Thursday, May 9, 2019

Welcome to GasNewsOnline.com!  We check the country’s interstate natural gas pipeline companies for their most recent critical postings and bring you information about significant changes in pipeline operating conditions prior to this Mother’s Day weekend.

Today, we will also update you on the latest publicly released news about one of Anadarko Petroleum‘s suitors. Plus, we’ll give you the extended temperature forecast through May 19 from the National Weather Service, too.  

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From the US Energy Information Administration, working natural gas in storage was 1.547 Tcf as of Friday, May 3, 2019.  This represents a net increase of 85 Bcf from the previous week.

Natural gas in storage is now 16% below the five-year historical average.

On the New York Mercantile Exchange, the natural gas futures price for June, 2019 was down more than three cents on Thursday to finish at about $2.57/MMBtu. 

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Chevron Corporation announced today that, under the terms of its previously announced Merger Agreement with Anadarko Petroleum Corporation, it will not make a counterproposal and will allow the four-day match period to expire.  Accordingly, Chevron anticipates that Anadarko will terminate the Merger Agreement.

Chevron’s Chairman and CEO Michael Wirth said, “Winning in any environment doesn’t mean winning at any cost. Cost and capital discipline always matter, and we will not dilute our returns or erode value for our shareholders for the sake of doing a deal. Our advantaged portfolio is driving robust production and cash flow growth, higher investment returns and lower execution risk. We are well positioned to deliver superior value creation for our shareholders.”

Upon termination of the Merger Agreement, Anadarko will be required to pay Chevron a termination fee of $1 billion.

Earlier this week, Anadarko’s Board of Directors deemed a revised offer from Occidental Petroleum Corporation as a “Superior Proposal” and plans to move ahead with the OXY offer.

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On Wednesday, Marathon Petroleum Corporation and midstream affiliates MPLX LP and Andeavor Logistics LP announced that the two midstream companies have entered into a definitive merger agreement whereby MPLX will acquire Andeavor in a unit-for-unit transaction at a blended exchange ratio of 1.07x. This represents an equity value of approximately $9 billion and an enterprise value of $14 billion for the acquired entity. The transaction has been unanimously approved by MPLX’s and ANDX’s respective Conflicts Committees and both Boards of Directors. Subject to the satisfaction of customary closing conditions and receipt of regulatory approvals, the transaction is expected to close in the second half of 2019.

Under the terms of the merger agreement, ANDX public unitholders will receive 1.135x MPLX common units for each ANDX common unit held, representing a premium of 7.3%, and MPC will receive 1.0328x MPLX common units for each ANDX common unit held, representing a 2.4% discount. The blended exchange ratio of 1.07x represents a 1% premium to market1.

“This transaction simplifies our MLPs into a single listed entity and creates a leading, large-scale, diversified midstream company anchored by fee-based cash flows,” said Gary R. Heminger, chairman and chief executive officer. “This transaction is projected to be immediately accretive to MPLX unitholders on distributable cash flow, demonstrating MPC’s commitment to positioning its midstream business for long-term success”.

Mike Hennigan will remain President of the combined entity and lead all midstream activities.

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Now, let’s take a look at the latest critical notices from the electronic bulletin boards of the country’s interstate natural gas pipeline grid:

ANR Pipeline:

Effectively Wednesday, May 8, ANR will reduce the capacity for the Jena Southbound location (LOC #95105489), due to unplanned compressor maintenance at Jena compressor station located in the Southeast Southern Area (Zone 2).

The Jena Southbound location (LOC #9505489) capacity restriction is as follows:

75-MMcf/d (leaving 1,105-MMcf/d available) 5/8 – 5/22

Based on current nominations, it is anticipated that this posting may result in the capacity allocation reduction of IT, Firm Secondary and possibly a portion of Firm Primary volumes. Since ANR anticipates that this restriction may impact its ability to deliver all nominated Firm Primary services, ANR will apply the Reservation Charge Crediting Mechanism of Section 6.36.4 as necessary.

Colorado Interstate Gas (CIG):

In response to continuing and prolific natural gas production growth in the Denver-Julesburg Basin – and the mounting market need for timely transportation capacity – Colorado Interstate Gas Company, L.L.C. (CIG) is conducting a binding Open Season for additional firm capacity to be made available by approximately November 1, 2019.  The additional transportation capacity offered in this Open Season will have primary receipt rights from a new receipt point immediately upstream of the High Five Meter Station (PIN#TBD), and have primary delivery rights into CIG’s 5C at the High Five delivery point interconnection (PIN#53893) which is currently under construction, and CIG will construct additional capacity at this meter to accommodate a minimum of 125,000 Dth/day of additional capacity.  CIG is conducting this Open Season on the terms described below. 

This binding Open Season will commence on May 8, 2019 and is scheduled to close at 10:00 a.m. Mountain Time on May 22, 2019.  CIG intends to provide notification of capacity awards by 5:00 p.m. Mountain Time on May 2, 2019. 

Questions concerning this Open Season should be directed to: Greg Ruben (719-520-4870) or Laine Lobban (719-520-4344).

Columbia Gulf Transmission:

Columbia Gulf Transmission, LLC reminds customers of upcoming meter station work at MS 478 (Transco Evangeline) on Tuesday, May 14, 2019.  During this work, MS 478 will be set to a total capacity of 270,000 Dth per day.  Based on current scheduled volume, there is no expected impact to firm service.

On Wednesday, May 15, Columbia Gulf reminds customers of meter station work at MS 4118 (Florida Gas).  During this work, MS 4118 will be set to a total capacity of 294,000 Dth per day.  Based on current scheduled volume, there is no expected impact to firm service.

East Tennessee Natural Gas:

East Tennessee Natural Gas (ETNG) has limited operational flexibility to manage imbalances downstream of Boyds Creek Compressor Station (Boyds Creek). As a result, effective Wednesday, May 8, ETNG requires all delivery point operators east of Boyds Creek 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 east of Boyds Creek are required to keep actual 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.

If necessary, ETNG will utilize any provision of its tariff to ensure system integrity including the issuance of customer specific or system wide OFOs.  This notice will remain in effect until further notice.

Gulf South Pipeline:

Longview Compressor Station Maintenance:  Begins: May 13, 2019            Ends:  July 2, 2019

Longview Station #2 Scheduling Group – Capacity could be impacted by up to 50,000 dth/d for the duration of the maintenance.

Natural Gas Pipeline Company of America (NGPL):

Natural has experienced mechanical issues at Compressor Station 104 (CS 104) located in Barton County, Kansas (Segment 11 of Natural’s Midcontinent Zone).  This is a Force Majeure event that will limit Natural’s throughput capacity northbound out of the Midcontinent Zone through Compressor Station 104.   

The scheduling constraint will be at CS 104; therefore, any gas received south of CS 104 for delivery north of CS 104 will be impacted for the duration of this restriction.  For scheduling purposes, the Midcontinent Pool (LOC 25078) is located south of the constraint.  Additionally, firm transportation nominated from receipt points south of CS 104 (including the Midcontinent Pool) for injection at any Amarillo storage point will be impacted.  Receipt points north of CS 104 will not be impacted.     

As such, effective for gas day, Wednesday, May 8, 2019, Timely Cycle and anticipated to continue through gas day Monday, May 13, 2019,Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 77% of contract MDQ through CS 104.  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. 

The stated scheduling percentage is based upon the current level of firm capacity contracted for during this restriction and is subject to change based upon operational conditions and Shipper utilization.  Permian Zone delivery points will be available as an alternative.  The Trailblazer Gage (LOC 902900), Rex Jefferson (LOC 42499), and Northern Border Harper (LOC 908090) receipt points, as well as other supply points downstream of this constraint will also be available.

Southeast Supply Header (SESH):

Effective immediately, SESH is lifting the previously posted imbalance warning issued on April 6, 2019.

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 at its Danville Compressor Station (Danville) in Danville, Kentucky. While efforts to repair the station to full capacity are underway, the estimated time of restoration is unclear at this time.

As a result of this outage north to south capacity through stations on the 30 inch line will be reduced to approximately:

Owingsville 1,644,000 Dth/d
Danville 1,638,000 Dth/d
Tompkinsville 1,440,000 Dth/d

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

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The latest six-to-ten day temperature forecast from the National Weather Service for the period May 15-19 reveals that warmer than average temperatures will be seen along both the Southeast and Pacific Northwest regions.  From the Southwest through the Great Lakes and into New England, cooler than seasonal temperatures will prevail during much of the third week of May.

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

Please tell a friend in the natural gas scheduling and transportation business about us!    Make sure to listen to our companion audio podcasts via Apple Podcasts. It’s FREE, too!


Friday, March 22, 2019

Welcome to GasNewsOnline.com!  While we search over fifty interstate natural gas pipeline companies for their critical postings, other news is happening this week.  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.  

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From the US Energy Information Administration, working natural gas in storage decreased by 47 Bcf for the week ending Friday, March 15.  Natural gas stocks remaining in storage are now nearly 33% below the five-year historical range.

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Penn Virginia Corporation announced Thursday that it has mutually agreed with Denbury Resources Inc. to terminate their previously announced merger agreement.

“After careful consideration, the Penn Virginia board of directors decided that it is in the best interests of the Company and our shareholders to mutually agree to terminate our merger agreement with Denbury,” said John A. Brooks, President and Chief Executive Officer of Penn Virginia. “Given the caliber and dedication of our team, the high quality of our assets and the strength of our balance sheet, we believe we are well positioned to continue to execute our previously announced two rig development plan, which is expected to be fully funded from cash flow.  We remain focused on developing our assets and maximizing value for our shareholders as a standalone company.”

As a result, the special meeting of Penn Virginia’s shareholders, which was to be held on April 17, 2019, will not take place.  Under the terms of the merger agreement and the termination agreement, neither Penn Virginia nor Denbury will be responsible for any payments to the other party as a result of the termination of the merger agreement.

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Earlier this week, Williams announced a series of transactions that will establish a new platform for the optimization of its midstream operations in the western Marcellus and Utica basins through a long-term partnership with the Canada Pension Plan Investment Board.   

The $3.8 billion joint venture will include Williams’ 100 percent owned Ohio Valley Midstream system (“OVM”) and 100 percent of Utica East Ohio Midstream system (“UEO”).  The Canada Pension Plan Investment Board will invest $1.34 billion for a 35 percent ownership stake in the joint venture. Williams will retain 65 percent ownership, will operate the combined business, and will consolidate the financial results of the joint venture in Williams’ financial statements.

Concurrent with signing the agreement, Williams acquired the remaining 38 percent ownership stake in Utica East Ohio Midstream from Momentum Midstream and will take over operatorship.  UEO is involved primarily in the processing and fractionation of natural gas and natural gas liquids in the Utica Shale play in eastern Ohio.

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As winter transitions into spring, let’s review the latest postings from the interstate natural gas pipeline systems entering the weekend:

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 immediately, 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 as indicated below:

Effective Immediately – Gas Day March 24: The penalty shall apply to each dekatherm of actual delivery quantities exceeds the greater of 6,000 Dth or 106% of scheduled delivery quantities.

Gas Day March 25 and until further notice: The penalty shall apply to each dekatherm of actual delivery quantities exceeds the greater of 4,000 Dth or 104% of scheduled delivery quantities.

In each situation indicated above, 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.

ANR Pipeline:

ANR will begin planned pipeline maintenance near the St. John Compressor Station along its Michigan Leg South located in the Northern Area (Zone 7). The total St. John Eastbound, LOC #226633, capacity will be reduced by the following:

500-MMcf/d (leaving 767-MMcf/d available) 4/29 – 5/3

Based on current nominations, it is anticipated that this posting will result in the capacity allocation reduction of IT, Firm Secondary and possibly a portion of Firm Primary volumes. Since ANR anticipates that this restriction may impact its ability to deliver all nominated Firm Primary services, ANR will apply the Reservation Charge Crediting Mechanism of Section 6.36.4 as necessary. This posting will be updated as more information becomes available.

Columbia Gas Transmission:

In response to customer questions regarding its Leach XPress (LXP) and Mountaineer XPress (MXP) projects, Columbia Gas Transmission, LLC (TCO) has developed a schematic highlighting active project points and internal constraints for customers to reference.

https://navigates.cpg.com/infopost/webmethods/DownloadFile.aspx?Mode=V&S3FN=LXP_MXP+Project+Schematic.pdf&S3K=%2Ftco%2Fpermanentpostingsandfaqs%2FLXP_MXP+Project+Schematic.pdf

Although this schematic may serve as a useful tool for customers, TCO strongly recommends the continued utilization of the Internal Constraint Rights screen within Navigates when evaluating a specific contract’s rights for an input nomination.   

Columbia Gulf Transmission:

Columbia Gulf Transmission (CGT) would like to notify customers of an upcoming change in location numbers effective April 1, 2019, impacting the Gulf South – Delhi interconnect.

Currently, Gulf South Delhi nominations are entered at a single bi-directional location for receipts and deliveries. Currently shown as: GULF SOUTH DELHI – 4204

Starting April 1, 2019, all nominations for this location will move to two newly created location numbers:

Receipts from Gulf South Delhi:  Loc Prop 4204R
Deliveries to Gulf South Delhi:     Loc Prop 4204D

Loc Prop 4204 will become inactive on April 1, 2019. All receipts and deliveries for Gulf South Delhi should be nominated at the new 4204R and 4204D locations for Timely Cycle Gas Day April 1,2019. Any nominations at Loc Prop 4204 will be reduced to 0.

Dominion Energy Transmission:

As of Monday, April 1, 2019, Dominion Energy Transmission, Inc. will return to one (1) Operational Impact Area (OIA).

Also from Dominion:

Based on storage withdrawals during the 2018-2019 Winter Period, storage inventory levels are at near historic lows. As a result of the current inventory levels, DETI can handle only limited withdrawals from its storage pools until inventory levels increase.

To protect its storage pools and to minimize withdrawals, DETI will not require its GSS customers to meet their Minimum Turnover Obligations pursuant to Section 8.7 of Rate Schedule GSS for the period November 1, 2018 through April 15, 2019. As a result, no charges set forth in GT&C Section 35.3D will be assessed if the minimum turn obligation is not met during this period. Further, DETI requests that GSS customers voluntarily minimize withdrawals with the start of the injection season on April 1.

This voluntary action may allow the avoidance of the issuance of storage OFOs if inventory levels decline further. Customers are advised that DETI may be required to issue OFOs that limit storage withdrawals in April and possibly, require the use of all firm transportation capacity prior to the use of storage withdrawals.

Gulf South Pipeline:

Carthage Junction Compressor Station Maintenance:  Begins April 9, 2019 – Ends April 10, 2019

Area 8 to 16 Expansion Scheduling Group – Capacity could be impacted by as much as 150,000 dth/d for the duration of the maintenance for all services other than primary firm.

MidContinent Express Pipeline (MEP):

MEP will be performing a cleaning pig run on the entire portion of its pipeline system in Zone 2, segments 200 and 210, from Madison Parish, Louisiana to Choctaw County, Alabama.  This work will require MEP to restrict throughput capacity in Zone 2 of its system. 

As such, effective for gas day Wednesday, April 10, 2019, and continuing through gas day Thursday, April 11, 2019, MEP will schedule Primary Firm and Secondary-in-path Firm transports to no less than 71% of contract MDQ into Segment 200, assuming all such contracts are nominated at full applicable contract MDQ through the constrained segment.  Actual nomination levels, changes in pipeline conditions, and assistance MEP is seeking from connecting pipelines downstream of the outage could result in an increase to the percentage scheduled.

AOR/ITS and Secondary out-of-path Firm transports will not be available during this outage. Additionally, all park and loanservices under Rate Schedule PALS will not be available anywhere on the system.

Natural Gas Pipeline Company of America (NGPL):

As part of its required ongoing pipeline integrity Management Program, on gas day Tuesday, March 26, 2019, and continuing through gas day Thursday, April 11, 2019, Natural will perform an ILI tool run on the Gulf Coast #2 mainline between Compressor Station 300 located in Victoria County, Texas and Compressor Station 341 located in Nueces County, Texas (Segments 22 and 20 of Natural’s South Texas Zone).  This tool run will require Natural to schedule Primary Firm and Secondary in-path Firm transports, only, southbound into Segment 22 for the duration of this tool run.  AOR/ITS and Secondary out-of-path Firm transports will not be available.

On gas day Tuesday, March 26, 2019, and continuing through gas day Monday, April 1, 2019, Natural will be performing station maintenance at Compressor Station 303, located in Angelina County, Texas (Segment 26 of Natural’s Texok Zone). This work will require Natural to schedule Primary Firm and Secondary in-path Firm transports, only, southbound through Compressor Station 302 located in Montgomery County, Texas for the duration of this maintenance project.  AOR/ITS and Secondary out-of-path Firm transports will not be available during this work.  Additionally, Primary Firm and Secondary in-path Firm transports may also be at risk of not being fully scheduled.

Northwest Pipeline:

Effective immediately and until further notice, Northwest is increasing the available deliverability into the Jackson Prairie storage facility from 442,000 Dths to 550,000 Dths.

Northwest is able to support the increase above design capacity due to prevailing pressures and facility conditions, which it expects will continue into the summer.

Tennessee Gas Pipeline:

Pursuant to Article XII of the General Terms and Conditions of Tennessee’s FERC Gas Tariff, Tennessee posted a notice of an emergent repair issue on the 300-1 Line between STA 219 and MLV 301 located in Mercer County, PA effective for the Gas Day of Friday, March 15, 2019 (Notice Identifier 370784), due to an anomaly identified from results received from Tennessee’s ongoing integrity program.  Work continues on this section of the pipe. 

Anticipated return to service is projected to be April 7, 2019.  Tennessee continues to estimate the current impact to be up to 65,000 Dths. Based upon current and recent nominations, restrictions through a pro rata portion of Secondary Out of the Path nominations pathed through STA 307(Segment 307 BH) continue to be at risk. 

Texas Eastern Transmission:

Below is a link to Texas Eastern Transmission’s planned outage information for 2019: https://infopost.spectraenergy.com/GotoLINK/GetLINKdocument.asp?Pipe=10076&Environment=Production&DocumentType=Notice&FileName=TETLP+2019+Planned+Outage+Presentation.pdf&DocumentId=8aa1649f695385180169597ca33600ca

Texas Gas Transmission:

North Louisiana System Maintenance:

Start Date: March 25, 2019 – End Date: April 7, 2019

Texas Gas will be performing direct assessments on the North Louisiana Lateral. Capacity will be limited to 325,000 MMBtu for the Carthage East-West (CEW) segment.

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The National Weather Service temperature forecast for the last week of March shows a warming trend through the midsection of the United States.  Cooler-than-seasonal conditions will return to the Great Plains, the West Coast and much of the Southeast through March 31. 

That’s all for this edition of GasNewsOnline.com! Enjoy a weekend of watching the college basketball games, and we hope to see you again on Monday!

Thursday, March 14, 2019

Happy “Pi” Day!

After returning from a brief vacation touring portions of Oklahoma and Texas, it’s time to get back to work here at GasNewsOnline.com! Due to time constraints, there will be no audio podcast of today’s edition.

With a final cold blast and heavy winds buffeting parts of the country this week, the weekend looks to be quite busy on the interstate natural gas pipeline grid. Let’s check out the latest critical postings:

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 March 14, 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 as indicated below:

Gas Day March 14 – 15: The penalty shall apply to each dekatherm of actual delivery quantities exceeds the greater of 6,000 Dth or 106% of scheduled delivery quantities.

Gas Day March 16 and until further notice: The penalty shall apply to each dekatherm of actual delivery quantities exceeds the greater of 4,000 Dth or 104% of scheduled delivery quantities.

In each situation indicated above, 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.

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 March 13, 2019, and continuing until further notice.  Therefore, when necessary to minimize imbalances and protect system integrity, underperformance caps may be placed on nonperforming receipt points effective the next available nomination cycle until further notice.

In addition, CIG is limiting requests for NNT authorized withdrawal overruns to 100,000 Dth. 

Columbia Gas Transmission and Columbia Gulf Transmission:

Columbia Gas Transmission, LLC will be commencing service for the remaining contracted 330 MDth/d of its Mountaineer XPress (MXP) project capacity effective Gas Day Friday, March 15, 2019.   Nominations will be accepted beginning for the Timely Cycle for Gas Day Friday, March 15, 2019.  Please monitor the Daily Capacity Posting effective for Friday, March 15, 2019 for capacity changes related to MXP. 

Columbia Gulf Transmission, LLC will be commencing service for the remaining contracted 330 MDth/d of its Gulf XPress (GXP) project capacity effective Gas Day Friday, March 15, 2019.   Nominations will be accepted beginning for the Timely Cycle for Gas Day Friday, March 15, 2019. 

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, March 16, 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.

Natural Gas Pipeline Company of America (NGPL):

As part of its required ongoing pipeline integrity Management Program, on gas day Tuesday, March 26, 2019, and continuing through gas day Thursday, April 11, 2019, Natural will perform an ILI Smart Tool run on the Gulf Coast #2 mainline between Compressor Station 300 located in Victoria County, Texas and Compressor Station 341 located in Nueces County, Texas (Segments 22 and 20 of Natural’s South Texas Zone).  This tool run will require Natural to schedule Secondary in-path and Primary only southbound into Segment 22 (South Texas Zone) for the duration of this tool run.  AOR/ITS and Secondary out-of-path Firm transports will not be available. 

Also from NGPL:

On gas day Tuesday, March 26, 2019, and continuing through gas day Monday, April 1, 2019, Natural will be performing station maintenance at Compressor Station 303, located in Angelina County, Texas (Segment 26 of Natural’s Texok Zone).  This work will require Natural to schedule Secondary in-path and Primary only southbound through Compressor Station 302 located in Montgomery County, Texas, (Segment 26 of Natural’s Texok Zone) for the duration of this maintenance project.  AOR/ITS and Secondary out-of-path Firm transports will not be available during this work.  Primary Firm and Secondary in-path Firm transports may also be at risk of not being fully scheduled.

Northwest Pipeline:

Northwest will hold the annual maintenance conference call on Wednesday, March 20, 2019, from 3:00 PM to 4:00 PM MDT. The call-in number is 385-355-3006 and the conference id is 34150489.

The 2019 maintenance schedule has been posted on Northwest’s portal at http://www.northwest.williams.com. The information on the schedule represents Northwest’s best estimates given the information currently available.

Please note that the estimated capacity reductions and project durations are dependent on many variables and are subject to change. Northwest will update the schedule as the projects progress and new information becomes

available. 

Tennessee Gas Pipeline:

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 on the 300-1 Line between STA 219 and MLV 301 located in Mercer County, PA effective for the Gas Day of Friday, March 15, 2019.  Due to results from Tennessee’s ongoing integrity program, Tennessee has identified an anomaly that necessitates pressure reduction on this section of the pipe.  Tennessee is estimating the current impact to be up to 65,000 Dths. Based upon current and recent nominations, restrictions through a pro rata portion of Secondary Out of the Path nominations pathed through STA 307(Segment 307 BH) may be required. 

Texas Eastern Transmission:

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, 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 Zones 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.

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

Texas Gas Transmission:

Texas Gas will be performing direct assessments on the North Louisiana Lateral beginning March 25 through April 7, 2019.  Capacity will be limited to 325,000 MMBtu for the Carthage East-West (CEW) segment.

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

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:  Friday, March 15, 2019 until further notice

OFO Areas:  Zones 4, 5, and 6

Delivery Tolerance %:  10% Due to Shipper and 10% Due From Shipper

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After a blustery week in many portions of the United States, the National Weather Service six-to-ten day temperature forecast through March 24 shows a warming trend for the upper Midwest and the Northeast. Portions of the South, though, may still be a little cooler than normal for late March.

Thanks for checking in to GasNewsOnline.com! Please come back late Monday for a complete update and podcast to start your work week.

It’s the right price. FREE!

Edition 43 – Thursday, February 28, 2019

Welcome to this Thursday edition of GasNewsOnline.com.  We’ll bring you a few publicly-released news stories from the energy business, take a look at the latest interstate natural gas pipeline companies’ critical notices, and check next week’s temperature forecast from the National Weather Service.  It is all for FREE from GasNewsOnline.com.

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From the US Energy Information Administration, working gas in storage for the week ending Friday, February 22 decreased by 166 Bcf from the previous week.  The storage draw was slightly lower than the 171 Bcf estimate made by industry analysts. 

Natural gas volumes in storage are now 424 Bcf (or 21.6%) below the five-year average for the same week. 

In related news, the NYMEX natural gas futures price for April, 2019 was up a penny at about $2.81/MMBtu on Thursday. 

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On Tuesday, Dominion Energy provided the following statement:

“The U.S. Court of Appeals for the Fourth Circuit denied the Atlantic Coast Pipeline’s (ACP) request for an en banc rehearing related to the Court’s invalidation of the project’s U.S. Forest Service Appalachian Trail crossing authorization.  ACP’s en banc petition was supported by the Department of Justice on behalf of the U.S. Forest Service, as well as several prominent industry, labor, and business groups.

“Dominion Energy expects an appeal to be filed to the Supreme Court of the United States in the next 90 days.  The company is also pursuing legislative and administrative options as previously discussed on Dominion Energy’s Feb. 1, 2019 earnings call.  We are confident that the U.S. Departments of Interior and Agriculture have the authority to resolve the Appalachian Trail crossing issue administratively in a manner that satisfies the Court’s stated objection and in a time frame consistent with a restart of at least partial construction during the third quarter.  We will continue to work to resolve the outstanding biological opinion issue as well as any impediments to the project’s crossing of the Appalachian Trail, and believe, as a result, that at least partial construction will recommence in the third quarter of 2019.

“The project cost and timing guidance provided on the company’s Feb. 1 earnings call fully contemplated the possibility of an unsuccessful en banc request.  Therefore, yesterday’s Fourth Circuit decision does not alter our operating EPS guidance as provided to the investment community on that call.  Dominion Energy remains confident in the full completion of the Atlantic Coast Pipeline along the entire 600-mile route.”

The 600-mile underground Atlantic Coast Pipeline will originate in West Virginia, travel through Virginia with a lateral extending to Chesapeake, VA, and then continue south into eastern North Carolina, ending in Robeson County. Two additional, shorter laterals will connect to two Dominion Energy electric generating facilities in Brunswick and Greensville Counties.

Dominion Energy is a 48% owner of the Atlantic Coast Pipeline.

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Western Gas Equity Partners, LP (“WGP”) and Western Gas Partners, LP (“WES”) today announced the completion of their previously announced merger of a wholly owned subsidiary of WGP with and into WES, with WES continuing as the surviving entity and a subsidiary of WGP (the “Merger”). At the effective time of the Merger, each WES common unit (other than certain WES common units held by affiliates of WGP) converted into the right to receive 1.525 WGP common units. Based on the WES units outstanding, WGP issued approximately 234 million WGP common units to WES unitholders in connection with the Merger.

Immediately following the Merger, WGP changed its name to “Western Midstream Partners, LP“, and its common units will begin trading on the New York Stock Exchange (“NYSE”) under the ticker symbol “WES” when the market opens today. In addition, Western Gas Partners, LP has changed its name to “Western Midstream Operating, LP”, and its common units will no longer trade on the NYSE.

“With the closing of these transformational transactions, Western Midstream has a simple, clean capital structure and offers its customers a uniquely scalable and integrated, multi-commodity solution,” said Robin Fielder, Western Midstream’s Chief Executive Officer. “As a result of our organic growth opportunities and the accretive acquisition of midstream assets completed today, our portfolio is projected to deliver more than 50% Adjusted EBITDA growth year-over-year and generate healthy distribution per unit growth and coverage through 2021 without the need for equity financing.”

Effective upon the closing of the Merger, Messrs. Steven Arnold, Milton Carroll and James Crane, each of whom previously served as an independent director on the Board of Directors of Western Gas Partners, LP’s general partner, joined the Board of Directors of Western Midstream Partners, LP’s general partner.

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CenterPoint Energy Services (CES) has been ranked as the number one major Natural Gas Marketer in Mastio & Company’s recent Natural Gas Marketer Customer Value/Loyalty Benchmarking Study.

“We are honored to receive this recognition,” said Joe Vortherms, CenterPoint Energy’s Competitive Energy Businesses lead. “Our number one ranking is a testament to our employees and their commitment to providing safe and dependable services to our customers.”

CES is a leading provider of a wide range of competitive energy services to meet the unique needs of customers across the United States. CES delivers reliable natural gas and energy services to natural gas utilities, large industrials and municipalities, as well as to other large-volume market segments.

In its 22nd edition report, Mastio analyzed customers’ responses to determine their perceptions about the best supplier based on the company’s prices and the benefits it offers. CES ranked highest in several categories, including reliability of natural gas supply, speed of contract negotiations and the sales team’s knowledge.

The 2018 findings were based on interviews with more than 500 natural gas customers. The analysis also included approximately 2,400 responses to five open-ended questions regarding suppliers. The data was gathered through telephone interviews with key decision makers from August through November 2018.

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On Wednesday, the Board of Directors of Summit Midstream GP, LLC (the “Board”) has named Executive Vice President and Chief Operations Officer, Leonard Mallett, as President and Chief Executive Officer on an interim basis, effective immediately.

By mutual agreement with the Board, Steve Newby has stepped down as a director, President, and Chief Executive Officer of Summit Midstream Partners, LLC (“Summit Investments”) and Summit Midstream GP, LLC (collectively with Summit Investments, “Summit”). Mr. Mallett will maintain his COO responsibilities during this interim period. The Board has engaged an executive recruiting firm to assist it in conducting the search for a permanent CEO.

SMLP is undertaking a series of strategic actions (together referred to as the “Transaction”) to place SMLP in a stronger financial position with increased flexibility to fund accretive growth projects and settle the Deferred Purchase Price Obligation (“DPPO”) by 2020.  Among other things, the Transaction is expected to result in SMLP retaining approximately $85 million of incremental cash flow annually, which will improve its overall credit profile, reduce its cost of capital, and create a more competitive MLP, while significantly reducing its reliance on the public equity capital markets.

The Transaction consists of the following actions:

  • Sale of Tioga Midstream, a non-core gathering system in North Dakota, to affiliates of Hess Infrastructure Partners LP for $90.0 million, subject to customary closing adjustments;
  • Prepayment of $100.0 million of the DPPO and an agreement to fix the remaining obligation due in 2020 at $303.5 million;
  • Elimination of SMLP’s economic General Partner interest and incentive distribution rights (“IDRs”) in exchange for 8.75 million SMLP common units issued to a wholly owned subsidiary of Summit Investments; and
  • Establishment of a new distribution policy through the reduction of SMLP’s distribution per common unit to $0.2875 per quarter, beginning with the distribution to be paid in respect of the first quarter of 2019.

Mr. Mallett, interim President and Chief Executive Officer commented, “The Transaction announced today will drive improved operational and financial results with greater emphasis on our core focus areas, including the Utica, Williston, DJ and Permian. We are streamlining our business with a non-core asset sale, a strategy that we intend to dedicate even more focus and attention to evaluating in the near-term.  We are also positioning our balance sheet to fund attractive growth projects in 2019 as well as the DPPO by 2020, and further aligning the General Partner and the Limited Partners with the elimination of the IDRs.  We believe these actions bring notable benefits to SMLP’s credit profile, distribution coverage and cost of capital, which we believe will enhance long-term unitholder value.”

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March is roaring in like a lion as many interstate pipeline companies have posted critical notices related to cold weather for the next few days:

ANR Pipeline:

Attention All ANR Shippers and Storage Customers

Storage – Effective immediately for gas day Thursday 2/27/2019 and until further notice, per Part 6.18.12 of the ANRPL Tariff, General Terms and Conditions, Infield Storage Transfer Requests will be restricted if the request results in an increase to ANRPL’s service obligations, such as, but not limited to, requests from either Rate Schedule DDS or MBS to Rate Schedule FSS. All Infield Storage Transfer Requests will be considered on an individual basis.

Also, effective gas day Saturday 3/2/2019, Timely cycle and continuing thru gas day Wednesday 3/6/2019, in order to preserve system integrity and to ensure ANR is able to meet scheduled delivery commitments to all locations in ML7; 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,. 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.

Colorado Interstate Gas (CIG):

With significantly colder temperatures and moisture being forecast beginning Saturday, March 2, 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. In addition the following actions will be taken:

NNT overrun withdrawal requests will be allocated to 100,000 dth; Payback OFF the system will not be accepted; Payback ONTO the system will be approved; Absent other capacity concerns, interruptible services may be at risk. 

Columbia Gas Transmission:

Columbia Gas Transmission, LLC will be commencing service for an additional 750 MDth/d of its Mountaineer XPress (MXP) project capacity effective Gas Day Friday, March 1, 2019.   Nominations will be accepted beginning for the Timely Cycle for Gas Day Friday, March 1, 2019.  Please monitor the Daily Capacity Posting effective for Friday, March 1, 2019 for capacity changes related to MXP. 

Columbia Gulf Transmission:

Columbia Gulf Transmission, LLC began service for 530 MDth/d of its Gulf XPress (GXP) project capacity effective Wednesday, February 27, 2019.   Nominations are now being accepted.   

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 28, 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.

Gulf South Pipeline:

Tallulah (LA) Compressor Station Maintenance:  Start date:  February 27, 2019   End Date:  March 9, 2019

Expansion Receipts Upstream Tallulah Scheduling Group.

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

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 28, 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 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 Friday, March 1, 2019, due to lower than normal forecasted system weighted temperatures.

Northwest Pipeline:

Due to the declining deliverability at Jackson Prairie described in Notice # 19-042, and the anticipated reduction of available gas supply at Sumas beginning Wednesday, February 27 as a result of Enbridge work, Shipper compliance with Realignment and Must-Flow OFOs will be critical to avoid issuance of a Supply Shortage OFO.

If there is insufficient gas supply physically available to comply with Must-Flow OFOs, Northwest will issue a Supply Shortage OFO. Non-compliance with a Must-Flow OFO will result in penalties, unless Northwest accepts an affidavit, executed by an officer of Shipper, declaring that gas was physically unavailable for OFO compliance. Northwest will not accept such an affidavit if is aware of the physical availability of supply.

Panhandle Eastern Pipe Line:

Weather Alert – Based on current cold weather forecasts, Panhandle is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day Saturday, March 2, 2019, until further notice, Panhandle is requesting all delivery point operators to minimize over-takes and all receipt point operators to minimize their under-deliveries into the system. 

Intraday scheduling reductions may be implemented to ensure that nominations match actual flowing quantities. Shippers are encouraged to submit their nominations for the Timely cycle. Evening and Intraday nominations are subject to scheduling reductions based on nomination levels and physical capacity. 

The following nominations are subject to scheduling reductions based on nomination levels and physical capacity:  Interruptible and Secondary Outside-the-Path.

Similarly, all storage customers are requested to stay at or below their Maximum Daily Withdrawal Quantity (MDWQ). Storage customers should adjust flowing volumes to remain at or below these limits. 

To ensure system integrity, Power Plant Operators must have nominated supply.  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.

Rover Pipeline:

Weather Alert – Based on current cold weather forecasts, Rover is preparing for reduced operational flexibility. Effective Gas Day March 2, 2019, until further notice, Rover 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 will be implemented to ensure that nominations match actual flowing quantities.

Rover 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:

Due to severe weather conditions forecasted, Southern Star is issuing a Winter Weather Warning effective Friday, March 01, 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 Wednesday, March 06, 2019.

Trunkline Gas Company:

Weather Alert – Based on current cold weather forecasts, Trunkline is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day Saturday, March 2, 2019, until further notice, Panhandle is requesting all delivery point operators to minimize over-takes and all receipt point operators to minimize their under-deliveries into the system. 

Intraday scheduling reductions may be implemented to ensure that nominations match actual flowing quantities. Shippers are encouraged to submit their nominations for the Timely cycle. Evening and Intraday nominations are subject to scheduling reductions based on nomination levels and physical capacity. 

The following nominations are subject to scheduling reductions based on nomination levels and physical capacity:  Interruptible and Secondary Outside-the-Path.

Similarly, all storage customers are requested to stay at or below their Maximum Daily Withdrawal Quantity (MDWQ). Storage customers should adjust flowing volumes to remain at or below these limits. 

To ensure system integrity, Power Plant Operators must have nominated supply.  Trunkline may limit Auto-Unpark nominations on the pipeline for the duration of the extreme weather. These limits will be evaluated on a daily basis.

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From the National Weather Service, the six-to-ten day temperature forecast calls for more cold weather for all areas of the lower 48 states except for the desert Southwest and south Texas through March 10.  Brr!!!

That concludes this busy Thursday edition of GasNewsOnline.com.  We’ll return on Monday to give you an update on pipeline conditions to start the new work week. 

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 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 19 – Thursday, November 29, 2018

Welcome back to GasNewsOnline.com!  We search for publicly released data from a variety of sources to keep you informed about the natural gas pipeline business twice every week.  FREE!

The US Energy Information Administration has provided some good news for most of the gas business in their latest release today.   Alas, Santa may be leaving a lump of coal for producers in the Permian basin of West Texas until additional gas pipeline transportation capacity arrives on the scene next year.

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From the Energy Information Administration’s “Natural Gas Weekly” dated November 29, 2018:

Net withdrawals from working gas totaled 59 billion cubic feet (Bcf) for the week ending November 23. The storage pull was less than the analyst estimate of 77 Bcf.

Working natural gas stocks are 3,054 Bcf.  That is 17% lower than the year-ago level and 19% lower than the five-year (2013–17) average for this week.

The Henry Hub, Louisiana average spot price for natural gas has seen four straight weeks of increases. During the past four report weeks, spot prices increased from $3.29/MMBtu to $4.68/MMBtu as most of country experienced generally cooler weather.

Unfortunately, discounting at the Permian Basin trading hub reached a new record low.   Prices at the Waha Hub in West Texas, which is part of the Permian Basin, averaged 46¢/MMBtu on Wednesday!  That is nearly $4/MMBtu lower than Henry Hub prices.  Yesterday’s discount is the highest price difference between the Henry Hub and Permian for the year as excessive gas supplies are trying to access extremely tight gas transportation takeaway capacity.

At the NYMEX, the December 2018 contract rose during the past report week, expiring Wednesday at $4.72/MMBtu. The January 2019 contract price settled down 6 cents on Thursday at about $4.59/MMBtu.

The EIA reported that, for the week ending Wednesday, the natural gas plant liquids composite price at Mont Belvieu, Texas, fell by 63¢/MMBtu.  The liquids price still equates to $6.54/MMBtu, though.

According to Baker Hughes, for the week ending Wednesday, November 21, the natural gas rig count remained flat at 194. The number of oil-directed rigs fell by 3 to 885. The total rig count decreased by 3, and now stands at 1,079.

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With cold weather in control of much of the country the past week, it is time to take a look at some of the latest critical information postings from the electronic bulletin boards of the interstate gas pipeline grid:

ANR Pipeline:

Southwest Mainline Capacity Reduction (Updated 11/29/18)
This posting supersedes CN ID #8972

ANR continues its planned and unplanned compressor maintenance at various compressor stations along its Southwest Mainline in Zones 5 and 6.

The total SWML Northbound (DRN#226630) capacity will be reduced by the following:

55-MMcf/d (leaving 675-MMcf/d available) 11/29 – 11/30
20-MMcf/d (leaving 710-MMcf/d available) 12/1 – 12/6
55-MMcf/d (leaving 675-MMcf/d available) 12/7 – 12/14
20-MMcf/d (leaving 710-MMcf/d available) 12/15 – 12/31

Since the last posting, ANR has made the following changes. December impacts are now posted as a result of compressor maintenance impact extensions. Future dates adjusted accordingly.

Based on current nominations, it is anticipated that this posting may result in the capacity allocation reduction of IT, Firm Secondary and possibly a portion of Firm Primary volumes.

 

Columbia Gulf Transmission:

In the event of FERC approval of the TRA rate change filing effective December 1, 2018, Columbia Gulf Transmission, LLC (CGT) has reflected the revised retainage fuel rates in Navigates to give customers time to align nominations between their supplies and markets.  As a reminder the proposed rates are as follows:

Mainline –  North to South     1.947%

Mainline –  South to North     0.0%

CGT will keep customers informed when approval is received.

 

Dominion Energy Transmission:

Subject: Storage/MCS/Transportation Imbalances Effective Immediately

Due to current and anticipated system conditions, customers are reminded to monitor contractual storage entitlements and take the necessary steps to manage deliveries within those firm entitlements.  Transportation customers are also advised to equalize receipts and deliveries so as to minimize imbalances on DETI’s system.

Capability for over-withdrawals, short-term loans, and park payback activity are expected to be very limited or possibly not available. They may be subject to allocation or potential penalties if warranted by an OFO, in accordance with the terms of DETI’s tariff.

  

East Tennessee Natural Gas:

East Tennessee Natural Gas, LLC (ETNG) hereby declares a Force Majeure in accordance with Section 24 of the General Terms and Conditions of its FERC Gas Tariff. The Force Majeure event is due to an unplanned outage at its Boyds Creek Compressor Station on the 3300 Line in Tennessee which occurred on November 28, 2018.

While repair efforts will commence as soon as possible, the estimated time of restoration is unclear at this time.   ETNG will post updates to the status of repairs as they are known.

 

Gulf Crossing Pipeline Company:

Subject:  Tallulah (LA) Compressor Station Maintenance

Effective:  December 1, 2018 – December 8, 2018 (9AM)

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

 

Natural Gas Pipeline Company of America (NGPL):

SEGMENT 20 – SOUTH TEXAS (CS 341) – HOT TAP INSTALLATION

On gas day Friday, November 30, 2018, and continuing through gas day Monday, December 3, 2018, Natural will be performing a hot tap installation on the Gulf Coast #1 mainline just south of Compressor Station 341 located in Nueces County, Texas (Segment 20 of Natural’s South Texas Zone).  Natural does not anticipate that this work will impact shippers.

 

Panhandle Eastern Pipe Line Company:

11/29/2018 – Weather Alert – Update #1

Effective immediately, Panhandle has lifted the weather restrictions set forth in Critical Notice ID 8059.

 

PG&E – California Gas Transmission:

Limits on Pipeline Inventory Flexibility

Thursday, November 29, 2018

Due to the start of scheduled maintenance on the Line 300 A/B system, we have reduced flexibility on our pipeline inventory. Beginning gas day November 30, 2018 through February 4, 2019, we will be reducing our upper and lower limits on our pipeline inventory:

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

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

With the reduced flexibility on our pipeline inventory, the likelihood of OFOs may increase.

What can shippers do to help avoid OFOs noncompliance charges?

Balance supply and demand daily. Work to ensure that supplies brought in for your customers balance with their daily demands.   Keep an eye on the System Inventory Status information posted on Pipe Ranger.

 

Southern Natural Gas:

The Type 3 Level 1 OFO that was implemented effective November 26, 2018 and expanded November 27, 2018 for the North and South systems will be cancelled effective start of the gas day, Thursday, November 29, 2018 until further notice.

 

Southern Star Central Gas Pipeline:

Subject: Winter Weather Advisory — Effective December 04, 2018

Cold weather is being forecasted across much of the Southern Star system beginning Tuesday, December 4, 2018, through Wednesday December 5, 2018. Southern Star is issuing a weather advisory effective gas day Tuesday, December 4, 2018, and requests that operators and shippers monitor weather conditions and ensure their business plans consider the temperatures forecasted.

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.

 

Transcontinental Gas Pipe Line Company (Transco):

Subject: Terminate Operational Flow Order – Scheduling

The Operational Flow Order – Scheduling (OFO) currently in effect on the Transco system in Zones 4, 5 & 6 will be terminated effective 9:00 AM CST, Friday, November 30, 2018.

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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It’s time to check out the extended temperature forecast from the National Weather Service.   The newly updated 8 -14 day map shows the Eastern third of the US back into the freezer for the second week of December.   West of the Rockies, though, temperatures will rise to above normal again.

 

That’s a wrap for November, 2018!  Thanks for your support of GasNewsOnline.com.  Please tell a friend in the natural gas scheduling and transportation business about us, and subscribe to our companion audio podcasts on I-tunes.  All for FREE!

Edition 8 – Monday, October 15, 2018

Welcome to GasNewsOnline.com for Monday, October 15, 2018.  We work hard to bring you the latest publicly-sourced news and information concerning the natural gas business – for FREE!

Can you believe that we are at the halfway mark in October already?  Temperatures down south have plunged from 90 degrees over the weekend down into the 50’s to start the new week.  Did we just skip fall this year?

The gas pipelines are busy getting ready for the approaching traditional winter season from November through March.  Let’s take a look at some of the latest critical postings from the electronic bulletin boards from several interstate gas pipeline companies:

Vector Pipeline:

Vector Pipeline Critical Notice – Capacity Constraint at Rover

This notice is for Shippers using Rover to make deliveries into the Vector System. Rover is currently delivering gas to Vector Pipeline that contains free liquids and does not meet the Gas Quality Specifications required by the Vector FERC Gas Tariff. At this time, Rover has not provided a time period for resolution to the issue. Pursuant to Vector’s FERC Gas Tariff GT&C, Vector will reduce the scheduled quantities at the Rover receipt point beginning with the October 16, 2018 gas day and until further notice.

Vector’s receipt capacity at the Rover point will be determined based on Vector’s ability to  operationally manage non-conforming gas received from Rover.  As such, capacity at the Rover receipt point may be revised daily as circumstances change.

To minimize scheduled quantity reductions, Shippers are encouraged to seek supply from alternative receipt points on the Vector system. Further information will be communicated as it becomes available.

NEXUS Gas Transmission:

NEXUS Ready for Service – Notice Text:

NEXUS Gas Transmission, LLC (NEXUS US) accepted nominations for its first day of gas flow, Saturday October 13, 2018.

Initially, TEAL facilities beginning at receipt meter N4995 (NEXUS Interconnect with Texas Eastern Transmission Mainline, Monroe Co, Ohio) and ending at delivery meter N4IL1 (Supply Zone to Market Zone In-Line Transfer point), which also includes meter N4993 (NEXUS Interconnect with TET, Open Lateral), will be in service along with Greenfield facilities interconnecting with DTE at Ypsilanti, Michigan (NEXUS meter N1001). However, meters within DTE and Vector facilities can be nominated for gas day 11/01/2018 forward. NEXUS will provide another notification when additional meters are available on the TEAL facility.

Algonquin Gas Transmission:

AGT Imbalance Notice and FERC Order 698 — Update – Notice Text:

As previously posted, Algonquin Gas Transmission (AGT) has limited operational flexibility to manage imbalances. Effective 9:00 AM CCT, October 16, 2018, AGT requires all delivery point operators 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 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.

Columbia Gulf Transmission:

CGT would like to notify its customers of an upcoming tariff filing to be filed on or before November 1, 2018.

CGT will be filing with the Federal Energy Regulatory Commission to adjust its Transportation Retainage Adjustment (TRA), requesting an effective date of December 1, 2018.  Additionally, CGT is proposing modifications to its tariff to re-institute separate directional south-to-north and north-to-south mainline retainage rates.

A copy of the draft filing is attached below for your convenience and can be found under the Presentation section of CGT’s EBB. This filing reflects CGT’s estimated retainage rates.  To the extent any additional real-time adjustments occur, the filing made with FERC on November 1st will reflect those adjustments.

Enable Gas Transmission:

CHILES DOME – END OF SEASON MAINTENANCE – Notice Text:

This Operational Alert (OA) is being issued pursuant to Section 20, GT&C of EGT s Tariff to notify shippers of planned end-of-season maintenance at its Chiles Dome Storage Facility (located in southeastern Oklahoma).

Beginning November 16, 2018, EGT will begin end-of-season storage maintenance at its Chiles Dome Storage Facility.  EGT expects to complete the maintenance on November 30, 2018.

Shippers system-wide shall maintain actual receipts and deliveries commensurate with scheduled volumes.  EGT will have limited operational flexibility to manage pipeline imbalances and anticipates it will be unable to support unscheduled long positions.  EGT may reduce scheduled receipts intraday to balance with the corresponding deliveries as necessary to maintain system deliverability and operational integrity.  EGT requires all delivery point operators to keep actual daily takes out of the system equal to or greater than scheduled quantities, regardless of their cumulative imbalance position, unless scheduled with EGT.

Natural Gas Pipeline Company of America (NGPL):

Natural will hold a WebEx Winter Scheduling review on Tuesday, October 23, 2018, from 2:30 to 4:00 PM Central Time, to discuss anticipated scheduling impacts to shippers for the upcoming winter.  Natural would appreciate your participation.  Here are the dial-in directions.

Paste the following link in your browser:

https://webmeet.kindermorgan.com/orion/joinmeeting.do?MTID=f319b23c8b1216a3cbf2e95ae45f52dc

Meeting Number: 993 679 244

Meeting Password: NGPLCustMeet

Audio Connection: 713-420-6338

Access Code: 993 679 244

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The aftermath of Hurricane Michael left millions of people in the southeastern United States without power.  Here are some of the latest postings from a few of the largest power companies:

Dominion Energy reported that more than 6,000 workers have made substantial progress in restoring service in the aftermath of Tropical Storm Michael. About 80 percent of the 600,000 customers who lost power have been restored but about 120,000 customers remained without service in hard-hit areas of central and southern Virginia including the Hampton Roads area.

Duke Energy reported that about 4,000 repair workers continued to restore power to the company’s customers on the Florida Panhandle following Hurricane Michael. The company has repaired more than 62,000 outages, but about 14,000 customers remained without power as of Monday morning.

And Southern Company, which operates in several southeastern states, said that Hurricane Michael caused outages to 614,000 customers.

As of Noon EDT on Monday, Oct. 15, Georgia Power has restored power to 97 percent, or more than 375,000 customers, impacted by Hurricane Michael.

More than 140,000 Gulf Power customers were impacted by Hurricane Michael. Already, 95 percent of all customers who can receive power in Panama City Beach west of Highway 79 have been restored. Gulf Power anticipates 95 percent of their customers who can accept electric service will be restored by next Wednesday,  October 24 – just 14 days after Hurricane Michael made landfall.

Alabama Power crews completed restoration work to 83,000 customers in Alabama on Sunday morning.

Nationwide, electric companies mobilized an army of more than 35,000 workers from at least 27 states and Canada to restore power safely and as quickly as possible.

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The U.S. Energy Information Administration’s “Today in Energy” publication is forecasting natural gas storage inventories will reach 3.26 trillion cubic feet at the end of October, the lowest end-of-October level for U.S. natural gas inventories since 2005.

Lingering cold temperatures in April 2018, the coldest April in the past 21 years, delayed the start of the natural gas storage refill season by about four weeks.

On the supply side, the EIA said that U.S. natural gas production has averaged a record 82.7 Bcf/d in 2018, an 11% increase from 2017. With production outpacing domestic consumption, the United States has transitioned to being a net exporter of natural gas.

For the year, the EIA expects U.S. gross exports of natural gas to average 10.1 Bcf/d in 2018, a 16% increase from the previous year, with most of the growth coming from exports of liquefied natural gas.

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As of late Monday October 15, the National Hurricane Center indicates that there are no tropical systems expected to threaten the US Gulf Coast or eastern seaboard over the next several days.

If you like cold weather over the next week, head to the upper Midwest and along the east coast of the United States.  Here is the latest National Weather Service six-to-ten day temperature forecast through October 25, 2018:

And that’s a wrap for Monday,  October 15, 2018!  Thanks for reading GasNewsOnline.com!  Please tell your friends!