tgp maintenance/operations update may 16, 2017...brian merchant director, engineering gas control,...
TRANSCRIPT
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Agenda
Cathy Soape Hutton Manager, Trans and Storage Svc, KMI East Region
Brian Merchant
Director, Engineering Gas Control, KMI East Region
TGP Gas Control Organizational Structure TGP System Overview DART/Scheduling Updates Winter Look Back (‘16/17) Operations Overview Summer Preview (‘17) Planned Maintenance Development Project Updates Questions and Feedback
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TGP Gas Control Organizational Structure
GAS CONTROL ORGANIZATIONAL STRUCTURE
TGP GAS CONTROL ORGANIZATIONAL STRUCTURE
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TGP System Overview
Marcellus Shale
Utica Shale
Southeast
Northeast
EagleFord Shale
Haynesville Shale
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Tennessee Gas Pipeline
11,800 miles of pipeline 104 Bcf of storage capacity ~10.23 Bcf/d – design capacity Abundant & Growing Supply
System Overview
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System Flows – 2017
800 Line
500 Line
200 Line
300 Line
100 Line
200 Line
Long Haul to the south
Sta 87
Marcellus ~3.2-3.4 Bcf/d Utica ~1.0-1.2 Bcf/d ~2.0-2.2 Bcf/d South flow at Sta 87 Consistent exports to Mexico and Canada High system utilization- Maintenance
performed at mutually agreeable times
TGP Operations
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TGP Increasing Annual Throughput
*YTD through March
MD
th/d
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
2014 2015 2016 2017 YTD
ZONE 6
ZONE 5
ZONE 4
ZONE 3
ZONE 2
ZONE 1
ZONE L
ZONE 0
+5% +6%
+8%
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First Quarter Lookback
*North East Market Area
2015 YTD 2016 YTD 2017 YTD Change
LDC* 1,691 1,335 1,350 1%
Power 1,160 1,143 1,051 -8%
Pipeline
Interconnects 4,670 5,018 5,197 4%
Mexico 572 731 849 16%
Other 836 886 744 -16%
TOTAL 8,928 9,113 9,192 1%
• All volumes are MDth/d
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DART/Scheduling Updates
DART UPDATE
• El Paso Natural Gas (EPNG) implementation date 10-1-17
• Enhancements coming to DART – Additional information on Overrun Cut Notice
Emails – effective Tuesday, April 18, 2017
– New confirmation screen features coming soon 2017
• New Enhancements on the horizon – New MDQ Utilization screen features/validations-
coming soon 2017
– New Hourly OFO tolerance screen
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DART SCHEDULING TOOLS
• No delivery nominations allowed to Dracut • No receipt nominations allowed at Mendon until ID1 (compared to
EPSQ volumes) • No delivery nominations allowed at Wright/Shelton until ID1
(compared to EPSQ volumes) • Invalid nominations not allowed • Limitations of Storage Services/Linepack Services • No meter bounces allowed at power plants downstream (may be
invoked) • New restriction locations as needed • Imbalance Warnings • Monthly OFOs • Daily OFOs • Hourly OFOs • Additional Segment Capacities Posted to EBB
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Winter Look Back (‘16/17)
Winter Look Back Summary
• Peak Day was ~10.1 Bcfd on Jan 7, 2017 - Deliveries
• Peak Day was ~1.7 Bcfd on Jan 8, 2017 – Storage (withdrawal)
• Peak Day was ~1.8 Bcfd on Jan 7, 2017 – Power Plant Load
• Winter OFO count
– 2016/2017 Zones 5 & 6 - 28 vs 21 in 2015/2016
11 OFO’s were directed at power plants (Dec/Jan) vs 8 in 2015/16
– 2016/2017 All other zones - 16 vs 6 in 2015/2016
• Storage Inventories down from 2015/16
– 44% lower than the levels for 2015/16
– 2% higher than 2014/15
• System Challenges
– Less supply coming in from Dracut/Distrigas
– Short Term Unit/Pipeline Issues • Managed without cutting In-Path Services at Timely
• Continuous communication between Commercial, Scheduling and Gas Control Groups
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Winter Days - (%) Restricted Restriction Point Highly Utilized TGP Paths
Percentage Days Restricted
(November - March)
Percentage Days Restricted
(November - March)
Percentage Days Restricted
(November - March)
Percentage Days Restricted
(November - March)
2013/2014 2014/2015 2015/2016 2016/2017
Sta. 200/204 30.46% 22.52% 64.47% 68.87%
Sta. 245 100% 100% 100.00% 99.33%
Sta. 261 30.46% 32.45% 68.42% 27.81%
Sta. 267 2.65% 5.29% 30.92% 55.63%
MLV 273 0.00% 0.00% 0.00% 17.22%
Sta. 315 BH 100% 100% 76.32% 96.69%
Sta. 321 94.70% 94.71% 86.18% 92.72%
MLV 336 50.33% 73.51% 57.24% 30.46%
MLV 355 BH 70.20% 5.96% 9.21% 5.30%
Sta. 1 BH 50.99% 11.26% 84.21% 0.00%
Sta. 9 BH 0.00% 0.00% 0.00% 43.71%
Mahwah 49.67% 64.24% 92.76% 88.08%
Rivervale 80.79% 80.79% 66.45% 80.79% 18
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Winter Summary - System Deliveries
volumes are MDth/d
2014-2015 2015-2016 2016-2017 % Change
LDC 2,079 1,654 1,720 4%
Power 1,040 1,132 1,095 -3%
Interconnects 4,727 4,942 5,173 5%
Mexico 499 696 844 21%
Other 240 366 299 -18%
TOTAL 8,585 8,790 9,131 4%
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Cold New England Weather
200
400
600
800
1000
1200
1400
Nov Dec Jan Feb Mar
HD
Ds
Winter 2016/17
Winter 2015/16
Winter 2014/15
Winter 2013/14
30 Year Average
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Winter Northeast Market Deliveries
volumes are MDth/d
2014-2015 2015-2016 2016-2017 % Change
LDC 1,506 1,178 1,279 +9%
Power 315 326 266 -19%
Interconnects 1,361 1,485 1,493 +1%
TOTAL 3,183 2,989 3,038 +2%
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Winter North Supply Analysis
Winter Period (Nov-Mar) Average MDth/d
MD
th/d
0
1,000
2,000
3,000
4,000
5,000
6,000
2013-2014 2014-2015 2015-2016 2016-2017
Cobb
Cornwell
Dracut
Distrigas
Marcellus
Rex
Shelton
Utica
Wright
-1%
+17%
+16%
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OPERATIONS OVERVIEW
OPERATIONS ORGANIZATIONAL STRUCTURE
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OPERATIONS ORGANIZATIONAL STRUCTURE
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Division 10 Map
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New England Area Map
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Summer Preview (‘17)
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Summer Preview
• Demand to remain strong across the system
• Capacity Utilization on the 200/300 Line in Northeast should remain high • Marcellus and Utica Production to remain at High Levels • Southbound Flows
– Volumes through Station 87 should remain in the 2.0-2.2 Bcf/d as maintenance activities are completed
• Exports to Mexico and Canada to remain strong • Storage Field Levels
– Northern Storage levels down from last year; better able to manage maintenance activities and handle market area supply swings
– Bear Creek Storage levels higher than last year; better able to handle higher power demand in the South
• High level of system maintenance, repair, rebuild activity
• GETTING READY FOR WINTER
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Planned Maintenance (‘17)
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EBB Website
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Impact Report – Next Week Outages
Segment
Design Capacity
Available Capacity & Amount reduced by
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Impact report – Monthly Report
Disclaimers • Anticipated Impacts are estimates. Actual
nominations, market demand, weather and pipeline conditions, etc. will determine if, and through what level, restrictions become necessary.
• Unless otherwise stated, all scheduled dates represent gas days as defined in the Tennessee Gas Pipeline tariff to mean a period of twenty-four consecutive hours, beginning and ending at 9:00 a.m. (Central Clock Time).
Disclaimers Disclaimers
• Scheduled dates are subject to change.
• Projects may be added, altered, delayed or cancelled.
• TGP will provide notice of such additions or changes via DART postings.
• Dates posted on DART should be deemed correct in the event of conflicts between DART posted dates and dates within this presentation.
Disclaimers
• Yellow
– Restrictions are possible, but not likely
– With extended duration, restrictions could be necessary from time to time
– (M) denotes that meter(s) may be impacted, refer to EBB posting
• Red
– Restrictions are probable
Color Key for Maps
Zone 4 (2017)
Anomaly Remediation MLV 200-4B to 204-4 (5/29/2017 – 6/10/2017)
MLV 207-4 to 208-4 (5/26/2017 – 6/7/2017) MLV 204-2 to 209-2 (6/26/2017 – 7/8/2017)
MLV 209-2 to 214-2 (6/12/2017 – 6/24/2017) Capacity of 1,837 reduced to 1510 - 1780 (seg. 204 BH)
Station Outage Sta. 323A (6/16/2017 – 6/29/2017)
Capacity of 1,594 reduced to 1,400 (seg. 324 FH)
Station Outage Sta. 315 (6/5 – 6/11, 7/3 – 7/16)
Capacity of 1,774 reduced to 1,490 (seg. 315 BH)
Station Outage Sta. 317 (6/12 – 6/15. 7/17 – 7/27))
Capacity of 1,774 reduced to 1,680 (seg. 315 BH)
Station Outage(Power Company Outage) Sta. 317 (10/2 – 10/6)
Capacity of 1,774 reduced to 1,680 (seg. 315 BH)
Anomaly Remediation Mlv 321-2 to 325-2 (3Q2017)
Capacity of 1,594 reduced to 1,150 (seg. 324 FH)
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Unit Maintenance Sta. 245 (8/11/2014 – 8/14/2014)
Zone 5 (2017)
ILI Cleaning MLV 313A-100/313A-400 (5/9, 5/11 & 5/16)
Capacity of 813k reduced to 420k (seg. 299FH)
ESD Test Sta. 241 (6/12/2017 – 6/16/2017)
Capacity of 1,080 reduced to 800k (seg. 245 FH)
ESD Test Sta. 245 (6/19/2017 – 6/23/2017)
Capacity of 1,080 reduced to 760k (seg. 245 FH)
Connecticut Expansion Tie-Ins( 200 Line (3rd Qtr. 2017)
Anomaly Digs MLV 329-1 to MLV 336-1 (5/30 – 6/7)
MLV 325-1 to MLV 329-1 (8/28 – 11/11)
Hydrotest MLV 251-2 to MLV 252-2 (7/24 – 8/1)
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Anomaly Digs MLV 237-1 to MLV 245-1 (6/26– 8/5)
Zone 6 (2017)
New England Area Cleaning/ILI Pig Runs 270B-100 Line (8/22/2017 & 8/23/2017)
270C-103 VS (8/4/2017 – 8/9/2017)
New England Area Anomaly Remediation 270C-300 line (TBD)
270A-100 line (5/22/2017 - 6/23/2017) 265C-100 line (8/7/2017 – 8/11/2017)
265A-100 line (8/14 – 8/25)
New England Area ILI/Cleaning MLV 336-1 to 356-1 (4/27, 5/3, 5/8 & 5/31)
Hydrotest(M) MLV 261B-100(6/19/2017 – 6/23/2017)
Controls Replacement (M) Sta. 266A (9/26/2017 – 10/20/2017)
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Connecticut Expansion Tie-Ins( 200/300 Lines (3rd Qtr. 2017)
Unit Maintenance Station 264 (one unit at a time)
(5/22 – 5/26)
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Development Project Updates
Sta 87
Supply-Push Dth/d In-Service
Broad Run Expansion 200,000 Jun-2018
Susquehanna West 145,000 Nov-2017
Orion 135,000 Jun-2018
Market-Pull Dth/d In-Service
SW Louisiana Supply 900,000 Q1-2018
Lone Star 300,000 Jan-2019
Connecticut Expansion 72,100 Nov-2017
Triad 180,000 Jun-2018
Development Project Updates
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Sta 219
Sta 17
Sta 534
Sta 313
Sta 47
Sta 40
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Questions and Feedback