southern natural gas winter review - kinder morgan · nov dec jan feb mar 2014/15 2015/16 2016/17...
TRANSCRIPT
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1
Southern Natural Gas
Winter Review
May 2019
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2
Agenda
• Operations Review
• Summer Maintenance Update
• Scheduling Review & Dart Updates
• Open Discussion
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3
Operations Review
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Gas Control Organizational Structure
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Gas Control Organizational Structure
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Gas Control Organizational Structure
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Winter Review • SNG’s facilities performed well during this winter
– Compressor stations staffed 24x7 as needed
– Horsepower reliability
• Overall average winter with milder temperatures
• Storage assets were heavily utilized. Extended customer withdrawals through March
• Peak Day – January 30, 2019
– Peak Day Throughput: 4,105,000
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Average Daily Deliveries (Nov – Mar)
1,338 1,228
1,428 1,306
1,049 1,222
1,326 1,375 1,156 1,097
1,330 1,358
228 403
420 509
800
914 716
951
921 957
952 882
203 194
222 240 256
245 231
238
229 205
202 208
479 305
378 381 298
286 312
292
310 448
579 582
2,248 2,130
2,448 2,436 2,403
2,667 2,585
2,856
2,616 2,707
3,063 3,030
-250
250
750
1,250
1,750
2,250
2,750
3,250
2007/08 2008/09 2009/10 2010/11 2011/12 2012/13 2013/14 2014/15 2015/16 2016/17 2017/18 2018/19
Md
th/d
LDC Power Industrial Interconnects
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Winter Heating Degree Days (HDDs*) 2013-2019
November December January February March
2014/15 448 479 646 671 230
2015/16 253 267 665 456 157
2016/17 212 451 361 236 247
2017/18 293 548 732 204 334
2018/19 410 524 597 332 306
30 Year Average 326 538 596 455 286
0
100
200
300
400
500
600
700
800Polar Vortex
*HDD = 65 Degrees Minus System Mean Temperature
HD
Ds
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Winter Average Daily Power Demand
Md
th/d
0
200
400
600
800
1,000
1,200
Nov Dec Jan Feb Mar
2014/15 2015/16 2016/17 2017/18 2018/19
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Winter Average Daily LDC Demand
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
Nov Dec Jan Feb Mar
2014/15 2015/16 2016/17 2017/18 2018/19
Md
th/d
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Average January Daily Deliveries 2011-2019
1,660
1,236 1,248
1,722 1,603 1,595
1,211
1,768 1,637
612
820 811
793 957 933
862
1,029
867
392
303 294
329 327 354
538
612
574 247
262 248
228 242 217
203
187
214 2,911 2,621
2,601
3,072 3,129 3,099
2,814
3,596
3,292
0
100
200
300
400
500
600
700
800
900
0
500
1,000
1,500
2,000
2,500
3,000
3,500
2011 2012 2013 2014 2015 2016 2017 2018 2019
HD
Ds M
dth
/d
LDC Power Interconnects Industrial HDDs
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Average Daily Deliveries* (Nov- March)(MDth/d)
2019 Nov-
Mar
2018 Nov-
Mar % Change
LDC 1,358 1,330 2.1%
Power 882 952 -7.3%
Industrial 208 202 2.8%
Interconnects 582 579 0.5%
TOTAL 3,030 3,063 -1.1%
*EXCLUDES DELIVERIES INTO STORAGE
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Customer Storage Inventory Levels
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Summer Maintenance
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Maintenance Planning Process Typical Types of Maintenance Work
Compressors: • ESD and safety tests • Emission tests • Run-hour inspections &
maintenance to insure reliability
• Various engine/compressor repairs
Integrity Management: • Various pig runs (ILI) • Remediation of
anomalies • Hydrotests • Selected wrinkle bend
replacements
3rd Party Needs: • Class location changes • Line relocations • Expansion projects Storage Field: Shut-in tests & maintenance – spring & fall
• Gas Control models impact to capacity and compares to expected flow to determine best outage windows
• Goal is to avoid impact to firm service or coordinate with impacted customers to manage the impact
• Plan may be adjusted for unscheduled outages, multiple outages, availability of equipment and contractors, and weather
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2019 Maintenance
Monthly Outage Call
• 3rd Wednesday of the month at 1:30 pm CST
Overview # of jobsSystem total 714
Posted 91Posted(with possible impact) 63Posted(no impact expected
but risks could develop) 28
South Main lines 11North Main lines 16Other lines 41
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Maintenance • Ongoing -
Fairburn Unit 1 = Limited to 210Mdth/d
South Section 28 Force Majeure RTS to be determined
• Upcoming -
North Main Line Segment 110 McConnells 4/24 – 5/1 = 223 Mdth/d
East Gadsden Line Hydro testing 6/24 – 7/15 = Line out of service
Ocmulgee Compressor Station unit maintenance 6/1 – 10/31 = 72 Mdth/d
Enterprise Compressor Station unit maintenance 9/2 – 9/27 = 177 Mdth/d
• Completed -
Muldon and Bear Creek Spring Test are complete
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SNG North System Maint. Review Remainder of Year
LA
MS
AL
GA
Logansport
Bienville
Bear Creek Storage
Onward
Pickens
Rankin
Louisville
Muldon Storage
Reform
McConnells
Providence
Tarrant Pell City
DeArmanville
Bell Mills
Rome
Compressor Station
Storage Field
Huntsville
Chattanooga
Atlanta
Southern will be conducting other general maintenance during this period
AL
Pigging 14” Logansport line last half of year, dates TBD
Bear Creek Shut-in test 10-15-19 to 9 AM 10-22-19
DIQ and DWQ allocated 64%
Muldon Shut-in test 10-1-19 to 10-7-19
DIQ and DWQ allocated 36%
Pigging NMLL (37081)
8-27-19 & 8-29-19
Pigging 2ndNML(37000) 7-22-19,
7-23-19, and 7-25-19.
Pigging Bessemer Calera loop line(37079) last half of year,
dates TBD
Pigging Logansport loop line last half of year, dates TBD
Pigging Montgomery
Columbus line(37012) last half of the year , dates TBD.
Maint. At Logansport and
Bienville in the fall, date TBD
Remediation on Gwinville
Pickens loop line last half of year, dates TBD. Seg. 400
capacity of 234 Mdth/d reduced up to 67 Mdth/d
Pigging NMLL(37017)
8-20-19, 8-21-19, 8-23-19, and 8-26-19..
Hydro-Test on Bessemer Calera line(37025) 8-5-19 to 8-19-19
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SNG South System Maint. Review Remainder of Year
MS
AL
GA
Enterprise
Gwinville
Selma
Auburn
Ellerslie
Thomaston
Ocmulgee
Hallgate
Wrens
Elmore
York
Gallion
Bay Springs
Compressor Station
Storage Field
LNG
Atlanta
Elba
Hartwell
Aiken
Holy Trinity
Albany
Pavo
Brookman
Riceboro
Southern will be conducting other general maintenance during this period
Pigging SM3rdLL(37077) East of Enterprise 8-13-19 & 8-15-19
Pigging SMLL(37080) east of Gallion 7-8-19, 7-9-19,
& 7-11-19
Pigging Graniteville Expansion line(37006)
7-16-19 & 7-18-19
Pigging SM2ndLL(37019) East of Ocmulgee
7-23-19, 7-24-19, & 7-25-19
Pigging Gwinville Pickens loop line(37049)
7-22-19 to 8-2-19
Pigging Montgomery #2 line(37085)
3rd Qtr. Dates TBD
Unit Maint. At Enterprise 9-2-19 to 9-27-19. Seg. 430 capacity of 2,283
Mdth/d reduced up to 177 Mdth/d
IT & OOP could be impacted
Remediation on the Douglas line 37(37007) September, dates TBD
P/L maintenance on Main line 01(37518)-October,
dates TBD Sta. Maint. At Gwinville
October timeframe Dates TBD Seg. 410
capacity of 1,658 Mdth/d reduced up to 270 Mdth/d
IT & OOP could be impacted
Remediation on the Marietta Branch line
Last half of year, dates TBD
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SNG South Louisiana System Maint. Review Remainder of Year
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New Outage Impact Report
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Scheduling Review & Dart Updates
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Eastern Region TSS Management Team
Gina Mabry
Director-Scheduling
Transportation/Storage Services
Houston Headquarters
Katie Cornutt
Manager-Scheduling
Transportation/Storage Services
Houston Headquarters
Adam Harris
Manager-Scheduling
Transportation/Storage Services
Houston Headquarters
Cathy Soape
Manager-Scheduling
Transportation/Storage Services
Houston Headquarters
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SNG Winter 2018/2019 Segment Constraints (November-March)
Segment Location Days Impacted
30 ONWARD 26
90 DUNCANVILLE LATERAL 70
130 TARRANT To PELL CITY 8
150 CHAT LINE ROME TO WHITFIELD 9
160 ATLANTA NORTH 5
180 Chat Line Rome To Whitfield Ct 9
380/SESH Lateral SNG-SESH LATERAL 82
400 PICKENS TO GWINVILLE 28
430 ENTERPRISE TO ZONE 1/2 BNDARY 7
490 ELLERSLIE 15
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Winter Restrictions Percentage Days Restricted
(November - March)
Restriction Point Highly Utilized SNG Paths
Percentage Days Restricted (November - March)
Percentage Days Restricted (November - March)
Percentage Days Restricted (November - March)
2016/2017 2017/2018 2018/2019
Segment 30 0.00% 18.54% 17.22%
Segment 90/Duncanville Lateral N/A N/A 46.35%
Segment 130 0.00% 0.00% 5.30%
Segment 150 0.00% 0.00% 5.96%
Segment 180 0.00% 0.00% 5.96%
Segment 380/SESH Lateral 4.64% 1.32% 54.31%
Segment 400 0.00% 19.21% 18.54%
Segment 490 7.95% 14.57% 9.93%
American Midstream Duncanville 1.99% 21.19% 22.52%
Columbia Gulf 0.66% 13.91% 10.60%
East Tenn Whitfield 0.00% 0.00% 9.27%
Thomson/SNG Jefferson 0.00% 7.28% 5.30%
AGL/SNG Thomaston 0.00% 1.32% 5.30%
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SNG Pathing for Fairburn • Transco Fairburn Pin 50069 is the only receipt pin on the Fairburn
Lateral and will primarily flow south
– Default Route is from Seg 510 to the South Mainline and then east or west (and up Seg 400 to the North Mainline)
• An exception route for a limited quantity has also been set up to allow nominations from the Transco-Fairburn interconnect from Seg 510 to the North Mainline via Seg 160 and ending at Seg 80
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Petal Nomination Changes • Effective May 1, 2019, Southern will be utilizing two pins for
nominations at the Petal Storage Interconnect:
– 606200 – Gulf South/SNG Petal Clarke Receipt – will be utilized for Receipt (Withdrawal) nominations
– 606210- Gulf South/SNG Petal Clarke Delivery-will be utilized for Delivery (Injection) nominations
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Proposed Segment Name Changes
• Changes expected to be implemented in the 3rd Quarter of 2019
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Type 3 OFO Factors • Type 3 Operational Flow Orders (OFOs) are implemented when
demand in an area of the system is forecasted to exceed capacity
– OFOs are used to protect primary firm services
– System conditions dictate the level of interruptible reductions and OFOs
needed
• Factors SNG considers when evaluating whether Type 3 OFO penalties need to be implemented: – Weather Forecast – system means in the mid-40’s and mid-80’s are where demand starts
to approach capacity
– Day of week – weekday demand exceeds weekend/holiday demand
– Expected duration of heavy demand
– Recent history
– Nominated deliveries
– Actual takes from the system higher than entitlements
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Protecting System Integrity • SNG’s objective is to provide reliable service and protect our
firm commitments
• SNG’s Type 3 OFO
– For daily quantities taken in excess of the Shipper’s Daily Entitlement plus a stated tolerance
– Penalties are assessed only after a variety of group, shipper, and agent checks
– The current penalty as of December 2018 now includes the price of gas as a component
• Level 1 - $10
• Level 2 - $15 + Highest Regional Daily Price
• Level 3 - $25 + 2x Highest Regional Daily Price
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Type 3 OFO Winter Count* (November- March)
2016/17 2017/18
2018/19
Type 3 Level 1 7 2 25
Type 3 Level 2 12 36 10
Type 3 Level 3 0 0 0
Total 19 38 35
* Number of days OFO was in effect for any group(s) on the system
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DSR Scheduling Contacts Phone Email Ice Chat Handle
Gina Mabry, Director Transportation
and Storage Services (713) 420-3685 [email protected]
Katie Cornutt, DSR Manager (713) 420-5648 [email protected]
Walker Agnew (713) 420-6059 [email protected] Wagnew
Krysta Henry (713) 420-3023 [email protected] Khenry4
Adam Ivy (713) 369-8922 [email protected] AIvy
Tracy Minter (713) 420-7030 [email protected] Tminter
Carol Whatley (713) 420-3889 [email protected] CWhatley
SNG Hotline
(713) 420-7213 [email protected]
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WEARS Scheduling Contacts Cathy Soape, WEAR Manager (713) 420-3814 [email protected] Ice Chat Handle
Mandey Allen (713) 369-9369 [email protected] Mallen11
Virginia (Ginger) Bryan (713) 420-6135 [email protected] Gbryan5
Todd Davis (205) 325-7440 [email protected] Tdavis23
Charlotte Hawkins (713) 420-4873 [email protected] Chawkins4
Nicole Lang (713) 420-5992 [email protected] Nlang
Phyllis Miller (713) 420-3738 [email protected] Pmiller7
Ahsan Mohammad (713) 420-5644 [email protected] Amohammad
Jill Overman (713) 420-3450 [email protected] Joverman
Jeremy Rainwater (713) 420-6385 [email protected] Jrainwater
David (Scott) Sokira (205) 325-7313 [email protected] Ssokira
Debra (Debbie) Tweedy (713) 420-5289 [email protected] Dtweedy
Norma Villarreal (713) 420-3924 [email protected] Nvillarreal
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Contract Administration Contacts:
Sherry Noack, Manager
(713) 420-3764 [email protected]
Shari Jones (713) 420-3710 [email protected]
Marquette Williams (713) 369-9336 [email protected]
Natarsua Player (713) 369-9871 [email protected]
Lindsay Sanford
(713)420-2382 [email protected]
SNG Contract Administration Hotline
(713) 420-4455
SNG Contracts Contacts
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Commercial Contacts
Carl Haga, VP, Commercial
(205) 325-7544 [email protected]
Darryl Outlaw, Director, Commercial (205) 325-7421 [email protected]
Walter Coe (205) 325-3708 [email protected]
Lisa Guthrie (205) 325-3816 [email protected]
Jerry Nelson (205) 325-7257 [email protected]
On call Account Manager
(800) 315-0575
SNG Commercial Contacts
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SNG Gas Control Contacts
Gas Control Contacts:
Maurice (Reese) Hart III, Manager
(713) 420-4774 [email protected]
Kal Dankovich, Outage Coordinator (713) 420-7522 [email protected]
Jimmy Reese, Lead Controller (713) 420-7310 [email protected]
Daniel Mitchell, Lead Controller (713) 420-5874 [email protected]