Monday, May 6, 2019

Welcome to GasNewsOnline.com! The battle for control of Anadarko Petroleum has taken another step as one of the suitors has sweetened the pot on Sunday! 

Meanwhile, a variety of springtime temperatures (some cool and others quite warm) have continued to depress the natural gas prices again as we start the week.    

We’ll check the latest interstate pipeline company critical notices plus an update on latest energy news and temperature forecasts into the middle of May, too.

********************

At the NYMEX, the June 2019 contract closed at about $2.53/MMBtu, down 4¢ from Friday. The price of the 12-month strip averaging June 2019 through May 2020 futures contracts has dropped 6¢ over the past week to about $2.67/MMBtu on Monday.

From the US Energy Information Administration’s “Natural Gas Weekly Update” publication, net injections to working gas in storage totaled 123 billion cubic feet (Bcf) for the week ending April 26. Volumes in storage are currently 1.462 Tcf, which is 18% lower than the five-year (2014–18) average for this week.

The natural gas plant liquids composite price at Mont Belvieu, Texas, fell by 1¢, averaging $6.11/MMBtu for the week ending May 1. The price of isobutane, natural gasoline, and butane fell by 1%, 2%, and 3% respectively. The price of propane rose by 2%. The price of ethane remained flat week over week.

According to Baker Hughes, for the week ending Tuesday, April 23, the natural gas rig count decreased by 1 to 186. The number of oil-directed rigs fell by 20 to 805. The total rig count decreased by 21, and it now stands at 991.

********************

On Sunday, Occidental Petroleum Corporation delivered a letter to the Board of Directors of Anadarko Petroleum Corporation setting forth the terms of a revised and significantly enhanced superior proposal to acquire Anadarko for $76.00 per share comprised of $59.00 in cash and 0.2934 shares of Occidental common stock per share of Anadarko common stock.

The revised proposal, which has been unanimously approved by the Occidental Board of Directors, represents a premium of approximately 23.3% to the $61.62 per share value of Chevron’s pending offer as of market close on May 3, 2019.

On April 29, 2019, Anadarko announced its Board of Directors had determined that Occidental’s prior proposal, made on April 24, could reasonably be expected to result in a “Superior Proposal”, and the two companies have engaged since that determination.

Occidental’s President and CEO, Vicki Hollub, said, “We firmly believe that Occidental is uniquely positioned to drive significant value and growth from Anadarko’s highly complementary asset portfolio. This combination will create a global energy leader with the scale and geographic diversification to drive compelling returns to the shareholders of both companies,” she added.

********************

Williams reported Friday that the Federal Energy Regulatory Commission (FERC) has issued a certificate of public convenience and necessity authorizing the Northeast Supply Enhancement project – an expansion of the existing Transco natural gas pipeline designed to serve New York markets in time for the 2020/2021 winter heating season.

The Northeast Supply Enhancement project will provide 400,000 dekatherms per day of additional natural gas supply to National Grid – the largest distributor of natural gas in the northeastern United States. National Grid is converting about 8,000 customers per year from heating oil to natural gas in New York City and Long Island. The Northeast Supply Enhancement Project is critical to make these conversions possible, as well as keep up with new development in the area.

“Natural gas is a critical component of the mix of energy sources necessary to meet the region’s growing energy needs and to help meet its aggressive clean air goals,” said Williams Chief Operating Officer Micheal Dunn. “We appreciate the Commission’s thorough review of this important infrastructure enhancement project, which will help ultimately advance New York City toward meeting the statewide carbon emissions goals outlined in the New York State Energy Plan.”

Following the receipt of all necessary regulatory approvals, Williams anticipates beginning construction on the Northeast Supply Enhancement project facilities in the fall of 2019.

Transco is a major provider of cost-effective natural gas services that reach U.S. markets in 12 Southeast and Atlantic Seaboard states, including major metropolitan areas in New York, New Jersey and Pennsylvania.

Additional information about the Northeast Supply Enhancement project can be found at www.northeastsupplyenhancement.com.

********************

Late last week, U.S. Secretary of Energy Rick Perry signed the Department of Energy’s authorization allowing Sempra Energy‘s Port Arthur LNG to export approximately 13.5 million tonnes per annum of U.S.-produced liquefied natural gas (LNG) to countries that do not have a free-trade agreement (FTA) with the U.S. during the first U.S.-EU Energy Council High-Level Energy Forum in Brussels, Belgium.

“I am pleased to announce the order signed authorizing Port Arthur LNG to export up to 1.91 billion cubic feet per day of LNG, to any country that does not have an FTA with the United States,” said Perry. “The United States is in its third consecutive year as a net exporter of natural gas, now exporting domestic LNG to 35 countries. I applaud the American private sector for continuing to reach new milestones and look forward to continued growth in this sector.”

The Port Arthur LNG export project in development in Jefferson County, Texas is expected to include two liquefaction trains, up to three LNG storage tanks and associated facilities.  

Port Arthur LNG is expected to create approximately 3,500 on-site engineering and construction jobs, as well as several hundred jobs in Texas in support of the project, including fabrication and operational jobs. Nearly 200 full-time jobs will be created to operate and maintain Port Arthur LNG facility.

********************

Now, let’s review the latest critical postings from the electronic bulletin boards of the interstate natural gas pipeline companies:

Dominion Energy Questar Pipeline:

The revised injection capacity at Clay Basin Storage is now 300 Mdth/d plus 25 Mdth/d Park and Loan for a total of 325 Mdth/d.  Storage withdrawal capacity will be 175 Mdth/d.

Enable Gas Transmission:

Effective Tuesday, May 7, 2019, EGT will begin planned maintenance at EGT’s Round Mountain Compressor Station, located in Conway County, Arkansas and in EGT’s North Pooling Area, with an anticipated completion date of May 10, 2019.         

During this period delivery locations East of EGT s Round Mountain Compressor Station should nominate from their MRO locations.  The availability of non-ratable services including EFT will be limited.  Shippers with EFT services should continue to submit their proposed non-ratable burn schedules in line with the normal scheduling process. Such schedules will be approved and scheduled daily, based on EGT s operating conditions for that day.

Delivery meters located East of EGT s Dunn Compressor Station will be limited to primary firm nominations only.

Also on Enable Gas Transmission:

This Operational Alert is being issued pursuant to Section 20, GT&C, of EGT s Tariff to notify its Shippers of upcoming pigging activity on EGT’s Line S system.  Pigging activity will begin May 14, 2019 at 9:00 a.m., with an anticipated completion date of May 18, 2019.

During this time nominations to delivery meters located in EGT’s South Pooling Area could be impacted.  EGT anticipates impacts to IT Services and possible impacts to Firm Services.

Kern River Gas Transmission:

The force majeure and associated pipe repair at Kern River’s Fillmore compressor station continues. Kern River requires that all customers match their scheduled nominations with physical receipts and deliveries to maintain system integrity.

Kern River does not currently have an estimated return to service date for the entire compressor station facility; however, beginning gas day May 6, 2019 Intraday 1 cycle the operating capacity at the Fillmore compressor station will be increased from 1,995,000 Dth to 2,308,000 Dth.  Kern River will provide updates as new information becomes available.

Natural Gas Pipeline Company of America (NGPL)

STORAGE – Changes/Restrictions

Injections  – Effective for gas day Tuesday, May 7, 2019, Timely Cycle and continuing until further notice, injections above MDQ for DSS and NSS in all zones on the Gulf Coast System will not be scheduled.

Texas Gas Transmission:

Texas Gas will be preforming maintenance at the Youngsville/Henry Hub meter (#2790) beginning May 7 through June 1, 2019. Deliveries to the meter will be unavailable for the duration of the maintenance.  If you have any questions, please contact your customer service representative.

Transwestern Pipeline:

East Mainline Receipts – Capacity reduction

May 7th thru May 11th, 2019 (5 Days) – Total capacity for East Mainline receipt volumes (West flow) will be reduced from 750,000 MMBtu/d to approximately 550,000 MMBtu/d. Perform verification digs to confirm pipe anomalies that were detected from an ILI Smart Tool run in the Section 9 – Mainline system from Roswell, NM to Station 8 (Corona, NM). 

This maintenance could affect receipt volumes from the West Texas & Panhandle Laterals flowing through the East Mainline system.

********************

The National Weather Service six-to-ten day temperature outlook continues to show that Pacific Northwest and parts of the Southeastern US should see warmer than seasonal temperatures through May 16.  In between, normal to cooler than average weather patterns should dominate most regions from West Texas into New England. 

That’s all for this Monday edition of GasNewsOnline.com.  We’ll return Thursday to provide an update on the interstate gas pipeline conditions expected for the weekend. 

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

Thursday, April 11, 2019

Welcome to GasNewsOnline.com!  We review the electronic bulletin boards for over sixty interstate natural gas pipeline companies to obtain their most recent critical postings about changes in operating conditions. 

Today, we’ll also update you on the latest publicly-released news from major energy companies and provide the extended National Weather Service extended temperature forecast, too.  

********************

Equitrans Midstream Corporation and EQM Midstream Partners, LP today announced that EQM has completed the acquisition of a 60% interest in Eureka Midstream Holdings, LLC (Eureka Midstream) and a 100% interest in Hornet Midstream Holdings, LLC (Hornet Midstream) for total consideration of $1.03 Billion, comprised of approximately $860 million in cash and approximately $170 million of assumed pro-rata debt. Concurrently, EQM closed the private placement of $1.2 billion of newly issued Series A Perpetual Convertible Preferred Units (Convertible Preferred Units). A portion of the net proceeds from the private placement was allocated to the cash purchase price of the acquisition, with the remaining net proceeds to be used for general purposes.

“We are pleased to have completed this important acquisition and our team is excited to begin integrating the Eureka and Hornet systems and leveraging our existing assets and core operating capabilities,” said Diana M. Charletta, chief operating officer of EQM. “These value-enhancing assets will diversify our producer customer mix and increase exposure to wet Marcellus acreage; expand our supply hub and create additional commercial opportunities; reduce unit operating costs through increased scale; and accelerate opportunities for our water services business.”

Eureka Midstream is a 190-mile gathering header pipeline system in Ohio and West Virginia that services both dry Utica and wet Marcellus production. Hornet Midstream is a 15-mile, high-pressure gathering system in West Virginia that connects to the Eureka system.

********************

Williams and Crestwood Equity Partners LP (“Crestwood”) announced on Wednesday that Williams has sold its 50 percent interest in Jackalope Gas Gathering Services, L.L.C. (“Jackalope”) to an affiliate of Crestwood for $484.6 million in cash.

Prior to the transaction, Crestwood was Williams’ 50% joint venture partner in Jackalope where Williams acted as operator, responsible for managing construction and operations and Crestwood served as marketer, responsible for commercial services. Following the transaction, Crestwood has assumed operatorship of Jackalope.

Williams plans to use the cash proceeds from the transaction plus approximately $90 million in avoided 2019 Jackalope capital spending to help fund its extensive portfolio of attractive growth capital and debt reduction. The Jackalope holdings are in Converse County, Wyoming, and provide gathering, compression and processing services and include the Jackalope Gas Gathering System and the Bucking Horse Processing Plant.

********************

Depending on which area of the country you live in, the natural gas pipelines are dealing with cold weather conditions or warmer-than-average conditions which are affecting system operations for the weekend:

ANR Pipeline:

Update: Due to planned compressor maintenance at the Eunice (Louisiana) Compressor Station located in the Southeast Area Segment (Zone 1), ANR will limit deliveries at the Eunice Total Location (LOC #505592) and the Jena Southbound location (LOC #9505489) to the following:

Eunice Total (LOC #505592)
1,000-MMcf/d 4/10 – 4/11
875-MMcf/d 4/12
1,000-MMcf/d 4/13 – 4/30

Jena Southbound (LOC #9505489)
1,000-MMcf/d 4/12

Since the last posting, ANR has made the following change. Added a capacity reduction for Jena Southbound for 4/12, leaving 1,000-MMcf/d available.

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

Colorado Interstate Gas (CIG):

With significantly colder temperatures, moisture and potential blizzard conditions being forecast beginning the afternoon of Wednesday, April 10, 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 the next available nomination cycle until further notice. In addition the following actions will be taken:

NNT overrun withdrawal requests will continue being allocated to 100,000 dth (notice #118466).

Payback OFF the CIG system may not be accepted; payback ONTO the system will be approved, absent other capacity concerns. Interruptible services may be at risk.

Egan Hub Storage:

Egan Hub Storage (Egan) will be conducting maintenance beginning Gas Day April 5, 2019 and continuing through Gas Day April 17, 2019, which will impact Kinder Morgan MR 45122.

During this outage Egan will be unable to accept withdrawals for delivery to Kinder Morgan however; injections from Kinder Morgan will not impacted. As a result, Egan may be required to restrict withdrawal nominations at MR45122 to a net zero withdrawal position.

El Paso Natural Gas:

El Paso Natural Gas Company, L.L.C. (EPNG) has identified anomalies on Line 1103 downstream of the Guadalupe Compressor Stationwhich will require pipe replacement. EPNG will isolate Line 1103 from the Guadalupe compressor station to MLV 15 starting April 13, 2019. Accordingly, the operational capacity through the GUADLUP constraint of 1,182,500 dekatherms (Dth) per day will be reduced by 438,800 Dth per day yielding an operational capacity of 743,700 Dth per day effective Gas Day April 13, 2019, Timely Cycle (Cycle 1) thru Gas Day April 18, 2019.  EPNG will provide updates on the progress of this work as information becomes available.

This incident constitutes an event of force majeure under EPNG’s FERC Gas Tariff, General Terms and Conditions, Section 11.3. 

Based on current nominations through the GUADLUP constraint, EPNG does not anticipate any impact to shippers at this time.

Great Lakes Gas Transmission:

(Updated 4/10/19)  Due to planned compressor and pipeline maintenance at various compressor stations, the Iron River Eastbound capacity will be reduced as follows:

1,050-MMcf/d (leaving 1,101-MMcf/d available)  4/10 – 4/11

995-MMcf/d (leaving 1,156-MMcf/d available)  4/12 – 4/15

908-MMcf/d (leaving 1,243-MMcf/d available)  4/16 – 5/5

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

Gulf South Pipeline:

Vixen (Louisiana) Compressor Station Maintenance:  Begins: April 22, 2019    Ends:  April 26, 2019

Expansion Receipts Upstream Vixen Scheduling Group – Capacity could be impacted by as much as 200,000 dth/d for the duration of the maintenance.

Natural Gas Pipeline Company of America (NGPL):

Pursuant to Section 23.5 of the General Terms and Conditions of its Tariff, Natural is continuing an Advisory Action to all shippers receiving gas in Segment 10 of the Midcontinent Zone (Affected Area).  Due to the large quantity of gas nominated for receipt in the Affected Area utilizing secondary or interruptible point rights, Natural is at capacity for receipts in the Affected Area. 

Effective for gas day Friday, April 12, 2019, Timely Cycle, and continuing until further notice, Natural has removed the Primary Firm and Secondary in-path Firm only restriction.  AOR/ITS and Secondary out-of-path Firm transports will be available at the receipt points listed below up to the total receipt point capacity.  Natural will schedule a total receipt point capacity of 340,000 dth per day in the Affected Area.Receipt points flowing less than 1,000 Dth per day will not be affected unless nominations increase to above 1,000 Dth per day.

Receipt Points in the Affected Area (Segment 10) are:

PIN                  Name                                                  

3251                EPNG MOORE

46856              SOUTHERN STAR BEAVER

901429            CAMERICK PLT BEAVER

905207            COLORADO INTERSTATE GAS FORGAN

Because of the number of restricted points and the number of transactions from these points that use the MidContinent Pooling Point (PIN 25078), shippers nominating Primary firm or secondary in-path firm transport under Rate Schedule FTS from these points should ensure that any gas going to the Pooling Point is clearly identified to the proper FTS contract.  Natural recommends that shippers nominate their FTS contracts directly to the Pooling Point from the specific receipt location.  Any transactions whose downstream contract is not identified when nominated to the Pooling Point sourced from a restricted point will be scheduled as Out-of-path Secondary (prorated based upon nominations, if required).

Southern Natural Gas:

Type 6 OFO Warning

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

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

We request that all Shippers/Poolers monitor the balance between actual receipts and deliveries to ensure that a daily out-of-balance situation does not occur.

Texas Eastern Transmission:

As previously posted, Texas Eastern (TE) has limited operational flexibility to manage imbalances. As result, effective 9:00 AM CCT, April 12, 2019, TE requires all delivery point operators in Access Area Zones STX, ETX, WLA, ELA, Market Area Zones M1-30, M2-30 and M3 to keep actual daily takes out of the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative. All receipt point operators in Access Area Zones STX, ETX, WLA, ELA, Market Area Zones M1-30, M2- 30 and M3 are required to keep actual daily receipts into the system equal to or less than scheduled quantities regardless of their cumulative imbalance position unless otherwise coordinated with your operations account representative.

Additionally, TE requires all shippers and point operators in Market Area Zones M1-24 and M2-24 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 issued April 6, 2019 will remain in effect until 9:00 AM CCT, April 12, 2019.

This notice will remain in effect until further notice.

Texas Gas Transmission:

Texas Gas will be performing maintenance at the Henry Hub location (#2790) beginning April 11 through April 25.  Deliveries at the location will be unavailable for the duration of the maintenance.

Wyoming Interstate Gas:

With significantly colder temperatures, moisture and potential blizzard conditions being forecast, WIC 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 the next available nomination cycle until further notice. In addition the following actions will be taken:

Payback OFF the WIC system may not be accepted; payback ONTO the WIC system will be approved, absent other capacity concerns.

*********************

The National Weather Service six-to-ten day extended temperature forecast now calls for cooler than average temperatures up and down the Mississippi River basin from Minnesota to Louisiana.  The East and West coastal areas will see warmer than seasonal weather through next weekend.

That’s a wrap for this Thursday edition of GasNewsOnline.com.  We’ll return on Monday to give you an update on pipeline conditions and the latest energy news. 

Remember that our companion audio podcast is available   via Apple Podcasts.  Subscribe today – it’s FREE

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.  

********************

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.

********************

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.

********************

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.

********************

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.

********************

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!

Edition 24 – Monday, December 17, 2018

The long-awaited thaw has begun for most of the country to start the new work week.  With expectations of moderating temperatures continuing through the end of December, the natural gas futures price for January is taking a beating today.   Scenes of a melting Frosty-the-Snowman are apparently going viral on gas traders’ screens today.   

Welcome back to GasNewsOnline.com!  We search for publicly available news and information about the natural gas business and bring it to you twice every week – for FREE!

Today, the NYMEX natural gas futures price for January, 2019 has dropped by about thirty cents as a lack of cold weather in the forecast for the next few weeks will cause a glut of gas supplies.   January’s natural gas price has tanked to just about $3.50/MMBtu. 

********************

Let’s review the EIA’s Natural Gas Weekly Update dated December 13, 2018:

At the NYMEX, the natural gas price of the 12-month strip from January 2019 through December 2019 futures contracts declined 8¢/MMBtu to $3.165/MMBtu last week.

Net storage withdrawals from working gas totaled 77 billion cubic feet (Bcf) for the week ending December 7.  Working natural gas stocks are 20% lower than the five-year (2013–17) average.

The natural gas plant liquids composite price at Mont Belvieu, Texas, rose by 6¢/MMBtu, averaging $6.73/MMBtu for the week ending December 12. The price of ethane and isobutane fell by 2% and 1%, respectively.  The price of natural gasoline, propane, and butane rose by 5%, 1%, and 4%, respectively.

According to Baker Hughes, for the week ending Tuesday, December 4, the natural gas rig count increased by 9 to 198. The number of oil-directed rigs fell by 10 to 877.  The total rig count decreased by 1, and it now stands at 1,075.

********************

Williams reported on Friday that the Federal Energy Regulatory Commission (FERC) has issued a certificate authorizing the Gateway Expansion Project – an expansion of the existing Transco natural gas pipeline designed to create 65,000 MMBtu/day of firm transportation capacity for northeastern markets.

The Gateway project helps meet growing natural gas demand by consumers in New Jersey and New York in time for the 2020/2021 winter heating season, providing additional natural gas service to PSEG Power and UGI Energy Services.

Virtually all of the project activities are within Transco’s existing rights of way and/or property boundaries. It includes adding electric horsepower at an existing Transco compressor station in Essex County, N.J., in addition to making modifications to two existing Transco meter stations in Passaic County and Essex County, N.J.

Williams anticipates beginning construction on the Gateway Expansion Project in the spring of 2019, with a target in-service date of Nov. 1, 2020.

********************

Enbridge Inc. and Spectra Energy Partners, LP announced today that they have completed the previously announced merger pursuant to an Agreement and Plan of Merger dated as of August 24, 2018 (the Merger Agreement). The Merger resulted in Enbridge (through a wholly owned subsidiary) acquiring all of the outstanding public common units of SEP and SEP becoming an indirect, wholly owned subsidiary of Enbridge.

Effective today, SEP unitholders of record as of the close of business on November 5, 2018 (other than Enbridge and its subsidiaries) are entitled to receive from Enbridge pursuant to the Merger Agreement, for each SEP common unit held, 1.111 common shares of Enbridge.

********************

The interstate gas pipeline system has eased-up on the weather-related critical notices to start the new week.  Let’s check out the latest 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, December 17, 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 2,000 Dth or 102% of scheduled delivery quantities. The penalty will be equal to three times the daily Platts Gas Daily “Daily Price Survey” posting for the High Common price for “Algonquin, city-gates” for the day on which such violation occurred as indicated in AGT’s General Terms and Conditions Section 26.8. In addition, AGT will not permit retroactive nominations to avoid an OFO penalty.

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

ANR Pipeline:

Southeast Mainline Capacity Reduction (Cancelled 12/17/18)
This posting supersedes PSO ID #8994

ANR has cancelled the planned station maintenance at its Cottage Grove Compressor Station (in Tennessee) along its Southeast Mainline. Effective immediately, the restriction for the Cottage Grove Southbound (LOC #505614) location has been lifted.

Since the last posting, ANR has made the following change. The operationally available capacity has been restored to 1,225-MMcf/d.

Columbia Gas Transmission:

Columbia Gas Transmission, LLC (TCO) notifies customers that the upcoming maintenance at the Chantilly Compressor Station has been delayed one day.  The work is now scheduled for Wednesday, December 19, 2018 through Thursday, December 20, 2018.  

Due to this maintenance, there is a potential to interrupt firm service at the Transco Chantilly interconnect (delivery meter 843105).

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 Rural Retreat Compressor Station in Rural Retreat, Tennessee which occurred on December 16,2018. 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.

Florida Gas Transmission:

JANUARY 2019 — FGT SUPPLY AREA MAINTENANCE IN ZONE 3

FGT will continue December pipeline maintenance near FGT Compressor Station 10. This maintenance is expected to continue through the end of gas day January 31, 2019.  During this maintenance FGT will schedule up to 1,150,000 MMBtu/day through Station 10. During normal operations FGT schedules up to 1,300,000 MMBtu/day through Station 10. 

Tennessee Gas Pipeline:

OFO DAILY CRITICAL DAY 1 DOWNSTREAM OF STA 254 EFFECTIVE 12-18-18

Due to forecasted colder weather and higher demand moving back into the northeast, for the Gas Day of Tuesday, December 18, 2018,Tennessee is issuing an OFO Daily Critical Day 1 for downstream of STA 254 on the 200 Line for all Balancing Parties (including LMS-PA, SA contracts acting as balancing parties, LMS-MA, and LMS-PL balancing parties).  This action is pursuant to Article X, Section 4 of the General Terms and Conditions of Tennessee’s FERC Gas Tariff. 

All delivery point operators downstream of STA 254 on the 200 Line are required to keep actual daily takes out of the system equal to or less than scheduled quantities regardless of their cumulative imbalance position.  All receipt point operators downstream of STA 254 on the 200 are required to keep actual daily receipts into the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position. In addition, it is essential that delivery point operators schedule gas at meters commensurate with takes within the affected areas.  All LMS-PA,SA contracts acting as balancing parties, LMS-MA and LMS-PL Balancing Parties are required to maintain an actual daily flow rate not exceeding 2% of scheduled quantities or 500 dths, whichever is greater for under-deliveries into the system and over-takes from the system. Customers will be assessed a rate of $5.00 plus the applicable Regional Daily Spot Price per dekatherm for that portion of physical quantities related to under-deliveries by receipt point operators and over-takes by delivery point operators which exceed this tolerance.

THIS DAILY OFO CRITICAL DAY 1 WILL REMAIN IN EFFECT UNTIL FURTHER NOTICE. TENNESSEE WILL INFORM CUSTOMERS BY EBB WHEN THIS OFO WILL BE LIFTED.

********************

Finally, the extended six-to-ten day temperature forecast from the National Weather Service is showing why Frosty-the-Snowman’s recent appearance may be a short one.   From coast-to-coast, holiday temperatures will be above to nearly normal.  

As a long-time friend in the energy business once told me nearly thirty years ago during a January when the temperature was above normal and natural gas prices were cratering, “Let’s go play golf!  At least we can be happy about something today, right?”

Indeed!  Thanks for checking in to GasNewsOnline.com!  We are your FREE source of information about the natural gas transportation business twice weekly.  Please tell a friend about us! 

Edition 21 – Thursday, December 6, 2018

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

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

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

********************

Columbia Gas Transmission:

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

Due to this maintenance, the below internal constraints will be set to zero total capacity.  All production will be shut-in with the exception of a limited quantity that may be needed to serve localized markets.

Cobb South MA18 (A03SOUTH)

Cobb Northeast MA18 (A03NORTH)

Cobb Northwest MA18 (A03LOW)

Cobb Line H (A03LINEH)

Cobb CS MA18 (COBBA03)

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

 

Dominion Energy Transmission:

Niagara Mohawk East and Bethlehem Energy Deliveries Primary Only

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

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

 

Florida Gas Transmission:

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

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

FGT is performing planned pipeline maintenance upstream of FGT Compressor Station 10. This maintenance began on December 3, 2018 and is to be completed by the end of gas day December 21, 2018. During this maintenance FGT will schedule up to 1,100,000 MMBtu/day through Station 10. During normal operations FGT schedules up to 1,300,000 MMBtu/day through Station 10.

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

 

Gulf South Pipeline:

Kiln Compressor Station Maintenance

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

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

 

Kern River Gas Transmission:

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

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

 

Natural Gas Pipeline Company of America (NGPL)

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

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

Natural has experienced horsepower issues at Compressor Station 168 (CS 168), located in Bailey County, Texas in Natural’s Permian Zone.  This is a Force Majeure event that requires Natural to temporarily reduce the maximum operating capacity northbound, thus limiting Natural’s throughput capacity through CS 168 during this restriction.

The scheduling constraint will be at CS 168; therefore, any gas received south of CS 168 for delivery north of CS 168 will be impacted for the duration of the restriction.  Additionally, transports associated with storage injections may be impacted.  The Permian Pool (PIN 25077) is located south (upstream) of the constraint.

As such, effective for gas day Friday, November 9, 2018, Timely Cycle, and anticipated to continue through gas day Monday, December 17, 2018, (previously Monday, December 10, 2018), Natural will schedule Primary Firm and Secondary in-path Firm transports to no less than 77% of contract MDQ through CS 168.  Actual nomination levels and changes in pipeline conditions could result in changes to the percentages scheduled (lower or higher) on subsequent gas days.  AOR/ITS and Secondary out-of-path Firm transports continue to not be available for the duration of this restriction.

 

Panhandle Eastern Pipe Line Company

Based on current cold weather forecasts, Panhandle is preparing for increased pipeline utilization and reduced operational flexibility. Effective Gas Day December 6, 2018, until further notice, Panhandle is requesting all delivery point operators to minimize over-takes and all receipt point operators to minimize their under-deliveries into the system.

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

Both interruptible and secondary outside-the-path nominations are subject to scheduling reductions based on nomination levels and physical capacity.

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

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

 

Southern Star Central Gas Pipeline:

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

Southern Star will issue underperformance notices to each point operator not delivering the scheduled quantities they had confirmed. Southern Star will unilaterally reduce scheduled quantities per the tariff to match actual flow if the delivering operator does not remedy the underperformance in accordance with the notice.

 

Tennessee Gas Pipeline

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

Due to forecasted colder temperatures moving into the Northeast, effective for Gas Day, Friday, December 7, 2018, Tennessee is implementing an OFO Daily Critical Day 1 for all areas east of STA 219 on the 200 Line (including the Niagara Spur) and all areas east of STA 219 on the 300 Line for all Balancing Parties (including LMS-PA, SA contracts acting as balancing parties, LMS-MA, and LMS-PL balancing parties).  This action is pursuant to Article X, Section 4 of the General Terms and Conditions of Tennessee’s FERC Gas Tariff.

All delivery point operators east of STA 219 on the 200 Line (including the Niagara Spur) and east of STA 219 on the 300 Line are required to keep actual daily takes out of the system equal to or less than scheduled quantities regardless of their cumulative imbalance position.  All receipt point operators east of STA 219 on the 200 Line (including the Niagara Spur) and east of STA 219 on the 300 Line are required to keep actual daily receipts into the system equal to or greater than scheduled quantities regardless of their cumulative imbalance position.  In addition, it is essential that delivery point operators schedule gas at meters commensurate with takes within the affected areas.

All LMS-PA, SA contracts acting as balancing parties, LMS-MA and LMS-PL Balancing Parties are required to maintain an actual daily flow rate not exceeding 2% of scheduled quantities or 500 dths, whichever is greater for under-deliveries into the system and over-takes from the system. Customers will be assessed a rate of $5.00 plus the applicable Regional Daily Spot Price per dekatherm for that portion of physical quantities related to under-deliveries by receipt point operators and over-takes by delivery point operators which exceed this tolerance.

THIS DAILY OFO CRITICAL DAY 1 WILL REMAIN IN EFFECT UNTIL FURTHER NOTICE. TENNESSEE WILL INFORM CUSTOMERS BY EBB WHEN THIS OFO WILL BE LIFTED.

 

Texas Eastern Transmission:

Line 16 Unplanned Pipeline Outage — UPDATE 3

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

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

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

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

********************

In other energy news…

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

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

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

********************

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

 

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