Post on 08-Jul-2020
2
Agenda
Cathy Soape Hutton Manager, Trans and Storage Svc, KMI East Region
Brian Merchant
Director, Engineering Gas Control, KMI East Region
TGP System Overview Scheduling Update Winter Look Back (‘16/17) Summer Preview (‘17) Scheduled Maintenance Development Project Updates Discussion and Feedback
3
TGP System Overview
Marcellus Shale
Utica Shale
Southeast
Northeast
EagleFord Shale
Haynesville Shale
4
Tennessee Gas Pipeline
11,900 miles of pipeline 96 Bcf of storage capacity ~10.23 Bcf/d – design capacity Abundant & Growing Supply
System Overview
5
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
6
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%
7
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
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
2,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2015 2016 2017YTD through March up 1%
-10%
-25%
-30%
-1%
9%
-20% -11% -7% -10%
-1%
6%
-40% -11%
-9%
32%
• Northeast Market
Average Daily LDC Demand (MDth/d)
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
2,000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2015 2016 2017
14% -9%
-8%
18%
1%
14% 24%
27%
4%
5%
-3%
11%
-18%
YTD through March down 8%
-17%
14%
System Average Daily Power Demand (MDth/d)
10
DART/Scheduling Updates
DART UPDATE
• Southern Natural Gas (SNG) implemented DART April 1, 2016
• 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
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 • New Rate Card effective April 1, 2017
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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
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%
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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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Winter Total System Power Plant Deliveries M
Dth
/d
-
200
400
600
800
1,000
1,200
2013-2014 2014-2015 2015-2016 2016-2017
Zone 6
Zone 5
Zone 4
Zone 2
Zone 1
Zone 0
9%
16%
-3%
18
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
19
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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Summer Preview (‘17)
22
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
26
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 0 and L (April/May)
Hydrotest (M) MLV 17-3 to 13- 3 (4/26/2017 – 6/30/2017)
Capacity of 688k reduced to 590k (seg. 109 BH)
ILI/Cleaning MLV 32-3S to 25-3D (4/18 & 4/20)
Spike Test (M) MLV 20-3 to 17-3 (3/20/2017 - 5/19/2017)
Pipe Replacement MLV 20-1 to 20-1A (3/2017 – 5/5/2017)
Capacity of 599k reduced to 415k (seg. 125 BH)
ESD Test Sta. 409 (4/19/2017 - 4/21/2017)
Capacity of 563k reduced to 350k (seg. 490 FH)
Recoat MLV 823-1 to 827-1 (4/3/2017 – 5/31/2017)
Zone 0 and L (June)
Hydrotest (M) MLV 17-3 to 13- 3 (4/18/2017 – 6/30/2017)
Capacity of 688k reduced to 590k (seg. 109 BH)
Spike Test (M) MLV 20-2 to 17-2 (6/1/2017 - 7/20/2017)
Capacity of 599k reduced to 415k (seg. 125 BH)
Hydrotest (M) MLV 826-1 to MLV 827 (6/19/2017 - 7/20/2017)
Capacity of 221k is reduced to 0 (seg. 823 BH)
Station 823 – Station Reversal Piping Modifications (6/5/2017 - 6/15/2017) Capacity of 221k is reduced to 0 (seg. 823 BH)
Zone 1 (April/May)
Trap Modifications Sta. 546 (4/10/2017 –6/10/2017)
Capacity of 1,263 reduced to 1,000 (seg. 548 BH)
ILI/Cleaning MLV 538-2 to 542-2 (5/25/2017 & 6/8/2017)
Zone 1 (June)
Trap Modifications Sta. 546 (4/10/2017 –6/10/2017)
Capacity of 1,263 reduced to 1,000 (seg. 548 BH)
ILI/Cleaning MLV 538-2 to 542-2 (5/25/2017 & 6/8/2017)
ILI/Cleaning MLV 555-1 to 555-1 (6/13, 6/14, 6/20 & 6/22) Capacity 1,263 reduced to 1,040 ( seg. 548 BH)
Zone 2 and 3 (April/May)
Pipe Replacement MLV 107-5 to 109-5 (3/13/2017 – 5/27/2017)
Capacity of 2,366 reduced to 2,300 (seg. 187 BH)
Pipe Replacement MLV 866-1 to 867-1 (4/17/2017 – 4/23/2017)
Capacity of 2,366 reduced to 1,950 (seg. 187 BH)
Zone 2 and 3 (June)
Spike Test MLV 106-4D – 108-4 (6/26/2017 – 9/16/2017)
Capacity of 2,366 reduced to 2,280 (seg. 187 BH)
Zone 4 (April/May)
Drip Removal Sta. 214-1 to 215-1 (4/17/2017 – 5/1/2017)
Capacity of 1,837 reduced to 1,560 (seg. 204 BH)
ILI/Cleaning MLV 307-1 to 219-2 (4/18/17, 4/20/17 & 4/25/17)
Capacity of 1,185 reduced to 800k (seg. 307 BH)
Anomaly Remediation MLV 321-2 to 325-2 (4/24/2017 – 5/6/2017)
Capacity of 1,594 reduced to 1,150 (seg. 324 FH)
Station Outage Sta. 310 (4/20/2017 )
Capacity of 1,145 reduced to 1,000 (seg. 307 BH)
Anomaly Remediation MLV 200-4B to 204-4 (5/29/2017 – 6/10/2017)
MLV 207-4 to 208-4 (5/26 – 6/7) Capacity of 1,837 reduced to 1,510 (seg. 204 BH)
Zone 4 (June)
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 Tie-In Sta. 323A (6/16/2017 – 6/29/2017)
Capacity of 1,594 reduced to 1,400 (seg. 324 FH)
Station Tie-In Sta. 315 (6/5/2017 – 6/11/2017)
Capacity of 1,774 reduced to 1,490 (seg. 315 BH)
Electrical Tie-Ins Sta. 317 (6/12/2017 – 6/15/2017)
Capacity of 1,774 reduced to 1,680 (seg. 315 BH)
Unit Maintenance Sta. 245 (8/11/2014 – 8/14/2014)
Zone 5 (April/May)
Unit Maintenance Sta. 241-2A (4/17/2017 – 4/21/2017) Sta. 249-2A (4/24/2017 – 4/29/2017)
Capacity of 1,014 reduced to 990k – 960k (seg. 245 FH)
Unit Maintenance Sta. 245-1C (5/1/2017 – 5/3/2017)
Sta. 249-one unit @ a time (5/8/2017 – 6/16/2017) Capacity of 1,014 reduced to 990k – 880k (seg. 245 FH)
Unit Maintenance Sta. 254-2B (5/1/2017 – 5/7/2017)
Capacity of 1,178 reduced to 910k (seg. 256 FH)
ILI Cleaning MLV 313A-100/313A-400 (5/9, 5/11 & 5/16)
Capacity of 813k reduced to 420k (seg. 299FH)
ESD Test Sta. 405 (5/9/2017)
Unit Maintenance Sta. 325-3A & 4A (5/30/2017 – 6/2/2017)
Capacity of 1,594 reduced to 1,580 (seg. 324 FH)
Unit Maintenance Sta. 245 (8/11/2014 – 8/14/2014)
Zone 5 (June)
Unit Maintenance Sta. 249-1B,2B (5/8/2017 – 6/16/2017)
Capacity of 1,014 reduced to 890k (seg. 245 FH)
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)
Unit Maintenance Sta. 325-3A & 4A (5/30/2017 – 6/2/2017)
Capacity of 1,594 reduced to 1,580 (seg. 324 FH)
Zone 6 (April/May)
New England Area ILI/Cleaning MLV 264B-101 (4/12/2017 & 4/13/2017) MLV 268A-101 (4/24/2017 & 4/26/2017 MLV 270B-400 (4/10/2017 & 4/11/2017)
New England Area Anomaly Remediation MLV 270C-300 (4/3/2017 & 4/28/2017)
New England Area Anomaly Remediation MLV 270C-300 (5/1/2017 - 5/19/2017) MLV 270A-100 (5/22/2017 - 6/23/2017) MLV 270C-301 (5/1/2017 - 5/19/2017)
New England Area ILI/Cleaning MLV 336-1 to 356-1 (4/27, 5/3, 5/8 &
5/31/2017)
Zone 6 (June)
New England Area Anomaly Remediation MLV 270A-100 (5/22/2017 - 6/23/2017)
Zone 0
Automation Control Update Sta. 409A (Sep./Oct. Exact Dates TBD)
Spike Test MLV 405-2 to 408-2 (moved to 1Q18)
Future Significant Outages
Zone L& 1 (Cameron LNG Project)
Station Reversal Sta. 827 (5/9/2017 - 8/17/2017)
Sta. 847 (8/12/2017 - 12/14/2017) Cooling System Upgrade
Sta. 823 (9/1/2017 - 11/30/2017 Hydrotest
MLV 846-1 to 847-1 (9/15/2017 - 10/15/2017) Sta. 847 (9/15/2017 - 10/15/2017)
Tie-Ins Delhi Lateral (8/7/2017 - 8/17/2017) Station 836A ( 8/7/2017 -8/17/2017)
Future Significant Outages
Zone 3
Pipe Replacement MLV 119-2 (3rd Qtr. 2017 – Exact Dates TBD)
Future Significant Outages
Zone 4
200 Line Ohio/ Kentucky Anomaly Remediation 200-1,-2, -3 & -4 - Various Sites
(June – July)
Susquehanna Expansion 300 Line Tie-Ins (June - July)
Future Significant Outages
Zone 5
Pipe Replacement MLV 231-2 (3rd Qtr. 2017)
Connecticut Expansion Tie-Ins( 200 Line (3rd Qtr. 2017)
Future Significant Outages
Zone 6
Connecticut Expansion Tie-Ins( 200/300 Line (3rd Qtr. 2017)
Controls Replacement (M) Sta. 266A (9/26/2017 – 10/20/2017)
Future Significant Outages
48
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
49
Sta 219
Sta 17
Sta 534
Sta 313
Sta 47
Sta 40
50
Questions and Feedback
51
Appendix
TGP Hourly Process
• Nominations due 1 hour prior to effective hourly cycle for all hourly cycles except 8 AM cycle
(8 AM cycle nominations due at 8 AM CCT) • Schedulers available until 10 PM CCT nightly • Nominations for hourly cycles after 11 PM cycle:
– Must be entered in Dart – Call Gas Control – Gas Control will call the On Call Scheduler – All parties in the chain must be available to confirm changes – Scheduler schedules/disapproves the nomination for the hourly cycle – Any nominations for hourly cycles 12 AM to 6 AM will be disapproved if Gas Control is not
notified – Nominations must physically be able to flow/adjusted for the hourly cycle (Maximum Hourly
Entitlement MHE); NOTE: Gas Control may not be able to set rate for 8 AM nominations – Service priority switching for hourly cycles may be disapproved – No new business nominations will be accepted at the 8 AM cycle
• Entire batch may be resubmitted; however changes must be “checked” • Be sure to check both Upstream(s) and Downstream(s) • If nominations are disapproved, the customer will be contacted
TGP Retro Process
• A request for retro must be made within 7 calendar days of the gas day affected
• Retro nominations are submitted in Dart as an 8 AM • Customer sends an email to TGP Scheduler with retro request
including all affected/confirming parties for approvals • Separate email(s) to affected/confirming parties can be used for
proprietary information • Email(s) should contain the valid reason for the retro • A summary of the transaction is helpful for analysis • All affected parties should reply all with their
approval/disapproval • If all approvals are received, TGP Scheduler will process the retro • If all approvals are not received, the customer’s 8 AM retro will
be disapproved and the customer and all affected parties will be notified
Acceptable Reasons for Retros
• Discrepancies with confirming parties (EDI mismatch, EPSQ, late cuts, etc on a case by case basis)
• Obvious customer data entry errors ie. transposed pin nos, GIDs, etc (accommodated on a best efforts basis and all parties involved in chain must approve)
• EPSQ/system balanced issues • System issues • Schedule change in order to allocate gas.
Not Acceptable Reasons for Retros
• Customer requests made outside of the 7 day window. • Doing new business after the last cycle has ended • If the correction removes a penalty • To increase volume through a restriction • Request that would put any party or meter further out
of balance with the pipeline • Reallocation of supply and/or market after gas day is
complete
BACKHAUL FUEL OVERRIDE CHANGES
TGP holds Quarterly meetings to review system operations. Rate Schedules; Rate Schedule FT-A; Subsection 5.5 Fuel and Losses “….. The quantity of gas retained by Transporter for Fuel and Losses shall be equal to the quantity of gas scheduled for delivery to Transporter multiplied by the applicable F&LR percentage shown in the Summary of Rates and Charges in Transporter’s effective FERC Gas Tariff for the zone of receipt and zone of delivery applicable to the transportation service. However, for service that is rendered entirely by displacement and for gas scheduled and allocated for receipt at the Dracut, Massachusetts receipt point, Shipper shall furnish only that quantity o f gas associated with Losses as shown in the Summary of Rates and Charges in Transporter’s FERC Gas Tariff. ….” The losses component of the F&LR is equal to 0.01% effective April 1, 2017.
BACKHAUL FUEL OVERRIDE CHANGES
Backhaul Fuel Override Paths • Station 267 to Station 237 (Segment 266, Segment 265, Segment 261, Segment 260, Segment
256, Segment 249, Segment 245, Segment 241, Segment 237) • Niagara Spur North to South (Segment 296, Segment 295) • MLV 336 to Station 319 (Segment 324, Segment 321, Segment 320, Segment 394, Segment
319) • Station 219 to Station 318 (Segment 300, Segment 307, Segment 313, Segment 314, Segment
315, Segment 316, Segment 317, Segment 318) • Station 230 to Station 219 (Segment 224, Segment 219) • Station 87 to Station 219 (Segment 187, Segment 200, Seg 204, Seg 209, Seg 212, Seg 214,
Seg 216, Seg 217) • STA 110 to East End of WV Lateral (Segment 111 FH, Segment 112 BH, Segment 114 FH) • Station 834 to Station 87 (Segment 834, Segment 847, Segment 860) • Station 534 to Station 860 (Segment 534, Segment 542, Segment 548) • Carthage Lateral (from Station 40 to the end of the lateral) (Segment 700 from mainline to
End of lateral) • Station 40 to Station 32 (Segment 132) – delete this backhaul fuel group entirely • Station 409 to STA 40 (Segment 409, Segment 101, Segment 109, Segment 117, Segment
125, Segment 132)
STAFF HOURS
Staffing Hours Regular work hours from 7:30 AM until 4:30 PM Call After Hours line for any questions after 4:30 PM 713-420-4999
Weekends, After Hours, Holidays from 7:30 AM until 10:00 PM Call After Hours line for any questions 713-420-4999
After 10:00 PM call Gas Control 1-800-231-2800