 45 million tonnes per annum of LNG export capacity to serve global
markets.
“With
a renaissance in domestic energy production, Sempra Energy is pleased to
advance America as one of the world’s largest exporters of LNG,”
said Jeffrey W. Martin, chairman and CEO of Sempra Energy. “We
are committed to providing a cleaner fuel source to the global markets while
supporting job creation right here at home.”
Cameron LNG Phase 1 is one of five LNG projects Sempra Energy is developing in North America. Other projects under development include Cameron LNG Phase 2, previously authorized by the Federal Energy Regulatory Commission (FERC), which could include up to two additional liquefaction trains and up to two additional LNG storage tanks; Port Arthur LNG in Texas, which recently was approved by FERC; and Energía Costa Azul LNG Phase 1 and Phase 2 in Mexico.
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Several interstate natural gas pipeline companies have posted notices warning customers that there isn’t much room left for excess gas supplies heading into the weekend. Let’s review the latest EBB postings:
ANR Pipeline:
ANR will begin planned maintenance at the Brownsville (Tennessee) Compressor Station located in the Southeast Southern Segment (Zone 2). The total Brownsville Southbound (LOC #1260569) capacity will be reduced by the following:
Based on current nominations, it is anticipated that this posting may result in the capacity allocation reduction of IT, Firm Secondary and possibly a portion of Firm Primary volumes. Since ANR anticipates that this restriction may impact its ability to deliver all nominated Firm Primary services, ANR will apply the Reservation Charge Crediting Mechanism of Section 6.36.4 as necessary. This posting will be updated as more information becomes available. Additionally, customers may experience lower than normal line pressures south of the Brownsville Compressor Station.
The estimated impact to Firm Primary is as follows:
17% – Based on the Current Net Southbound Shipper Nominations 20% – Based on the Current Southbound Contracted MDQ
Columbia Gas Transmission:
Columbia
Gas Transmission, LLC (TCO) reminds
customers of upcoming pigging on MXP Line 100 (previously posted on the
Construction and Maintenance Schedule) beginning Tuesday, May 21, 2019 through Friday, May 24,
2019. Due to the pigging, the below impact is anticipated for the
following Gas Days:
643131
– Corral:
May
21, 2019 – 0 Non-Firm
SHERWODB
– Sherwood B MA42:
May
21, 2019 – 940,000 Total Capacity
MXPSEG
– MXPSEG MA42:
May
22, 2019 – 1,720,000 Total Capacity
May
23, 2019 – 1,600,000 Total Capacity
May
24, 2019 – 1,600,000 Total Capacity
Based on current scheduled volumes,
there are no anticipated reductions to firm service.
As a reminder, the impacted capacities will not be reinstated until the work is
complete, which may impact Timely and Evening Cycle nominations for Gas Day May
25, 2019.
Reservation
charge credits will be determined per the process set forth in the General
Terms and Conditions, Section 38 of TCO’s FERC Gas Tariff. Any shipper
eligible for reservation charge credits should review this section and comply
with the described process to ensure receipt of any credits.
Dominion Energy Questar Pipeline:
Effective Gas Day May 16, 2019, Timely Cycle and continuing until further notice, Dominion Energy Questar Pipeline (DEQP) will not allow in-kind imbalance payback to the pipeline and is requiring shippers and point operators to have production volumes aligned with scheduled nominations.
This notice is due to the high inventory in DEQP’s Clay Basin balancing account and current pipeline conditions resulting in minimal line pack available for balancing.
Customers with questions should contact their DEQP representative or call the Customer Service Hotline at (801)324-5200.
Gas Transmission Northwest (GTN):
Effective immediately,
GTN Pipeline is issuing an OFO watch. GTN Pipeline is concerned about the
operational integrity of its system as a result of high line pressures.
The OFO watch is in
effect through gas day Tuesday May 21st, in order to allow for GTN pipeline
system to regain its operational integrity. GTN has limited flexibility to
manage imbalances and strongly encourages all shippers manage their system
requirements to ensure the matching of receipts and deliveries daily.
Absent voluntary imbalance management by shippers to ensure daily balancing,
GTN may be required to take further action, including the immediate issuance of
an imbalance Operational Flow Order. If further action is required, it may be
necessary for that action to become effective immediately, with no additional
prior notice available.
This posting will be updated as more information becomes available. Please
contact your GTN Nominations Representative with any questions regarding
nominations or scheduling at (888)
750-6275
Gulf South Pipeline:
Index 818 – ILI Pigging Begins:
June 19, 2019 Ends:
June 21, 2019
Expansion Area 19 (Central Mississippi)
Delivery Scheduling Group – Capacity could be impacted by up to 500,000 dth/d
for the duration of the maintenance.
Please contact your customer service representative if you have any questions.
Mississippi River Transmission (MRT):
This
System Protection Warning
(SPW) is being issued to notify shippers of unplanned maintenance at MRT’s
Fountain Hill Compressor Station located in Ashley County, Arkansas, effective
May 17, 2019.
The unplanned maintenance on the
Fountain Hill Compressor Station will begin May 17, 2019 and is anticipated to
continue through September 30, 2019.
During this time, nominations and allocations to delivery points located
south of MRT s Fountain Hill compressor station will be subject to the
following criteria:
Nominations and allocations will need to be within their primary path and primary direction of flow. Nominations
and allocations will not be allowed to exceed their Line Priority, Rate Zone
Capacity or Line Capacity.
It may become necessary for MRT to
schedule down primary firm nominations during this period of unplanned
maintenance.
This System Protection Warning (SPW) will remain in effect until further
notice and will be updated as more information becomes available. If you have any questions concerning this
Alert, please contact your Scheduling Representative.
Natural Gas Pipeline Company of America (NGPL):
Effective
for gas day Thursday, May 16, 2019, and
continuing until further notice, Natural is at operating capacity for
gas going southbound through Compressor Station 302 located in Montgomery
County, Texas (Segment 26 of Natural’s Texok Zone) for deliveries eastbound
into Segment 25 or southbound into Segment 22. AOR/ITS and
Secondary out-of-path Firm transports are at risk of not being fully scheduled.
Tennessee Gas Pipeline:
Effective Timely
Cycle (9:00 AM CCT), for the Gas Day of Saturday, May 18, 2019,
Tennessee Gas Pipeline, L.L.C. (“Tennessee”) will not accept nominations for Interruptible Storage
Injection Services (IS-PA) at the Bear Creek (460017) or Portland (460025)
storage fields.
Tennessee will continue to not approve any transfers from
accounts at TGP Bear Creek Storage to SNG Bear Creek Storage (460017)(IS-PA,
FS-PA) until further notice. Transfers into TGP Bear Creek Storage
(460017) from SNG Bear Creek Storage will be allowed under the FS-PA storage
service only with partner
approvals.
Texas Gas Transmission:
Effective today (May 16), based on current operating conditions on
the Youngsville East Lateral (YVE) in Louisiana, capacity will be limited to 300,000
MMBtu.
Please contact your customer service
representative if you have any questions.
Transcontinental Gas Pipe Line Company (Transco):
Transco has been
advised that third party gas processing (North Terrebonne Gas Processing Plant)
straddling the Southeast Louisiana Lateral (SELA) is currently not
available. This condition is expected to continue until early next week.
Currently, Transco is able to manage gas quality for volumes received upstream of Station 62. However, the situation may require management of scheduled quantities upstream of Station 62 if increases are realized from current scheduled quantities.
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The latest six-to-ten day temperature forecast from the National Weather Service continues to project that above average temperatures will dominate the eastern US through May 26. The West Coast and Rockies will continue to see below normal weather conditions through late this month.
Thanks for joining us at GasNewsOnline.com! 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.
Please tell a friend in the natural gas scheduling and transportation business about us. Have a great weekend!
Welcome to GasNewsOnline.com! We always review the country’s largest interstate natural gas pipeline companies for their most recent critical postings and bring you information about changes in gas pipeline operating conditions.
Plus, we will update you on the latest publicly released news from major energy companies and provide the extended temperature forecast for the next few weeks from the National Weather Service, too.
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From the US Energy Information Administration, working natural gas in storage increased by 92 Bcf for the period ending Friday, April 19. Natural gas volumes in storage are 369 Bcf or 22% below the five-year average for the same week.
On the New York Mercantile Exchange, the May, 2019 natural gas futures price climbed nearly five cents on Thursday to close at nearly $2.51/MMBtu.
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Will there be a bidding war for Anadarko Petroleum? After last week’s bid by Chevron to acquire Anadarko, Occidental Petroleum Corporationsubmitted a competing bid for the company on Tuesday.
Occidental
delivered a letter to the Anadarko Board of Directors setting forth the terms
of a superior proposal by Oxy to acquire Anadarko for $76.00 per share, in
which Anadarko shareholders would receive $38.00 in cash and 0.6094 shares of
Occidental common stock for each share of Anadarko common stock. The Occidental
proposal represents a premium of approximately 20% to the value of Anadarko’s
pending transaction from Chevron.
Occidental
believes its proposal is superior both financially and strategically for
Anadarko’s shareholders, creating a global energy leader with the scale and
geographic diversification to drive growth and deliver compelling value and
returns to the shareholders of both companies. The combined company will be
uniquely positioned to leverage Occidental’s demonstrated operational and technical
expertise, producing greater anticipated synergies than Anadarko’s pending
transaction. The 50-50
cash and stock transaction is valued at $57 billion, based on Occidental’s
closing price on April 23, 2019, including the assumption of net debt and book
value of non-controlling interest.
“Occidental
is a leader in using technological innovation to create value, and we will
deploy our expertise to enhance the performance and productivity of Anadarko’s
assets not only in the Permian, but globally,” said Vicki Hollub, Oxy’s President and Chief Executive
Officer said, “Occidental and Anadarko have a highly complementary asset
portfolio, providing us with a unique opportunity to realize significant
operating, cost, and capital allocation synergies and achieve near-term cash
flow accretion.”
Vicki Hollub continued, “We have been focused on Anadarko for several years because we have long believed that we are ideally positioned to generate compelling value from a combination with them. We look forward to engaging immediately with Anadarko’s Board and stakeholders to deliver this superior transaction.”
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Murphy Oil Corporationannounced Tuesday that its wholly owned subsidiary, Murphy Exploration & Production Company – USA (“Murphy”), has entered into a definitive agreement to acquire deep water Gulf of Mexico assets from LLOG Exploration Offshore, L.L.C. and LLOG Bluewater Holdings, L.L.C.. The accretive, cash flow providing Gulf of Mexico assets currently produce approximately 38,000 barrels of oil equivalent per day net (Boepd) and are expected to add approximately 66 million barrels of oil equivalent net (Mmboe) of Proven (1P) reserves and 122 Mmboe of Proven and Probable (2P) reserves1.
Murphy will pay a cash consideration of
$1.375 billion. Additional contingent
consideration payments are based on the following: up to $200 million in the
event that revenue from certain properties exceeds certain contractual
thresholds between 2019 and 2022; and $50 million following first oil from
certain development projects. The transaction will have an effective date of January 1, 2019 and is
expected to close in the second quarter, subject to normal closing adjustments.
The
acquisition will be funded by a combination of cash on hand and availability
under the company’s $1.6 billion revolving credit facility. Total outstanding
borrowings under the revolving credit facility, including the current balance
of $325 million, are expected to be fully repaid immediately following the
closing of the previously announced $2.127 billion divestiture of Murphy’s
Malaysian assets.
“This immediately accretive transaction continues to strengthen our Gulf of Mexico portfolio by adding quality assets at a very attractive price. We expect these newly acquired assets to generate meaningful cash flow over the next several years that will provide us with additional flexibility for future capital allocation,” stated Roger W. Jenkins, President and Chief Executive Officer.
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There are several changes in the major interstate natural gas pipeline companies’ operating conditions to be aware of heading into the weekend. Let’s take a look:
ANR Pipeline:
ANR will begin 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:
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.
Also on ANR:
Willow Run Capacity Reduction (Updated 4/25/19)
ANR will continue planned pipeline maintenance between its Defiance Compressor Station and Willow Run Meter Station located in the Northern Area (Zone 7), which will result in the following capacity reduction:
Based on current nominations, it is anticipated that the above reductions may impact interruptible and firm secondary services.
Columbia Gas Transmission:
Columbia
Gas Transmission, LLC (TCO) reminds
customers of upcoming pigging on Line LEX (LXP) that will impact scheduled
volumes for certain hours in the gas day between Lone Oak Compressor Station
and Summerfield Compressor Station (May 1, 3) and between Summerfield
Compressor Station and Rockbridge Regulator Station (May 4, 6).
TCO is working with operators for
hourly operational assistance during the pigging. As a
result of this work, the following impact is anticipated at this time:
Gas Day May 1:
743093
– Stagecoach-LXP – 55,000 Total Capacity
743103
– Eureka – 200,000 Total Capacity
LONEOAKA
– Lone Oak A MA41 – 100,000 Total Capacity
LONEOAKB
– Lone Oak B MA41 – 565,000 Total Capacity
Gas Day May 3:
743093
– Stagecoach-LXP – 55,000 Total Capacity
743103
– Eureka – 200,000 Total Capacity
LONEOAKA
– Lone Oak A MA41 – 125,000 Total Capacity
LONEOAKB
– Lone Oak B MA41 – 690,000 Total Capacity
Gas Day May 4:
LXPSEG
– LXPSEG MA41 – 550,000 Total Capacity
Gas Day May 6:
LXPSEG
– LXPSEG MA41 – 750,000 Total Capacity
Dominion Energy Transmission:
Dominion
Energy Transmission, Inc. (DETI)’s Cornwell Station (West Virginia) will be out
of service for planned maintenance
from Friday, April 26, 2019 to Friday, May 3, 2019.
During
this outage, all production flowing on the Dominion Gathering and Processing (DGP) system to
the DETI facilities listed below, must be shut in. DETI will make another posting when
production can be turned back in line.
The
facility shut in dates and requirements are as follows:
All
gathering wet system production flowing to Cornwell Station 7 and 8 will need
to be shut in by 7:00 am EDT on
Friday, April 26. Direct Taps
on TL-585 will need to be shut in by 7:00 a.m. EDT on Monday, April 29. DGP Production Bubbles to be shut in: 2206,
2303, 2304, 2305, and 9912. Producers
in bubbles 2301, 2306 and 9913 that can physically flow off system via H-18155
can do so. This includes production
behind Oscar Nelson Station, Searls Station, Shadd Station, Panther Station,
Oozley Station, and Hardman
Station.
DETI
will make another posting if allocations become necessary. Delivery nominations during this period
from 10, 12 and 13 will be kept whole by DETI.
Delivery nominations during this period from EB005, EB045, EB145, EB335, EB460,
EB620 and EB635 will be kept whole
by DETI. Please monitor these
postings for further updates.
El Paso Natural Gas:
El
Paso Natural Gas is
pleased to announce the new Graphical Pipe screen in the iDART system.
This new screen will enable shippers to view nominations, priorities, and
entitlements based on segment for a given gas day and cycle. The new Graphical
Pipe screen is located in the Scheduled Quantity folder under the Nominations
folder in the iDART system.
Please
contact the scheduling hotline at 1-800-238-3764 Option 1 if you have any
questions about this new screen.
Enable Gas Transmission:
This Operational Alert is being issued pursuant to Section 20, GT&C of EGT s Tariff to notify all parties of planned maintenance on EGT s Line BT-1 in the North Pooling Area beginning April 27, 2019, with an expected completion date of May 13th,
2019.
During this maintenance, a series of integrity digs will be conducted along EGT s Line BT-1. Be advised, there is no capacity impact associated with the integrity digs, but should a determination be made that a repair is necessary, there could be a capacity reduction associated with the repair. Depending upon the nature
of any required repair, the announcement of a capacity reduction could come at
short notice.
This alert will remain in effect until further notice and will be updated as more information becomes available.
Gas
Transmission Northwest (GTN):
Effective Gas Day April 26th
at the Timely Nomination Cycle, GTN is lifting the Force Majeure related to the repairs at the Ione
Compressor Station 9 (Oregon).
The operationally available capacity for the Flow Past Kingsgate location has been increased to 2126-MMcf/d.
The operationally available capacity for the Flow Past Station 8 Location is 1865-MMcf/d.
As a reminder to customers, planned
maintenance at Compressor Station 8 continues until May 10th.
Natural Gas Pipeline Company of America (NGPL):
SEGMENT 11 – SOUTH OF STA 106 – AT OPERATING
CAPACITY
Effective for gas day Friday, April 26, 2019, and continuing until
further notice, Natural is at operating capacity for northbound
flow through Compressor Station 106 located in Gage County, Nebraska (Segment
11 of Natural’s Midcontinent Zone). AOR/ITS and Secondary out-of-path
Firm transports are at risk of not being fully scheduled.
Also from NGPL:
SEGMENT 13 – STA 107– AT OPERATING CAPACITY
Effective for gas day Friday, April 26, 2019, and continuing until
further notice, Natural is at operating capacity for northbound flow
through Compressor Station 107 located in Mills County, Iowa (Segment 13 of
Natural’s Amarillo Mainline Zone). AOR/ITS and Secondary out-of-path Firm
transports are at risk of not being fully scheduled.
Rockies
Express Pipeline (REX):
CHANDLERSVILLECOMPRESSOR STATION MAINTENANCE
On Gas Day Wednesday, May
1, 2019 through Gas
Day Friday, May 3, 2019, REX will be performing maintenance at its Chandlersville (Ohio) Compressor Station.
Operating capacity will be
limited to 2.935 Bcf/d through
pipeline Segment 380.
At this capacity level, primary and secondary firm quantities,
as well as ITS/AOR are at risk
of not being scheduled.
TransColorado Gas
Transmission:
The Force Majeure (FMJ) declared at Blanco Hub Compressor
Station, Segment
310, in notice #118680 has been lifted.
TransColorado Gas Transmission
Company, L.L.C. (TC) has
repaired the compressor station and, as such, is lifting the Force
Majeure that was in effect. The
capacity will return to 250,000 Dth effective Gas Day April 25, Cycle 4
(Intraday 2) and Gas Day April 26, Cycle 1 (Timely).
Transcontinental Gas Pipe Line Company (Transco):
Transco
recently provided notice of limited flexibility to manage imbalances and
recommended shippers maintain a concurrent balance of receipts and deliveries.
In order to ensure system integrity, maintain safe operations, manage
imbalances, and handle within-the-day volatility, Transco is issuing an Imbalance Operational Flow
Order (OFO).
Effective: Saturday,
April 27, 2019
Ends: Until
Further Notice
Transactions: Deliveries
Type: Due
to Shipper
OFO Area(s): Zones 4, 5, and 6
Tolerance: 10%
(or 1000 dth, whichever is greater)
This OFO is directed to shippers consistent with Section 52 of Transco’s FERC Gas Tariff General Terms and Conditions with a minimum of $50 per dth per day penalty. This OFO will continue until further notice. Buyers with imbalances greater than allowed tolerance will be subject to penalties specified in Section 52 of Transco’s FERC Gas Tariff General Terms and Conditions.
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The National Weather Service six-to-ten day forecast for the first few days of May is showing some cooler weather on the way for the northern plains states as well as New England. Otherwise, May will be ushered in with average temperatures across much of the nation. In the South, though, temperatures may be slightly above average for the first week of the new month.
Thanks for joining us at GasNewsOnline.com. 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.
Please tell a friend in the natural gas scheduling and transportation business about us. Have a great weekend!
Welcome to a very busy Easter weekend edition of GasNewsOnline.com! There are a host of critical notices from several of the country’s interstate natural gas pipeline companies about issues relating to changes in pipeline operating conditions.
Plus, we’ll also update you on the latest publicly released news of the day and provide the first glimpse of May’s expected temperatures from the National Weather Service, too.
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Working natural gas in storage was 1.247 Tcf as of Friday, April 12, 2019, according toUS Energy Information Administration estimates. This represents a net increase of 92 Bcf (which was 5 Bcf greater than analyst estimates).
Natural gas stocks were 414 Bcf (or
26%) below the five-year average for the same week.
On the NYMEX, the May, 2019 natural gas futures price reacted to the news and was down about three cents on Thursday at approximately $2.49/MMBtu. Natural gas prices declined to their lowest level in nearly three years due to a seasonal lull in heating and cooling demand combined with surging gas supplies.
It is interesting to note that not a single month of today’s NYMEX natural gas futures strip (through April, 2021) showed a natural gas price above $3.00/MMBtu.
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During today’s quarterly earnings release and conference call, Kinder Morgan provided an update on a few natural gas pipeline projects currently in progress:
In the Permian area, construction
continues on the Gulf Coast Express
Pipeline (GCX) project. The remaining 40 miles of the 36-inch Midland
lateral was placed in service at the beginning of April 2019. Construction is
progressing well on the 42-inch mainline and compressor stations associated
with the project, which remains on schedule for a full in-service date of
October 2019.
The approximately $1.75 billion project
is designed to transport about 2.0 Bcf/d of natural gas from the Permian Basin
to the Agua Dulce, Texas area, and is fully subscribed under long-term, binding
agreements.
Progress also continues on the Permian Highway Pipeline (PHP) project .
The civil and environmental surveys are substantially complete, and the land
acquisition process is underway.
The approximately $2 billion PHP
Project is designed to transport up to 2.1 Bcf/d of natural gas through
approximately 430 miles of 42-inch pipeline from the Waha, Texas area to the
U.S. Gulf Coast and Mexico markets and is expected to be in service in October
2020, pending regulatory approvals.
On the East Coast, the first of ten
liquefaction units of the nearly $2 billion Elba Liquefaction Project is expected to be placed in service by
approximately May 1, 2019. The remaining nine units are expected to be placed
in service sequentially, one per month thereafter.
The federally approved project at the existing Southern LNG Company facility at Elba Island near Savannah, Georgia, will have a total liquefaction capacity of approximately 2.5 million tonnes per year of LNG, equivalent to approximately 350 million cubic feet per day of natural gas.
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In summary, many interstate natural gas pipelines have posted critical notices to shippers requiring that they do not create pipeline imbalances caused by lack of market demand during the upcoming Easter holiday weekend. Let’s review…
Algonquin Gas Transmission:
Algonquin
Gas Transmission (AGT) has limited operational flexibility to manage
imbalances. Effective 9:00 AM CCT, Friday, April 19, 2019, AGT requires all
delivery point operators keep actual daily takes out of the system equal to or
greater than scheduled quantities regardless of their cumulative imbalance
position unless otherwise coordinated with your operations account
representative.
All
receipt point operators are required to keep actual daily receipts into the
system equal to or less than scheduled quantities regardless of their
cumulative imbalance position unless otherwise coordinated with your operations
account representative.
ANR will begin planned maintenance at the Havensville compressor station between April 29 and May 2. The total SWML Northbound (LOC#226630) capacity will be reduced by the following:
Based on current nominations through the SWML, it is anticipated that this posting will result in the capacity allocation reduction of IT and Firm Secondary volumes.
Also from ANR:
SW Area Capacity Restriction (Posted 4/18/19)
From April 29th through May 4th, ANR will perform planned pipeline maintenance between its E.G. Hill and Gageby Compressor Stations in the Southwest Area (Zone 4). As a result, ANR will shut-in the Beaver-CIG (REC FR CIG) receipt point, DRN #16435.
The total E.G. Hill from Gageby (LOC #226643) capacity will be reduced by the following:
Based on current nominations, it is anticipated the above reductions will result in the curtailment of nominations associated with IT and Firm Catalog Receipt points in the affected area. Also, interconnects along this segment may experience higher line pressures.
Colorado Interstate Gas (CIG):
In
response to continuing and prolific natural gas production growth in the
Denver-Julesburg Basin – and the mounting market need for timely transportation
capacity – Colorado Interstate Gas Company, L.L.C. (CIG) is conducting a
binding Open Season for additional firm capacity to be made available by
approximately November 1, 2019. The additional transportation
capacity offered in this Open Season will have primary receipt rights into
CIG’s 5C Line north of a proposed new interconnection (“High Five Meter
Station”) with CIG’s High Plains Lateral to be constructed at approximately
milepost 29, and will have primary delivery rights at the High Five Meter
Station of the CIG 5C Line and the Wyoming Interstate Company, L.L.C. (“WIC”)
facilities at Bowie.
For
more details, please check the CIG Electronic Bulletin Board. The posting is dated April 18, 2019.
This binding Open Season will commence today (April 18, 2019) and is scheduled to close at 10:00 a.m. Mountain Time on May 8, 2019. CIG intends to provide notification of capacity awards by 5:00 p.m. Mountain Time on May 9, 2019.
Questions concerning this Open
Season should be directed to: Greg Ruben (713-520-4870) or Laine Lobban
(719-520-4344).
Columbia Gas Transmission:
Columbia
Gas Transmission, LLC (TCO) reminds customers of a station power outage at the
Cobb Compressor Station scheduled for Saturday, April 27, 2019 through Sunday,
April 28, 2019.
Due
to this maintenance, the below internal constraints will be set to Zero Total
Capacity. All production will be shut-in with the exception of a limited
quantity that may be needed to serve localized markets.
Cobb
South MA18 (A03SOUTH)
Cobb
Northeast MA18 (A03NORTH)
Cobb
Northwest MA18 (A03LOW)
Cobb
Line H (A03LINEH)
Cobb
CS MA18 (COBBA03)
East Tennessee Natural Gas:
Boyds Creek Compressor Station Outage – April 23 – 24
ETNG will be conducting a compressor station outage at its Boyds Creek Compressor Station (Boyds) on the 3300 line. During this outage, west to east capacity through Boyds will be reduced to approximately 80,000 Dth per day.
Based on
historical nominations, restrictions may be required for interruptible and
secondary services and potentially primary firm services.
Enable Gas Transmission:
This Operational Alert is being issued pursuant to Section 20, GT&C, of EGT’s Tariff to advise shippers system wide that they will be required to maintain actual receipts and deliveries commensurate with scheduled volumes, beginning on Friday, April 19, 2019 at 9:00 A.M. and continuing until further notice.
Due to limited storage capacity, EGT
anticipates it may be unable to support imbalance positions and may reduce
scheduled quantities intraday to balance actual receipts and deliveries
necessary to maintain system deliverability and operational integrity.
The availability of balancing and
non-ratable services will be limited.
Hourly non-ratable nominations, as well as the use of imbalance
positions must be pre-approved or within the posted limits on EGT s Daily
Operating Plan. EGT will continue to monitor the pipeline s pressure and
imbalances and will, if necessary, take further actions, including the issuance
of one or more Operational Flow Orders (OFO).
EGT will schedule receipts and
deliveries in accordance with EGT s Tariff.
This Operational Alert will remain in effect until further notice
and will be updated as more information becomes available.
Gas
Transmission Northwest (GTN):
May 2019- GTN Fuel and Line Loss Percentage
Pursuant
to Gas Transmission Northwest’s
(GTN) Tariffed Fuel Adjustments Provision, for the period of May 01, 2019 through May 31,
2019, a fuel usage rate of 0.0021% per Dth/mile will be in effect.
This
percentage is inclusive of GTN’s current fuel and line loss surcharge of
0.0000% per Dth per pipeline mile, which is in effect through December 31,
2019, in accordance with GTN’s approved tariff provision, “Adjustment
Mechanism for Fuel, Line Loss, and Other Unaccounted For Gas.”
Gulf
South Pipeline:
Index 818 I.L.I. Pig Run – Begins April
23, 2019 – Ends April 24, 2019
Expansion Area 19 (Mississippi) Delivery
Scheduling Group.- Capacity could be impacted by as much as 300,000 dth/d for
the duration of the maintenance. Please contact your customer service
representative if you have any questions.
Kinder Morgan Louisiana Pipeline (KMLP):
SEGMENT 140 – MLV #7 – AT OPERATING CAPACITY
Effective for gas day Friday, April
19, 2019, Timely Cycle, and continuing until further notice, KMLP is at
operating capacity for gas going southbound through Segment 140, located in
Jefferson Davis Parish, Louisiana. AOR/ITS and Secondary out-of-path Firm
transports are at risk of not being fully scheduled.
Mississippi River Transmission (MRT):
Due to the potential negative impact of
significant shipper long imbalance positions on MRT storage withdrawal
operations, MRT is issuing a System Protection Warning (SPW)
effective 9:00 a.m. Thursday, April 18, 2019, and
continuing until further notice.
During this time:
1) Shippers should avoid daily long
imbalance positions
2) MRT may not schedule any nominations
that result in a daily long position.
3) MRT may not accept any makeup of
short positions
4) MRT may not schedule nominations
that result in counter-seasonal injection.
Failure to comply with this SPW may
result in the issuance of an OFO.
Nominations will be confirmed and scheduled in accordance with MRT s
Tariff.
Southern Natural Gas:
Based on the current milder weather forecast and projected demand on Southern’s system for the Holiday weekend, we are implementing an OFO Type 6 for long imbalances on Southern’s contiguous pipeline system effective for the start of the gas day, Friday, April 19, 2019, and until further notice. In order to maintain the operational integrity of Southern’s system, it is essential that Shippers and Poolers remain in balance (including their available no-notice injection entitlements).
The OFO Type 6 order will subject each Shipper/Pooler to the following tiered imbalance penalties:
Daily Imbalance Penalty (Percent of Allocated Deliveries ) ( Per Dth )
Since the projected operational conditions are affected by receipts exceeding deliveries, the penalty will apply only to each Shipper/Pooler that has a net long imbalance (i.e., the party’s total allocated receipts exceed total allocated deliveries including available no-notice storage injections).
Tennessee Gas Pipeline:
OFO DAILY CRITICAL DAY 1 FOR ALL
OF ZONES L, 1, 2, 3, 4, 5 AND 6 EFFECTIVE 4-19-19
Due to forecasted
milder weather, storage fields on test and anticipated lower demand for the
holiday weekend, effective for the Gas
Day of Friday, April 19, 2019, and until further notice, Tennessee Gas
Pipeline, L.L.C. (“Tennessee”) is implementing
an OFO Daily Critical Day 1 for all of Zones L, 1, 2, 3, 4, 5 and 6 for all Balancing Parties (including LMS-PA, SA contracts acting
as balancing parties, LMS-MA, and LMS-PL balancing parties). This action
is pursuant to Article X, Section 4 of the General Terms and Conditions of
Tennessee’s FERC Gas Tariff.
All delivery point
operators in all of Zones L, 1, 2, 3, 4, 5 and 6 are required to keep actual
daily takes out of the system equal to or greater than scheduled quantities
regardless of their cumulative imbalance position. All receipt point operators
in all of Zones L, 1, 2, 3, 4, 5 and 6 are required to keep actual daily receipts into the system equal to
or less than scheduled quantities regardless of their cumulative imbalance
position. In addition, it
is essential that delivery point operators schedule gas at meters commensurate
with takes within the affected areas. All LMS-PA, SA contracts
acting as balancing parties, LMS-MA and LMS-PL Balancing Parties are required
to maintain an actual daily flow rate not exceeding 2% of scheduled quantities
or 500 dths, whichever is greater for over-deliveries into the system and
under-takes from the system. Customers will be assessed a rate of $5.00 plus
the applicable Regional Daily Spot Price per dekatherm for that portion of
physical quantities related to over-deliveries by receipt point operators and
under-takes by delivery point operators which exceed this tolerance.
THIS DAILY OFO CRITICAL DAY 1 WILL
REMAIN IN EFFECT UNTIL FURTHER NOTICE. TENNESSEE WILL INFORM CUSTOMERS BY EBB
WHEN THIS OFO WILL BE LIFTED.
Trailblazer Pipeline Company:
TRAILBLAZER
MECHANICAL ISSUE–COMPRESSOR
STATION 603–UPDATE #1
Trailblazer Pipeline Company LLC (“Trailblazer”) identified a mechanical issue with one of the two compressor units at Compressor Station 603. The unit is currently unavailable and is not expected to be available until late May, 2019.
At
this time, secondary firm
quantities, as well as ITS/AOR are at risk
of not being scheduled.
Trailblazer will post updates as additional information
becomes available. For questions,
please call your Account Director
or Scheduling Representative.
Transcontinental Gas Pipe Line Company (Transco):
Transco
recently provided notice of limited flexibility to manage imbalances and
recommended shippers maintain a concurrent balance of receipts and deliveries.
In order to ensure system integrity, maintain safe operations, manage
imbalances, and handle within-the-day volatility, Transco is issuing an Imbalance Operational Flow
Order (OFO).
Effective: Friday,
April 19, 2018
Ends: Until
Further Notice
Transactions: Deliveries
Type: Due
to Shipper
OFO Area(s): Zones 4, 5, and 6
Tolerance: 10%
(or 1000 dth, whichever is greater)
This OFO is directed to shippers consistent with Section 52 of Transco’s FERC Gas Tariff General Terms and Conditions with a minimum of $50 per dth per day penalty. This OFO will continue until further notice. Buyers with imbalances greater than allowed tolerance will be subject to penalties specified in Section 52 of Transco’s FERC Gas Tariff General Terms and Conditions.
********************
The National Weather Service has published their first glimpse at the temperature forecast from the month of May. It shows that the East and West coast areas could see above normal temperatures next month, while the majority of the midsection of the US is predicted to have normal to slightly below seasonal temperatures during the month of May.
That’s a wrap for this Thursday edition of GasNewsOnline.com. We’ll return on Monday to provide an update on pipeline conditions and the latest energy news.
Remember that our companion audio podcast is available via Apple Podcasts. Subscribe today – it’s FREE!
Welcome back to GasNewsOnline.com! After a week of warmer weather across much of the US, temperatures are returning to normal across the West and Upper Midwest. A number of natural gas pipeline companies have posted critical notices regarding colder weather conditions for their systems.
Before we cover those notices, let’s check out the latest energy news:
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The US Energy Information Administrationreleased its weekly estimate of natural gas volumes in storage. For the week ending February 1, working gas in storage decreased by 237 Bcf.
Stocks were estimated to be 415 Bcf or 17.5% below the five-year average for the same week.
********************
Yesterday, as part of its ongoing commitment to reducing wildfire risk, Pacific Gas and Electric Company (PG&E) submitted its 2019 Wildfire Safety Plan to the California Public Utilities Commission. The safety plan marks an expansion of enhanced and additional safety precautions PG&E began implementing in 2017 and 2018 to address the growing threat of extreme weather and wildfires across its service area.
Given
the continued and growing threat of extreme weather and wildfires, and as an
additional precautionary measure, PG&E’s plan includes expanding and
enhancing its Community Wildfire Safety Program to further reduce wildfire
risks and help keep customers and the communities it serves safe. Ongoing and
expanded efforts include further enhancing vegetation management around power
lines, conducting enhanced safety inspections of electric infrastructure in
high fire-threat areas, and a hardening of our electric system.
Also
included in the 2019 plan, PG&E announced additional and enhanced safety
precautions including the expansion of PG&E’s Public Safety Power Shutoff
(PSPS) program to include all electric lines that pass through high fire-threat
areas – both transmission and distribution. While customers in high fire-threat
areas are more likely to be affected, any of PG&E’s more than 5 million
electric customers could have their power shut off for safety only as a last
resort when forecasted fire danger conditions warrant.
“We
know how much our customers rely on electric service. Proactively turning off
power is a highly complex issue with significant public safety risks on both
sides – all of which need to be carefully considered and addressed,” said
Michael Lewis, Electric Operations senior vice president. “We understand
and appreciate that turning off the power affects first responders and the
operation of critical facilities, communications systems and much more. We will
only turn off power for public safety and only as a last resort to keep our
customers and communities safe.”
To be clear, the decision to initiate a PSPS is informed by local forecasts, so PG&E is not indicating that it would ever turn off power to all customers at once. Instead, due to the complexity of the electric grid, and the web-like connection between transmission lines, distribution lines and substations, there is a possibility that some customers outside a high-risk fire threat area could have their power turned off based on the need to turn off a specific high-voltage circuit. The expanded program includes timely notification to customers of potential PSPS events.
********************
With another blast of winter affecting the northern half of the US for a few more days, let’s check out the latest critical postings from the interstate natural gas pipeline companies’ electronic bulletin boards:
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, February 8, 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 2,000 Dth or 102% 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.
Correspondingly, the OFO issued on February 6, 2019 will continue to be in
effect until 9:00 AM CCT, February 8, 2019.
This OFO will remain in effect until further notice.
ANR Pipeline:
Attn:
All ANR Shippers
Due to projected cold weather forecasts, current operational conditions, and
nomination levels, it is increasingly important that ANRPL shippers maintain
sufficient receipt and delivery volumes to minimize imbalances and ensure
system integrity.
As of February 7, ANR is not taking further action at this time other than to
notify our customers of the projected weather forecast. However, ANR Pipeline
will continue to monitor pipeline operations and the weather forecasts, and may
take further action if necessary. Please continue to monitor our EBB for
updates.
Columbia Gas Transmission:
Shippers
are advised that due to forecasted colder temperatures, storage levels, and
increased market demands beginning Saturday, February 9, 2019, Columbia Gas
Transmission, LLC (TCO) may issue Transport Critical Days for deliveries to all
Operating Areas and Storage Critical Days for withdrawals (MDWQ overruns) for
all Operating Areas. TCO will post the Critical Day notices, if
warranted, on Friday, February 8, 2019.
Also,
TCO may have limited ability to handle non-ratable takes in the impacted Market
Areas during this period. Please monitor the Daily Capacity Posting for
details.
TRANSPORT
CRITICAL DAY: If a Transport Critical
Day is called for Saturday, February 9, 2019 until further notice, the
following daily Transport Critical Day penalty will apply:
Applicable
Penalty: TFE – If Shipper’s takes on
any Day exceed the greater of 103 percent or 1,000 Dths more than its Total
Firm Entitlement (TFE), Shipper shall be assessed and pay a penalty based on
the higher of: (i) a price per Dth equal to three times the midpoint of the
range of prices reported for “Columbia Gas, Appalachia” as published
in Platts Gas Daily price survey for all such quantities in excess of its TFE,
or (ii) a price per Dth equal to 150 percent of the highest midpoint posting
for either: Mich Con City-gate, Transco, Zone 6 Non-N.Y., or Texas Eastern, M-2
Receipts as published in Platts Gas Daily price survey for all such quantities
in excess of its TFE. Section 19.1(ii) penalties will only be assessed on
days in which the daily spot price of gas exceeds three times the midpoint of
the range of prices reported for “Columbia Gas, Appalachia.
NOTE:
Takes in excess of Total Firm Entitlements (“TFE”) are penalized on Critical
Days based on takes exceeding the aggregate daily amount of gas that TCO
is obligated to deliver to a shipper under the shipper’s applicable rate
schedule. Each applicable rate schedule outlines this delivery obligation
and, consequently, a shipper’s TFE.
STORAGE
CRITICAL DAY: If a Storage Critical
day is called for Saturday, February 9, 2019 until further notice, all firm
storage services will be fully available. Interruptible storage
withdrawals (SIT and ISS), excess FSS withdrawals, and PAL loans and unparks
will not be available if delivered in the impacted operating areas.
Applicable
Penalties:
–
FSS MDWQ- Withdrawn quantities in excess of 103% of the applicable contract
MDWQ will be assessed a penalty based on a price per Dth equal to three times
the midpoint rate for “Columbia Gas, Appalachia,” posted in Gas Daily.
– FSS
MMWQ – Monthly Withdrawal Quantities that exceed 30% (February Limit) of
SCQ will be assessed a penalty of $5.00 per Dth.
–
FSS SCQ – If withdrawals from storage result in the FSS contract having a
negative SCQ balance, a penalty of $5 per Dth will be assessed.
Colorado Interstate Gas (CIG):
With significantly colder temperatures being forecast beginning Wednesday, February 6, 2019 through Friday, February 8, 2019, CIG is anticipating an increase in demand on its system which will limit its ability to manage imbalances associated with supply shortfalls. Therefore, when necessary to minimize imbalances and protect system integrity, underperformance caps may be placed on nonperforming receipt points effective until further notice.
Dominion Energy Transmission:
Effective
start of gas day Friday, February 8, 2019, and continuing until further notice,
DETI will not schedule any IT
or Non PL-1 firm transportation on its PL-1 system. This includes deliveries at
the following locations:
40209 Columbia of Pennsylvania (Pleasant Gap)
21305 Texas Eastern Chambersburg (East Coast)
40201 Texas Eastern Chambersburg (PL-1)
40202 Texas Eastern Steckman Ridge
40224 Baltimore Gas and Electric
22000 Washington Gas and Electric
23500 Dominion Cove Point Loudoun
40704 Transco Nokesville
40303 Virginia Natural Gas
22400 Doswell
22500 City of Richmond
22600 VA Electric & Power
22700 Columbia of Virginia
22800 VEPCO (Lady Smith)
22900 Genon Mid-Atlantic (Dickerson)
30016 Panda Stonewall
30230 PL-1 customers with delivery points north
of Leesburg compressor station may not effectuate deliveries to
any PL-1 point south of Leesburg. PL-1 customers with delivery points south of
Leesburg compressor station may
effectuate deliveries to PL-1 points both north and south of Leesburg. DETI can
effectuate secondary and IT
deliveries to points north of Leesburg compressor station if sourced from the
receipt of DETI-Loudoun (40704)
or Transco-Nokesville (40303) via displacement. DETI can effectuate secondary and IT deliveries to points south of
Leesburg compressor station if sourced from the receipt of Transco-Nokesville (40303) via displacement.
Please
note that “Unauthorized Overrun Charges – Daily” rate of $10.00/dth
will apply.
East Tennessee Natural Gas:
Due to
impending colder weather, in order to maintain the operational integrity of the
system, ETNG is issuing a Balancing Alert Operational Flow Order (OFO) pursuant
to Section 14.7 of the General Terms and Conditions of ETNG’s FERC Gas Tariff
effective 9:00 AM CCT, February 8, 2019 for all meters east of the Boyds Creek
Compressor Station.
This OFO does not affect the ability of ETNG to receive or deliver quantities
of gas for scheduled nominations to any customer, storage field, or pipeline.
During the effectiveness of this OFO, balancing parties under Rate Schedules
LMSMA and LMSPA must be balanced such that actual deliveries of gas out of the
system must be equal to or less than scheduled deliveries out of the system and
actual receipts of gas into the system must be equal to or greater than
scheduled receipts into the system. Additionally, balancing parties with meters
west of Boyds Creek will not be allowed to utilize undertakes at meters located
west of Boyds Creek to offset overtakes at meters located east of Boyds Creek.
The penalty provisions under Section 47.5(b) of the General Terms and
Conditions of ETNG’s FERC Gas Tariff shall apply for failure to conform for
each dekatherm of actual receipt quantities that are less than scheduled
receipt quantities and for each dekatherm of actual delivery quantities that
are greater than scheduled delivery quantities, in each case with a tolerance
of 2% of scheduled quantities or 500 dekatherms (whichever is greater).
In addition, ETNG will not permit retroactive nominations to avoid an OFO
penalty.
Gas Transmission Northwest:
GTN
OFO Watch (Posted 2/6/19)
Effective immediately, GTN Pipeline is issuing an OFO watch. GTN Pipeline is concerned about the operational
integrity of its system as a result of low line pressures.
The OFO watch is in effect through gas day February 15th, in order to allow for GTN pipeline system to regain its operational integrity. GTN has limited flexibility to manage imbalances and strongly encourages all
shippers manage their system requirements to ensure the matching of receipts
and deliveries daily.
Absent voluntary imbalance management by shippers to ensure daily balancing, GTN may be required to take further action, including the immediate issuance of an imbalance Operational Flow Order. If further action is required, it may be necessary for that action to become effective immediately, with no additional prior
notice available.
This posting will be updated as more information becomes available. Please contact your GTN Nominations Representative with any questions regarding nominations or scheduling
at (888) 750-6275.
Kern River Transmission:
Line
pack continues to decrease (approximately 75,000
Dth over the past 24 hours) despite Kern River’s warning of
colder than normal weather and expected high
demand in Kern River’s market areas. Additionally, several upstream and downstream operators have declared some form
of strained operating condition.
Therefore,
all Kern River shippers and delivery point operators are required to align daily scheduled nominations and
physical receipts and deliveries. If line pack
continues to decrease, Kern River may take corrective action to increase line pack by limiting physical flow at
delivery points where a negative imbalance
was created during prior gas days to ensure line pack and the integrity of the system is maintained.
Mississippi River Transmission
(MRT):
Due to the potential for maximum utilization of northbound firm Main Line capacity causing a potential supply deficiency
in the Market Zone, MRT is issuing a System Protection Warning (SPW) effective
9:00 a.m. Thursday, February 7, 2019 and continuing until further notice.
During this time:
1) MRT
may not schedule any IT or AOR volumes for delivery north of Glendale.
2) Firm
volumes may be limited to their primary direction of flow on the system north
of Glendale.
3) MRT
may not schedule volumes that result in a daily short position in either the
Market or Field Zones.
4) The
use of imbalance positions may not be scheduled.
5) Pool
transfers will not be permitted from MRT s Field Zone to its Market Zone.
6) Customers with primary delivery points north of the Glendale Compressor station and a receipt point that utilizes South to North transportation, will be required to nominate and source all, or a portion of, their total nomination at primary receipt points
and/or at available Market Zone supply locations, not to exceed applicable
maximum receipt point quantities in order to support their primary deliveries.
7) Shippers whose firm transportation contracts have Texas Gas Boardwalk (Boardwalk) and/or EGT Olyphant (Olyphant) and/or Noark listed as primary receipt points, must schedule the full amount of their primary receipt point quantity each of those points or, if the primary receipt point is Boardwalk and/or Olyphant, at an alternative Main Line receipt point that is north of their primary receipt point (Olyphant and/or Noark) if they desire to fully utilize their contract MDQ. Shippers may elect to forego nominating their full primary receipt point quantity at any/all of these points, however, such shipper’s maximum scheduled and confirmed contract quantity shall be limited to their contract MDQ less any primary receipt point quantity at Boardwalk and/or Olyphant and/or Noark that is not scheduled and confirmed.
8) Instantaneous
flow rates for shippers delivering to meters located in MRT s Market Zone
cannot exceed 110% of their daily entitlements.
Shippers whose deliveries are affected by any of the Seven (8) conditions above are encouraged to source supply at their primary receipt points, MRT’s East Line, MoGas, or reduce applicable delivery volumes.
Failure
to comply with this SPW may result in Customers being issued an individual
OFO. Nominations will be confirmed and
scheduled in accordance with MRT s Tariff.
Northern Border Pipeline:
Northern
Border OFO Watch (Posted
2/6/19)
Effective
immediately, Northern Border Pipeline is issuing an OFO watch. Northern Border
is concerned about the
operational integrity of its system as a result of extremely cold weather.
The OFO
watch is in effect through gas
day February 16th, in order to allow for the Northern Border pipeline system
to regain its operational integrity. Northern Border has limited flexibility to
manage imbalances and strongly
encourages all shippers manage their system requirements to ensure the matching of receipts and deliveries daily.
Absent
voluntary imbalance management by shippers to ensure daily balancing, Northern
Border may be required to take
further action, including the immediate issuance of an imbalance Operational Flow Order. If further action is required, it may be
necessary for that action to become effective immediately, with no additional prior notice available. This posting will be updated as more
information becomes available
Northern Natural Gas:
Operational Alert – A
System Overrun Limitation (SOL) has been called for all Market Area zones (ABC,
D and EF) with 0% System Management Service (SMS) available for Gas Day Friday
February 8, 2019 due to lower than normal system weighted temperatures.
Northern is expecting
record cold temperatures and record market deliveries this week. At this time,
Northern does not anticipate the need to call a Critical Day. Northern will
continually evaluate the condition of the system, and will make all efforts to
call a Critical Day in advance of the gas day if the pipeline system
experiences low line pack or other conditions, including significant natural
gas price volatility, that threaten the integrity of Northern’s pipeline
system. Customers are encouraged to nominate supply volumes sufficient to cover
anticipated loads to prevent the need for Northern to call a Critical Day.
Northwest Pipeline:
Please
keep in mind that pursuant to All-shipper Notice No. 19-016, Northwest is currently
under a Stage II (8%) Overrun Entitlement for all Receiving Parties north of the
Kemmerer compressor station which began on gas day February 06, 2019.
Effective
gas day Saturday, February 9, pursuant to All-shipper Notice No. 19-017,
Northwest will be under a Stage I (3%) overrun Entitlement north of the
Plymouth compressor and a Stage II (8%) overrun Entitlement in the Kemmerer to
Plymouth corridor.
Northwest
would like to clarify that the Stage I (3%) overrun Entitlement north of the Plymouth
compressor includes the Spokane and Wenatchee laterals.
PG&E – California Gas
Transmission:
PG&E’s
California Gas Transmission has revised the Low Inventory System-Wide OFO for
gas day 02/08/2019 to a Stage 4 at $25.00/Dth, 5% tolerance.
Southern Star Central Gas
Pipeline:
With a colder weather forecast across the Southern Star system, Southern Star is issuing a winter weather watch beginning Thursday, February 7, 2019 at 9:00 AM CST. Southern Star requests that shippers adhere to the following criteria:
Customers
with TSS and STS contracts should ensure that their flowing gas to storage gas
withdrawal relationship is per their contractual agreements
ISS
withdrawals and PLS withdrawals will be available on a limited basis
Incremental
Loans will be available on a limited basis
Imbalance
makeup for gas due others (Southern Star off-system) will be available on a
limited basis
Receipt
and delivery point operators should ensure that flowing volumes match confirmed
scheduled quantities
Southern Star will issue underperformance notices to each point operator not delivering the scheduled quantities they
had confirmed. Southern Star will unilaterally reduce scheduled quantities per
the tariff to match actual flow if the delivering operator does not remedy the
underperformance in accordance with the notice.
If
customers do not adhere to these requests, or if actual weather or operating
conditions require it, Southern Star could issue a system wide, point or
shipper specific OFO on short notice.
These
conditions are expected to remain in effect through Saturday, February 9, 2018.
Texas Eastern Transmission:
Due to impending colder weather, in order to maintain the operational integrity of the system, TE is issuing an Operational Flow Order (OFO) pursuant to Section 4.3 of the General Terms and Conditions of TE’s FERC Gas Tariff effective 9:00AM CCT February 8, 2019 to all delivery parties, with the exception of those governed by a FERC gas tariff, in Texas Eastern’s Market Area Zones M1-24, M2-24 and M3.
This OFO does not affect the ability of TE 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 out of the system. The penalty shall apply to each dekatherm of actual delivery quantities that exceeds the greater of 2,000 Dth or 102% 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 the geographical region, as defined in Section 8.5(a) of the General Terms and Conditions of TE’s FERC Gas Tariff for the day on which such violation occurred. In addition, TE will not permit retroactive nominations to avoid an OFO penalty.
TE may be required to issue an hourly OFO pursuant to General Terms and Conditions Section 4.3(H) to impose further restrictions in order to maintain the operational integrity of the system. TE will inform customers via EBB when this OFO will be lifted.
********************
The National Weather Service temperature forecast for the next six-to-ten days shows that the Northwest, Rockies, Midwest and Great Lakes areas will to see below average temperatures while the above-normal temperatures remaining across the South, Mid-Atlantic, and New England.
You’re now up-to-date courtesy of GasNewsOnline.com. All for you, and all for FREE! Please tell a friend in the natural gas transportation business about us, and check out our FREE podcasts on iTunes. Have a great weekend!
With a polar vortex weather system bringing extremely cold weather to areas east of the Rockies this week, this is a busy time for the natural gas pipeline companies. Here at GasNewsOnline.com, we will update you on the latest news and provide a full report on the latest critical notices from the interstate natural gas pipeline companies’ electronic bulletin boards.
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Let’s first take a look at a few stories making news today.
On Sunday, Enbridgereleased an update about ongoing work on the two additional lines that parallel the impacted 30-inch Line 10 Texas Eastern Transmission pipeline in Noble County, Ohio. A week ago, Texas Eastern’s 30-inch line ruptured in southeast Ohio.
Following
a completion of a comprehensive integrity assessment, the company placed one of
the other two pipelines in the right-of-way (Line 25) back into service.
Texas
Eastern will continue to shippers informed as work progresses and more definite
timelines are known for returning the 2 other pipelines (Line 10 and parallel
Line 15) back into service.
Enbridge
is working with the Ohio Public Utilities Commission and the federal
government’s Pipeline and Hazardous Materials Safety Administration (PHMSA) to
verify the integrity of the Texas Eastern pipeline system.
EBB
from Sunday 1/27 – PM
Texas Eastern (TE) is providing
the following update on its progress to return partial service to the 30 inch
pipeline system following the incident that occurred on Line 10 on Monday,
January 21, 2019 in Noble County, OH between its Berne and Athens compressor
stations. The progress report is as follows:
As previously posted, TE has determined that further investigations on Line 10
between its Athens and Uniontown compressor stations are required and TE had
isolated Line 10 between Athens and Uniontown. At this time, TE has returned
Line 10 valve section 4 between Holbrook and Uniontown back to service while
the remainder of Line 10 remains isolated. As a result of valve section 4
between Holbrook and Uniontown returning to service, TE estimates the eastbound
capacity through its Uniontown compressor station will increase to
approximately 4,300,000 Dth/d. TE will provide a timeline on the restoration of
capacity through Uniontown as soon as it is known.
As posted this morning, TE returned Line 25 for north to south flow through its
Berne compressor station to approximately 1,600,000 Dth/d effective for Gas Day
January 27th, 2019. TE is taking the necessary steps to return Line 15
immediately south of the Berne compressor station to service as soon as safely
possible. TE will provide a timeline on the restoration of north to south
capacity through Berne as soon as it is known.
********************
Despite a blast of frigid cold air with this week’s “Polar Vortex”, the February, 2019 NYMEX natural gas futures price took a dive on Monday and closed down about 27 cents at about $2.91/MMBtu. As we’ll cover later, the National Weather Service temperature forecast for the first week of February is showing a significant warm-up in store for the Great Lakes and East coast areas coming next week at this time.
Net
withdrawals from working gas totaled 163 billion cubic feet (Bcf) for the week
ending January 18. Working natural gas stocks 11% lower than the five-year
(2014–18) average for this week.
The
natural gas plant liquids composite price at Mont Belvieu, Texas, rose by
5¢/MMBtu, averaging $6.51/MMBtu for the week ending January 23. The price of
natural gasoline fell by 2%. The price of ethane and butane rose by 2%, and the
price of propane rose by 1%. The price of isobutane remained flat week over
week.
According
to Baker Hughes, for the week ending Tuesday, January 15, the natural gas rig
count decreased by 4 to 198. The number of oil-directed rigs fell by 21 to 852.
The total rig count decreased by 25, and it now stands at 1,050. This is the
largest week-over-week decrease in total rig count since February 2016.
********************
With much of the nation gripped in a deep freeze this week, let’s review the latest critical notices from the interstate gas pipeline grid.
Colorado Interstate Gas (CIG):
In anticipation of colder weather, Colorado Interstate Gas
Company, L.L.C., CIG will take the following actions impacting its No-Notice
Storage and Transportation Service (NNT) beginning Gas Day January 28, 2019,
and continuing until further notice.
CIG is limiting requests for NNT authorized withdrawal overruns to
100,000 Dth.
Interruptible Storage Withdrawals will be taken to zero (0 Dth).
CIG expects operators to continuously manage their confirmations
on a cycle to cycle basis to match actual flow rates, factoring in freeze off
and other conditions as necessary, particularly the cold weather impacts to
field production and pipeline operations.
Dominion Energy Transmission:
Subject:
System Alert/OFO Advisory Due to Forecasted Extreme Weather Conditions
Due
to extreme weather conditions that are expected in our area this upcoming week,
Dominion Energy
Transmission, Inc. (DETI) hereby advises its customers that OFOs will likely be issued in certain areas of
DETI’s system. Customers are advised to continue to monitor the EBB for any OFO
issuances.
As a reminder, the penalties for violations of transportation OFOs are based on a penalty per Dth equal to the higher
of $10.00 or two times the Penalty Index Price.
East Tennessee Natural Gas:
Due to impending colder weather, in order to maintain the operational integrity of the system, ETNG is issuing a Balancing Alert Operational Flow Order (OFO) pursuant to Section 14.7 of the General Terms and Conditions of ETNG’s FERC Gas Tariff effective 9:00 AM CCT, January 29, 2019 for all meters east of the Boyds Creek Compressor Station.
This OFO does not affect the ability of ETNG to receive or deliver quantities of gas for scheduled nominations to any customer, storage field, or pipeline.
During the effectiveness of this OFO, balancing parties under Rate Schedules LMSMA and LMSPA must be balanced such that actual deliveries of gas out of the system must be equal to or less than scheduled deliveries out of the system and actual receipts of gas into the system must be equal to or greater than scheduled receipts into the system. Additionally, balancing parties with meters west of Boyds Creek will not be allowed to utilize undertakes at meters located west of Boyds Creek to offset overtakes at meters located east of Boyds Creek.
The penalty provisions under Section 47.5(b) of the General Terms and Conditions of ETNG’s FERC Gas Tariff shall apply for failure to conform for each dekatherm of actual receipt quantities that are less than scheduled receipt quantities and for each dekatherm of actual delivery quantities that are greater than scheduled delivery quantities, in each case with a tolerance of 2% of scheduled quantities or 500 dekatherms (whichever is greater).
In addition, ETNG will not permit retroactive nominations to avoid an OFO penalty.
Florida Gas Transmission:
Overage Alert Day 25% Tolerance
Near freezing temperatures are forecasted to move into North Florida over the next couple of days; therefore, for the gas day of January 28, 2019, FGT would like to notify their customers in FGTs Market Area that it is issuing an Overage Alert Day at 25% (twenty five percent) tolerance.
For the gas day of January 28, 2019, FGT will not interrupt previously scheduled Market Area ITS-1 service below the elapsed prorated scheduled quantity.
FGT will continue to monitor hourly and daily takes. Please closely monitor your scheduled point quantities versus actual burn point quantities.
Gas Transmission Northwest (GTN):
As referenced in a recent posting, TransCanada will be hosting an industry meeting on February 12th in Calgary to discuss the dithiazine matter. At this meeting, TransCanada and others from the industry will provide a forum to detail technical issues caused by the presence of dithiazine in natural gas, ongoing research and development, provide an opportunity to hear from others, and to discuss next steps. Please be advised that the intent of this meeting is to discuss technical challenges and solutions only. Space will be limited.
The meeting will be held at the Westin in Downtown Calgary from 1:30pm to 4:30pm Mountain Time. Company representatives planning to attend the meeting must register in advance. To register for the meeting, please reach out to Scott Currier (scott_currier@transcanada.com or 708-446-3738) by February 7.
Gulf South Pipeline:
During
the McComb (MS) compressor station maintenance, capacity could be impacted by
as much as 100,000 dth/d for the duration of the maintenance beginning today
(January 28 – February 16).
The
following meters are in the Montpelier to McComb Index 130 Scheduling Group.
002424
GREENSBURG CITY GATE
002432
KENTWOOD CITY GATE
002549
MONTPELIER & PINE GROVE CITY GATE
002559
TANGIPAHOA CITY GATE
002583
KENTWOOD BRICK & TILE PLANT
002690
HOLMESVILLE (TO TRANSCO)
013087
TRANSFER @ MONTPELIER / ST HELENA
013456
TRANSFER @ HOLMESVILLE (TRANSCO)
022114
WALTHALL (TO TRANSCO)
022182
MONTPELIER/ST HELENA (TO FGT)
022573
TRANSFER @ WALTHALL (TO TRANSCO)
Mississippi River Transmission
(MRT):
Due to the potential for maximum utilization of northbound firm Main Line capacity causing a potential supply deficiency in the Market Zone, MRT is issuing a System Protection Warning (SPW) effective 9:00 a.m. Tuesday, January 29, 2019 and continuing until further notice.
During this time:
1) MRT
may not schedule any IT or AOR volumes for delivery north of Glendale.
2) Firm
volumes may be limited to their primary direction of flow on the system north
of Glendale.
3) MRT
may not schedule volumes that result in a daily short position in either the
Market or Field Zones.
4) The
use of imbalance positions may not be scheduled.
5) Pool
transfers will not be permitted from MRT s Field Zone to its Market Zone.
6) Customers with primary delivery points north of the Glendale Compressor station and a receipt point that utilizes South to North transportation, will be required to nominate and source all, or a portion of, their total nomination at primary receipt points and/or at available Market Zone supply locations, not to exceed applicable maximum receipt point quantities in order to support their primary deliveries.
7) Shippers whose firm transportation contracts have Texas Gas Boardwalk (Boardwalk) and/or EGT Olyphant (Olyphant) and/or Noark listed as primary receipt points, must schedule the full amount of their primary receipt point quantity each of those points or, if the primary receipt point is Boardwalk and/or Olyphant, at an alternative Main Line receipt point that is north of their primary receipt point (Olyphant and/or Noark) if they desire to fully utilize their contract MDQ. Shippers may elect to forego nominating their full primary receipt point quantity at any/all of these points, however, such shipper’s maximum scheduled and confirmed contract quantity shall be limited to their contract MDQ less any primary receipt point quantity at Boardwalk and/or Olyphant and/or Noark that is not scheduled and confirmed.
8) Instantaneous
flow rates for shippers delivering to meters located in MRT s Market Zone
cannot exceed 110% of their daily entitlements.
Shippers whose deliveries are affected by any of the Seven (8) conditions above are encouraged to source supply at their primary receipt points, MRT’s East Line, MoGas, or reduce applicable delivery volumes.
Failure
to comply with this SPW may result in Customers being issued an individual
OFO. Nominations will be confirmed and
scheduled in accordance with MRT s Tariff.
This
SPW will be updated as more information becomes available.
Natural Gas Pipeline Company of
America (NGPL):
CRITICAL TIME DECLARATION – MARKET DELIVERY ZONE
Natural is declaring a Critical Time in its Market Delivery
Zone effective gas day, Tuesday, January 29, 2019, which will
remain in effect until further notice. This action is in response to the
recent cold weather and the current forecast for continued extreme colder than
normal weather, the high demand for gas on Natural’s system, and the need to
maintain system pressures in its Market Delivery Zone. Based on this
current weather forecast, the Critical Time is anticipated to continue in
effect at least through the end of the gas day, Friday, February 1, 2019.
The Critical Time will apply to under-receipts and over-deliveries of gas
vis-à-vis confirmed nominations. Please monitor Natural’s Interactive
Website for updates as to the duration of the Critical Time.
During the Critical Time, Shippers are required to comply
with the ongoing Operational Flow Order (See most recent posting dated Sunday,
January 27, entitled “OPERATIONAL FLOW ORDER ISSUED – MARKET DELIVERY ZONE –
UPDATE #2”). Variances to the detriment of the system at any of a
Shipper’s Receipt or Delivery Points are subject to significant charges and
penalties, as set forth in Sections 12.4 and 23.7 (c) of the General Terms and
Conditions of Natural’s Tariff. There is no right to be out of balance by
any amount and Shippers can be required to correct any and all imbalances. It
is Shipper’s responsibility to ensure that appropriate nominations are in place
to reflect actual quantities that will flow.
Accordingly, a Shipper should ensure by communication with
its Point Operator that quantities of gas equal to or greater than its
nominations are being delivered into Natural’s system at Receipt Points.
A Shipper should also ensure that quantities no greater than those nominated
(plus firm no-notice rights) are being taken from Natural’s system at Delivery
Points.
Northern Natural Gas:
Effective Gas Day 01/28 and until
further notice, the Carlton Resolution flow obligation will be at 100%.
Operational Alert – A
System Overrun Limitation (SOL) has been called for all Market Area zones (ABC,
D and EF) with 0% System Management Service (SMS) available for Gas Days
Tuesday and Wednesday, January 29 and 30, 2019, due to lower than normal system
weighted temperatures.
Northern is expecting
record cold temperatures and record market deliveries this week. At this time,
Northern does not anticipate the need to call a Critical Day. Northern will
continually evaluate the condition of the system, and will make all efforts to
call a Critical Day in advance of the gas day if the pipeline system
experiences low line pack or other conditions, including significant natural
gas price volatility, that threaten the integrity of Northern’s pipeline
system. Customers are encouraged to nominate supply volumes sufficient to cover
anticipated loads to prevent the need for Northern to call a Critical Day.
Southern Natural Gas:
Based
on the weather forecast predicting colder temperatures as well as the
corresponding increase in projected demand on Southern’s North and South
pipeline systems, we are notifying all Shippers that the existing Type 3 Level
1 OFO is being upgraded to a Type 3 Level 2 OFO and is being expanded effective
with the start of the gas day, Tuesday, January 29, 2019 until further notice.
OFO Type 3 Level 2: Daily Demand Exceeds Capacity TARIFF SECTION 41.2 EFFECTIVE DATE: January 29, 2019 EFFECTIVE TIME of OFO: 9:00 AM (CCT)
PENALTY:
$15.00 + Highest Regional Daily Price* per Dth for quantities taken in excess
of the tolerance
TOLERANCE:
Greater of 102% of the Daily Entitlement or 200 dth
Southern Star Central Gas Pipeline:
Due
to severe weather conditions forecasted, Southern Star is issuing a Winter
Weather Warning effective Tuesday, January 29, 2019. The following actions will
be taken to preserve system integrity:
Firm
Storage withdrawals will be limited to MDWQ (AOS will not be allowed)
Customers
with TSS and STS contracts should ensure that their flowing gas to storage gas
withdrawal relationship is per their contractual agreements.
Storage customers should ensure that their storage balances are at the appropriate levels for the duration of this Notice.
ISS
withdrawals and PLS withdrawals will be unavailable.
Incremental
Loans will not be available.
Imbalance
makeup for gas due others (SSC off-system) will not be available.
Receipt
and delivery point operators should ensure that flowing volumes match confirmed
scheduled quantities.
Intraday
scheduling reductions will be implemented to ensure that nominations match
actual flowing quantities.
Operational
flexibility will not be available during this time.
Southern Star will issue underperformance notices to each point operator not delivering the scheduled quantities they
had confirmed. Southern Star will unilaterally reduce scheduled quantities per
the tariff to match actual flow if the delivering operator does not remedy the
underperformance in accordance with the notice.
If
customers do not adhere to the request, or if actual weather or operating
conditions require it, Southern Star could issue a system wide, point or
shipper specific OFO on short notice.
These conditions are expected to
remain in effect through Thursday, January 31, 2019.
Tallgrass Interstate Gas
Transmission:
BIG SPRINGS EAST LOAD ADVISORY
This Advisory is effective starting Gas Day Tuesday, January
29, for Evening cycle until further notice.
Based on the current weather forecast, TIGT is expecting the Big Springs
East loads to remain elevated through at least Thursday, January 31, 2019.
TIGT requests that shippers continue to match their supply
nominations to the on-system loads.
Otherwise, TIGT may issue a Directional Notice to maintain the
operational integrity of its pipeline.
PEPL/GRANT (Location 6616)
SSC/TIGT THOMAS (Location 7448)
NNG/TIGT MILLIGAN FILLMORE (Location 8601)
MCMC/TIGT GRANT (Location 11510, by displacement only)
TB/TIGT ADAMS (Location 7857)
TB/TIGT CLAY (Location 8382)
CHEYENNE PLAINS/TIGT SCOTT (Location 41544)
Tennessee Gas Pipeline:
OFO DAILY CRITICAL DAY 1 EXPANDED
TO INCLUDE ALL OF ZONES 2, 3, 4, 5 AND 6 EFFECTIVE 1-30-19
Due to a forecast of colder weather and higher demand moving across most of the system, effective for the Gas Day of Wednesday, January 30, 2019, and until further notice, Tennessee Gas Pipeline, L.L.C. (“Tennessee”) is expanding the existing OFO Daily Critical Day 1 from all areas east of STA 245 on the 200 Line to include all of Zones 2, 3, 4, 5 and 6 for all Balancing Parties (including LMS-PA, SA contracts acting as balancing parties, LMS-MA, and LMS-PL balancing parties). This action is pursuant to Article X, Section 4 of the General Terms and Conditions of Tennessee’s FERC Gas Tariff.
All delivery point operators in all of Zones 2, 3, 4, 5 and
6 are required to keep actual daily takes out of the system equal to or less
than scheduled quantities regardless of their cumulative imbalance
position. All receipt point operators in all of Zones 2, 3, 4, 5 and 6
are required to keep actual daily receipts into the system equal to or greater
than scheduled quantities regardless of their cumulative imbalance
position. In addition, it is essential that delivery point operators
schedule gas at meters commensurate with takes within the affected areas.
All LMS-PA, SA contracts acting as balancing parties, LMS-MA and LMS-PL
Balancing Parties are required to maintain an actual daily flow rate not
exceeding 2% of scheduled quantities or 500 dths, whichever is greater for
under-deliveries into the system and over-takes from the system. Customers will
be assessed a rate of $5.00 plus the applicable Regional Daily Spot Price per
dekatherm for that portion of physical quantities related to under-deliveries
by receipt point operators and over-takes by delivery point operators which
exceed this tolerance.
THIS DAILY OFO CRITICAL DAY 1 WILL
REMAIN IN EFFECT UNTIL FURTHER NOTICE. TENNESSEE WILL INFORM CUSTOMERS BY EBB
WHEN THIS OFO WILL BE LIFTED.
Texas Gas Transmission:
Below
normal temperatures are expected to move across the Texas Gas service area over
the next few days.
While it is fully expected that all primary firm service obligations will be met, the following services/activities
are subject to scheduling reductions until further notice:
Imbalance
Payback from Transportation Service Provider
Park
Withdrawal
Loan
ISS
Withdrawal
FSS
Overrun Withdrawal
Interruptible
and out-of-path Firm Transportation
HOT
– Hourly Overrun Transportation
Additionally, Texas Gas is requesting all shippers take deliveries within their contractual hourly rights so
that receipts and Deliveries match their associated scheduled quantities.
If
shippers do not voluntarily comply with these provisions, Texas Gas may be
forced to issue an Operational Flow Order, which could result in penalties for
shippers.
********************
While much of the country hunkers down this week with extremely cold temperatures in the offing, the National Weather Service six-to-ten day outlook is showing that temperatures will be significantly improved by this time next week. Warmer than average temperatures are expected east of the Rockies while the Mountain West and West Coast will have the colder than seasonal weather for much of next week.
Stay warm, everyone! Thanks for joining us at GasNewsOnline.com. We check all of the publicly sourced natural gas pipeline and energy news for you and bring you the weather outlook for the coming week. All for you, and all for FREE!
If you like cold weather, you’ll LOVE this edition of GasNewsOnline.com! With another winter storm bearing down on the midsection of the country and, this weekend, along a large portion of the East Coast, the gas pipelines are busy writing critical notices. GasNewsOnline.com brings you all of the publicly released gas pipeline news and the updated temperature forecasts. All for FREE!
********************
As a follow up to its EBB notice dated June 29, 2018, Gas Transmission Northwest LLC (GTN), indirectly and partially owned by TransCanada PipeLines Limited (TransCanada), is informing interested parties that a chemical substance, Dithiazine, continues to appear at facilities on the GTN System, and those of some upstream and downstream connecting pipelines.
Dithiazine is a sulphur compound by-product created through the
use of Triazine, a liquid chemical scavenger used by producers to remove
hydrogen sulfide (H2S) from gas streams. TransCanada has become aware that
Dithiazine may drop out of the gas stream, under certain conditions, in the
form of a white powder, and further chemically change to an adhesive,
putty-like substance at some points of pressure reduction (for example, at a
regulator) due to a temperature drop that accompanies the pressure reduction.
If a sufficient quantity of the material is accumulated in certain
appurtenances, it could cause them not to function properly.
As TransCanada has previously advised, multi-stage pressure
regulation and/or heating of the gas stream prior to the pressure cut can
mitigate against Dithiazine dropping out of the natural gas stream. In
addition, periodic equipment inspections and cleaning to remove any observed
solid deposits may help prevent operational issues with facility equipment.
However, due to the potential for
Dithiazine to interfere with equipment functionality, TransCanada is
considering disallowing the receipt of gas that has interacted with Triazine
into the GTN System if the factors contributing to the presence of Dithiazine
do not change. In the event Dithiazine continues to appear at facilities on the
GTN System, GTN may decide to issue an Operational Flow Order by April 1, 2019
in accordance with Section 6.30 of its FERC Gas Tariff, as amended from time to
time, to maintain or restore the operational integrity of its system.
To provide additional clarity and address any questions,
TransCanada invites all parties to attend a working session to be held the
second week of February 2019 in Calgary, Alberta.
TransCanada will continue to provide stakeholders with updates as appropriate. In the meantime, GTN commercial and operations representatives are available to meet with any affected parties at their convenience, or to address any questions.
********************
BlueMountain Capital Management has delivered an open letter to the Board of Directors of PG&E Corporation.
The
investment firm, which owns several million shares of PGE stock, said that the
company’s plan to file bankruptcy soon is “damaging, avoidable, and unnecessary”
for the company’s stockholders.
According to the letter, BlueMountain Capital Management asserts that PG&E “has ample liquidity to operate its business; the amount of liabilities remains uncertain and contestable; there are meaningful probabilities of offsets from settlements and cost recovery; and any potential liabilities are payable in the future”.
********************
From the US Energy Information Administration, the weekly natural gas storage report showed a net decrease of 81 Bcf pulled from storage for the week ending January 11. Remaining natural gas stocks in storage are now 2.5 Tcf. That volume is 11.4% below the five-year average for the same week.
********************
Due to another winter storm moving across the MidWest and, for this weekend, into the Northeast, this is an extremely busy week of gas pipeline company critical notices.
ANR Pipeline:
Attn:
All ANR Market Area Shippers
Due to projected cold weather forecasts, current operational conditions, and
nomination levels, it is increasingly important that ANRPL shippers maintain
sufficient receipt and delivery volumes to minimize imbalances and ensure
system integrity.
ANR is not taking further action at this time other than to notify our
customers of the projected weather forecast. However, ANR Pipeline will
continue to monitor pipeline operations and the weather forecasts, and may take
further action if necessary. Please continue to monitor our EBB for updates.
Columbia Gas Transmission:
Pursuant
to the General Terms & Conditions of TCO’s FERC Gas Tariff, Section 19.7,
shippers are advised that due to sustained colder temperatures, storage levels,
and increased market demand extending several days beginning Friday, January
18, 2019, Transport and Storage Critical Days are necessary in all Market Areas
across the TCO system. Please note the following:
Transport
and Storage Critical Days: Friday, January 18, 2019 and
until further notice. TCO will monitor conditions and provide updates as
necessary.
Applicable
Market Areas: All Market Areas and All
Storage Withdrawals delivered to all Market Areas.
Applicable Transport Penalty:
TFE – If Shipper’s takes on any Day exceed the greater of 103 percent of or
1,000 Dths more than its Total Firm Entitlement (TFE), Shipper shall be
assessed and pay a penalty based on the higher of: (i) a price per Dth equal to
three times the midpoint of the range of prices reported for “Columbia
Gas, Appalachia” as published in Platts Gas Daily price survey for all
such quantities in excess of its TFE, or (ii) a price per Dth equal to 150
percent of the highest midpoint posting for either: Mich Con City-gate,
Transco, Zone 6 Non-N.Y., or Texas Eastern, M-2 Receipts as published in Platts
Gas Daily price survey for all such quantities in excess of its TFE.
Section 19.1(ii) penalties will only be assessed on days in which the
daily spot price of gas exceeds three times the midpoint of the range of prices
reported for “Columbia Gas, Appalachia.
NOTE:
Takes in excess of Total Firm Entitlements (“TFE”) are penalized on Critical
Days based on takes exceeding the aggregate daily amount of gas that TCO is
obligated to deliver to a shipper under the shipper’s applicable rate
schedule. Each applicable rate schedule outlines this delivery obligation
and, consequently, a shipper’s TFE. (Notice ID 25678425 posted on
December 1, 2015 explains in detail)
Columbia
will be evaluating whether shippers have exceeded their TFE within the specific
Market Areas affected by the Critical Day. Firm entitlements in other Market
Areas will not be included in determining whether a shipper’s flows are within
their TFE in any Market Area subject to the Critical Day.
Applicable
Storage Penalties:
–
FSS MDWQ – Withdrawn quantities in excess of 103% of the applicable contract
MDWQ will be assessed a penalty based on a price per Dth equal to three times
the midpoint rate for “Columbia Gas, Appalachia,” posted in Gas Daily.
–
FSS SCQ – If withdrawals from storage result in the FSS contract having a
negative SCQ balance, a penalty of $5 per Dth will be assessed.
–
FSS MMWQ – Monthly Withdrawal Quantities that exceed 40% (November
Limit) of SCQ will be assessed a penalty of $5.00 per Dth.
NOTE: Transporter
projects no availability of interruptible storage withdrawal services (SIT and
ISS) and excess FSS withdrawals with delivery to one of the affected Market
Areas. PAL loans or unparks with a delivery within the affected Market
Areas will not be available. Due ship nominations will be scheduled to
zero.
East Tennessee Natural Gas:
ETNG
Operational Flow Order – East of Boyds Creek
In
order to maintain the operational integrity of the system, ETNG is issuing a
Balancing Alert Operational Flow Order (OFO) pursuant to Section 14.7 of the
General Terms and Conditions of ETNG’s FERC Gas Tariff effective 9:00 AM CCT,
January 17, 2019 for all meters east of the Boyds Creek Compressor Station.
This OFO does not affect the ability of ETNG to receive or deliver quantities
of gas for scheduled nominations to any customer, storage field, or pipeline.
During the effectiveness of this OFO, balancing parties under Rate Schedules
LMSMA and LMSPA must be balanced such that actual deliveries of gas out of the
system must be equal to or less than scheduled deliveries out of the system and
actual receipts of gas into the system must be equal to or greater than
scheduled receipts into the system. Additionally, balancing parties with meters
west of Boyds Creek will not be allowed to utilize undertakes at meters located
west of Boyds Creek to offset overtakes at meters located east of Boyds Creek.
The penalty provisions under Section 47.5(b) of the General Terms and
Conditions of ETNG’s FERC Gas Tariff shall apply for failure to conform for
each dekatherm of actual receipt quantities that are less than scheduled
receipt quantities and for each dekatherm of actual delivery quantities that
are greater than scheduled delivery quantities, in each case with a tolerance
of 2% of scheduled quantities or 500 dekatherms (whichever is greater).
In addition, ETNG will not permit retroactive nominations to avoid an OFO
penalty.
Enable Gas Transmission:
BALANCING
OPERATIONAL ALERT
THIS
OPERATIONAL ALERT IS BEING ISSUED PURSUANT TO SECTION 20, GT&C, OF EGT S
TARIFF TO ADVISE SHIPPERS SYSTEM WIDE
THAT THEY WILL BE REQUIRED TO MAINTAIN ACTUAL RECEIPTS AND DELIVERIES COMMENSURATE WITH SCHEDULED
VOLUMES, BEGINNING ON THURSDAY, JANUARY 17, 2019 AT 9:00 A.M. AND CONTINUING UNTIL FURTHER
NOTICE.
DUE
TO FORECASTED HIGH DEMANDS, EGT ANTICIPATES IT MAY BE UNABLE TO SUPPORT
IMBALANCE POSITIONS AND MAY REDUCE SCHEDULED QUANTITIES INTRADAY TO BALANCE
ACTUAL RECEIPTS AND DELIVERIES NECESSARY TO MAINTAIN SYSTEM DELIVERABILITY AND
OPERATIONAL INTEGRITY.
DURING
THIS TIME, EGT ANTICIPATES HIGH STORAGE DEMAND AND MAY, IF NECESSARY, SCHEDULE ACCORDINGLY
IN ORDER TO GET THE WITHDRAWALS THROUGH ITS ALLEN AND CHANDLER COMPRESSOR STATIONS. IT AND SECONDARY SHIPPERS IN THE WEST 1, WEST
2 AND FLEX (WEST OF CHANDLER) POOLING
AREAS MAY BE IMPACTED.
THE
AVAILABILITY OF BALANCING AND NON-RATABLE SERVICES WILL BE LIMITED. HOURLY NON- RATABLE NOMINATIONS MUST BE
PRE-APPROVED OR WITHIN THE POSTED LIMITS ON EGT S DAILY OPERATING PLAN. EGT
WILL CONTINUE TO MONITOR THE PIPELINE S PRESSURE AND IMBALANCES AND WILL, IF NECESSARY, TAKE FURTHER ACTIONS,
INCLUDING THE ISSUANCE OF ONE OR MORE OPERATIONAL FLOW ORDERS (OFO). SHIPPERS WHOSE TAKES EXCEED THEIR APPLICABLE
SCHEDULED VOLUMES WILL BE SUBJECT TO EXCESS CONTRACT QUANTITIES CHARGES
PURSUANT TO EGT’S TARIFF.
EGT
WILL SCHEDULE RECEIPTS AND DELIVERIES IN ACCORDANCE WITH EGT’S TARIFF. THIS
OPERATIONAL
ALERT WILL REMAIN IN EFFECT UNTIL FURTHER NOTICE AND WILL BE UPDATED AS MORE INFORMATION
BECOMES AVAILABLE.
Florida Gas Transmission:
Overage
Alert Day 25% Tolerance
FGT line-pack is below target levels. Near freezing
temperatures are forecasted in Florida this weekend; therefore,
for the gas day of January 17, 2019, FGT would like to notify their
customers in FGTs Market Area that it is issuing an Overage Alert Day at 25%
(twenty five percent) tolerance.
For the gas day of January 17, 2019, FGT will not interrupt previously
scheduled Market Area ITS-1 service below the elapsed prorated scheduled
quantity.
FGT will continue to monitor hourly and daily takes. Please closely monitor
your scheduled point quantities versus actual burn point quantities.
Gulf Crossing Pipeline:
Below normal temperatures are expected to move across the Gulf Crossing service area over the next few days.
While
it is fully expected that all primary firm service obligations will be met, the
following services/activities are subject to scheduling reductions until
further notice:
Imbalance
Payback from Transportation Service Provider
Park
Withdrawal
Loan
Interruptible
Additionally, Gulf Crossing is requesting all shippers to balance their transportation and storage contracts by conforming receipts into the system with the deliveries being taken from the system, and to receive and deliver quantities at a uniform hourly rate of flow, pursuant to Section 6.7[1.] and 6.7[2.] of
Gulf Crossing’s FERC Gas Tariff.
If
shippers do not voluntarily comply with these provisions, Gulf Crossing may be
forced to declare a Critical Period or issue an Operational Flow Order, which
could result in penalties for shippers.
Gulf South Pipeline:
Below
normal temperatures are expected to move across the Gulf South service area
over the next few days.
While
it is fully expected that all primary firm service obligations will be met, the
following services/activities are subject to scheduling reductions until
further notice:
Imbalance
Payback from Transportation Service Provider
Park
Withdrawal
Loan
ISS
and ISS-P Withdrawal
FSS-P
Overrun Withdrawal
Interruptible,
Firm Secondary Service, Firm Supplemental Service and Firm Out-of-Path Service
Additionally, Gulf South is requesting all shippers to balance their transportation and storage contracts by conforming receipts into the system with the deliveries being taken from the system, and to receive and
deliver quantities at a uniform hourly rate of flow “as practicable”,
pursuant to Section 6.7[2.] and 6.7[3.] of Gulf South’s FERC Gas Tariff
(Tariff).
If
shippers do not voluntarily comply with these provisions, Gulf South may be
forced to declare a Critical Period or issue an Operational Flow Order, which
could result in penalties for shippers.
Mississippi River Transmission
(MRT):
Due
to the potential for maximum utilization of northbound firm Main Line capacity
causing a potential supply deficiency in the Market Zone, MRT is issuing a
System Protection Warning (SPW) effective 9:00 a.m. Wednesday, January 16,
2019, and continuing until further notice.
During
this time:
1) MRT
may not be able to schedule IT or AOR volumes for delivery north of Glendale.
2) It
may be necessary for MRT to limit firm volumes to their primary direction of
flow on the system north of Glendale.
3) MRT
may not be able to schedule volumes that result in a daily short position in
either the Market or Field Zones, and Shippers must ensure that they remain in
balance.
4) MRT
may not be able to schedule the use of imbalance positions, and Shippers must
ensure physical receipts sufficient to cover scheduled deliveries.
5) Pool
transfers will not be permitted from MRT s Field Zone to its Market Zone.
6) Customers
with primary delivery points north of the Glendale Compressor station and a
receipt point that utilizes South to North transportation, will be required to
nominate and source all, or a portion of, their total nomination at primary
receipt points and/or at available Market Zone supply locations, not to exceed
applicable maximum receipt point quantities in order to support their primary
deliveries.
7) Shippers
whose firm transportation contracts have Texas Gas Boardwalk (Boardwalk) and/or
EGT Olyphant (Olyphant) and/or Noark listed as primary receipt points, must
schedule the full amount of their primary receipt point quantity each of those
points or, if the primary receipt point is Boardwalk and/or Olyphant, at an
alternative Main Line receipt point that is north of their primary receipt
point (Olyphant and/or Noark) if they desire to fully utilize their contract
MDQ. Shippers may elect to forego nominating their full primary receipt point
quantity at any/all of these points, however, such shipper’s maximum scheduled
and confirmed contract quantity shall be limited to their contract MDQ less any
primary receipt point quantity at Boardwalk and/or Olyphant and/or Noark that
is not scheduled and confirmed.
Shippers
whose deliveries are affected by any of the Seven (7) conditions above are
encouraged to source supply at their primary receipt points, MRT s East Line,
MoGas, or reduce applicable delivery volumes.
Failure
to comply with this SPW may result in Customers being issued an individual
OFO. Nominations will be confirmed and
scheduled in accordance with MRT’s Tariff.
Natural
Gas Pipeline Company of America (NGPL):
OPERATIONAL FLOW ORDER ISSUED – MARKET DELIVERY ZONE
Based
on current market demand, anticipated maximum peaking withdrawals from storage
facilities, and current system operating conditions, Natural is issuing an
Operational Flow Order (OFO) in the Market Delivery Zone effective 9:00 am., Central Clock Time, Saturday,
January 19, 2019, and continuing until further notice. Additionally,
Natural continues to monitor operating conditions system wide. If
necessary, Natural will issue additional OFOs to address Shipper actions that
are detrimental to such operating conditions outside the Market Delivery Zone.
See below for specific actions Natural is requiring shippers follow and the
applicable timing requirements (daily and hourly) for compliance with the
OFO. Additionally, if conditions warrant, a Critical Time will be issued
in the near future. Please monitor Natural’s Interactive Website for
updates.
DAILY
For
the gas day, each Shipper (including Point Operators) is prohibited from taking
any volume in excess of those equal to confirmed transportation nominations plus
no-notice rights at delivery points in the Market Delivery Zone. Excess
daily takes will be subject to applicable Unauthorized Overrun charges, OFO
charges and/or OFO balancing charges (as described below). Natural is
reminding Shippers and Point Operators that as part of this OFO, tolerances
under POA agreements are limited to 2% (instead of 5%) of
confirmed nominations or 1,000 Dth/d; whichever is greater, at the point.
Daily Balancing Charges and overrun charges associated with Shippers and Point
Operators under taking volumes (long position) will be waived during this OFO
in accordance with Natural’s FERC Gas Tariff.
HOURLY
Additionally,
as provided in Section 7.4 of Natural’s FERC Gas Tariff, at each point in the
Market Delivery Zone, Point Operators and Shippers (where no point operator
exists) are required to limit hourly takes. The hourly rights for each
Shipper and Point Operator will be limited by service priority and nomination
cycle, based on hours remaining in the gas day. Shippers and Point
Operators are responsible for calculating and monitoring their hourly usage so
as not to exceed the limits described herein. Excess hourly takes will be
subject to OFO charges (as described below).
Hourly Rights for Firm Service – 120%
Includes
Primary and Secondary Confirmed Nominations and Unused No-Notice firm service
rights
Timely/Evening Cycles
Limited to 5.00% (120% / 24 hours) of Firm
Service.
Intra-Day 1 Cycle
Limited to the hourly rights
computed in the previous cycle for Firm Service; plus 6.316% (120% / 19 hours)
of the difference of current cycle Firm Service minus prior cycle Firm
Service.
Intra-Day 2 Cycle
Limited to the hourly rights
computed in the previous cycle for Firm Service; plus 8.00% (120% / 15 hours) of the difference of current cycle Firm
Service minus prior cycle Firm Service.
Intra-Day 3 Cycle
Limited to the hourly rights
computed in the previous cycle for Firm Service; plus 10.91% (120% / 11 hours) of the difference of current cycle Firm Service
minus prior cycle Firm Service.
Hourly Rights for Interruptible Service – 105%
Includes Interruptible and AOR nominations, as well as POA tolerances
Timely/Evening Cycles
Limited to 4.375% (105% / 24 hours) of
Interruptible Service.
Intra-Day 1 Cycle
Limited to the hourly rights
computed in the previous cycle for Interruptible Service; plus 5.53% (105% / 19 hours) of the difference of current cycle Interruptible
Service minus prior cycle Interruptible Service.
Intra-Day 2 Cycle
Limited to the hourly rights
computed in the previous cycle for Interruptible Service; plus 7.00% (105% / 15 hours) of the
difference of current cycle Interruptible Service minus prior cycle
Interruptible Service.
Intra-Day 3 Cycle
Limited to the hourly rights
computed in the previous cycle for Interruptible Service; plus 9.55% (105% / 11 hours) of the
difference of current cycle Interruptible Service minus prior cycle
Interruptible Service.
Limitation on Nominations in All Cycles for Firm and
Interruptible Service
Shippers are advised that
nominations should be received by Timely/Evening Cycle in order to utilize full
rights over 24 hours, to avoid exceeding the 24 hour ratable hourly takes
calculation. In all cases, any first time nominations received on
Non-Timely Cycles for full MDQ utilization rights, plus any scheduled ITS
nominations, are subject to penalty on any hourly takes overages if the hourly
takes rate exceeds the 24 hour ratable calculation. Shipper’s hourly
rights based on firm MDQ, plus interruptible nominations, must be sufficient to
accommodate the calculated hourly rights for the remaining hours of the gas
day. Specifically, hourly rights cannot exceed 120% / 24 hours of
Shipper’s MDQ on the nominated contract, plus 105% / 24 hours of Shipper’s
interruptible nominations.
CHARGES FOR VIOLATIONS OF OFOs
HOURLY
Section
23.6 of the General Terms and Conditions of Natural’s FERC Gas Tariff sets
forth the provisions, including applicable penalties, for failure to comply
with an OFO.
DAILY
UNATHORIZED
OVERRUN
Point
Operators are on notice that any volumes taken in excess of the confirmed
nominations and no-notice rights plus the greater of 2% of all
confirmed nominations, or one thousand (1,000) Dth/day, will be treated as
Unauthorized Overrun subject to any applicable charges (Section 12), penalties
for violating the OFO (Section 23.6), and any Balancing Service Charges (as
referenced below). This OFO overrides any prior predetermined allocation
included in Section 11 of the General Terms and Conditions of Natural’s FERC
Gas Tariff to the extent the overtake would be treated differently.
BALANCING
SERVICE CHARGES
Section
12.3 of the General Terms and Conditions of Natural’s FERC Gas Tariff sets forth
the provisions when Balancing Service Charges shall apply when an OFO is in
effect, if actual deliveries allocated to a Shipper at any point or under any
Agreement do not conform to the sum of such Shipper’s confirmed nominations and
no-notice rights applicable to such point.
Daily
Balancing Charges and overrun charges associated with Shippers and Point
Operators under taking volumes (long position) will be waived during this OFO
in accordance with Natural’s FERC Gas Tariff.
Northern Natural Gas:
Effective Gas Day 01/18/2019
09:00:00 AM until further notice, the Carlton Resolution flow obligation will
be at 100%.
Operational Alert – A
System Overrun Limitation (SOL) has been called for all Market Area zones (ABC,
D and EF) with 50% System Management Service (SMS) available for Gas Day Friday,
January 18, 2019, due to lower than normal system weighted temperatures.
Northwest Pipeline:
Northwest
Pipeline’s current account balance at the Jackson Prairie Storage Facility is
currently under 1 Bcf. This is due to cooler
weather experienced over the last several days and subsequent drafting of the system
North of the Kemmerer Compressor station.
In addition, with the change of gas flows due the Westcoast incident in
early October, Northwest has significantly under recovered fuel for the last several
months. With cooler weather anticipated
early next week, intermittent volumes from Westcoast based on planned in-line
inspections and declining deliverability from Jackson Prairie; Northwest will be implementing a Stage III
(13%) Entitlement North of the Kemmerer Compressor station pursuant to Section
14.6 of the Northwest Gas Pipeline Tariff effective January 18, 2019.
In
addition, Northwest is preparing to file an Emergency Fuel Filing with the
Federal Energy Regulatory Commission seeking approval, to be effective February
1, 2019, to change the current system fuel rate from 1% to 1.61%.
Panhandle Eastern
Pipe Line Corporation:
Weather
Alert
Based
on current cold weather forecasts, Panhandle is preparing for increased
pipeline utilization and reduced operational flexibility. Effective Gas Day January 19, 2019, until further notice, Panhandle
is requesting all delivery point operators to minimize over-takes and all
receipt point operators to minimize their under-deliveries into the system.
Intraday
scheduling reductions may be implemented to ensure that nominations match
actual flowing quantities. Shippers are encouraged to submit their nominations
for the Timely cycle. Evening and Intraday nominations are subject to
scheduling reductions based on nomination levels and physical capacity.
The
following nominations are subject to scheduling reductions based on nomination
levels and physical capacity: Interruptible;
Secondary Outside-the-Path
Similarly,
all storage customers are requested to stay at or below their Maximum Daily
Withdrawal Quantity (MDWQ). Storage customers should adjust flowing volumes to
remain at or below these limits.
Panhandle
may limit Auto-Unpark nominations on the pipeline for the duration of the
extreme weather. These limits will be evaluated on a daily basis.
Southern Natural Gas:
Based
on the latest weather forecast predicting colder weather with a significant
drop in temperatures as well as the corresponding increase in projected demand
on Southern’s system, we are notifying Shippers on the North and South systems will
be subject to an OFO Type 3 Level 2 effective
the start of the gas day, Sunday, January 20, 2019 until further notice.
OFO Type 3 Level 2: Daily Demand Exceeds Capacity
TARIFF SECTION 41.2
EFFECTIVE DATE: January 20, 2019
EFFECTIVE TIME of OFO: 9:00 AM (CCT)
PENALTY:
$15.00 + Highest Regional Daily Price* per Dth for quantities taken in excess
of the tolerance
TOLERANCE:
Greater of 102% of the Daily Entitlement or 200 dth
This is to notify all customers who are allocated gas at any delivery point in
the North and South system segments listed by SNG that they are subject to an
operational flow order commencing on the effective date set out in this notice
and continuing until further notice. The above-stated penalty will be assessed
on any shipper whose allocated deliveries at any delivery point(s) exceed both
102% of their daily entitlement and 200 dth at such delivery point(s) within an
OFO Group.
Southern Star Central Gas Pipeline:
Due to severe weather conditions expected, Southern
Star is issuing a Winter Weather Warning effective Saturday, January 19, 2019.
The following actions will be taken to preserve
system integrity:
Firm
Storage withdrawals will be limited to MDWQ (AOS will not be allowed)
Customers
with TSS and STS contracts should ensure that their flowing gas to storage gas
withdrawal relationship is per their contractual agreements.
Storage customers should ensure that their storage balances are at the appropriate levels for the duration of this Notice.
ISS
withdrawals and PLS withdrawals will be unavailable.
Incremental
Loans will not be available.
Imbalance
makeup for gas due others (SSC off-system) will not be available.
Receipt
and delivery point operators should ensure that flowing volumes match confirmed
scheduled quantities.
Intraday
scheduling reductions will be implemented to ensure that nominations match
actual flowing quantities.
Operational
flexibility will not be available during this time.
Southern Star will issue underperformance notices to each point operator not delivering the scheduled quantities they
had confirmed. Southern Star will unilaterally reduce scheduled quantities per
the tariff to match actual flow if the delivering operator does not remedy the
underperformance in accordance with the notice.
If
customers do not adhere to the request, or if actual weather or operating
conditions require it, Southern Star could issue a system wide, point or
shipper specific OFO on short notice.
These
conditions are expected to remain in effect through Monday, January 21, 2019.
Southern Star will review and provide any changes or updates on the status of
its system for the period of this posting.
Tennessee Gas Pipeline:
OFO DAILY CRITICAL DAY 1 FOR ALL
AREAS EAST OF STA 245 EFFECTIVE 1-17-19
Due to forecasted colder weather and higher demand moving
back into the northeast, effective for the Gas Day of Thursday, January 17,
2019, and until further notice, Tennessee Gas Pipeline, L.L.C.
(“Tennessee”) is issuing an OFO Daily Critical Day 1 for all areas east
of STA 245 on the 200 Line for all Balancing Parties (including LMS-PA, SA
contracts acting as balancing parties, LMS-MA, and LMS-PL balancing
parties). This action is pursuant to Article X, Section 4 of the General
Terms and Conditions of Tennessee’s FERC Gas Tariff.
All delivery point operators east of STA 245 on the 200 Line
are required to keep actual daily takes out of the system equal to or less than
scheduled quantities regardless of their cumulative imbalance position.
All receipt point operators east of STA 245 on the 200 are required to keep
actual daily receipts into the system equal to or greater than scheduled
quantities regardless of their cumulative imbalance position. In
addition, it is essential that delivery point operators schedule gas at meters
commensurate with takes within the affected areas. All LMS-PA, SA
contracts acting as balancing parties, LMS-MA and LMS-PL Balancing Parties are
required to maintain an actual daily flow rate not exceeding 2% of scheduled
quantities or 500 dths, whichever is greater for under-deliveries into the
system and over-takes from the system. Customers will be assessed a rate of
$5.00 plus the applicable Regional Daily Spot Price per dekatherm for that
portion of physical quantities related to under-deliveries by receipt point
operators and over-takes by delivery point operators which exceed this
tolerance.
THIS DAILY OFO CRITICAL DAY 1 WILL
REMAIN IN EFFECT UNTIL FURTHER NOTICE. TENNESSEE WILL INFORM CUSTOMERS BY EBB
WHEN THIS OFO WILL BE LIFTED.
In the event this OFO is not sufficient to maintain the
operational integrity of the system, Tennessee may escalate to a Critical Day
II, an OFO Balancing Alert, Meter Specific OFO(s) or Hourly OFO(s). Tennessee
cannot accept unscheduled imbalances and requires all customers to nominate and
schedule all payback requests.
Tennessee will deem all affected Shippers to be in
compliance with the actions specified in these Daily Critical Day 1 OFOs if
after the measurement close the actual system conditions were opposite to the
conditions for which the OFOs were issued.
Texas Gas Transmission:
Below
normal temperatures are expected to move across the Texas Gas service area over
the next few days.
While
it is fully expected that all primary firm service obligations will be met, the
following services/activities are subject to scheduling reductions until
further notice:
Imbalance
Payback from Transportation Service Provider
Park
Withdrawal
Loan
ISS
Withdrawal
FSS
Overrun Withdrawal
Interruptible
and out-of-path Firm Transportation
Additionally,
Texas Gas is requesting all shippers take deliveries within their contractual
hourly rights so that receipts and Deliveries match their associated scheduled
quantities.
If
shippers do not voluntarily comply with these provisions, Texas Gas may be
forced to issue an Operational Flow Order, which could result in penalties for
shippers.
Transcontinental Gas Pipe Line
Company:
Subject:Operational
Flow Order – Imbalance
Transco
recently provided notice of limited flexibility to manage imbalances and
recommended shippers maintain a concurrent balance of receipts and deliveries. In
order to ensure system integrity, maintain safe operations, manage imbalances,
and handle within-the-day volatility, Transco is issuing an Imbalance
Operational Flow Order (OFO).
Effective: Sunday, January 20, 2019 until further notice
OFO
Areas: Zones 4, 5, and 6
Delivery
Tolerance %: 5%
Trunkline Gas Company:
Weather
Alert
Based
on current cold weather forecasts, Trunkline is preparing for increased
pipeline utilization and reduced operational flexibility. Effective Gas Day January 19, 2019, until further notice, Trunkline
is requesting all delivery point operators to minimize over-takes and all
receipt point operators to minimize their under-deliveries into the system.
Intraday
scheduling reductions may be implemented to ensure that nominations match
actual flowing quantities. Shippers are encouraged to submit their nominations
for the Timely cycle. Evening and Intraday nominations are subject to
scheduling reductions based on nomination levels and physical capacity.
The
following nominations are subject to scheduling reductions based on nomination
levels and physical capacity: Interruptible;
Secondary Outside-the-Path
Similarly,
all storage customers are requested to stay at or below their Maximum Daily
Withdrawal Quantity (MDWQ). Storage customers should adjust flowing volumes to
remain at or below these limits.
Trunkline
may limit Auto-Unpark nominations on the pipeline for the duration of the
extreme weather. These limits will be evaluated on a daily basis.
********************
As you can tell based on today’s gas pipeline report, the weather forecast through the end of January is for colder than average temperatures. The National Weather Service temperature forecast through the end of the month is now showing only the West Coast of the US with above average weather.
Bundle up, and enjoy the football games this weekend! Remember to subscribe to our audio podcasts via iTunes!
Winter is sneaking up on us quickly with some parts of the US expected to receive their first freeze or snowfall of the season over the next several days.
Welcome back to GasNewsOnline.com! We do the heavy lifting so that you may receive a summary of some of the important publicly-released energy and gas pipeline news of the week along with a forecast of temperatures over the next few weeks, too. All for FREE! Let’s get started with a look at this week’s gas storage report.
*********************
The weekly natural gas storage survey released today from the U.S. Energy Information Administration showed an additional 65 Bcf of gas injected into storage last week (vs. 58 Bcf predicted by a survey of analysts). The current volume of gas in storage remains about 16% below the five-year average.
Thursday’s NYMEX natural gas futures price for December closed down one cent to finish Thursday at about $3.54/MMBtu.
The natural gas plant liquids composite price at Mont Belvieu, Texas, fell by 41¢/MMBtu, averaging $7.54/MMBtu for the week ending November 7. The price of natural gasoline, ethane, and propane fell by 10%, 7%, and 4%, respectively. The price of butane and isobutane remained flat week over week.
According to Baker Hughes, for the week ending Tuesday, October 30, the natural gas rig count remained flat at 193.
EIA forecasts that dry natural gas production will average 83.2 Bcf/d in 2018, up 8.5 Bcf/d from 2017.
Both the level and growth of natural gas production in 2018 would establish new records. EIA expects natural gas production will continue to rise in 2019 to an average of 89.6 Bcf/d.
Despite relatively low storage levels, the EIA expects strong growth in U.S. natural gas production to put downward pressure on gas prices in 2019.
EIA predicts Henry Hub (Louisiana) natural gas spot prices to average $2.98/million British thermal units (MMBtu) in 2019, down 4 cents from the 2018 average.
********************
In other energy news today…
Anadarko Petroleum Corporation today announced a transaction to sell substantially all of its remaining midstream assets for $4.015 billion to Western Gas Partners, LP (WES) with $2.0075 billion cash proceeds, and the balance to be paid in new Western Gas equity. Concurrently, WES announced it has entered into a merger agreement with Western Gas Equity Partners, LP which will result in a simplified midstream structure. The sale is expected to close in the first quarter of 2019, concurrently with the closing of the merger.
“The size of this asset sale, along with the clear benefits of the simplification transaction, highlights the tremendous value of Anadarko’s midstream business,” said Al Walker, Anadarko Chairman, President and CEO.
Under the terms of the asset sale transaction, WES will acquire substantially all of Anadarko’s remaining midstream assets, which are largely associated with Anadarko’s two premier U.S. onshore oil plays in the Delaware and DJ basins. The acquired assets include DBM Oil Services (100-percent interest), APC Water Holdings (100-percent interest), the Bone Spring Gas Plant (50-percent non-operated interest), and the MiVida Gas Plant (50-percent non-operated interest) in the Delaware Basin of West Texas. In the DJ Basin of northeast Colorado, WES will acquire Anadarko’s 100-percent interest in both the DJ Basin Oil System and the Wattenberg Plant. Additional Anadarko midstream assets to be acquired by WES include equity stakes in the Saddlehorn Pipeline (20-percent non-operated interest), the Panola Pipeline (15-percent non-operated interest), and the Wamsutter Pipeline (100-percent interest).
Under the terms of their merger transaction, WGP will acquire all of the outstanding publicly held common units of WES and substantially all of the WES common units owned by Anadarko in a unit-for-unit, tax-free exchange. WES will survive as a partnership with no publicly traded equity, owned 98 percent by WGP and 2 percent by Anadarko. WES will remain the borrower for all existing debt and future issuances and the owner of all operating assets and equity investments.
********************
It’s a busy start to the winter season on the natural gas pipeline grid. Let’s check out the latest critical postings from several gas pipelines’ electronic bulletin boards:
ANR Pipeline:
Southwest Mainline Capacity Reduction (Updated 11/8/18)
This posting supersedes CN ID #8922
ANR continues its planned and unplanned compressor and pipeline maintenance at various compressor stations along its Southwest Mainline in Zones 5 and 6. Additionally, ANR will be performing pipeline maintenance in Zone 6.
The total SWML Northbound (DRN#226630) capacity will be reduced by the following:
Since the last posting, ANR has made the following changes. The 120-MMcf/d impact is extended from 11/10 – 11/12. Future dates adjusted accordingly.
Based on current nominations, it is anticipated that this posting may result in the capacity allocation reduction of IT, Firm Secondary and possibly a portion of Firm Primary volumes.
Columbia Gas Transmission:
Pursuant to Section 15 of the General Terms and Conditions of Columbia Gas Transmission, LLC’s (TCO) FERC Gas Tariff, TCO is declaring a Force Majeure effective Evening Cycle for Gas Day Thursday, November 8, 2018 until further notice for volumes flowing through the Waynesburg North MA35 (WAYNESNO) Internal Constraint due to discovered pipeline anomalies on Line 1360 south of Ellwood City Compressor Station in Pennsylvania.
Effective Evening Cycle for Gas Day Thursday, November 8, 2018, WAYNESNO will be set to a Total Capacity of 315,000 Dth. Based on current scheduled volumes, the potential impact to firm service is 75,000 Dth/day.
Florida Gas Transmission:
FGT will be performing planned pipeline maintenance between FGT Compressor Station 9 and FGT Compressor Station 10. This maintenance is scheduled to begin on November 14, 2018 and to continue through end of gas day November 20, 2018. During this maintenance FGT will schedule up to 1,100,000 MMBtu/day through Station 10. During normal operations FGT schedules up to 1,300,000 MMBtu/day through Station 10.Potential Overage Alert Day
Gas Transmission Northwest (GTN):
Notice of Force Majeure (Posted 11/8/18):
This is to notify all contracted parties of Gas Transmission Northwest (“GTN”) that due to unforeseen and uncontrollable repairs at Stations 3 and 5, pursuant to Section 6.10 of GTN’s FERC Gas Tariff, GTN is issuing a Force Majeure event in effect for all natural gas transactions that Flow Past Kingsgate (Loc 3500), located in Boundary County, Idaho.
GTN anticipates that this restriction will result in the inability to deliver a portion of the Firm delivery volumes scheduled at Flow Past Kingsgate (Loc 3500). The Reservation Charge Crediting Mechanism of Section 5.1.3.9 shall apply to this outage.
GTN will reduce the capacity at Flow Past Kingsgate (Loc 3500) to 2,184-MMcf/d.
Natural Gas Pipeline Company of America (NGPL):
Natural has experienced horsepower issues at Compressor Station 168 (CS 168), located in Bailey County, Texas in Natural’s Permian Zone. This is a Force Majeure event that requires Natural to temporarily reduce the maximum operating capacity northbound, thus limiting Natural’s throughput capacity through CS 168 during this restriction.
The scheduling constraint will be at CS 168; therefore, any gas received south of CS 168 for delivery north of CS 168 will be impacted for the duration of the restriction. Additionally, transports associated with storage injections may be impacted. The Permian Pool (PIN 25077) is located south (upstream) of the constraint.
As such, effective for gas day Friday, November 9, 2018, Timely Cycle, and continuing until further notice, Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 77% of contract MDQ through CS 168. 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.
The project end date has been changed, as noted below. This notice was last posted on October 18, 2018, entitled “NOVEMBER 2018 – SCHEDULED MAINTENANCE PROJECTS”.
On gas day Wednesday, October 24, 2018, and continuing through gas day Tuesday, November 20, 2018, (previously Thursday, November 8, 2018), Natural will be performing pipeline maintenance to install pigging facilities on the Gulf Coast #2 mainline near Compressor Station 302, located in Montgomery County, Texas (Segment 22 of Natural’s South Texas Zone). AOR/ITS and Secondary out-of-path Firm transports may not be available during this work. Primary Firm and Secondary in-path Firm transports may also be at risk of not being fully scheduled.
Northern Border Pipeline:
Northern Border OFO Watch (Posted 11/08/18)
Due to low inventory levels and cumulative operational imbalance issues, Northern Border Pipeline is posting an OFO Watch for the following locations:
Stateline (DRN# 1251297)
Squaw Creek (DRN# 1113226)
Rawson (DRN# 1399965)
Hay Butte (DRN# 1367615)
Watford City (DRN# 109973)
Spring Creek (DRN #1251436)
Kildeer (DRN # 1402285)
Manning (DRN# 378214)
Glen Ullin (DRN# 43726)
The issuance is per Northern Border Tariff Section 6.10.6 Interruption of Service.
The OFO Watch is effective immediately and extends through gas day November 13th, in order to allow the interconnecting parties to remediate the cumulative operational imbalance issue. If an interconnect operator is unable to remediate the issue within the given timeframe, Northern Border will, pursuant to Northern Border Tariff Section 6.10.6 Interruption of Service, issue an OFO requiring curtailment of interruptible services and/or forced balancing of nominations and actual flows at these interconnects.
Panhandle Eastern Pipeline:
Based on current cold weather forecasts and ongoing pipeline maintenance, Panhandle is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day November 9, 2018, until further notice, Panhandle is requesting all delivery point operators to minimize over-takes and all receipt point operators to minimize their under-deliveries into the system.
Intraday scheduling reductions may be implemented to ensure that nominations match actual flowing quantities. Shippers are encouraged to submit their nominations for the Timely cycle. Evening and Intraday nominations are subject to scheduling reductions based on nomination levels and physical capacity.
Interruptible and Secondary Outside-the-Path nominations are subject to scheduling reductions based on nomination levels and physical capacity.
Similarly, all storage customers are requested to stay at or below their Maximum Daily Withdrawal Quantity (MDWQ). Storage customers should adjust flowing volumes to remain at or below these limits.
Panhandle may limit Auto Un-park nominations on the pipeline for the duration of the extreme weather. These limits will be evaluated on a daily basis.
Southern Natural Gas:
Based on the current colder weather forecast in addition to the unplanned maintenance on Southern’s South system, we are notifying all Shippers will be subject to an OFO Type 3 Level 1 effective the start of the gas day, Saturday, November 10, 2018 until further notice.
OFO Type 3 Level 1: Daily Demand Exceeds Capacity
TARIFF SECTION 41.2
EFFECTIVE DATE: November 10, 2018
EFFECTIVE TIME of OFO: 9:00 AM (CCT)
PENALTY: $10.00/Dth
This is to notify all customers who are allocated gas at any delivery point in these segments that they are subject to an operational flow order commencing on the effective date set out in this notice and continuing until further notice. The above-stated penalty will be assessed on any shipper whose allocated deliveries at any delivery point(s) within the groups listed below exceed 105% of their daily entitlement at such delivery point.
Transcontinental Gas Pipe Line Company (Transco):
Subject: System Operating Conditions
Below normal temperatures and associated increased gas demand are currently forecasted for much of Transco’s market area late this week and into next week. Transco has limited flexibility to manage imbalances and strongly encourages all shippers to manage their system requirements to ensure a concurrent balance of receipts and deliveries on a daily basis.
Specifically, shippers are encouraged not to create “due from” imbalances (short to the pipeline). In addition, shippers that currently have a “due to” (long to the pipeline) imbalance position are encouraged to not under-supply their market requirements in an effort to reduce their “due to” imbalance position.
Absent voluntary compliance, Transco may be required to take further action including, issuing an Imbalance or Scheduling Operational Flow Order (OFO). These OFOs may include Shipper(s) specific and Location(s) specific OFOs directed to parties that have imbalances which has or may, affect the operational integrity of the system.
Trunkline Gas Company:
South Texas System Pigging – Beginning Gas Day December 1, 2018, Trunkline Gas Company will undertake pigging operations on its South Texas Modified Transmission System. Expected duration of the run is 11 days. Operators could experience higher daily line pressures and pressure fluctuations while the pigging operations are in progress.
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Based on all of the pipeline activities above, the temperatures are definitely heading downward quickly. The updated National Weather Service temperature outlook for the period ending November 18 shows the eastern 2/3 of the country with below average readings, while the Rockies and west coast regions will continue to enjoy warmer-than-normal temperatures.
Go out and enjoy the fall temperatures! Thanks for visiting us at GasNewsOnline.com. Check out I-tunes as our Podcast should now be available if you would prefer to listen on your drive to or from work. Please tell a friend!
Is it already November? Why, yes it is! Cooler weather, great football games, and, sadly, this is the weekend for you to re-set your clocks as the “Fall Back – Time change” begins Sunday morning.
Welcome back to GasNewsOnline.com! We review a large variety of publicly released information to keep you informed about the natural gas business – for FREE! We have a busy report for you today with a lot of gas pipeline news, a few publicly reported energy company transactions, and another update of the nation’s November temperature outlook.
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From the US Energy Information AdministrationNatural Gas Weekly Update dated November 1, let’s get started!
The Energy Information Administration released its weekly natural gas storage report today. Storage levels rose 48 Bcf for the week ending last Friday vs. a consensus industry estimate of 50 Bcf. Total gas in storage remains about 17% lower than the 5-year average.
At the New York Mercantile Exchange (Nymex), the November 2018 contract expired Monday at $3.185/MMBtu. The natural gas futures price for December fell two cents Thursday and settled at nearly $3.24/MMBtu.
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In energy news…
EncanaCorporation has agreed to acquire Newfield ExplorationCompany in an all-stock transaction valued at $5.5 billion. Encana will also assume $2.2 billion of Newfield’s debt.
The deal includes 360,000 net acres in Oklahoma near the center of the STACK/SCOOP areas in the Anadarko Basin.
Dominion Energyannounced Wednesday that it will sell its 50% interest in the Blue Racer Midstream pipeline to private equity company First Reserve and affiliated investment funds for up to $1.5 billion including $1.2 billion in cash and up to $300 million payable from 2019 through 2021 based on Blue Racer Midstream’s performance.
Dominion said that Blue Racer has become non-core to the company as it focuses on its regulated energy infrastructure. The transaction is expected to close by year-end 2018.
Enterprise Products Partners said Wednesday that it is planning an expansion to its natural gas liquids fractionation complex in Mont Belvieu, Texas to add another 150,000 barrels/day of processing capability. The company said that the newest NGL fractionator will be completed by early 2020 and is supported by long-term fee-based contracts with customers.
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Now let’s take a look at some recent critical notices from several interstate gas pipeline companies:
Columbia Gas Transmission:
Columbia Gas Transmission, LLC (TCO) reminds customers of maintenance work at the Summerfield Compressor Station in Noble County, Ohio scheduled November 5 through November 9, 2018. During this work, the Leach Express system (LXPSEG MA41) Internal Constraint will be set to 1,340,000 Dth Total Capacity. At this level, TCO estimates a reduction to firm service of less than 50,000 Dth per day based on current scheduled volumes.
Dominion Energy Transmission:
Storage and Transportation Imbalances Effective Immediately – Notice Text:
Due to current and anticipated system conditions, customers are reminded to monitor contractual storage entitlements and take the necessary steps to manage deliveries within those firm entitlements.
Transportation customers are also advised to equalize receipts and deliveries so as to minimize imbalances on DETI’s system. Capability for over-injections, short-term parking, and loan payback activity are expected to be very limited or possibly not available. They may be subject to allocation or potential penalties if warranted by an OFO, in accordance with the terms of DETI’s tariff.
In addition, DETI may restrict due pipe imbalance paybacks. Your cooperation is appreciated.
El Paso Natural Gas:
El Paso Natural Gas Company, (EPNG) plans to conduct a review of the 2019 scheduled Permian Basin maintenance on Wednesday, November 7 in Odessa, Texas. The intent of the meeting is to better coordinate EPNG’s 2019 planned maintenance with Permian Basin producer maintenance to minimize the impact to EPNG’s customers.
The meeting is primarily designed for Permian Basin operators and gas control personnel, but EPNG will not seek to exclude any interested individuals.
The meeting will be held at the EPNG Odessa Area Operations office located at 1550 Windway, Odessa, Texas. The meeting will start at 9:00 AM CST. EPNG will provide lunch.
GTN has posted its November maintenance schedule, and shippers will have to deal with some capacity restrictions over the next few weeks.
From November 6 through November 8, pipeline ILI activities will reduce capacity to about 1.9 Bcf/d at Station 14. At this volume, the pipeline projects a high probability of cuts to primary firm transportation during the period.
Beginning November 9 through the 21st, maintenance at the Starbuck Compressor Station will create a similar capacity restriction of 1.9 Bcf/d through Station 14 and a likelihood of reductions to firm transport shippers.
Natural Gas Pipeline Company of America:
STORAGE RESTRICTIONS – Update
WITHDRAWALS – No changes
INJECTIONS – Change concerning Amarillo System
Effective for gas day Friday, November 2, 2018, Timely Cycle, and continuing until further notice, injections above MDQ for DSS and NSS in all zones on the Amarillo System will not be scheduled.
No changes yet for the Gulf Coast System. Injections above IQ and MDQ for DSS and NSS in all zones on the Gulf Coast System will be scheduled.
Northern Natural Gas:
Northern is experiencing major underperformance at several Field Area delivery points located in the Permian Basin area. Northern has limited operational flexibility due to high line pack and capacity constraints to accommodate underperformance at these delivery points. As a result, Northern will be calling a Field Area specific System Underrun Limitation (SUL) for all delivery points located in the Beaver System South Allocation Group (Group #13) effective for Gas DayThursday, November 1, 2018 and continuing until further notice. In addition, Northern may be required to allocate the underperforming delivery points to actual flowing volumes during an intraday nomination cycle in order to protect the pipeline’s integrity. Allocations will continue at corresponding rates of performance and the initial occurrence for any particular gas day may be on the Intraday 3 nomination cycle. As performance improves at these delivery points, allocations may be lifted.
Nomination changes impacting constrained Field Area allocation groups may not be allowed during the Final true-up nomination cycle. This includes nominations to storage points for injection that would impact constrained groups not allocated during the Intraday 3 nomination cycle because nominated quantities for the group were slightly less than or equal to the operating capacity level.
During an SUL, System Management Service (SMS) is available below and above the scheduled volume; however, no 5% tolerance will apply below the customer’s scheduled volume before the Positive daily delivery variance charges (DDVCs) $1.00 rate will apply. (See Tariff Sheet No. 292).
Southern Natural Gas:
Transco Fairburn – New I/C Update #1
Southern Natural Gas Company, L.L.C. (“SNG”) provides this information to update its Shippers on the latest estimated in-service date for the new interconnect being placed in service with Transco during the 4th quarter of this year. SNG continues working on the Fairburn Expansion Project which will provide access to a new interconnection with Transco near Atlanta, Georgia (PIN # 50069) capable of receiving supplies of natural gas from Transco into SNG. The Fairburn Expansion Project provides new firm capacity on the SNG system by up to 370,000 Dth/d. Due to additional testing and related work, SNG now expects the project to be placed in-service by November 15, 2018 barring any further unexpected delays. If you have any questions about this planned project, please contact your account manager. We will post another notice with the in-service date prior to November 15th.
Southern Star Central Gas Pipeline:
Line Segment 130 Force Majeure (UPDATE #10)
Southern Star will be hosting a Webex call on Friday 11/02/2018 at 1:30 PM CST
Please join this Webex for updates on Line R (Kansas Hugoton Line) (Line Segment 130). Phone – 650-479-3208 – Access Code – 731 336 303
This call will provide updates on the status to fully restore service for Line Segment 130.
Also on Southern Star:
Notice Text –Location 121415 (NGPL Barton), and Location 35515 (ANR Alden) Operational Capacity Changes
Effective gas day November 1, 2018, operational capacities will remain reduced at the following locations due to changes in pipeline conditions:
Location 121415 (NGPL Barton) – 30,000 Dth/d
Location 35515 (ANR Alden) – 0 Dth/d
These operational capacities will remain in effect until January 1, 2019.
Subject: Gulf Connector Expansion and the Assessment of Fuel Charges in Zones 1, 2 and 3
On August 16, 2016, Transcontinental Gas Pipe Line Company, LLC (Transco) filed an application, as supplemented on May 2, 2017, under section 7(c) of the Natural Gas Act (NGA) and Part 157 of the Commission’s regulations for a certificate of public convenience and necessity authorizing the construction and operation of three new compressor stations, a new pipeline interconnect, and modifications to two existing compressor stations in Southeast Texas for its Gulf Connector Expansion Project (“Project”). The Project will provide 475,000 dekatherms per day of firm transportation under Rate Schedule FT from Transco’s existing Compressor Station 65 Zone 3 Pool southward to new delivery points in Transco’s Zones 1 and 2.
Once the project facilities are placed in service, Transco’s Zones 1, 2 and 3, which previously flowed from South to North, will become bi-directional and Transco will begin compressing gas southward for deliveries in Zones 1 and 2. Given the need to compress gas for these deliveries and the bi-directional nature of Zones 1 through 3, Transco will begin assessing its generally applicable Zones 1, 2 and 3 fuel retention percentages, coincident with the in-service date of the Project, on all gas transported in Transco’s Zones 1, 2 and 3. The assessment of Transco’s generally applicable fuel retention percentages is consistent with the assessment of fuel in Transco’s other bi-directional zones.
The Gulf Connector Expansion Project is expected to be placed into full or partial service as early as December 1, 2018.
Williston Basin Interstate Pipeline:
Valley Expansion Project In Service
WBI Energy Transmission, Inc. is pleased to announce that the eastern North Dakota Valley Expansion Project is in service effective November 1, 2018.
The new receipt and delivery point locations associated with the interconnect with Viking Gas Transmission are now available for scheduling and are as follows:
Point 01950 VGT-Felton (D)
Point 01951 VGT-Felton (R)
In conjunction with the expansion project, WBI has added Line Section 31. Please call the Scheduling Department at (701)530-1630 if you have any questions.
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In weather news, there are no tropical cyclones in either the Atlantic Ocean or in the Gulf of Mexico to report as we start the month.
The National Weather Service has updated their November temperature outlook for the United States. With warmer than seasonal weather expected along the east and west coast regions, the new forecast predicts a likelihood that the midsection of the country will see average to below average November temperatures.
Remember to “Fall Back” this Saturday night for the time change back to standard time again beginning Sunday!
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