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.  

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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.

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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.

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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.

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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

Thursday, March 28, 2019

Welcome to GasNewsOnline.com!  We review over fifty interstate natural gas pipeline companies to share their most recent critical postings about changes in operating conditions. 

We’ll also update you on the latest publicly released news from energy companies and provide the latest National Weather Service extended temperature forecasts, too.  

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According to the US Energy Information Administration, working gas in storage for the week ending Friday, March 22, 2019 registered a net decrease of 36 Bcf.  This was close to the analysts’ estimates of a 40 Bcf weekly gas storage draw. 

Natural gas stocks were 285 Bcf less than last year at this time and 551 Bcf (or 33.2%) below the five-year average.

The May, 2019 natural gas futures price on the NYMEX responded by adding a little over one cent to finish Thursday at around $2.73/MMBtu.

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Southern California Gas (SoCalGas) announced on Tuesday that the company will lower the price of compressed natural gas at all of its 13 public access natural gas vehicle fueling stations by $0.26 per gallon beginning April 1st. Through a California Public Utilities Commission approved program, the utility is able to offer a reduced price by returning revenue generated from the sale of Low Carbon Fuel Standard (LCFS) credits to customers.

The LCFS program is administered by the California Air Resources Board and seeks to reduce greenhouse gas emissions from transportation fuels by 20 percent through 2030. Under the program, fuels that help lower GHG emissions, such as natural gas, generate LCFS credits.

Natural gas costs significantly less than gasoline or diesel per gallon. For example, the average pump price at utility compressed natural gas stations was $2.37 per gallon in February, whereas the average cost of gasoline in California was $3.24 per gallon, and the average cost of diesel was $3.73 per gallon, according to the Energy Information Administration.

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Florida Power & Light Company today announced a plan to build the world’s largest solar-powered battery system – four times the capacity of the largest battery system in operation – as part of an innovative modernization plan that will accelerate the retirement of two natural gas power generation units.

The future FPL Manatee Energy Storage Center will have 409 megawatts of capacity – the equivalent of approximately 100 million iPhone batteries – when it begins serving customers in late 2021 and will be charged by an existing FPL solar power plant in Manatee County. By deploying energy from the batteries when there is higher demand for electricity, FPL will offset the need to run other power plants – further reducing emissions and saving customers money through avoided fuel costs.

The FPL Manatee Energy Storage Center is part of an innovative modernization plan to accelerate the retirement of two, 1970s-era natural gas generating units at FPL’s neighboring power plant, and replace them with clean and renewable energy.

In addition to the energy storage system in Manatee County, FPL is planning smaller battery installations across the state, numerous solar power plants and efficiency upgrades to existing combustion turbines at other power plants to replace the 1,638 megawatts of generating capacity. The project will save customers more than $100 million and could eliminate more than 1 million tons of carbon dioxide emissions.

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Let’s now check the latest critical information postings from the interstate natural gas pipeline systems around the United States:

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, April 1, 2019, to all parties, with the exception of those Operational Balancing Agreements required by FERC regulations, on the AGT system.

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

During the effectiveness of this OFO, all parties must be balanced such that actual deliveries of gas out of the system must be equal to or less than scheduled deliveries. The penalty shall apply to each dekatherm of actual delivery quantities that exceeds the greater of 6,000 Dth or 106% 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.

This OFO will remain in effect until further notice.

ANR Pipeline:

Attn: All ANRPL FSS Customers

Reminder – FSS Customers with contracts expiring effective gas day 3/31/19 will need to transfer the ending balance from the terminating contract to another contract effective gas day 4/1/19. Customers are able to submit Infield Storage Transfers in Gems for gas day 4/1/19 prior to 9:00 a.m. CST on 4/2/19.
For any questions please contact the ANR Noms Team at 1-800-827-5267 or email to: ANR_Noms_Scheduling@Transcanada.com

Also from ANR:

SW Area Capacity Restriction (Posted 3/26/19)

Due to planned pipeline maintenance at the Transok Compressor Station, ANR will not schedule nominations at the Custer City /Transok (LOC #16842) location from April 22nd – 30th.

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

Dominion Energy Questar Pipeline:

Dominion Energy Questar Pipeline, LLC (DEQP) is updating the Clay Basin Conditioning Reimbursement Factor (CRF). Effective May 1, 2019 the CRF applied to all injections and withdrawals from Clay Basin will be 1.5%. The CRF is calculated annually as required by Part 3 General Terms and Conditions §16.4(b) of DEQP’s FERC Gas Tariff and is posted in DEQP’s Informational Postings, Other, Storage, Clay Basin Stipulation.

East Tennessee Natural Gas:

East Tennessee Natural Gas, LLC (“ETNG”) will be hosting a WebEx meeting to provide customers and other interested parties an overview of ETNG’s upcoming 2019 planned outages on Wednesday, April 3, from 1:00PM CDT to 2:30PM CDT via WebEx. A copy of the presentation will be posted on ETNG’s bulletin board approximately one hour before the event. There will be a question and answer segment immediately following the presentation.

Enable Gas Transmission:

This Operational Alert is being issued pursuant to Section 20, GT&C, of EGT s Tariff and shall constitute notice of Force Majeure under Section 8, GT&C of EGT s Tariff to notify all parties of unplanned maintenance at EGT’s Byars Lake Compressor station located in McClain County, Oklahoma.

EGT anticipates impacts to IT, Secondary services, and potentially Primary services.  During the unplanned maintenance, shippers with receipts West of Allen should nominate point-to-point to maintain the highest priority level of service.

Great Lakes Gas Transmission:

Due to planned compressor and pipeline maintenance at various compressor stations, the Emerson Eastbound capacity will be reduced as follows:

1,187-MMcf/d (leaving 1,251-MMcf/d available)  3/26 – 3/31
1,050-MMcf/d (leaving 1,251-MMcf/d available)  4/1 – 4/15
805-MMcf/d (leaving 1,496-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.

For any questions regarding nominations or scheduling, please call the GLGT Noms and Scheduling Hotline at 1-866-454-7572.

Gulf Crossing Pipeline:

Below normal temperatures are expected to move across the Gulf Crossing service area over the next few days. While it is fully expected that all primary firm service obligations will be met, the following services/activities are subject to scheduling reductions until further notice:

Imbalance Payback from Transportation Service Provider

Park Withdrawal

Loan

Interruptible

Additionally, Gulf Crossing is requesting all shippers to balance their transportation and storage contracts by conforming receipts into the system with the deliveries being taken from the system, and to receive and deliver quantities at a uniform hourly rate of flow, pursuant to Section 6.7[1.] and 6.7[2.] of Gulf Crossing’s FERC Gas Tariff.

If shippers do not voluntarily comply with these provisions, Gulf Crossing may be forced to declare a Critical Period or issue an Operational Flow Order, which could result in penalties for shippers.

MidContinent Express Pipeline (MEP):

MEP has been notified that the Fuel Reimbursement percentage for its Enable Leased Capacity (Segment 10) will change effective for gas day April 1, 2019, for all transports using the Leased Capacity.  Please check the company’s EBB for a link to the new Fuel Reimbursement percentages. 

Natural Gas Pipeline Company of America (NGPL):

SEGMENT 2/15 – OE#1 M/L (CS 156/801) – PIPELINE INTEGRITY

Natural will be inspecting and, if necessary, performing pipeline remediation work per its pipeline Integrity Management Program standards on the OE#1 mainline between Compressor Station 156 (CS 156) located in Kiowa County, Oklahoma and Compressor Station 801 (CS 801) located in Carter County, Oklahoma (Segment 2 of Natural’s Midcontinent Zone/Segment 15 of Natural’s Texok Zone).  Natural anticipates that this inspection and possible remediation work will continue through the end of May 2019.

Northwest Pipeline:

Effective Gas Day Friday, March 29, 2019 and until further notice, Northwest is issuing an OFO Recall Advisory and Operational Flow Order (OFO) through the Roosevelt compressor and the Plymouth South constraint location pursuant to Section 14.15(d) of its Tariff.

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

If the northbound scheduled quantities exceed the greater of Northwest’s design capacity of 546,000 Dth/d at Roosevelt or 536,300 Dth/d at Plymouth South or the operational available capacity at Plymouth South, which is currently 575,000 Dth/d, Northwest will provide Shippers with their specific OFO obligations by 4:00 p.m. MST. Shippers must comply with their OFO obligations no later than the Evening nomination deadline (5:00 p.m. MST).

Northwest would like to remind customers that the Rangely OFO remains in effect.

Southern Natural Gas:

Southern is posting the following information in order to provide customers with additional operational data to assist in planning your business for the upcoming week.

The Muldon storage shut-in test will begin on Tuesday, April 2, 2019 and continue to Tuesday, April 9, 2019 at 9 AM.

As a result of the shut-in test, Southern will reduce each CSS customer’s DIQ and DWQ on a pro-rata basis. Each CSS customer will be allocated thirty- six percent (36%) of its currently effective DIQ and DWQ posted on the EBB during the Muldon shut-in test.

Based on current supplies and anticipated demand, we expect storage injection requirements to be near Southern’s maximum storage injection capabilities. 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:

On March 25, 2019, Texas Eastern Transmission, LP submitted an OFO Penalty Disbursement Report.

https://infopost.spectraenergy.com/GotoLINK/GetLINKdocument.asp?Pipe=10076&Environment=Production&DocumentType=Notice&FileName=Report.pdf&DocumentId=8aa1649f699ac30d0169b64231f702b2

Transcontinental Gas Pipe Line Company (Transco):

The Operational Flow Order – Imbalance (OFO) currently in effect on the Transco system in Zones 4, 5, & 6 will be terminated effective Monday, April 01, 2019 at 9:00 AM CDT.

Effective April 1, 2019 and continuing until further notice, Transco may issue a Shipper and/or Location specific OFO(s) to Shippers and/or Locations that exceed 10 percent daily or 5 percent cumulative imbalance. These Shippers and/or Locations could be subject to a 10 percent daily “Due From” and/or “Due To” Operational Flow Order. The OFO could become effective immediately and continue until further notice or for the remainder of the month in which it was issued. Shippers that create imbalances in excess of the tolerance are subject to being included in the OFO.

Transco reminds all parties that it may also be required to issue system-wide or zonal OFOs regardless of the daily or cumulative imbalance percentage.

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Looking at the six-to-ten day temperature forecast for early April from the National Weather Service, normal temperatures are expected for most of the country.  Warmer than seasonal conditions are expected for New England, most of the desert Southwest, the Rockies, and along the West Coast. 

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

Please tell a friend in the natural gas scheduling and transportation business about us!  It’s FREE!  

Edition 6 – Monday, October 8, 2018

Hurricane Michael formed quickly in the Gulf of Mexico over the weekend and is currently forecast to affect the Florida Panhandle region by as early as Wednesday afternoon.

Welcome back to GasNewsOnline.com!  We scour all public sources of information to bring you the latest natural gas pipeline outages, gas storage news, and relevant weather and temperature forecasts which move the needle on natural gas supplies and demand.

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Let’s start this week with the latest news about Hurricane Michael as of Monday evening, October 8:

Michael is strengthening as it heads toward Florida, forecast to become the second hurricane to make landfall in the U.S. in a month.

The fast-moving storm has already shut in some oil and natural-gas production in the Gulf of Mexico. Michael is expected to skirt the eastern Gulf before making landfall on the Florida panhandle by midweek. Currently a Category 1 storm on the Saffir-Simpson scale, it could increase to a 2 or 3 by the time it reaches the U.S. on Wednesday.

“Steady to rapid strengthening is forecast during the next day or so, and Michael is forecast to become a major hurricane by Tuesday or Tuesday night,” the U.S. National Hurricane Center said in an advisory.

The storm could generate a 12-foot surge, and 4-8 inches of rain in the region, with isolated areas getting as much as 12 inches.   As of Monday evening, below is the official National Hurricane Center forecast with maximum winds.

FORECAST POSITIONS AND MAX WINDS

INIT  08/2100Z 22.2N  85.2W   70 KT  80 MPH
 12H  09/0600Z 23.7N  85.7W   85 KT 100 MPH
 24H  09/1800Z 25.7N  86.4W   95 KT 110 MPH
 36H  10/0600Z 27.9N  86.6W  105 KT 120 MPH
 48H  10/1800Z 30.2N  85.8W  100 KT 115 MPH...NEAR THE COAST
 72H  11/1800Z 34.5N  80.5W   45 KT  50 MPH...INLAND
 96H  12/1800Z 39.8N  68.8W   55 KT  65 MPH...POST-TROP/EXTRATROP
120H  13/1800Z 46.2N  50.0W   60 KT  70 MPH...POST-TROP/EXTRATROP

Duke Energy Corp. warned customers in the region to prepare for potential outages.

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Now, let’s take a look at some of the latest postings from the interstate pipeline grid:

ANR Pipeline:

October 9th through 23rd, ANR is performing planned compressor and station maintenance at the Eunice Compressor Station located in the Southeast Area Segment (Zone 1).

As a result, ANR will have limited delivery capacity and lower pressures and will restrict the following locations:

– Eunice Eastbound (LOC #226641): 460-MMcf/d (See PSO ID #8924)
– Eunice Total (LOC #505592): 750-MMcf/d (See PSO ID #8923)

Due to pressure incompatibility and lower pressures, the following delivery meters will be scheduled to 0-MMcf/d:

– LOWRY PLANT INLET (LOC #28554)
– PINE PRAIRIE NORTH DEL (LOC #490941) (See CN ID #8919)
– PINE PRAIRIE SOUTH DEL (LOC #766185) (See CN ID #8918)

Due to pressure incompatibility and lower pressures, the following delivery meters will be limited to Firm Primary only nominations:

– GRAND CHENIER/LRC (LOC #7695)
– RIVERWAY (TO BRIDGELINE) (LOC #42593)
– ST. MARTINVILLE E TO LRC (LOC #218192)
– DURALDE EVANGELINE INT (LOC #312115)

Based on current nominations, it is anticipated that this posting WILL reduce IT and Firm Secondary volumes to 0 and possibly the capacity allocation of 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.

Florida Gas Transmission:

FGT will be performing maintenance on the compressor units at the FGT/Tennessee Carnes Interconnect in Stone County, Mississippi (POI 10258). This maintenance is scheduled to begin on October 1, 2018 and is to be completed by the end of gas day October 13, 2018.  During this maintenance, zero volumes will be scheduled at the interconnect. During normal operations, FGT schedules up to 60,000 MMBtu/day through the FGT/Tennessee Carnes Interconnect.

Dominion Energy Transmission:

Critical: Y:  Notice Eff Date: 10/11/2018

The Gilmore Station (Ohio) is expected to be returned to service on Thursday, October 11, 2018.

Great Lakes Gas Transmission:

Emerson Eastbound Available Capacity

Due to planned and unplanned pipeline and compressor maintenance at various compressor stations, the Emerson Eastbound capacity will be reduced as follows:

By 553-MMcf/d (leaving 1,748-MMcf/d available)  10/8 – 10/14
By 262-MMcf/d (leaving 2,039-MMcf/d available)  10/15 – 10/20
By 39-MMcf/d (leaving 2,262-MMcf/d available)  10/21 – 10/31

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

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Finally, here is a look at the updated six-to-ten day national temperature forecast from the National Weather Service through October 18.

We try our best to keep you up-to-date with the latest public information from the natural gas business every week – for FREE!  Thank you for reading GasNewsOnline.com.  Please tell a friend!