Edition 44 – Monday, March 4, 2019

Welcome to this busy Monday edition of GasNewsOnline.com.  With cold weather gripping much of the United States, we will cover the latest critical postings from the interstate gas pipeline grid along with a few news stories from the energy business, and, of course, take a look ahead at the temperature forecast from the National Weather Service.  It is all FREE from GasNewsOnline.com.

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Cheniere Energy, Inc. and Bechtel Oil, Gas and Chemicals, Inc. announced today that Substantial Completion of Train 1 of the Corpus Christi liquefaction project was achieved on Thursday, February 28, 2019. Commissioning is complete and Bechtel has turned over care, custody, and control of Train 1 to Cheniere.

“Train 1 at Corpus Christi has achieved Substantial Completion, becoming the first liquefaction train placed into operation at a greenfield liquefaction facility in the lower 48 states,” said Jack Fusco, President and CEO of Cheniere. “This momentous achievement was made possible by Cheniere’s professionals and our EPC partner, Bechtel, who worked diligently together to ensure a seamless transition from construction to operations. I’d like to thank the Cheniere team and Bechtel for their world class execution, which has enabled us to continue our impeccable record of bringing trains online safely, ahead of schedule, and within budget.”

“The entire Bechtel team is very proud of our contribution to Cheniere’s success on the U.S. Gulf Coast, as we hand over custody of this historic first Texas LNG train,” said Brendan Bechtel, Chairman and Chief Executive Officer of Bechtel. “It was three years ago that we were able to support Cheniere’s entry into the LNG export market with Train 1 at the Sabine Pass Liquefaction project. With five trains now completed and operating well ahead of schedule, we are excited to continue working alongside Cheniere to deliver their next wave of trains with the reliability of outcome that Cheniere and Bechtel have become known for delivering. This program is a great example of how a one-team approach can bring world-class results, and I want to congratulate Jack and the Cheniere team for fostering this environment of collaboration and mutual success.”

Under sale and purchase agreements (“SPAs”) with Endesa S.A. and PT Pertamina (Persero), the date of first commercial delivery is expected to occur in June 2019, upon which the term of each of these SPAs commences. Additionally, bridging volumes are expected to begin in June 2019 under an SPA with Iberdrola, S.A.

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Last Friday, Cheniere announced that Midship Pipeline Company, LLC has issued Notice to Proceed to Strike, LLC, M.G. Dyess, Inc., TRC Pipeline Services, LLC, and Cenergy, LLC to construct the Midship natural gas pipeline and related compression and interconnect facilities (the “Midship Project”). The Midship Project received final Notice to Proceed from the Federal Energy Regulatory Commission in February 2019 and is expected to be placed in service by the end of 2019. Midship Pipeline is indirectly and jointly owned by Cheniere and EIG.

To complete financing of the Midship Project, Midship Pipeline entered into senior secured credit facilities with total commitments of up to approximately $680 million. The credit facilities consist of an approximate $615 million construction loan facility and a $65 million revolving credit facility. Proceeds from these credit facilities will be used to fund a portion of the costs of developing, constructing, and placing into service the Midship Project, to fund working capital requirements, and for related general corporate purposes.

The Midship Project is being developed to create pipeline capacity of up to 1,440,000 Dekatherms per day of firm transportation to connect production from the emerging STACK and SCOOP resource plays in the Anadarko Basin in Oklahoma to growing Gulf Coast and Southeast markets. The Midship Project is expected to consist of approximately 200 miles of 36 inch diameter new mainline pipeline, several laterals, compressor stations and interconnects that will provide receipts from STACK and SCOOP processing plants and provide deliveries to Bennington, Oklahoma, as well as access to downstream markets including the TexOk hub near Atlanta, Texas, and the Perryville Hub near Tallulah, Louisiana. Midship Pipeline has secured commitments from subsidiaries and/or affiliates of Cheniere, Devon Energy Corporation, Marathon Oil Corporation, and Gulfport Energy Corporation.

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Also on Friday, TransCanada Corporation announced the Federal Energy Regulatory Commission (FERC) had approved the full in-service of its Mountaineer XPress (MXP) project, allowing the company to increase the flow of gas on MXP and begin operating its Gulf XPress (GXP) project. The projects are a vital link between Appalachian natural gas supplies and growing markets in the U.S. and beyond.

“Mountaineer XPress and Gulf XPress are extremely important to TransCanada as they provide much-needed takeaway capacity for our customers, while also growing our extensive footprint in the Appalachian Basin,” said TransCanada President and Chief Executive Officer Russ Girling. “Both projects will also deliver attractive long-term returns and stable cash flow for our shareholders.”
                                                         
Designed to deliver clean, affordable, domestically produced natural gas, MXP is comprised of 170 miles of 36-inch-diameter pipeline, three new compressor stations, and modifications to three existing compressor stations – representing an investment of approximately US$3.2 billion. The pipeline is capable of transporting 2.7 billion cubic feet of natural gas per day to the TCO Pool and Leach markets on the Columbia Gas Transmission System. MXP is underpinned by long-term contracts with customers.

Partial in-service of the approximately US $600-million GXP project includes placing into service four new compressor stations located in Kentucky, Tennessee and Mississippi. Together, these facilities will provide additional capacity of 530,000 million cubic feet of natural gas per day on the Columbia Gulf Transmission System, which equates to approximately 60 percent of the project’s total capacity. GXP is also underpinned by long-term contracts with customers and is expected to be placed into full service in the coming weeks.

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With cold weather gripping the majority of the nation on Monday, several interstate gas pipelines posted operational notices on their electronic bulletin board systems to start the new week:

ANR Pipeline:

ANR is performing planned maintenance at its LaGrange Compressor Station on its Tie-Line located in Indiana in the Northern Fuel Segment (Zone 7). ANR will reduce the LaGrange Westbound location (LOC #314515) capacity by the following:

175-MMcf/d (leaving 525-MMcf/d available) 3/12 – 3/15

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

El Paso Natural Gas:

Pipeline Conditions – Permian Basin Weather Concerns 

The Permian supply basin is experiencing significant underperformance issues related to the winter weather that moved in overnight. Actual receipts into the system are approximately 545 MM below scheduled quantities for Gas Day March 4 (79% of schedule). A combination of freeze-offs and power outages coupled with road closures are impacting the ability of receipt point operators to restore supply to the system.  The Permian Basin overnight lows tomorrow morning are forecast again to be significantly below the seasonal average and additional supply underperformance is anticipated. 

Delivery point operators are encouraged to review their scheduled supplies to ensure that they are aligned with their flowing quantities.  Supply operators are encouraged to maintain their deliveries into the EPNG system at their scheduled rates.  Underperformance caps will be placed on underperforming supplies and if necessary EPNG will declare an SOC for DRAFT condition. 

Imbalance payback off the system, such as Make-Up Delivery (MD) transactions, may be limited or denied due to operational concerns related to maintaining adequate linepack. 

Washington Ranch is fully operational.

Gulf South Pipeline:

Index 300 Maintenance Pig Run:  March 20 – March 21, 2019 and again beginning March 27 – March 28, 2019

Capacity could be impacted by up to 25,000 dth/d for the duration of the maintenance. Based on current nominations and operational conditions Gulf South does not anticipate any customer impact.

Mobile Bay Delivery Scheduling Group – Capacity could be impacted by up to 150,000 dth/d for the duration of the maintenance.

Moss Point System Scheduling Group – Capacity could be impacted up to100,000 dth/d for the duration of the maintenance.

Northern Border Pipeline:

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 March 8th, 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.

Northern Natural Gas:

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 Tuesday and Wednesday, March 5 and 6, 2019, due to lower than normal forecasted system weighted temperatures.

Northwest Pipeline:

Effective for gas day Wednesday, March 6, 2019 and until further notice, Northwest is revising its current Overrun Entitlement as follows:

Receiving Party locations north of the Plymouth South constraint point, including the Spokane and Wenatchee laterals, will be revised from a Stage I (3%) Overrun Entitlement to a Stage III (13%) Overrun Entitlement.    

For Receiving Party locations between the Kemmerer compressor and the Plymouth South constraint the Stage II (8%) Overrun Entitlement will be lifted.

Even though the Entitlements are being changed or lifted, Northwest is not allowing balancing off the system. Customers can avoid future Entitlements by procuring sufficient supply for their market needs.

Panhandle Eastern Pipe Line:

On Sunday, March 3, Panhandle Eastern Pipe Line experienced a rupture downstream of the Centralia Compressor Station. This outage will require a section of the 400 Line to be shut-in for repairs, reducing mainline capacity.

Effective immediately, until further notice, Panhandle will be limiting nominations through Haven to 1,125,000 MMBtu/day, with gas scheduled in accordance with Section 8.8 (c) of Panhandle’s FERC Gas Tariff. This outage will be considered a Force Majeure event pursuant to Section 20 of Panhandle’s FERC Gas Tariff. 

Shippers are encouraged to bring in physical flowing gas from their Primary receipt point, or physical market area receipt meters downstream of this outage in order to avoid the constraint, and potential scheduling reductions of their nominated activity.  

The cold weather restrictions outlined in Critical Notice ID 8196 will remain in effect. Panhandle will be requiring all Enhanced Firm Transportation (EFT) shippers to limit their physical deliveries (takes) to a one-sixteenth hourly rate of the nominated volume. 

Updates on the impact to shipper nominations will be posted as they become available.

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 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 also being expanded to include all of the following groups listed below effective the start of the gas day, Tuesday, March 5, 2019 until further notice.
OFO Type 3 Level 2: Daily Demand Exceeds Capacity

TARIFF SECTION 41.2
EFFECTIVE DATE: March 5, 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 Pipeline:

System Advisory Notice:

Southern Star Central Gas Pipeline is issuing a Storage notice to protect the integrity of SSCGP’s storage facilities. A number of storage customers have inventory levels at or below five percent (5%). This issuance requires all TSS, STS, and FSS customers to have inventories at or above zero (0 %) and asks TSS and STS customers to also ensure they have at least one (1) day of inventory available. Failure to voluntarily comply could result in the issuance of an Operational Flow Order (OFO).

Tennessee Gas Pipeline:

EMERGENT REPAIR AT STATION 323A – SEGMENT 324 – EFFECTIVE 3-05-19 

Pursuant to Article XII of the General Terms and Conditions of Tennessee’s FERC Gas Tariff, Tennessee is posting notice of an emergent repair issue impacting a unit at Station 323A in Pike County, PA. Tennessee has personnel on site and repairs are underway. Tennessee is estimating the current impact to be up to 200,000 Dths at Segment 324 (FH). Based on current nominations, Secondary Out of the Path nominations and Secondary In Path nominations pathed through Segment 324 (FH) are at risk as early as Timely Cycle for the Gas Day of Tuesday, March 5, 2019.

Also on Tennessee Gas…

Due to a forecast of colder weather and higher demand moving across most of the system, effective for the Gas Day of Monday, March 4, 2019, and until further notice, Tennessee Gas Pipeline, L.L.C.  (“Tennessee”) is implementing an  OFO Daily Critical Day 1 for 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 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 Tuesday, March 5, 2019 to all parties, with the exception of those governed by a FERC gas tariff, in Texas Eastern’s Market Area Zone M2-30.

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.

During the effectiveness of this OFO, all parties must be balanced such that actual receipts of gas into the system must be equal to or greater than scheduled receipts into the system. The penalty shall apply to each dekatherm of actual receipt quantities that are less than scheduled quantities minus 2,000 Dth or 98% of scheduled receipt 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.

Texas Gas Transmission:

Below normal temperatures have moved into the Texas Gas service area for the first part of this week. 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:    Tuesday, March 5, 2019 and until further notice

OFO Areas:  Zone 6

Tolerance %:  5% for gas Due from Shippers

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The National Weather Service six-to-ten day forecast into March 14 is showing that Texas and most areas east of the Mississippi River will show a warming trend while temperatures remain below normal over the Upper Midwest, the Rockies, and the West Coast regions. 

That’s all for this chilly Monday edition of GasNewsOnline.com.  Please come back on Thursday for an update on the interstate gas pipeline conditions expected for the weekend. 

Please let your friends in the natural gas scheduling and transportation business know about us!  Also, our companion audio podcast is available via Apple Podcasts.  Subscribe today – it’s FREE

Edition 37 – Thursday, February 7, 2019

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 Administration released 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. 

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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.

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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.

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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!

Edition 35 – Thursday, January 31, 2019

Welcome to another “Polar Vortex” edition of GasNewsOnline.com!  While we search over fifty interstate natural gas pipeline companies for their critical postings, a lot of other news is happening this week.  Here at GasNewsOnline.com, we’ll update you on the publicly released news from energy companies and will give you the latest National Weather Service temperature forecast, too.    All for FREE!

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The US Energy Information Administration released its weekly update on natural gas in storage today.

Working gas in storage decreased by 173 Bcf from the previous week (versus an estimate of 189 Bcf by industry analysts).  Stocks were still 328 Bcf (or 13%) below the five-year average for the same week. 

On the NYMEX, the March, 2019 natural gas futures price has decreased by about 4 cents on Thursday at approximately $2.82/MMBtu.

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Consumers Energy greatly appreciates conservation efforts by all its natural gas customers across Lower Michigan to assist with a supply issue on the company’s gas distribution network. Conservation, even by gas customers served by other utilities than Consumers Energy, is making a difference.

Thursday morning, the company is cautiously optimistic that public requests to reduce gas use are having a positive effect.

However, with Thursday’s continued historically cold weather, the company asks that conservation measures continue through the end of the day Friday, Feb. 1.

Repairs at the Ray Compressor Station are ongoing and the station is partially in service, providing natural gas to our distribution system. However, customers are requested to continue to conserve energy until the end of the day Friday, Feb. 1, to allow for temperatures to moderate and additional repairs to the Ray Station.

“As a result of an unexpected incident at a Gas Compressor station on Wednesday January 30 in Southeast Michigan, we are asking customers to temporarily reduce gas usage at this time while we continue to contain the incident and help keep Michigan residents warm during this cold spell,” said Garrick Rochow, Senior Vice President of Operations for Consumers Energy.

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Tallgrass Energy, LP (NYSE: TGE) and Blackstone (NYSE: BX) today announced that affiliates of Blackstone Infrastructure Partners (“BIP”) have entered into a definitive agreement with affiliates of Kelso & Co., The Energy & Minerals Group, and Tallgrass KC, LLC, an entity owned by certain members of TGE’s management, to acquire 100% of the membership interests in TGE’s general partner, as well as an approximately 44% economic interest in Tallgrass, for total cash consideration of approximately $3.3 billion. Affiliates of GIC, Singapore’s sovereign wealth fund, will be a minority investor in the transaction.

“Blackstone’s scale, long-term capital, and investment expertise across the energy industry make it an ideal partner for our business as we continue to create value and invest capital in accretive growth opportunities,” said Tallgrass President and CEO David G. Dehaemers Jr. “We appreciate the successful partnership we have had with Kelso and EMG since 2012 and thank them for their significant support. We look forward to working with Blackstone to continue maximizing value for all stakeholders.”

“Tallgrass is managed by an exceptional team that has an outstanding track record of commercial, operational and financial success,” said Sean Klimczak, Global Head of Infrastructure at Blackstone. “This transaction represents a rare opportunity to invest in a large-scale U.S. midstream infrastructure platform that connects high-production supply basins to key markets and is underpinned by long-term contracts. We are excited to partner with and to support the established Tallgrass management team over the long term as they execute on their robust backlog of attractive growth projects.”

Closing of the transaction remains subject to customary closing conditions and is expected within the first quarter of 2019.

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On January 29, 2019, PG&E moved forward with its previously announced plan to file for Chapter 11 with the following press release.

We are continuing to provide safe and reliable electric and natural gas service. We are not “going out of business,” and we expect that there will be no disruption to the services you expect from us as a result of the Chapter 11 process.

Our extensive restoration and rebuilding efforts to help communities recover from the devastating wildfires are continuing. We are committed to these efforts and safety remains our most important responsibility.

PG&E is also working very hard to address future wildfire risks and continuing to make critical investments in our systems and infrastructure to further improve safety. Our Community Wildfire Safety Program includes:

  • Conducting detailed and enhanced safety inspections of more than 50,000 transmission poles and towers and 5,500 miles of transmission lines in the highest wildfire-threat areas;
  • Aggressively removing vegetation in areas of high wildfire risk, including trees and branches near power lines and trees at risk of damaging our lines;
  • Investing in more real-time monitoring and intelligence like 1,300 new weather stations and nearly 600 new, high definition cameras to enhance weather forecasting and modeling;
  • Installing stronger and more resilient poles and covered power lines in the highest fire risk areas; and
  • Replacing equipment to further reduce wildfire risks and tailoring upgrades based on terrain and weather conditions using more granular analysis of fire-prone regions.

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ExxonMobil said Wednesday that it has reached a final investment decision and started construction on a new unit at its Beaumont, Texas refinery that will increase crude refining capacity by more than 65 percent, or 250,000 barrels per day. The third crude unit within the facility’s existing footprint will expand light crude oil refining, supported by the increased crude oil production in the Permian Basin area.

 “With access to terminals, railways, pipelines and waterways nearby, the Beaumont refinery is strategically positioned to benefit from Permian production growth,” said Bryan Milton, president of ExxonMobil Fuels and Lubricants Company. “The addition of a third crude unit in Beaumont will enhance the refinery’s competitive position and truly establish it as a leader in the U.S. refining industry.”

Startup of the new unit is anticipated by 2022. The project is expected to create up to 1,850 jobs during construction and between 40 and 60 permanent jobs once completed.

ExxonMobil’s integrated operations in Beaumont include a 366,000 barrel-per-day capacity refinery, as well as chemical, lubricants and polyethylene plants. ExxonMobil has approximately 2,100 employees in the Beaumont area and its operations account for approximately one in every seven jobs in the region.

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With much of the country still dealing with extremely cold weather, let’s take a look at the latest critical postings from the interstate natural gas pipeline companies around the lower 48 states:

Algonquin Gas Transmission:

With the impending colder weather beginning Wednesday January 30, 2019 and in order to maintain the operational integrity of the “G” system, Algonquin Gas Transmission, LLC (AGT) is requesting all customers/point operators on the “G” system to fully nominate their 6% “G” system contracts to the appropriate “G” system meter station. In the event customers do not properly nominate in such a manner, point operators will be limited in their ability to take non-ratable/accelerated deliveries above scheduled volumes to these meters for 6 consecutive hours.

Furthermore, AGT requires that customers/point operators on the “G” lateral be aware of the impact non-ratable hourly takes from the system and the impact it could have on system operations. Delivery pressures could reach lower than desire levels to the extent point operators’ hourly takes exceed their maximum hourly transportation quantity (MHTQ) based on their scheduled quantities. AGT’s “G” lateral is not designed to sustain delivery pressures above contractual pressure obligations if:
1)Point operators’ hourly rates are exceeding their MHTQ levels based on nominated quantities or
2)Point operators’ hourly rates are exceeding 1/24th of the daily nominated quantity for more than 6 consecutive hours (or greater than 6 hours on any gas day)

Furthermore, if customers/point operators do not manage hourly takes from the system within their scheduled MHTQ limits AGT may be required to impose further restrictions or courses of action in order to maintain the operational integrity of the system including the issuance of an hourly OFO pursuant to General Terms and Conditions Section 26.7(d).

ANR Pipeline:

Attention All ANR Shippers (Lifted 2/1/19 Timely Cycle)
This posting supersedes CN ID #9059

Update: Effective February 1 at the Timely Nomination Cycle, ANR is lifting the restriction limiting customers delivering north of the Woodstock compressor station to their contractual primary delivery points.

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

Columbia Gas Transmission:

Pursuant to Section 15 of the General Terms and Conditions of Columbia Gas Transmission LLC’s (TCO’s) FERC Gas Tariff, TCO is declaring a Force Majeure effective immediately for the ID-1 cycle for Gas Day 31.

The Force Majeure will impact volumes flowing through the MXP (Markwest) Sherwood Plant (Loc Prop 643185) receipt location only at this time.

A need for an investigative dig has been discovered that necessitates further action. TCO will keep shippers apprised of any changes in operational restrictions for this outage.   

For the Timely cycle for Gas Day Friday, February 1st and until further notice, the MXP Sherwood receipt location will be set to zero Total Capacity. 

TCO will continue to provide updates as information becomes available.

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.

Florida Gas Transmission:

FEBRUARY 2019 — FGT SUPPLY AREA MAINTENANCE IN ZONE 3

FGT will continue pipeline maintenance near FGT Compressor Station 10. This maintenance is expected to continue through the end of gas day February 28, 2019.  During this maintenance FGT will schedule up to 1,150,000 MMBtu/day through Station 10. During normal operations FGT schedules up to 1,300,000 MMBtu/day through Station 10.

FGT will perform pipeline maintenance near FGT Compressor Station 11. This maintenance is scheduled to begin February 1, 2019 and to continue through the end of gas day February 28, 2019.  During this maintenance FGT will schedule up to 3,050,000 MMBtu/day through Station 11. During normal operations FGT schedules up to 3,250,000 MMBtu/day through Station 11.

Gulf South Pipeline:

Vixen Compressor Station Maintenance

Begins: February 4, 2019  –  Ends: February 8, 2019

Expansion Receipts Upstream Vixen Scheduling Group.

Capacity could be impacted by up to 100,000 dth/d for the duration of the maintenance.

Please contact your customer service representative if you have any questions.

Mojave Pipeline Company:

Force Majeure Lifted – Mojave-Topock Unit #2 

The Force Majeure event that was declared on January 18, 2019 (Reference Critical Notice #604348) at Topock Compressor Station with Unit 2 has been resolved.  

The available capacity through the Segment 3000 constraint will be increased to 463,000 dekatherms (Dth) per day effective Cycle 1 (Timely) for February 1, 2019

Northern Natural Gas:

Effective Gas Day 02/01 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 Day Friday, February 1, 2019, due to lower than normal system weighted temperatures.

Northwest Pipeline:

Notice ID:  19-014

Subject:  Overrun Entitlement north of Kemmerer for all Receiving Parties

Due to a forecast of colder than normal weather, Northwest is declaring a Stage III (13%) Overrun Entitlement for all Receiving Parties north of the Kemmerer compressor station beginning gas day Saturday, February 02, 2019 until further notice.

If you have any questions, please contact your Marketing Services Representative or the Scheduling Hotline at (801) 584-7301.

Rockies Express Pipeline (REX):

Effective for the ID 1 Cycle, Gas Day Thursday, January 31, 2019 and until further notice, REX is partially lifting the capacity constraint at Markwest – Seneca (Loc 56116) and accepting receipts up to 200 MDth/d. 

Sabine Pipeline Company:

Sabine Pipe Line LLC (“Sabine”) plans to perform maintenance to one of the units at its Henry Compressor Station (the “Compressor Station”) which will reduce overall available compression capacity at the Henry Hub.

Maintenance is scheduled to occur February 4 through February 8. 

While we do not expect capacity in this area to be affected, we encourage shippers to closely monitor the website for capacity updates.

Southern Star Central Gas Pipeline:

Winter Weather Warning will terminate effective 1/31/2019 ID1 cycle due to elevated temperatures.

Thank you all for working with Southern Star during this weather event.

Texas Eastern Transmission:

Texas Eastern Transmission, LP (TE) hereby declares a Force Majeure in accordance with Section 17 of the General Terms and Conditions of its FERC Gas Tariff. The Force Majeure event is due to an unplanned outage on its 36″ system at the Marietta Compressor Station (Marietta) in Marietta, Pennsylvania which occurred on January 31, 2019. While efforts to repair the compressor station to full capacity are underway, the estimated time of restoration is unclear at this time.

TE will post updates to the status of repairs as they are known.

Transcontinental Gas Pipe Line Company (Transco):

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).

Beginning:  Friday, February 1, 2019 and until further notice

OFO Areas:  Zone 6

Tolerance %:  10% for gas Due from Shippers

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With the Midwest, Great Lakes, Middle Atlantic, and New England still dealing with another day of the latest Polar Vortex cold weather outbreak, the National Weather Service six-to-ten day temperature outlook paints a brighter picture for those regions by this time next week. 

The forecast for February 6 – 10 is now calling for warmer than seasonal temperatures generally east of the Mississippi River to the East Coast while the West Coast and Rockies get their first winter cold blast of this new year. 

That wraps up an eventful January here at GasNewsOnline.com!  Please let your friends in the natural gas scheduling and transportation business know about us.  Our companion audio podcast is FREE and available via iTunes.  Check it out!

Edition 34 – Monday, January 28, 2019

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, Enbridge released 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.

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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.

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

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.

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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.

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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

Edition 33 – Thursday, January 24, 2019

Another weekend of cold weather is hitting the Upper Midwest and the East Coast. GasNewsOnline.com brings you the latest natural gas pipeline company critical notices, today’s energy news, and a peek at the February temperature forecast. All for FREE!

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Earlier today, Enbridge provided an update regarding an incident that occurred Monday, January 21, 2019, near Summerfield, Ohio, on its Texas Eastern pipeline system.

There was a natural gas pipeline rupture on the Texas Eastern Transmission 30-inch “Line 10” in Noble County, Ohio on Monday morning about two miles south of Summerfield.

There was a fire, which was extinguished.  In an earlier posting, the company acknowledged that two individuals living nearby suffered injuries and three nearby homes were damaged. 

Today’s press release said that company personnel have begun work to help further secure the site in preparation for investigation and maintenance activities.

This morning, the Texas Eastern electronic bulletin board posted the following critical notice:

30″ Unplanned Outage — UPDATE (2)

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:

TE has three lines between its Berne and Athens compressor stations that make up its 30 inch pipeline system in this area. These lines are: Line 10, Line 15 and Line 25. As posted on January 22, 2019, TE has restricted capacity north to south thru its Berne compressor station to net -0- through the station by also isolating Lines 15 and 25 providing the ability to safely investigate the incident as well as the integrity of those two pipelines prior to returning them to service. At this time, TE is taking the necessary steps to return Line 25 back to service as soon as safely possible.

Texas Eastern will provide an update on the estimated date that Line 25 will be returned to partial service and the associated capacity of such activity as early as Friday evening.

TE will continue to post subsequent updates to the status of the repairs and return to service plan as soon as it is known for all three lines.

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Working gas in storage was 2,370 Bcf as of Friday, January 18, 2019, according to EIA estimates. This represents a net decrease of 163 Bcf versus the analysts’ estimate of 145 Bcf withdrawal. 

Natural gas volumes in storage remain at 305 Bcf or 11.4% below the five-year average.

As a result of the larger-than-expected gas storage pull, the NYMEX February, 2019 gas futures price is up around thirteen cents on Thursday at about $3.11/MMBtu.

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With frigid weather returning again for the weekend, let’s check out the latest critical posting information from the interstate natural gas pipeline company electronic bulletin boards:

ANR Pipeline:

Attention All ANR Shippers,

Effective gas day Thursday 1/24/2019, Evening cycle and until further notice, in order to preserve system integrity and to ensure ANR is able to meet scheduled delivery commitments to all locations in ML7, ML3 and in ML2 between the Sardis and Madisonville Compressor stations; ANR is, in accordance with the General Terms and Conditions, declaring an “Extreme Condition” as that term is defined in ANR’s FERC Gas Tariff §6.1, lowering the Swing Percentage from 10% to 5 %.

ANR is requesting, in accordance with §6.6.4 of its FERC Gas Tariff, that all receipt and delivery services, excluding ETS and FTS-3 services, to be at a uniform hourly flow rate over a twenty-four (24) hour period. ETS and FTS-3 shippers are required to be at their contractually agreed upon hourly rate.

Requests for operational flexibility with regard to variable hourly flow rates will be denied. All shippers must adhere to the flow rates applicable to the rate schedule of their nominated contract. Nominations on FTS-3 and ETS contracts to Secondary delivery gates must flow at an even-hourly rate

Requests for ITS-3 service will not be scheduled on ANR’s contiguous system in ML7, ML3 and in ML2 between the Sardis and Madisonville Compressor stations. Additionally, requests for Interruptible and Overrun delivery service on Rate Schedules ITS and IWS through Bridgman Westbound, Loc ID 226625, Sandwich Northbound, Loc Id 359925 and Crystal Falls-Fortune LK Loc Id 11661, WILL NOT be scheduled.

ANR is also reminding all MBS shippers that volumes not within operating tolerances and not at a uniform hourly flow rate of 1/24th of scheduled nominations will not be permitted.

In addition, ANR is not allowing any “Unauthorized Overrun” under Rate Schedules FTS-1, FTS-2, FTS-3, FTS-4, FTS-4L, STS and ETS. Please refer to ANR’s FERC Gas Tariff under each rate schedule for further detail.

As a reminder, per ANR’s FERC Gas Tariff §6.6.3, “Shipper will not have the right to receive quantities of Gas that it has not simultaneously nominated and delivered to Transporter at Receipt Point(s).”

ANR reserves the right to revoke any conditionally approved operational flexibility.

To clarify, ANR is NOT declaring an Operational Flow Order (OFO) at this time.

Southeast Mainline Capacity Reduction (Posted 1/23/19)

ANR will begin planned and unplanned pipeline maintenance on its SEML located in the Southeast Southern Area (Zone 2). For the period January 23rd through February 2nd, ANR will not schedule nominations at the Kinder Morgan Midcontinent Express location, LOC #803183.

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

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 25, 2019, Transport Critical Days are necessary in all Market Areas across the TCO system.  Please note the following: 

Transport Critical Days:  Friday, January 25, 2019 and until further notice.  TCO will monitor conditions and provide updates as necessary. 

Applicable Market Areas:  All Market Areas 

Applicable 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. 

In addition:

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 25, 2019, Storage Critical Days are necessary for deliveries to all Market Areas across the TCO system.  Please note the following: 

Storage Critical Days:  Friday, January 25, 2019 and until further notice.  TCO will monitor conditions and provide updates as necessary. 

Applicable Market Areas:  All Storage Withdrawals delivered to all Market 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 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. 

Florida Gas Transmission:

FEBRUARY 2019 — FGT SUPPLY AREA MAINTENANCE IN ZONE 3

FGT will continue pipeline maintenance near FGT Compressor Station 10 in southern Mississippi. This maintenance is expected to continue through the end of gas day February 28, 2019.  During this maintenance FGT will schedule up to 1,150,000 MMBtu/day through Station 10. During normal operations FGT schedules up to 1,300,000 MMBtu/day through Station 10.

FGT will perform pipeline maintenance near FGT Compressor Station 11 in southern Mississippi. This maintenance is scheduled to begin February 1, 2019 and to continue through the end of gas day February 28, 2019.  During this maintenance FGT will schedule up to 3,050,000 MMBtu/day through Station 11. During normal operations FGT schedules up to 3,250,000 MMBtu/day through Station 11.

Natural Gas Pipeline Company of America (NGPL):

OPERATIONAL FLOW ORDER ISSUED – MARKET DELIVERY ZONE – UPDATE #1

The hourly rights for Firm service have been decreased to 110% (previously 120%).  This notice was last posted on January 17, 2019, entitled “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, Thursday, January 24, 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.  Additionally, if conditions warrant, a Critical Time will be issued in the near future.  Please monitor Natural’s Interactive Website for updates.

Northern Border Pipeline:

Northern Border OFO Watch (Posted 1/23/19)

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 through gas day February 5, 2019 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. 

Northern Natural Gas:

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 January 25, 2019, due to lower than normal forecasted system weighted temperatures.

Northwest Pipeline:

Effective gas day January 24, 2019 and until further notice, Northwest is issuing an OFO Recall Advisory and Operational Flow Order (OFO) northbound through the Rangely compressor station pursuant to Section 14.15(d) of its Tariff. 

Under the OFO Recall Advisory, Shippers are required to: (1) recall capacity that is subject to an OFO recall provision; or (2) take other action that is acceptable to Northwest, to satisfy its OFO obligation.

If the scheduled quantities for gas day January 24, 2019 exceed the operational available capacities through the Rangely compressor, Northwest will provide Shippers with their specific OFO obligations.

Panhandle Eastern Pipe Line Company:

Based on current cold weather forecasts, Panhandle is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day January 19, 2019, Panhandle is requesting all delivery point operators to minimize over-takes and all receipt point operators to minimize their under-deliveries into the system. 

In addition, effective Gas Day January 24, 2019 – To ensure system integrity, Power Plant Operators must have nominated supply. Panhandle is requesting all Shippers under Rate Schedule EFT, EIT, SCT, GDS or LFT to limit their hourly deliveries to one-sixteenth of the quantity scheduled for delivery on the applicable Day. Please refer to the GT&C Section 12.11(g) of the Panhandle Tariff regarding the penalty provisions as it applies to customers in the event of noncompliance with this request. 

Southern Natural Gas:

Based on the weather forecast predicting colder weather 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 2 OFO is being expanded effective the start of the gas day, Friday, January 25, 2019 until further notice.

OFO Type 3 Level 2: Daily Demand Exceeds Capacity
TARIFF SECTION 41.2
EFFECTIVE DATE: January 25, 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

Also on SNG:

Southern Natural Gas Company has experienced an unscheduled station outage at its Providence compressor station.  Segment 120 capacity of 658 MMBtu/d will be impacted up to 114 MMBtu/d effective Gas Day, January 25th 2019. 

During this outage, a reduction in IT service and Out of Path service will be necessary.   

SNG is working diligently to return these units to full service. We will continue to send updates as more information becomes available. 

Tennessee Gas Pipeline:

OFO DAILY CRITICAL DAY 1 FOR ALL OF ZONES 2, 3, 4, 5 AND 6 EFFECTIVE 1-25-19

Due to a forecast of colder weather and higher demand moving across most of the system, effective for the Gas Day of Friday, January 25, 2019, and until further notice, Tennessee Gas Pipeline, L.L.C.  (“Tennessee”) is implementing an OFO Daily Critical Day 1 for 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 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 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.

Also on Tennessee Gas:

EMERGENT REPAIR AT STA 254 UNIT 2A EFFECTIVE 1/28/19 THROUGH 2/1/19

In accordance with Article XII of Tennessee Gas Pipeline, LLC’s (“Tennessee”) FERC Gas Tariff, Tennessee is posting notice of an emergent repair issue at Station 254 Unit 2A near Nassau, NY.  A unit outage will be required to check the foundation bolts of the unit.  Based on current nominations, Secondary Out of the Path nominations pathed through STA 254 (Segment 256 FH) are at risk as early as Timely Cycle for the Gas Day of Monday, January 28, 2019.  The expected return to service is Friday, February 1, 2019.

Tennessee estimates the impact to be up to 10,000 Dths of Secondary Out of the Path nominations pathed through STA 254 (Segment 256 FH).  

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).

Beginning:  Friday, January 25, 2019 and until further notice

OFO Areas:  Zone 6

Tolerance %:  10% for gas Due from Shippers or Due to Shippers

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Looking at the temperature outlook for the entire month of February, the National Weather Service is showing that cooler than normal temperatures are likely in the Midwest and Southern states east of the Mississippi River.  Also, colder average temps are forecast for much of the Middle Atlantic region.  Normal February conditions are expected for New England, with warmer than seasonal weather conditions forecast for the Rockies to the West Coast.

Stay warm this weekend! Thanks for visiting GasNewsOnline.com! We check the publicly available sources to keep you up informed about the natural gas transportation business twice every week. All for you, and all for FREE! Please tell a friend, and remember to check out our nifty audio podcast and subscribe via iTunes, too. It’s FREE!

Edition 32 – Tuesday, January 22, 2019

Welcome to this Tuesday edition of GasNewsOnline.com.  After the MLK holiday, the National Weather Service is now advising that the colder weather pattern is now expected to continue right into early February.

We’ll give you the latest temperature update, a look at the gas pipeline companies’ critical notices, and take a look at the latest energy news of the day.  It is all for FREE from GasNewsOnline.com.

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From the US Energy Information Administration, let’s review some of the highlights of last week’s “Natural Gas Weekly Update” publication.

Natural gas spot prices rose at most locations last week.  For example, Henry Hub spot prices in Louisiana rose from $2.91 per million British thermal units (MMBtu) the prior week to over $3.60 MMBtu late last week.  .

At the NYMEX, the price of the February 2019 natural gas futures contract also increased last week, but it was trending backward in Tuesday’s trading.  After rising about fifty cents to over $3.50 last week, Tuesday’s NYMEX price was dropping back to about $3.05 MMBtu near today’s close.   

Net withdrawals from working gas totaled 81 billion cubic feet (Bcf) for the week ending January 11. Working natural gas stocks are still 11% lower than the five-year (2014–18) average for the same week.

The natural gas plant liquids composite price at Mont Belvieu, Texas, rose by 26¢/MMBtu, averaging $6.46/MMBtu for the week ending January 16. The price of natural gasoline, ethane, propane, butane, and isobutane all rose, by 5%, 1%, 7%, 3%, and 1%, respectively.

According to Baker Hughes, for the week ending Tuesday, January 8, the natural gas rig count increased by 4 to 202. The number of oil-directed rigs fell by 4 to 873. The total rig count remains unchanged at 1,075.

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Earlier today, BlueMountain Capital Management has delivered a second open letter today to the Board of Directors of PG&E Corporation. 

As you may recall, PG&E announced that it plans to file for bankruptcy protection prior to the end of January. 

In response, the investment firm, which reportedly owns several million shares of the California utility company’s stock, said that PG&E’s plan to file bankruptcy before the end of January is unnecessary and should be postponed at least until the next Annual Meeting of the company’s shareholders. 

Today’s letter concludes, “If the Board is unwilling to slow down, consult with stakeholders, and make a more deliberate decision, then the Company and its stakeholders deserve a different Board.”

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Let’s examine some of the latest critical notices from the interstate gas pipeline companies’ Electronic Bulletin Boards:

ANR Pipeline:

Attention All ANR Shippers:

Effective gas day Thursday 1/24/2019 for the Timely cycle and until further notice, in order to preserve system integrity and to ensure ANR is able to meet scheduled delivery commitments to all Market Area locations; ANR is, in accordance with the General Terms and Conditions, declaring an “Extreme Condition” as that term is defined in ANR’s FERC Gas Tariff §6.1, lowering the Swing Percentage from 10% to 5 %.

ANR is requesting, in accordance with §6.6.4 of its FERC Gas Tariff, that all receipt and delivery services, excluding ETS and FTS-3 services, to be at a uniform hourly flow rate over a twenty-four (24) hour period. ETS and FTS-3 shippers are required to be at their contractually agreed upon hourly rate.

Requests for operational flexibility with regard to variable hourly flow rates will be denied. All shippers must adhere to the flow rates applicable to the rate schedule of their nominated contract. Nominations on FTS-3 and ETS contracts to Secondary delivery gates must flow at an even-hourly rate. In addition, no incremental interruptible and overrun services including ANR’s hourly ITS-3 service will be scheduled in the Market Area (ML7) until further notice. Any currently scheduled ITS-3 nominations must flow at their nominated approved flow profile.

ANR is also reminding all MBS shippers that volumes not within operating tolerances and not at a uniform hourly flow rate of 1/24th of scheduled nominations will not be permitted.

In addition, ANR is not allowing any “Unauthorized Overrun” under Rate Schedules FTS-1, FTS-2, FTS-3, FTS-4, FTS-4L, STS and ETS. Please refer to ANR’s FERC Gas Tariff under each rate schedule for further detail.

As a reminder, per ANR’s FERC Gas Tariff §6.6.3, “Shipper will not have the right to receive quantities of Gas that it has not simultaneously nominated and delivered to Transporter at Receipt Point(s).”

ANR reserves the right to revoke any conditionally approved operational flexibility.

To clarify, ANR is NOT declaring an Operational Flow Order (OFO) at this time.

Kern River Gas Transmission:

Colder weather and higher demand are forecasted in Kern River’s market areas throughout Wednesday, January 23rd. Therefore, Kern River requires all shippers and receipt and delivery point operators align their daily scheduled nominations with physical receipts and deliveries to ensure Kern River’s line pack is maintained at current operating levels.

Customers should visit Kern River’s Daily Operational Report (DOR) at http://services.kernrivergas.com to monitor system conditions and other important information.

Mojave Pipeline Company:

Force Majeure – Mojave – Topock Station – Unit 2

Mojave Pipeline Company, L.L.C. (Mojave) has experienced an equipment failure associated with its Topock Compressor Station, and as such Unit 2 is currently unavailable. Accordingly, the operational capacity through the Segment 3000 constraint will be reduced from 463,000 dekatherms (Dth) per day to 346,000 Dth/day effective on January 19, 2019, Timely Cycle (Cycle 1) and remain in effect until further notice. 

Mojave will provide updates as more information becomes available. 

This incident constitutes an event of force majeure under Section 11.5 of the General Terms and Conditions of Mojave’s FERC Gas Tariff.

Nexus Gas Transmission:

Hanoverton Compressor Station Outage: January 23 – 28, 2019
Nexus Gas Transmission, LLC (NEXUS) will be conducting an outage at its Hanoverton Compressor Station. During this outage, capacity through Hanoverton will be reduced to approximately 900,000 Dth/d.

Based on recent nominations patterns, NEXUS does not anticipate restrictions associated with this outage; however depending on nominated quantities, restrictions may be required.

Northern Natural Gas:

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 January 23, 2019, due to lower than normal forecasted system weighted temperatures.

SOCAL Gas:

Due to cold weather conditions and high customer demand for natural gas, a system‐wide voluntary curtailment of electric generation demand was issued today at approximately 5:00 PM PCT and is effective for gas day January 22, 2019 through gas day January 23, 2019.

Note that a gas day is from 7:00 AM to 7:00 AM. SoCalGas has issued the system‐wide voluntary curtailment order of electric generation demand in accordance with the Aliso Canyon Withdrawal Protocol. The curtailment is a voluntary request coordinated through the Balancing Authorities (CAISO and LADWP) for them to limit and/or reduce electric generation demand on our system, to the extent it does not impact electric system integrity.

If needed, the Aliso Canyon Storage field may be used to meet the current demand as well as maintain inventory levels at the other storage fields for core reliability.

In addition, with the current forecasted weather, SoCalGas is asking customers to conserve natural gas where possible. 

Southern Natural Gas:

The Type 3 Level 2 OFO that was implemented effective January 20, 2019 will be partially lifted for certain groups on the North and South systems effective gas day, Tuesday, January 22, 2019 until further notice.  Please refer to SNG’s EBB dated January 22, 2019 for more information.

Southern Star Central Gas Pipeline:

Winter Weather Watch – Effective Thursday, January 24, 2019

With colder weather forecast across the Southern Star system, Southern Star is issuing a winter weather watch beginning Thursday, January 24, 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 Sunday, January 27, 2018.

Tennessee Gas Pipeline:

OFO DAILY CRITICAL DAY 1 LIFTED FOR ALL OF ZONES 2,3,4 AND PART OF ZONE 5 EFFECTIVE 1-22-19

Effective for today’s Gas Day of Tuesday, January 22, 2019, and until further notice, Tennessee Gas Pipeline, L.L.C. (“Tennessee”) is LIFTING the existing OFO Daily Critical Day 1 for all Zones 2, 3, 4 and part of Zone 5 due to milder temperatures moving into those areas.  THE OFO DAILY CRITICAL DAY 1 WILL CONTINUE TO BE IN EFFECT FOR ALL AREAS EAST OF STA 245 IN ZONE 5 ON THE 200 LINE AND FOR ALL OF ZONE 6 ON BOTH THE 300 (EAST OF MLV 336) AND 200 LINES 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 areas east of Station 245 in Zone 5 on the 200 Line and for all of Zone 6 on both the 300 (east of MLV 336) and 200 lines are still 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 areas east of Station 245 in Zone 5 on the 200 Line and for all of Zone 6 on both the 300 (east of MLV 336) and 200 lines are still 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 Eastern Transmission:

Texas Eastern Transmission, LP (TE) hereby declares a Force Majeure in accordance with Section 17 of the General Terms and Conditions of its FERC Gas Tariff. The Force Majeure event is due to an unplanned outage on its 30″ system south of the Berne Compressor Station (Berne) in Berne, Ohio which occurred on January 21, 2019. While efforts to restore this line to full capacity are underway, the estimated time of restoration is unclear at this time.

TE will post updates to the status of repairs as they are known.

Transcontinental Gas Pipe Line Corporation:

The Operational Flow Order – Imbalance (OFO) currently in effect on the Transco system in Zones 4, 5, & 6 will be terminated effective January 23, 2019 at 9:00 AM CST. 

Circumstances leading to the issuance of the OFO are expected to improve; however, 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 daily.

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The continuation of cold weather across the Upper Midwest to the East Coast is expected to linger into early February according to the 8-14 day temperature outlook from the National Weather Service.  The Southern states should also see temperatures at or a little below normal, while the Rockies and West Coast may continue to have warmer than seasonal weather conditions for early February. 

That wraps up this special Tuesday edition of GasNewsOnline.com.  Please look for our next update on Thursday in front of the coming weekend.  Remember that our audio podcast is available to you for FREE via iTunes as well!

Edition 25 – Thursday, December 20, 2018

Like George Bailey on the bridge in It’s A Wonderful Life, the natural gas business is hoping for a wintertime miracle to give another boost to natural gas prices for the coming year.

Welcome back to GasNewsOnline.com!   We take care of wrapping up the packages of natural gas news and gas pipeline bulletin board postings for you – all for FREEHo, Ho, Ho!

Before we take a look at a large number of critical notices from the interstate pipeline companies, let’s check out some of the latest natural gas news today:

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From the US Energy Information Administration‘s “Weekly Natural Gas Storage Report“, working gas in storage decreased by 141 Bcf from the previous week.   Natural gas stocks were 720 Bcf or 20.6% below the five-year average.

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Oklahoma Gas & Electric, the utility subsidiary of OGE Energy Corp., announced today that it will acquire two existing power plants to meet customers’ energy needs. The plants will replace capacity currently provided by power purchase contracts set to expire in 2019.

The company announced it will acquire the Shady Point plant near Poteau, Oklahoma, and the Oklahoma Cogeneration plant in Oklahoma City.

The Shady Point facility is a 360 MW coal- and natural gas-fired plant utilizing circulating fluidized bed boilers that produce lower emissions due to their design features and emissions controls.

The Oklahoma Cogeneration facility is a 146 MW natural gas-fired combined-cycle plant.

The company will pay approximately $53 million for the two plants, which currently serve OG&E customers.

“In the past five years, we’ve completed several critical projects that advance our commitment to deliver energy reliably and affordably to customers in an environmentally responsible way.  Today’s announcement builds on that commitment,” said OGE Energy Corp. Chairman, President and CEO Sean Trauschke. “Our diverse energy portfolio of natural gas, wind, solar and coal gives us the versatility to meet a variety of economic and environmental needs. The result is our electric rates are 29 percent below the national average, which is a driver of economic development, and OGE is among industry leaders in emissions reduction performance.

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ENGIE Resources today announced the acquisition of Plymouth Rock Energy based in Woodmere, NY. The transaction, which has received approval from the Federal Energy Regulatory Commission and became effective December 19, 2018, will enable ENGIE Resources to expand its natural gas and electricity presence in seven states and by more than 20,000 customers.

The combined organization expects to benefit from complementary products, geographies, and systems in addition to shared information technology and billing and service economies.

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The interstate gas pipeline network is getting ready for the long Christmas break by posting a number of critical notices to shippers and customers.  Let’s take a look:

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, December 24, 2018, to all parties, with the exception of those Operational Balancing Agreements required by FERC regulations, on the AGT system.

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

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

This OFO will remain in effect until further notice.

Columbia Gulf Transmission:

Effective December 20, 2018 for the ID1 cycle, the Kinder Morgan La. interconnect, Meter 4206 is now designated as bidirectional and available for delivery nominations on Columbia Gulf Transmission, LLC (CGT).  This meter is located in Evangeline Parish, LA on CGT’s Mainline.  

Dominion Energy Questar Pipeline

Dominion Energy Questar Pipeline’s fuel reimbursement rate is changed for January 1,2019 from 1.87% to 1.57% pending FERC approval by the end of December. If there are any changes to the rate, the approved rate will be reposted.

East Tennessee Natural Gas:

Line 3100 Outage Update

Enbridge is working with PHMSA towards a timely in-service of East Tennessee Natural Gas’ (ETNG) 22-inch natural gas pipeline impacted by the incident that occurred in Pleasant Shade, Tennessee, on December 15, 2018.

Safety is a fundamental principle in everything we do and we are ensuring all construction and restoration operations are completed safely.  We continue to refine our return to service plan, and currently do not have an estimated time of restoration. 

Enbridge is committed to bringing the affected section of its East Tennessee Natural Gas system back to operation in a safe manner.  We will provide further updates as future milestones are achieved or as circumstances warrant.

El Paso Natural Gas: 

Pipeline Conditions – Weekend Linepack Concerns 

Currently EPNG linepack is within acceptable limits going into the holiday weekend. However, EPNG is concerned that the forecasted milder weather across our service area could result in a high linepack situation. 

Customers are encouraged to review their transport to ensure that their flowing quantities are aligned with their scheduled supplies.   

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

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

Washington Ranch is on maximum injection. 

Payback to the system, such as Make-Up Receipt (MR) transactions, may be limited or denied due to operational concerns related to the potential for a high linepack condition. 

Enable Gas Transmission:

REVISED PLND BYARS LAKE MAIN

New Information Posted December 19th, 2018

This Operational Alert is being issued pursuant to Section 20, GT&C, of EGT’s Tariff to notify shippers of planned maintenance at EGT s Byars Lake Compressor Station.

Effective February 6, 2019, at 9:00 a.m. and continuing through February 7, 2019 (previously January 9 through 10), EGT will conduct planned maintenance on its Byars Lake Compressor Station, located in McClain County, Oklahoma and in EGTs West 2 Pooling Area.  During this maintenance, capacity through EGT’s Allen Compressor Station will be limited to approximately 780,000 Dth/d; point operators will experience higher pressure.

Based on current nominations, EGT expects impacts to its services, including potential impacts to firm service.  During the planned maintenance, shippers whose receipts are in the West 1 and West 2 pooling areas West of the Allen Compressor Station should nominate point to point in order to maintain the highest priority level of service.

Gulf South Pipeline:

Olla (Louisiana) Compressor Station Maintenance – Update

Effective date:  December 20, 2018               End Date:  December 28, 2018

For the Marksville Deliveries Scheduling Group, capacity could be impacted by as much as 100,000 dth/d for the duration of the maintenance.

Northern Natural Gas:

In an effort to provide timely and useful information that may impact customers’ decisions regarding nominated volumes, and to assist shippers in scheduling their transportation and storage services, Northern is providing advance notice of the Carlton Sourcing Obligation, System Underrun Limitation (SUL), and System Overrun Limitation (SOL) for the holiday weekend.

Based on temperatures that are currently forecast for the Market Area throughout the holiday weekend, the following system conditions will be in effect to ensure adequate line pack and delivery pressures.

The Carlton Sourcing Obligation will be as follows:

Gas Day Saturday, December 22, 2018, will be 0%

Gas Day Sunday, December 23, 2018, will be 0%

Gas Day Monday, December 24, 2018, will be 0%

Gas Day Tuesday, December 25, 2018, will be 0%

Gas Day Wednesday, December 26, 2018, will be 0% 

SUL and SOL status for both the Market and Field Areas will be as follows:  No SUL or SOL 

Holiday Weekend Temperatures Projected to be Warmer-Than-Normal

The likelihood of storage injection allocations is at a higher probability for the extended holiday weekend due to the forecast of warmer than normal temperatures. These conditions could lead to the allocation of interruptible storage injections, including firm deferred delivery overrun injections.

Although Northern does not anticipate calling an SUL, Northern may be required to allocate overperforming receipt points and/or underperforming delivery points located in the Permian basin to actual flowing volumes during an intraday nomination cycle in order to maintain adequate supply/market balance. As performance improves at these receipt and delivery points, allocations would be lifted.

Northwest Pipeline:

Effective December 21-23, 2018, Jackson Prairie will be undergoing maintenance. Nominations that net to an injection or withdrawal of 50,000 Dth/d will be accepted. Northwest requests that customers stay on rate to avoid the issuance of an Entitlement.

Northwest will schedule up to 10,000 Dth at $0.10 for both Park and Loan at JP for December 21-23. 

Northwest is NOT allowing interruptible in or out of JP December 21-23.

Northwest is asking Shippers to voluntarily reduce nomination through the Rangely compressor station to avoid the issuance of an OFO over the holidays. Operational capacity is 370,000 Dth/d. If nominations exceed 370,000 Dth/d Northwest could issue an OFO.

Northwest encourages you to continue scheduling your supply so that sufficient gas is being delivered to Northwest to cover your market.

Northwest Pipeline reserves the right to cut secondary gas to protect the operational integrity of its pipeline. This includes cutting secondary gas at any compressor in a constrained corridor; moving balancing gas to and from Clay Basin and Jackson Prairie; or to minimize OFOs for primary irm shippers.

PG&E – California Gas Transmission:

Due to the completion of maintenance on Line 300 A/B, pipeline inventory limits will be restored to the following ranges starting on today’s gas day, December  20, 2018:

Total System Demand above 2,800 MMcf will change back to 4,350-4,000 MMcf from 4,200-3,850 MMcf

Total System Demand at 2,800 MMcf or below will change back to 4,300-3,900 MMcf from 4,150-3,750 MMcf.

Southern Star Central Pipeline:

Line Segment 130 Force Majeure (UPDATE #13):

Southern Star Central Gas Pipeline (Southern Star) posted a Force Majeure Update on Line Segment 130 Tuesday, June 19, 2018. Southern Star continues working to fully restore service for Line Segment 130.

Additional work has been completed, Effective TIM Cycle Gas Day December 20, 2018, and Southern Star will increase capacity at the Kansas Hugoton Receipt constraint to 383,000 Dth/d.

Texas Eastern Transmission:

TE Imbalance Notice – UPDATE

As previously posted, Texas Eastern (TE) has limited operational flexibility to manage imbalances. As result, effective immediately, TE requires all delivery point operators in Market Area Zones M1-24 and M2-24 to keep actual daily takes out of the system equal to or less than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative. All receipt point operators in Market Area Zones M1-24 and M2-24 are required to keep actual daily receipts into the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Additionally, TE requires all shippers and point operators in Access Area Zones STX, ETX, WLA and ELA and Market Area Zone M1-30, M2-30 and M3 to carefully review demand for gas and schedule gas consistent with daily needs and to tender and receive gas consistent with confirmed nominations regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Correspondingly, effective immediately, the previously posted imbalance notice is no longer in effect.

This notice will remain in effect until further notice.

Trailblazer Pipeline:

TRAILBLAZER MECHANICAL ISSUE–COMPRESSOR STATION 603

Trailblazer Pipeline Company LLC (“Trailblazer”) has recently 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 early April 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.

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).

Beginning:  Friday, December 21, 2018 and until further notice

OFO Areas:  Zones 4, 5, and 6

Tolerance %:  10% for gas Due from Shippers or Due to Shippers

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The National Weather Service has posted its January, 2019 temperature forecast.  The picture shows average to slightly colder than average temperatures across the central and eastern portions of the United States.  The Rockies and West Coast will again see warmer than average weather.

Have a very MERRY CHRISTMAS and enjoy the holiday season!   Please tell a friend in the natural gas transportation business about GasNewsOnline.com!   Subscribe to our FREE audio podcasts on iTunes.

Edition 23 – Thursday, December 13, 2018

Welcome back to GasNewsOnline.com!   We hope to give you a little holiday cheer with publicly available news and information about the natural gas business and a glimpse of warmer weather in the extended forecast for the week of Christmas.

First, let’s take a look at what is making news in the energy business:

The US Energy Information Administration published their weekly natural gas storage report today.  Below is a summary of the report:

EIA Natural Gas Storage Data
Total (12/07/18): 2,914 Bcf
Total (11/30/18): 2,991 Bcf
Net change: -77 Bcf
Year ago stocks: 3,636 Bcf
% change from year ago: -19.9
% 5-year avg stocks: 3,637 Bcf
% change from 5-year avg: -19.9 %

Cheniere Energy, Inc. announced Wednesday that the first commissioning cargo of liquefied natural gas (LNG) has loaded and departed from its Corpus Christi liquefaction facility in Texas, marking the first export of LNG from the state and from a greenfield liquefaction facility in the lower 48 states. The LNG was loaded on the LNG carrier Maria Energy, chartered by Cheniere Marketing, LLP.

“Exporting the first commissioning cargo of LNG from Texas demonstrates Cheniere’s ability to deliver projects safely and ahead of schedule, including the first greenfield LNG export facility in the lower 48 states,” said Jack Fusco, Cheniere’s President and CEO. “This milestone further reinforces Cheniere’s position as the leader in U.S. LNG, with a world-scale liquefaction platform that provides significant competitive advantages as we continue to execute on our growth strategy.” 

The Corpus Christi liquefaction facility consists of three large-scale LNG production units — or trains — and supporting infrastructure, with an additional seven smaller trains proposed.  The facility’s first train produced first LNG in November and is expected to reach substantial completion in the first quarter of 2019.  Train 2 is expected to reach substantial completion in the second half of 2019, and Train 3 in the second half of 2021. The facility will also feature three LNG storage tanks with capacity of approximately 10.1 billion cubic feet equivalent and two marine berths.

In other energy news:

Houston-based Parker Drilling Company announced Wednesday that it has entered into a restructuring support agreement (“RSA”) with holders of the Company’s securities.  To implement that agreement, Parker has voluntarily filed for Chapter 11 protection in the U.S. Bankruptcy Court for the Southern District of Texas.

The existing management team is expected to remain in place, and the Company expects to complete the restructuring process in the first quarter of 2019.

The Company anticipates that its cash flow and existing liquidity will be sufficient to support global operations during this period.   The proposed Plan, which is subject to Court approval, reduces approximately two-thirds of funded debt and injects $95 million of new equity capital.

“Our operational results have continued to improve this year, and we anticipate new opportunities for profitable growth across our drilling and rental tools businesses. The steps we are announcing today will ensure that we have the appropriate capital structure to take advantage of these opportunities to strategically grow our assets, our global footprint, and our suite of products and services,” said Gary Rich, Chairman, President and Chief Executive Officer.

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The interstate gas pipeline grid is shifting from an early winter mode of operation and providing the industry a brief chance to replenish storage levels as some warmer weather is upon us.  Let’s take a look at some of the critical postings:

ANR Pipeline:

SW Area Capacity Restriction

New: ANR will begin unplanned compressor maintenance at its Mooreland Compressor Station located in Woodward County, Oklahoma, in the Southwest Area (Zone 4).  During the period of December 13th, 2018 through January 13th, 2019, ANR Shippers can expect higher than normal pressures in the pipeline segment upstream of the Mooreland Compressor Station.

Dominion Energy Transmission:

Effective start of gas day, Friday, December 14, 2018, PL-1 restrictions will be lifted (supersedes Notice ID: 209910).

Additionally, Dominion is lifting capacity restrictions on its Northern, TL-400, and Oakford operating areas on Friday, December 14.

Dominion Energy Questar Pipeline:

In-line inspection results for JL47 indicate that remediation is necessary on a portion of the pipeline.  Dominion Energy Questar Pipeline (DEQP) has scheduled the repair for December 18, 2018.  To facilitate the work, Altamont MAP 145, Randlett Tap MAP 419, Pleasant Valley Tap MAP 413 and Brundage Mtn Tap MAP 144 will all need to be shut-in and nominations will not be accepted for cycles Timely through ID2 with volumes, returning to normal in cycle ID3.

East Tennessee Natural Gas:

ETNG Operational Flow Order – East of Boyds Creek — LIFTED

Effective today (Thursday, December 13), East Tennessee Natural Gas (ETNG) is lifting the Operational Flow Order for meters east of Boyds Creek issued on December 5, 2018.

ETNG has limited operational flexibility to manage imbalances. ETNG requires all delivery points located east of Boyds Creek to carefully review demand for gas and schedule gas consistent with daily needs and to tender and receive gas consistent with confirmed nominations regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Additionally, ETNG requires all delivery points on its 3200 line located between Tracy City to Topside and on the 3500 line 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 on the 3200 Line between Tracy City to Topside and on the 3500 line are required to keep actual receipts into the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position.

El Paso Natural Gas:

The Force Majeure event that was declared on December 7, 2018 (Reference Critical Notice 603991) at Dimmitt Compressor Station will be lifted effective for Gas Day December 13, 2018 Cycle 3 (Intraday 1). The net capacity at AMAR N returns to 283,100 dekatherms consistent with El Paso Natural Gas Company’s December Maintenance Report (Reference latest Maintenance Notice 603975).

Enable Gas Transmission:

This Operational Alert is being issued pursuant to Section 20, GT&C, of EGT Tariff to notify shippers of planned maintenance at EGT’s Byars Lake Compressor Station.

Effective January 9, 2019, at 9:00 a.m. and continuing through January 10, 2019, EGT will conduct planned maintenance on its Byars Lake Compressor Station, located in McClain County, Oklahoma and in EGT’s West 2 Pooling Area.  During this maintenance, capacity through EGT’s Allen Compressor Station will be limited to approximately 780,000 Dth/d.  Point operators will experience higherpressure.

Based on current nominations, EGT expects impacts to its services, including potential impacts to firm service. During the planned maintenance, shippers whose receipts are in the West1 and West 2 pooling areas West of the Allen Compressor Station should nominate point to point in order to maintain the highest priority level of service.

Florida Gas Transmission:

FGT is performing planned pipeline maintenance upstream of FGT Compressor Station 10. This maintenance began on December 3, 2018 and is to be completed by the end of gas day December 21, 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.

FGT is performing maintenance on pipe near the FGT/Tennessee Carnes Interconnect (POI 10258). This maintenance began on December 3, 2018 and is to be completed by the end of gas day December 21, 2018. During this maintenance zero volumes will be scheduled at the FGT/Tennessee Interconnect. During normal operations, FGT schedules up to 60,000 MMBtu/day through the FGT/Tennessee Carnes Interconnect.

Kinder Morgan Louisiana Pipeline (KMLP):

Compression associated with the Sabine Pass Expansion Project, (Docket No. CP 17-22-00), is expected to go into service on December 13, 2018.  KMLP will begin assessing fuel gas on the “North to South Transportation Path” as defined in Section 1.30 of KMLP’s General Terms and Conditions. 

Effective December 13, 2018, the Fuel Gas Total Reimbursement Percentage will increase from 0.00% to 0.72%.  This percentage was approved by FERC on November 27,2018 in KMLP’s filing in Docket No. RP19-197-000.  The Unaccounted For Gas Total Reimbursement Percentage remains at 0.00%.  Shippers are advised to schedule quantities with the revised percentages. 

Natural Gas Pipeline Company of America (NGPL):

Natural has experienced horsepower issues on the Amarillo mainline at Compressor Station 103 (CS 103),located in Ford County, Kansas (Segment 11 of Natural’s Midcontinent Zone).  This is a Force Majeure event that will require Natural to reduce temporarily the maximum operating capacity northbound through CS 103 during this restriction. 

The scheduling constraint will be at CS 103; therefore, any gas received south of CS 103 for delivery north of CS 103 will be impacted. The Midcontinent Pool (PIN 25078) is located south (upstream) of the constraint.  Additionally,transports associated with storage withdrawals will be impacted. 

As such, effective for gas day Thursday, December 13, 2018, Timely Cycle, and anticipated to continue until further notice, Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 82% of contract MDQ through CS 103.  Actual nomination levels and changes in pipeline conditions could result in changes to the percentages scheduled (lower or higher).  AOR/ITS and Secondary out-of-path Firm transports continue to not be available during this event.   

Tennessee Gas Pipeline:

Effective for the Gas Day of Friday, December 14, 2018, and until further notice, Tennessee Gas Pipeline, LLC (“Tennessee”) is lifting the Daily Critical Day 1 OFO for all areas east of STA 219 on the 200 Line (including the Niagara Spur) and on the 300 Line.  However, it is imperative that customers continue to match physical flows with scheduled volumes in this area in order to avoid the issuance of any additional actions in these zones. 

Texas Eastern Transmission:

Texas Eastern Transmission (TE) has experienced an outage impacting capacity through its Bernville compressor station in Pennsylvania. This outage results in a capacity of approximately 2,947,000 Dth/d through the Bernville compressor station beginning on Gas Day December 14, 2018.  TE anticipates the outage will last for approximately 2-3days.

In addition…

Effective today (Thursday,December 13), Texas Eastern (TE) is lifting the Market Area Zone M3 Operational Flow Order effective on December 4, 2018.

As previously posted, TE has limited operational flexibility to manage imbalances. TE requires all delivery point operators in Market Area Zones M1-24, M2-24 and M3 to keep actual daily takes out of the system equal to or less than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative. All receipt point operators in Market Area Zones M1-24, M2-24 and M3 are required to keep actual daily receipts into the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Additionally, TE requires all shippers and point operators in Access Area Zones STX, ETX, WLA and ELA and Market Area Zone M1-30 and M2-30 to carefully review demand for gas and schedule gas consistent with daily needs and to tender and receive gas consistent with confirmed nominations regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Furthermore, 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 Monday, December 17, 2018 to all delivery parties, with the exception of those governed by a FERC gas tariff, in Texas Eastern’s Market Area Zone 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 arithmetic average of 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.

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According to Santa’s friends at the National Weather Service, the eight-to-ten day temperature forecast is showing that most of the United States may see normal to above-average readings heading into Christmas!  Ho, Ho, Ho, indeed!

Enjoy a weekend of fewer operational flow orders on the pipelines for a change! 

Thanks for visiting GasNewsOnline.com!  Please tell a friend in the gas transportation and scheduling/trading business about us.  Our information is FREE!  


Edition 21 – Thursday, December 6, 2018

It’s been a busy week in the United States as we have honored the passing of our 41st President, George H. W. Bush.

Welcome back to GasNewsOnline.com!   The interstate pipeline grid is filled with cold weather advisories for this weekend as we provide a review of the latest postings from the electronic bulletin boards ending this week.

If you remember Merle Haggard’s hit song called, If We Make it Through December, the National Weather Service is now showing a chance for a break in the recent colder weather coming before Christmas.   Stay tuned!

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Columbia Gas Transmission:

Columbia Gas Transmission, LLC (TCO) reminds customers of upcoming maintenance at the Cobb Compressor Station in West Virginia scheduled for Tuesday, December 11, 2018 through Wednesday, December 19, 2018.

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)

As a reminder, nominations through the impacted internal constraints will not be scheduled until the work is complete.

 

Dominion Energy Transmission:

Niagara Mohawk East and Bethlehem Energy Deliveries Primary Only

Due to forecasted temperatures, effective with the start of gas day Friday, December 7, 2018, deliveries at Niagara Mohawk East Meter (20550) and Bethlehem Energy Center Meter (30200) will be limited to primary only until further notice.

Please note that “Unauthorized Overrun Charges – Daily” rate of $10.00/dth will apply to deliveries made in excess of FT and FTNN entitlements while these restrictions are in place.

 

Florida Gas Transmission:

FIRST UPDATE – DECEMBER 2018 — FGT SUPPLY AREA MAINTENANCE IN ZONES 2 AND 3

FGT is performing maintenance on the FGT East White Lake Lateral upstream of FGT Compressor Station 75. This maintenance began on December 3, 2018. The original planned completion date of December 7, 2018 has been extended to the end of gas day December 13, 2018. During this maintenance FGT will schedule up to 470,000 MMBtu/day from the FGT East White Lake group. During normal operations FGT schedules up to 590,000 MMBtu/day from the FGT East White Lake group.

FGT is performing planned pipeline maintenance upstream of FGT Compressor Station 10. This maintenance began on December 3, 2018 and is to be completed by the end of gas day December 21, 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.

FGT is performing maintenance on pipe near the FGT/Tennessee Carnes Interconnect (POI 10258). This maintenance began on December 3, 2018 and is to be completed by the end of gas day December 21, 2018. During this maintenance zero volumes will be scheduled at the FGT/Tennessee Interconnect. During normal operations FGTschedules up to 60,000 MMBtu/day through the FGT/Tennessee Carnes Interconnect.

 

Gulf South Pipeline:

Kiln Compressor Station Maintenance

Begin date:  12/6/18   End Date: 12/12/18

Capacity could be impacted by as much as 200,000 dth/d for the duration of the maintenance. Gulf South will be working with point operators to reduce impact.

 

Kern River Gas Transmission:

Kern River hereby announces a force majeure due to an unexpected mechanical issue that will require a turbine engine exchange on Unit 1 at the Salt Lake compressor station. The force majeure will be effective Timely cycle for gas day December 11, 2018, and is expected to continue through the end of gas day December 13, 2018.

Kern River will initially reduce the Veyo operating capacity by 50,000 Dth to 2,430,000 Dth, after which Kern River will evaluate system conditions and nomination flow patterns each cycle and will increase the Veyo operating capacity in subsequent cycles, if possible, to ensure throughput is maximized.  Kern River does not anticipate any impact to previously scheduled nominations or to new primary or secondary firm nominations.

 

Natural Gas Pipeline Company of America (NGPL)

FORCE MAJEURE – SEGMENT 8 – COMPRESSOR STATION 168 – UPDATE #3

Additional information on the end date, as noted below.  This notice was last posted on November 19, 2018, entitled “FORCE MAJEURE – SEGMENT 8 – COMPRESSOR STATION 168 – UPDATE #2”.

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 anticipated to continue through gas day Monday, December 17, 2018, (previously Monday, December 10, 2018), 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.

 

Panhandle Eastern Pipe Line Company

Based on current cold weather forecasts, Panhandle is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day December 6, 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.

Both 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-Unpark nominations on the pipeline for the duration of the extreme weather.   These limits will be evaluated on a daily basis.

 

Southern Star Central Gas Pipeline:

The Winter Weather Advisory that went into effect December 4, 2018 is being extended through December 9, 2018 based upon updated forecast.

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.

 

Tennessee Gas Pipeline

OFO DAILY CRITICAL DAY 1 FOR ALL AREAS EAST OF STA 219 EFFECTIVE 12-7-18

Due to forecasted colder temperatures moving into the Northeast, effective for Gas Day, Friday, December 7, 2018, Tennessee is implementing an OFO Daily Critical Day 1 for all areas east of STA 219 on the 200 Line (including the Niagara Spur) and all areas east of STA 219 on the 300 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 219 on the 200 Line (including the Niagara Spur) and east of STA 219 on the 300 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 219 on the 200 Line (including the Niagara Spur) and east of STA 219 on the 300 Line 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 Eastern Transmission:

Line 16 Unplanned Pipeline Outage — UPDATE 3

The previously posted unplanned outage on Line 16 between Santa Fe Compressor Station (Santa Fe) and CENEGAS Mexico (EOL) has been further delayed. Texas Eastern Transmission (TE) currently anticipates Line 16 will return to service between Sunday December 9 and start of Gas Day Tuesday December 11, 2018.

As a reminder due to this unplanned outage the following meters will continue to be unavailable for flow:

71142 – VERNON FAULKNER-SAN SALVADOR FIELD – HIDALGO CO., TX (REC)
72222 – DEWBRE PETROLEUM-VALDERAS #1 / HIDALGO COUNTY, TX (REC)
72377 – SENECA RESOURCES – #1 GARZA, HIDALGO CO., TX
72716 – ENTERPRISE TEXAS PIPELINE LLC HILDALGO COUNTY, TX (REC)
72744 – RIO GRANDE ROYALTY CO., INC. – RIO GRANDE #1/HIDALGO CO., T
73113 – ENTERPRISE TEXAS PIPELINE LLC – HIDALGO COUNTY, TX
73180 – BLUESTONE – HIDALGO CO., TX
73345 – DEFS/SANTA FE RANCH GATHERING – KLEBERG CO., TX (REC)
73362 – SUEMAUR E&P-PEDRAZA #1 – HIDALGO CO., TX (REC)
73385 – SUEMAUR E & P – GOLDSBERRY GATHERING / HIDALGO CO., TX (REC
73414 – HESCO – DENALI GATHERING / HIDALGO CO., TX (REC)
73425 – WILLIAMS PIPELINE/LACY CROSSOVER – HIDALGO CO., TX (REC)
75258 – MAGIC VALLEY PL-CALPINE-POWER PROJECT(D73258/R73259)
75333 – CENAGAS – REYNOSA, MX (D70333/R76333)

TE will post updates to the status of this unplanned outage as soon as it is known.

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In other energy news…

Williams today announced the sale of certain pipeline systems located in the Gulf Coast area to Easton Energy LLC for $177 million in cash.  The sale closed on Nov. 30, 2018.

The 31-mile Texas Belle Pipeline, which transports natural gas liquids from Mont Belvieu to customers along the Houston Ship Channel, is included in this transaction as are the Purity Pipeline System, certain assets in the Live Oak Pipeline System and additional idle pipelines located along the Gulf Coast.

“We continue to assess and execute on opportunities to optimize our portfolio,” said Williams Senior Vice President for Corporate Strategic Development, Chad Zamarin. “We’re pleased to be able to leverage these assets, which were not core to our business strategy, into a source for growth capital and a driver for improved credit metrics.”

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With much of the southern half of the nation expecting heavy rain or snow and ice this weekend, the updated National Weather Service temperature map for the week ending December 16 shows a much-needed warm-up for the eastern half of the United States.  The Rockies will see the brunt of the cold weather during the same period.

 

Thank you for visiting GasNewsOnline.com.  We bring you the latest natural gas news and information from publicly available sources twice every week – for FREE!  Please tell a friend in the natural gas business about us!

Edition 20 – Monday, December 3, 2018

Winter has made an impressive early entrance in 2018 with the forecast showing the cold weather has made plans to stick around for awhile.

Welcome back to GasNewsOnline.com!   We’re keeping an eye on the latest happenings in the natural gas business (with our hands on a warm beverage) so that you will be up-to-date – for FREE!

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There are several critical notices being posted by the interstate gas pipeline companies for this week due to the cold weather.  Let’s jump right in…

Dominion Energy Transmission:

Subject:  PL-1 Restrictions South of Leesburg Effective December 4, 2018

Due to the forecasted weather and requirements on the PL-1 system, effective start of gas day Tuesday, December 4, 2018 and continuing until further notice, DETI will not accept any IT or Non PL-1 firm transportation south of Leesburg Compressor Station in northern Virginia. This will include the following meters:

Location Name Location

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

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 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 to deliveries made in excess of FT and FTNN entitlements while these restrictions are in place.

 

East Tennessee Natural Gas:

Force Majeure Declaration — LIFTED

As posted on November 28, 2018, East Tennessee Natural Gas (ETNG) experienced an unplanned outage at its Boyds Creek Compressor Station (Boyds Creek) in Boyds Creek, Tennessee. Effective immediately, Boyds Creek has returned to normal operation on December 1st.  As a result of the Boyds Creek return to service, all restrictions related with this Force Majeure have been lifted.

 

Florida Gas Transmission:

FGT will be performing maintenance on pipe near the FGT/Tennessee Carnes Interconnect (POI 10258). This maintenance is scheduled to begin on December 3, 2018 and is to be completed by the end of gas day December 21, 2018. During this maintenance zero volumes will be scheduled at the FGT/Tennessee Interconnect. During normal operations FGT schedules up to 60,000 MMBtu/day through the FGT/Tennessee Carnes Interconnect.

 

Gulf South Pipeline Company: 

Subject:  Vixen Compressor Station Maintenance

Effective Date:  December 4, 2018 through December 7, 2018

Expansion Receipts Upstream Vixen Scheduling Group:

Capacity could be impacted by up to 200,000 Dth/d for the duration of the maintenance. Possible scheduling to all services other than Primary Firm may occur.  Please contact your customer service representative if you have any questions.

 

 

Kern River Gas Transmission: 

Subject:  Kern River – Cold Weather and High Demand Forecasted through December 5

Cold weather and high demand are forecasted in Kern River’s market areas through this week. Therefore, Kern River requires all shippers and receipt and delivery point operators align their daily scheduled nominations with physical receipts and deliveries to ensure Kern River’s line pack is maintained at current operating levels.

 

 

Mississippi River Transmission (MRT):

MAIN LINE UTILIZATION SPW

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, December 4, 2018 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 in the Field Zone 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.

This SPW will be updated as more information becomes available.

 

Natural Gas Pipeline Company of America (NGPL):

FORCE MAJEURE – COMPRESSOR STATION 801

Natural experienced horsepower issues at Compressor Station 801 on its OE #1 Line in Grady County, Oklahoma (CS 801), in Segment 15 of Natural’s Texok A/G Zone, resulting in a need to make emergent repairs.  This is a Force Majeure event that will require Natural to temporarily reduce the maximum operating capacity eastbound through CS 801 during this event.

The scheduling constraint will be at CS 801; therefore, any gas received west of CS 801 for delivery east of CS 801 will be impacted. The Midcontinent Pool (PIN 25078) is located west (upstream) of the constraint.  Additionally, transports associated with storage injections or withdrawals will be impacted.

As such, effective for gas day Sunday, December 02, 2018, Intraday 2 Cycle, and continuing until further notice, Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 83% of contract MDQ through CS 801.  Actual nomination levels and changes in pipeline conditions could result in changes to the percentages scheduled (lower or higher).  AOR/ITS and Secondary out-of-path Firm transports continue to not be available during this event.

Continue to monitor Natural’s interactive website for any updates during this outage.

 

Northwest Pipeline:

Subject:  Entitlement changes and system info

Due to Westcoast’s notice to reduce the T-South flow and the weather forecasted to be below normal, the Stage III (13%) overrun Entitlement north/west of Roosevelt will remain in effect until further notice.

In addition, the following changes will be implemented on Northwest Pipeline to maintain integrity on its system:

-Stage III (13%) overrun Entitlement in the Kemmerer to Roosevelt corridor including the Spokane and Wenatchee laterals.

-Jackson Prairie Loan will be increased to 100,000 Dth

-Jackson Prairie Loan rate will be increased to the maximum Tariff rate

These changes are effective at the beginning of gas day December 4, 2018.

The Entitlement level will be evaluated on a daily basis based on system line pack, storage levels, weather forecasts and upstream pipeline notices.

If you have any questions, please contact your Marketing Services Representative or the Scheduling Hotline at 801-584-7301.

 

Rover Pipeline:

Pipeline Inspections – Majorsville and Sherwood Laterals

Rover will be performing pipeline inspections (pigging) on its Majorsville and Sherwood Laterals beginning Gas Day December 10, 2018, requiring limitations to scheduled quantities as specified below:

December 10 – 70004/Majorsville  – Operational capacity limited to 170 mmcf/d

December 11 – 70004/Majorsville  – Operational capacity limited to 250 mmcf/d

December 13 – 70001/Sherwood  – Operational capacity limited to 430 mmcf/d

December 18 – 70001/Sherwood  – Operational capacity limited to 500 mmcf/d

 

Southern Natural Gas:

Subject:  OFO Type 3 Level 1 South System 12-4-18
Based on the latest weather forecast predicting cooler temperatures moving into the area and the corresponding increase in projected demand on Southern’s system, we are notifying all Shippers that the groups listed below will be subject to an OFO Type 3 Level 1 effective the start of the gas day, Tuesday, December 4, 2018 until further notice.

OFO Type 3 Level 1: Daily Demand Exceeds Capacity
TARIFF SECTION 41.2
EFFECTIVE DATE: December 4, 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 the segments listed below 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.

 

Southern Star Central Gas Pipeline:

Subject: Update — Winter Weather Advisory — Effective December 04, 2018

The Winter Weather Advisory going into effect December 4, 2018 is being extended through December 7, 2018 based upon the updated forecast.

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.

Southern Star will review the status of its system throughout this period and will provide any changes or updates to this posting as necessary.

 

TallGrass Interstate Gas Transmission:

TIGT  STORAGE  ADVISORY

Based on current storage inventory levels, anticipated deliverability from storage, and current operating conditions, TIGT is hereby notifying shippers that, effective for the Timely Cycle, Gas Day Tuesday, December 4th, 2018, and until further notice, interruptible withdrawal activity at Huntsman locations 994000 and 994500 will not be scheduled.  If you have any questions, please contact your Account Director or Scheduling Representative.

 

Texas Eastern Transmission:

TE M3 Operational Flow Order – Notice Text

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 Tuesday, December 4, 2018 to all delivery parties, with the exception of those governed by a FERC gas tariff, in Texas Eastern’s Market Area Zone 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 arithmetic average of 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.

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In other energy news on this Monday, December 3rd:

Kinder Morgan announces 2019 financial projections and growth plans

On Monday, Kinder Morgan, Inc. announced its preliminary 2019 financial projections.

“This year has been a very good one for Kinder Morgan and we expect to nicely exceed our budget. In 2019, with our market fundamentals remaining very strong, the Elba Liquefaction Project coming online and Gulf Coast Express entering service, we project continued growth,” said Steve Kean, KMI chief executive officer. “We expect to generate $5.0 billion of distributable cash flow (DCF) which is approximately a 10 percent increase over our 2018 budgeted DCF. Our growth will continue to be supported by an approximately $6.5 billion backlog of high probability energy infrastructure expansion opportunities,” continued Kean.

KMI expects to increase the declared dividend per common share for 2019 to $1.00 per share (annualized), beginning with $0.25 per share for the Q1 2019 dividend (which is paid in Q2 2019).   KMI also continues to expect to increase the dividend to $1.25 per share (annualized) for 2020.

The company plans to invest $3.1 billion in expansion projects and contributions to joint ventures in 2019.  It expects to use internally generated cash flow to fully fund its 2019 dividend payment as well as the vast majority of its 2019 discretionary spending, with no need to access equity markets.

The company also wants to end 2019 with a Net Debt-to-Adjusted EBITDA ratio of 4.5 times. According to Steve Kean, “We continue to be well positioned for an upgrade to our credit ratings and are on positive outlook at all three rating agencies”.

KMI’s expectations assume average annual prices for West Texas Intermediate (WTI) crude oil and Henry Hub natural gas of $60.00 per barrel and $3.15 per MMBtu, respectively, consistent with forward pricing during the budget process. For more information, please visit www.kindermorgan.com.

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SemGroup and DCP Midstream Announce Open Season for Light Crude Transportation Solution from Cushing to Gulf Coast Markets

SemGroup® Corporation and DCP Midstream, LP have announced the commencement of an open season process to solicit binding commitments for the development of a new pipeline system to transport segregated, light batches of crude oil originating in Cushing, Okla. and terminating in Houston, Texas. All potential shippers must submit binding commitments by 5 p.m. Central Time on January 31, 2019.

The proposed Gladiator Pipeline would originate at SemGroup’s Cushing terminal and provide crude oil service to Gulf Coast markets. The Cushing origin would provide potential shippers the connectivity to source barrels from key pipelines that converge in Cushing, including the White Cliffs Pipeline, which serves Colorado’s DJ Basin.

At the pipeline’s destination, potential shippers would have many options for connecting barrels to a variety of demand centers, including refineries in the Houston area or to crude oil storage and export facilities, such as SemGroup’s HFOTCO Terminal. If sufficient commitments are obtained, subject to the receipt of all of the necessary approvals, permits and force majeure, the proposed Gladiator Pipeline may be operational by the third quarter of 2020, following the potential construction of new NGL capacity by DCP.

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Finally, the colder weather has decided to stick around another week or more, according to the National Weather Service.  The six-to-ten day temperature forecast through the second week of December shows below average temperatures for the eastern half of the country.  A warming trend begins from the Great Plains to the desert Southwest during the period.

 

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