Southern Star Central Gas Pipeline, Inc
Southern Star Central Gas Pipeline, Inc
Southern Star Central Gas Pipeline, Inc
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<strong>Southern</strong> <strong>Star</strong> <strong>Central</strong> <strong>Gas</strong> <strong>Pipeline</strong>, <strong>Inc</strong>.<br />
Notice ID: 3653 Critical Notice Indicator: N Notice Status: Initiate Posted Date/Time: 10/20/2010 10:45:00 AM<br />
Notice Type: Non-Critical Notice Eff Date/Time: 10/20/2010 10:45:00 AM Reqrd Rsp: No Response Required Duns Number: 007906233<br />
<strong>Southern</strong> <strong>Star</strong> <strong>Central</strong> <strong>Gas</strong> <strong>Pipeline</strong><br />
FALL CUSTOMER MEETING<br />
OCTOBER 12, 2010<br />
INTERCONTINENTAL, KANSAS CITY AT THE PLAZA
Jerry Morris<br />
2<br />
PRESIDENT &<br />
CHIEF EXECUTIVE OFFICER
• Industry Facts<br />
<strong>Pipeline</strong> Integrity & Safety<br />
◦ Interstate Transmission = 220,000 miles<br />
◦ Total <strong>Pipeline</strong> – 2.4 million miles<br />
◦ Congress enacted <strong>Pipeline</strong> Safety Act in 1968<br />
3<br />
◦ <strong>Pipeline</strong> Transportation is The Safest Form of Interstate<br />
Transportation Regulated by DOT (PHMSA)<br />
◦ Intrastate (PG&E) largely Regulated by States (DOT proposed<br />
DIMP in 2008)<br />
◦ <strong>Pipeline</strong> Safety Improvement Act of 2002 Mandated Integrity<br />
Management Program (IMP) for Transmission Lines<br />
◦ By the End of 2012,100% of HCA’s and 65% of Total Interstate<br />
Miles will have been assessed
• <strong>Southern</strong> <strong>Star</strong> Facts<br />
<strong>Pipeline</strong> Integrity & Safety<br />
◦ Total Miles of <strong>Pipeline</strong> – 5,900<br />
◦ Total Miles within High Consequence Areas (HCA’s) – 168<br />
◦ 81% of HCA Assessments Complete by End of 2010<br />
◦ Approximately 1,900 Total Miles will have been Assessed by<br />
End of 2010<br />
◦ <strong>Southern</strong> <strong>Star</strong> 2010 Integrity Expenditures<br />
$14 Million in Capital Projects<br />
$10 Million in Assessment Expense<br />
4
<strong>Southern</strong> <strong>Star</strong> – The Vision<br />
5
Legislative and Political Outlook<br />
Heading into 2010 Mid-Term Elections<br />
IMPLICATIONS FOR THE NATURAL<br />
GAS PIPELINE INDUSTRY<br />
6<br />
VICE PRESIDENT, LEGISLATIVE AFFAIRS<br />
INTERSTATE NATURAL GAS ASSOCIATION OF AMERICA<br />
Martin Edwards<br />
<strong>Southern</strong> <strong>Star</strong> <strong>Central</strong> Customer Meeting<br />
October 12 th , 2010
Gone Fishing – Congress Stands in Recess Until After<br />
the Elections<br />
• As anticipated, it was a slow summer for Congress<br />
legislatively. While Congress was able to complete<br />
Wall Street regulatory reform, pass a small business<br />
lending bill, and confirm a new Supreme Court<br />
justice, many high profile issues fell by the wayside<br />
due to election year politicking.<br />
• Outstanding must-pass legislative items will have to<br />
wait until after the November 2 nd elections.<br />
• Congress will return for a weeklong “lame duck”<br />
session from Nov. 15-19, with a second brief session<br />
in December also possible.<br />
7
The Lame Duck Session<br />
8<br />
• The primary focus of the lame duck will be to address<br />
spending bills needed to keep the government running.<br />
Congress was not able to pass any of the 12 annual<br />
appropriations bills needed to fund the government prior to<br />
recessing for the elections.<br />
• A continuing resolution was passed which funds<br />
government agencies at FY10 levels until Dec. 3 rd .<br />
• A second CR could be passed to fund the government at<br />
current levels into next spring, or Congress could combine<br />
multiple spending bills, setting new funding levels, into a<br />
large omnibus package.
The Lame Duck Session (cont.)<br />
• Beyond dealing with appropriations, Congress will take<br />
up the issue of expiring tax cuts. It is likely that tax cuts<br />
for the middle class will be extended, but cuts for higher<br />
income earners may be allowed to expire. Without some<br />
action by Congress, all tax cuts would expire on Jan. 2,<br />
2011.<br />
• Some action on energy and climate related issues is<br />
possible. Sen. Bingaman (D-NM) has expressed a desire<br />
to bring a renewable electricity mandate bill to the floor.<br />
Sen. Reid also plans to hold a vote on a bill incentivizing<br />
the purchase of natural gas vehicles.<br />
9
Potential Action on <strong>Pipeline</strong> Related Issues<br />
10<br />
• A comprehensive climate change bill is dead for this year –<br />
and likely for the next Congress as well.<br />
• A bill from Sen. Jay Rockefeller (D-WV) to block EPA from<br />
regulating greenhouse gases from industrial/power sources<br />
for two years has gained steam in the Senate and likely has<br />
the needed 60 votes to pass. Timing for a vote on the bill is<br />
a wildcard, but look for Republicans to attempt to attach it<br />
to spending or other “must-pass” legislation.<br />
• If a pipeline safety reauthorization is not passed during the<br />
lame duck, it will be an ongoing issue for 2011 and the next<br />
Congress.
<strong>Pipeline</strong> Safety<br />
• The Enbridge and San Bruno accidents have created a greater<br />
interest and urgency to this issue.<br />
• House and Senate committees of jurisdiction have held many<br />
recent hearings and several bills have been introduced.<br />
11<br />
‣ Feinstein/Boxer bill – would require automatic shut off valves for pipelines<br />
and would prevent pipelines from operating at high pressure unless they are<br />
internally inspected by smart pigs. Viewed as being heavy on new mandates.<br />
‣ Rockefeller/Lautenberg bill – would increase civil penalties for violations of<br />
pipeline safety law, require automatic shut off valves, and eliminate local<br />
exemptions from state “one call” programs. Generally considered a<br />
reasonable compromise bill.<br />
‣ Administration bill – lacks the “one call” provisions, but authorizes 40 new<br />
pipeline inspectors for PHMSA. Generally viewed as the more modest of the<br />
proposed bills.<br />
‣ If a consensus can be reached in the Senate Commerce<br />
Committee, then action during the lame duck is possible, but still<br />
a long shot, given the crowded calendar and short time frame.
Political Factors Heading into the Mid-Term<br />
12<br />
• Dissatisfaction over unemployment and the state of<br />
the economy are the overriding factors heading into<br />
the election.<br />
• Anti-Washington and anti-establishment sentiment<br />
are also running high, threatening incumbents and<br />
candidates backed by the national parties on both<br />
sides.<br />
• The result may be a step back from attempting to<br />
enact big programs with big costs and major<br />
regulations (e.g., cap-and-trade).
Are Energy/Climate Issues Important to Voters<br />
13
Public Opinion & <strong>Pipeline</strong> Safety<br />
• A recent poll found that 56% of Americans are at least somewhat<br />
concerned about the safety of natural gas pipelines, but opinions vary<br />
about who would do a safer job operating natural gas pipelines.<br />
14<br />
20%<br />
12%<br />
68%<br />
Source: Rasmussen Reports poll, Sept. 2010
Is a Wave Election Coming<br />
15<br />
• Polling continues to support that this will be a bad election<br />
for the Democrats. The chart below reflects the percentage<br />
of Americans who would currently vote to re-elect their<br />
member of Congress, versus voting for someone else.<br />
31%<br />
Source: Washington Post/ABC News poll, Sept. 2010
Is a Wave Election Coming (cont.)<br />
16<br />
• Democrats currently hold a 38 seat advantage in the House.<br />
In mid-term elections during the President’s first term, his<br />
party almost always loses seats. This year will be no<br />
exception, and the Republicans are well-positioned to pick<br />
up enough seats to take back the House.<br />
• In the Senate, the Democrats are in a better position to<br />
keep their majority, but are still likely to lose 6 to 8 seats,<br />
giving them a very thin working majority.<br />
• Candidates such as Christine O’Donnell (DE) and Joe<br />
Miller (AK) are making a Republican Senate takeover more<br />
difficult, but not impossible.
Most Vulnerable Senate <strong>Inc</strong>umbents<br />
17<br />
• Sen. Blanche Lincoln (D-AR) – Lincoln sits atop the list of<br />
Democrats who appear to be on their way out. Recent polling shows<br />
her trailing by anywhere between 10 and 25 points to Republican<br />
Rep. John Boozman. Lincoln has been a strong natural gas industry<br />
supporter and her loss will be costly.<br />
• Sen. Michael Bennet (D-CO) – Recent polling shows Bennet<br />
narrowly leading his opponent, but the race is within the margin of<br />
error. Bennet appears to suffer from the fact that he was appointed,<br />
rather than elected, when former Sen. Ken Salazar resigned to<br />
become Interior Secretary.<br />
• Sen. Harry Reid (D-NV) – The Majority Leader finds himself in a<br />
much closer than expected race, mainly due to an anti-Washington<br />
sentiment among his constituents, and the fact that his role as the<br />
Democratic leader prevents him from taking more centrist<br />
positions. Recent polls show his race with Tea Party candidate<br />
Sharron Angle a statistical tie, as both candidates are highly<br />
unpopular and gaffe prone.
Most Vulnerable Senate <strong>Inc</strong>umbents (cont.)<br />
• Sen. Barbara Boxer (D-CA) – California’s economic crisis and an<br />
anti-incumbent mentality are providing Sen. Boxer with her<br />
toughest race in years. Former Hewlett Packard CEO Carly<br />
Fiorina has name recognition and the ability to raise money<br />
which has made this a top tier race. Recent polls show Boxer<br />
ahead by 5 to 7%, but the race is likely to stay tight.<br />
• Sen. Russ Feingold (D-WI) – The three term incumbent from<br />
Wisconsin is trailing in his race, by as much as 12% according to<br />
recent polls. His support of the stimulus package and health care<br />
reform are exposing him to charges of excessive spending. This<br />
close race is the most surprising.<br />
• Sen. Patty Murray (D-WA) – Recent polls have this race too<br />
close to call. Murray is a senior member of the Democratic<br />
leadership which is harming her in a race against a well funded<br />
Washington outsider in an anti-incumbent year.<br />
18
What If…How Political Changes Could Impact<br />
the Natural <strong>Gas</strong> Industry<br />
19<br />
• If Republicans take the Senate, Sen. McConnell (KY) would be<br />
Majority Leader. Should the Democrats keep their majority, but<br />
Sen. Reid lose his race, Sen. Durbin (IL) or Sen. Schumer (NY) are<br />
likely replacements as Majority Leader.<br />
• Sen. Murkowski’s primary loss and subsequent write-in campaign<br />
have placed her ranking member roll on the Senate Energy<br />
Committee in doubt. If she loses, Sen. Richard Burr (R-NC) is likely<br />
to take her place. His positions on natural gas are largely unknown,<br />
but he is likely to focus on nuclear issues primarily.<br />
• The Senate Environment Committee would be led by Sen. Inhofe<br />
(R-OK) if the Republicans capture the Senate. If Sen. Boxer loses<br />
her race, Sen. Carper (D-DE) would take her place. He is more<br />
moderate and has a reputation for bipartisan work.
What If…How Political Changes Could<br />
Impact the Natural <strong>Gas</strong> Industry<br />
• If the Republicans take back the House, current Minority Leader John<br />
Boehner (OH) would become Speaker.<br />
• On the Energy and Commerce Committee, Rep. Fred Upton (MI) is<br />
likely to replace Joe Barton as either ranking member or Chairman.<br />
Upton has a good understanding of the natural gas industry and is a<br />
strong supporter.<br />
• Current Energy and Commerce Committee Chairman Henry Waxman<br />
(CA) would likely become the ranking member.<br />
• No changes to the Natural Resources Committee leadership are<br />
expected; chair would switch to Rep. Doc Hastings (R-WA) if the<br />
Republicans take back the House.<br />
20<br />
• House Transportation Committee (pipeline safety issues) would be led<br />
by Rep. John Mica (FL) in a Republican House; Rep. Jim Oberstar<br />
(MN) would remain the senior Democrat.
Dave Roberts<br />
21<br />
MANAGER,<br />
REGULATORY AFFAIRS
Recent Tariff Filings<br />
22<br />
FERC<br />
Docket No. Filing Type Filed Approved<br />
• RP10-514 Miscellaneous Tariff Filing 3/26/10 4/29/10<br />
• RP 10-636 Updated System Maps 4/26/10 5/27/10<br />
• RP10-796 eTariff Baseline Filing 6/1/10 7/27/10<br />
• RP10-1040 Third Party Storage Providers 8/2/10 8/31/10<br />
(Deferral)<br />
• RP10-1176 NAESB Version 1.9 Standards 9/1/10 ______
Upcoming Tariff Filings<br />
23<br />
Misc. Tariff Filing<br />
• Receipt point pressure commitments<br />
• Waiver of minor interest charges<br />
• Remove outdated language regarding imbalances related to MSQ<br />
• Update of various line segment numbers<br />
New Date for Fuel Filing<br />
• Current fuel rates will continue until April 1, 2011.<br />
• Fuel filing is required no later than March 1.
Elk City Storage Expansion Update<br />
Docket No. CP10-2<br />
FERC Order issued May 20, 2010 allows for:<br />
24<br />
• installation and operation of new compressor<br />
• increases field’s working gas capacity by 2.6 Bcf<br />
• increases field’s deliverability by 40,000 Mcf/day<br />
• allows for market-based rates<br />
• requires separate accounting to ensure no cross-subsidization<br />
• authorized 0.7 Bcf of ISS service until expansion capacity is available<br />
• credit 1.9 Bcf of gas to existing customers as of April 1, 2011 (MSQ)
Elk City Storage Expansion Update<br />
Docket No. CP10-2<br />
FERC Order issued May 20, 2010 disallowed:<br />
25<br />
• the conversion of 1.4 Bcf of base gas to working gas<br />
SSC filed an Amended Application requesting the 1.4 Bcf conversion and<br />
the rights to the proceeds from the sale of the base gas.<br />
FERC’s decision pending.
Doug Field<br />
26<br />
MANAGER,<br />
COMPLIANCE
Update on Non-Conforming Contracts<br />
• FERC’s October 22, 2008 Audit Order (Docket PA08-1) required<br />
<strong>Southern</strong> <strong>Star</strong> to address its non-conforming service agreements<br />
◦ Many customers were asked to sign amendments to conform their<br />
contracts with the pro forma agreements in the tariff<br />
◦ <strong>Southern</strong> <strong>Star</strong> made the necessary compliance filings<br />
Quarterly Reports<br />
March 20, 2009 Master List of Contracts<br />
September 28 Update of Master List<br />
• On August 17, 2010 FERC issued letter order in Docket RP09-<br />
1090 accepting the filing of <strong>Southern</strong> <strong>Star</strong>’s service agreements<br />
“in satisfactory compliance” with the 2008 Audit Order.<br />
27
Update on Non-Conforming Contracts<br />
• FERC’s October 22, 2008 Audit Order (Docket PA08-1) required<br />
<strong>Southern</strong> <strong>Star</strong> to address its non-conforming service agreements<br />
◦ Many customers were asked to sign amendments to conform their<br />
contracts with the pro forma agreements in the tariff<br />
◦ <strong>Southern</strong> <strong>Star</strong> made the necessary compliance filings<br />
Quarterly Reports<br />
March 20, 2009 Master List of Contracts<br />
September 28 Update of Master List<br />
• On August 17, 2010 FERC issued letter order in Docket RP09-<br />
1090 accepting the filing of <strong>Southern</strong> <strong>Star</strong>’s service agreements<br />
“in satisfactory compliance” with the 2008 Audit Order.<br />
28<br />
Thank you for your help bringing this issue to closure.
NAESB Version 1.9<br />
29<br />
• NAESB Version 1.9 Implementation Timeline<br />
◦ NOPR on Index Based Rates (IBR)for Capacity<br />
Release issued July 16, 2009 in RM96-1-30<br />
◦ NOPR on NAESB 1.9 issued November 19, 2009 in<br />
RM96-1-036<br />
◦ Order 587-U Adopting NAESB 1.9 (including IBR<br />
pricing for capacity release) issued 3/24/2010<br />
<strong>Pipeline</strong> Tariff filings due September 1, 2010<br />
Tariff Sheets implementing NAESB 1.9 to be<br />
effective November 1, 2010
<strong>Southern</strong> <strong>Star</strong> NAESB 1.9 Timeline<br />
• <strong>Southern</strong> <strong>Star</strong>’s Original Filing<br />
o Tariff Sheets filed September 1, 2010 in RP10-1176<br />
o Proposed effective date of October 20, 2010<br />
• Requesting an extension this week<br />
o Need for additional testing to verify that all NAESB 1.9<br />
changes work properly<br />
o Requesting up to 60 days extension to fully implement<br />
NAESB 1.9<br />
o Goal is to implement sooner rather than later<br />
30
Major Changes in NAESB 1.9<br />
31<br />
FERC Commissioner John Norris<br />
summed up NAESB 1.9 as follows:<br />
“This Final Rule adopts important new consensus business practice<br />
standards for pipelines that provide consistency in the use of rateindices<br />
to price capacity releases, allow new flexibility for pipeline<br />
shippers to redirect their natural gas, and establish more uniform<br />
reporting of gas quality information. …<br />
In particular, the new standards provide additional flexibility in receipt<br />
and delivery points to enable shippers, including gas-fired generators,<br />
to quickly and efficiently redirect gas to where it is needed.”
Major Changes in NAESB 1.9<br />
32<br />
FERC Commissioner John Norris<br />
summed up NAESB 1.9 as follows:<br />
“This Final Rule adopts important new consensus business practice<br />
standards for pipelines that provide consistency in the use of<br />
rate-indices to price capacity releases, allow new flexibility for<br />
pipeline shippers to redirect their natural gas, and establish more<br />
uniform reporting of gas quality information. …<br />
In particular, the new standards provide additional flexibility in receipt<br />
and delivery points to enable shippers, including gas-fired generators,<br />
to quickly and efficiently redirect gas to where it is needed.”
Major Changes in NAESB 1.9<br />
33<br />
FERC Commissioner John Norris<br />
summed up NAESB 1.9 as follows:<br />
“This Final Rule adopts important new consensus business practice<br />
standards for pipelines that provide consistency in the use of rateindices<br />
to price capacity releases, allow new flexibility for<br />
pipeline shippers to redirect their natural gas, and establish<br />
more uniform reporting of gas quality information. …<br />
In particular, the new standards provide additional flexibility in receipt<br />
and delivery points to enable shippers, including gas-fired generators,<br />
to quickly and efficiently redirect gas to where it is needed.”
Major Changes in NAESB 1.9<br />
34<br />
FERC Commissioner John Norris<br />
summed up NAESB 1.9 as follows:<br />
“This Final Rule adopts important new consensus business practice<br />
standards for pipelines that provide consistency in the use of rateindices<br />
to price capacity releases, allow new flexibility for pipeline<br />
shippers to redirect their natural gas, and establish more uniform<br />
reporting of gas quality information. …<br />
In particular, the new standards provide additional flexibility in receipt<br />
and delivery points to enable shippers, including gas-fired generators,<br />
to quickly and efficiently redirect gas to where it is needed.”
Major Changes in NAESB 1.9<br />
35<br />
FERC Commissioner John Norris<br />
summed up NAESB 1.9 as follows:<br />
“This Final Rule adopts important new consensus business practice<br />
standards for pipelines that provide consistency in the use of rateindices<br />
to price capacity releases, allow new flexibility for pipeline<br />
shippers to redirect their natural gas, and establish more uniform<br />
reporting of gas quality information. …<br />
In particular, the new standards provide additional flexibility in receipt<br />
and delivery points to enable shippers, including gas-fired generators,<br />
to quickly and efficiently redirect gas to where it is needed.”
NAESB 1.9 Highlights<br />
• Capacity Release Changes:<br />
◦ New Definitions 5.2.4 and 5.2.5;<br />
◦ Revised Standards 5.3.1 thru 5.3.3 and 5.3.26 and New Standards<br />
5.3.61 thru 5.3.69<br />
◦ Revised Data Sets 5.4.1; 5.4.2; 5.4.3; 5.4.7; 5.4.9 and 5.4.18<br />
◦ These Capacity Release Changes …<br />
Implement index based rates (IBR) for capacity release<br />
Reflect the removal of the price cap for short term releases<br />
Standardize how AMA releases are done<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Significant revisions to all CSI screens related to capacity release<br />
◦ Anyone using EDI will also have to adopt new data sets<br />
◦ Major changes for all shippers using capacity release<br />
36
NAESB 1.9 Highlights<br />
• Redirection of Scheduled Quantities:<br />
◦ New Standard 1.3.80<br />
◦ To the extent other scheduling requirements are met, pipelines<br />
should support the redirect of scheduled quantities to other receipt<br />
points upstream of a constraint point or delivery points<br />
downstream of a constraint point at any subsequent nomination<br />
cycle for the subject gas day, at least under the same contract,<br />
without requiring the quantities to be rescheduled through the<br />
point of constraint.<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Provides more flexibility once a customer is scheduled through a<br />
constraint point<br />
37
NAESB 1.9 Highlights<br />
• <strong>Gas</strong> Quality Informational Postings:<br />
◦ Revised Standards 4.3.90 and New Standards 4.3.95 thru 4.3.98<br />
◦ New 4.3.96 thru 4.3.98 do not apply to <strong>Southern</strong> <strong>Star</strong><br />
◦ These <strong>Gas</strong> Quality changes require more gas quality data to be<br />
posted on the pipeline’s Informational Postings website<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
38<br />
◦ <strong>Southern</strong> <strong>Star</strong> will begin posting Wobbe Index data and hydrocarbon<br />
dew point (HDP)<br />
◦ NAESB 1.9 gas quality changes only impact what the pipeline must post<br />
and do not directly affect shippers.
NAESB 1.9 Highlights<br />
• Transactional Reports in Informational Postings:<br />
◦ Revised Standards 5.4.20, 5.4.21 and 5.4.22<br />
◦ Implement revisions to the capacity release, firm and interruptible<br />
transactional reports required by 18 CFR Section 284.13 that are<br />
posted on the pipeline’s Informational Postings website.<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
39<br />
◦ Better reporting of transactional data.<br />
◦ Biggest changes will be in the capacity release transactional report.<br />
◦ Transactional report changes only impact what the pipeline must post<br />
and do not directly affect shippers.
• Nomination Changes:<br />
NAESB 1.9 Highlights<br />
◦ Revised Standards 1.3.60 and 1.3.63<br />
◦ Revised Data Sets 1.4.3, 1.4.4, and 1.4.6<br />
◦ New Location Capacity and Location Capacity Flow Indicator<br />
may be used in the nomination screens and data sets where<br />
bidirectional points are involved.<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Minimal: The new usage of the new Location Capacity data element<br />
is “mutually agreeable” and unlikely to be used often, if at all.<br />
40
NAESB 1.9 Highlights<br />
• EDI and EDI Trading Partner Agreement (TPA)<br />
◦ Revised Principles 4.1.39 and 10.1.9(not in tariff)<br />
◦ Revised Definition 10.2.10<br />
◦ Revised Standard 10.3.10 and new Standards 10.3.26 & 10.3.27<br />
◦ Revised 6.3.3 (EDI Trading Partner Agreement – not in tariff)<br />
◦ Minor changes to the standard EDI Trading Partner Agreement.<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Minimal: Only affects those who use EDI or may use EDI.<br />
41<br />
◦ The most potentially significant change is in the principles (which are<br />
not adopted by FERC or put in pipeline tariffs) stating that Trading<br />
Partners should use either the current or immediately previous<br />
published version of the NAESB standards.
NAESB 1.9 Highlights<br />
• Informational Postings and <strong>Pipeline</strong> Websites<br />
◦ Revised Standards 4.3.16, 4.3.26, 4.3.29, 4.3.32, 4.3.33, 4.3.69,<br />
4.3.92, 4.3.94, and 4.3.99<br />
◦ Revisions to the organization of some pipeline postings and<br />
their formats on pipeline websites.<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Better appearance and organization of postings on the website.<br />
◦ Website changes only impact what the pipeline must post and do<br />
not directly affect shippers.<br />
42
NAESB 1.9 Highlights<br />
• Other Minor and Technical Revisions<br />
◦ Revised Data Sets 1.4.1; 1.4.2; 1.4.5; 1.4.7; 2.4.1; 2.4.2; 2.4.3;<br />
2.4.4; 2.4.6; 2.4.7; 2.4.8; 3.4.1; 3.4.2; 3.4.4; 5.4.14; 5.4.18;<br />
5.4.16; 5.4.17; and 5.4.19<br />
◦ New Standards 0.3.16 and 0.3.17 and New Interpretations<br />
7.3.56 and 7.3.57<br />
◦ Minor changes related to new or revised data elements or code<br />
values, including replacing numerous blank code value<br />
definitions with the parenthetical [no definition necessary].<br />
• Impact at <strong>Southern</strong> <strong>Star</strong>:<br />
◦ Forget about it<br />
(unless you are a worse NAESB nerd than me)<br />
43
Bob Bahnick<br />
44<br />
SENIOR VICE PRESIDENT,<br />
OPERATIONS & SUPPORT SERVICES
Meter Station Flow Computer Upgrades<br />
<strong>Southern</strong> <strong>Star</strong> has 1064<br />
measurement points on<br />
its system.<br />
• 143 Receipt Meters<br />
• 843 Delivery Meters<br />
• 58 Check Meters<br />
• 20 Storage Meters<br />
45<br />
Orifice Meter with<br />
Superflo II Flow Computer
Meter Station Flow Computer Upgrades<br />
46<br />
<strong>Southern</strong> <strong>Star</strong> utilizes several<br />
types of meters on its<br />
system<br />
• 811 Orifice Meters<br />
• 92 Turbine Meters<br />
• 190 Rotary Meters<br />
• 366 Positive Displacement<br />
• 52 Ultrasonic Meters<br />
All of these meters report their<br />
flowing information into CSI<br />
Positive Displacement Meter<br />
with AMR Flow Computer
Meter Station Flow Computer Upgrades<br />
47<br />
<strong>Star</strong>ting in 2010, <strong>Southern</strong> <strong>Star</strong> has begun a four year<br />
program to upgrade flow computers and related<br />
communications systems.<br />
• 2010 = 109 targeted sites in the Wichita Operating<br />
District<br />
• 2011 – 2013 Remaining Operating Districts
Reasons for Upgrades<br />
48<br />
Many of SSCGP flow computers were installed prior to<br />
2000 and the technology has improved<br />
• Improved Reliability– Technology advancements are<br />
driving new product developments.<br />
• Metering Expandability – Faster processor speeds and<br />
more memory allow upgraded meters to implement new<br />
standards and more complex calculation routines required.<br />
• Standard software–SSCGP is migrating to manufacturers’<br />
standard software to maintain industry standards<br />
compatibility.
Improved Data Communications<br />
Communications Networks are also being upgraded<br />
along with flow computer upgrades<br />
49<br />
• Changing serial radios to Ethernet radios will provide<br />
bi-directional communications to enhance<br />
communications troubleshooting and provide the<br />
ability to send required updates to the flow computer<br />
• Upgrading antennas will improve signal strength and<br />
be a preventive measure for reliability.<br />
• Replacing Hart protocol devices with Modbus<br />
protocol devices will allow a single communications<br />
network type.
New Flow Computers<br />
50<br />
CONTROL MICROSYSTEMS<br />
SCADAPack 42O3<br />
<strong>Gas</strong> Flow Computer<br />
This flow computer will be the predominate<br />
flow computer type for single and dual run<br />
settings.<br />
Thermo Fisher Scientific<br />
AutoPILOT PRO<br />
Six-Run <strong>Gas</strong> Flow Computer &<br />
Remote Telemetry Unit<br />
This flow computer will be the flow<br />
computer type for multi run settings with<br />
more than two runs or requiring on-site<br />
chromatographs or PLC control.
SSCGP System Facilities<br />
Pipe Diameter<br />
51
SSCGP System Facilities<br />
Decade of Installation<br />
52
SSCGP System Facilities<br />
High Consequence Areas<br />
53
16.07<br />
16<br />
29.92<br />
8.82<br />
16<br />
53.22<br />
38.42<br />
30<br />
24.71<br />
23.7<br />
48.23<br />
16.63<br />
10<br />
28.22<br />
19.50<br />
137.00<br />
10.03<br />
12<br />
351.50<br />
445.84<br />
121.56<br />
54<br />
10.03 miles of<br />
HCA inspected in<br />
2010<br />
12 miles of HCA<br />
planned in 2010<br />
121.6 miles of<br />
pipeline inspected<br />
in 2010 as part of<br />
HCA program<br />
500<br />
450<br />
400<br />
350<br />
300<br />
250<br />
200<br />
150<br />
100<br />
50<br />
0<br />
Annual Assessment Mileage<br />
HCA Miles<br />
Assessed<br />
HCA Miles<br />
Planned<br />
Miles of <strong>Pipeline</strong><br />
Assessed<br />
Time Period<br />
Total Miles of HCA/Non‐HCA/<strong>Pipeline</strong> Assessed
55<br />
Program to Date<br />
HCA<br />
Assessment<br />
Mileage<br />
•137.0 miles of<br />
HCA inspected<br />
since 2004<br />
•1173.1 miles of<br />
pipeline inspected<br />
since 2004<br />
Total Miles of HCA Assessed/Planned<br />
150<br />
125<br />
100<br />
75<br />
50<br />
25<br />
16.516<br />
HCA Assessment Mileage<br />
HCA Miles Assessed<br />
HCA Assessment<br />
Planned<br />
Miles of <strong>Pipeline</strong><br />
Assessed<br />
32<br />
25.4<br />
64.8<br />
62<br />
206.7<br />
85.7<br />
82.2<br />
254.1<br />
98.7<br />
95.7<br />
605.6<br />
1051.4 138.95<br />
137.0<br />
126.9<br />
115.20<br />
1173.1<br />
1250<br />
1000<br />
750<br />
500<br />
250<br />
Total Miles of <strong>Pipeline</strong> Assessed<br />
0<br />
71.7<br />
21.0<br />
2004 2005 2006 2007 2008 2009 2010<br />
Time Period<br />
0
2010 HCA Assessments<br />
Line Line Name HCA <strong>Pipeline</strong><br />
56<br />
Assessment<br />
Type Year Status Comments<br />
FS Joplin Airport 16" & 20" 7406.1 22136 2010 Scheduled ILI<br />
FM Joplin to Lone Elm 10" 872.1 10924 2010 Completed ILI<br />
HM Rangeline 16" 26435.7 56244 2010 Completed ILI<br />
VPD<br />
12" to Smith<br />
Cogeneration 9550 61899 2010 Completed ILI<br />
S‐009 Ark City South 8" 17151 2010 Scheduled PT<br />
S‐010 Ark City South 6" 1211 2010 Scheduled PT<br />
S‐011 Total Refinery 6" 7540 2010 Scheduled PT<br />
S‐012 Baird 2" 4523.9 7604 2010 Scheduled PT<br />
UF Wellington 8" Tap 1143.1 1200 2010 Completed Tethered ILI<br />
RG<br />
12" to Farmland<br />
Industries 1291.2 66066 2010 Completed ILI<br />
W Arlington ‐ Cheyenne 1680.8 445991 2010 SCCDA 2011 ILI & SCCDA Mileage will be included in 2011<br />
XM Sedalia Loop 3409 25991 2010 Completed ILI<br />
XTB Lexington 889.1 9636 2010 In Progress DA<br />
W Schurr ‐ Hesston 1792.3 291057 2010 Scheduled ILI & SCCDA ILI Completed, SCCDA Scheduled<br />
DP Ottawa ‐ Welda 30" 2075.6 165780 2010 Completed SCCDA<br />
DT Ottawa ‐ Welda 26" 3482.7 166609 2010 Completed SCCDA<br />
Q Hesston ‐ Americus 2307.1 358071 2010 In Progress SCCDA<br />
ESA Kansas Electric Power 115 115 2010 Scheduled GWUT/Casing Removal<br />
XS‐002 St. Joe 8" 910.7 2010 Scheduled GWUT/Casing Removal<br />
VJ Oklahoma City 20" Loop 4689.4 87162 2010 Completed ILI<br />
R Stafford ‐ Hesston 3952.2 2010 In Progress SCCDA <strong>Pipeline</strong> Mileage <strong>Inc</strong>luded in 2008<br />
Total 74845.2 1356396 Ft<br />
14.18 256.89 Miles
2010 HCA ILI<br />
57
2010 Direct Assessments<br />
58
HCA Future Assessments<br />
59<br />
Year Comments HCA (mi) <strong>Pipeline</strong> (mi)<br />
2010 14.18 256.89<br />
2011 17.61 373.5<br />
2012 3.27 11.3<br />
2004‐2009 Total Assessed Miles 126.95 1051.42<br />
Assessed by 2012 162.01 1693.11
60<br />
Program to Date<br />
Non- HCA<br />
Assessment<br />
Mileage<br />
•303.1 miles of<br />
Non-HCA pipeline<br />
inspected in 2010<br />
•717.3 miles of<br />
pipeline inspected<br />
since 2009<br />
Total Miles of Non - HCA Assessed/Planned<br />
500<br />
450<br />
400<br />
350<br />
300<br />
250<br />
200<br />
150<br />
Non - HCA Assessment Mileage<br />
717.3<br />
414.1<br />
Non - HCA Miles Assessed<br />
Non - HCA Assessment Planned<br />
Miles of Non-HCA <strong>Pipeline</strong> Assessed<br />
750<br />
500<br />
250<br />
Total Miles of Non - HCA <strong>Pipeline</strong> Assessed<br />
100<br />
50<br />
0<br />
12/31/2009 8/31/2010<br />
0<br />
Time Period
2010 non-HCA Assessments<br />
61<br />
Line Line Name <strong>Pipeline</strong><br />
Assessment<br />
Type Year Status Comments<br />
EU, EU‐3 & EU‐4 Soldiers Home 6" 27782 DA 2010 Completed<br />
W Ogallah to Otis 233684 ILI 2010 Completed<br />
N MRL to Blackwell 301956 ILI 2010 Completed<br />
DS Ottawa ‐ Welda 20" 166114 ILI 2010 Completed<br />
W Riner ‐ Arlington 403479 ILI 2010 Completed<br />
N Alva ‐ MRL 89039 ILI 2010 Completed<br />
DB Elk City 26" 87118 ILI 2010 Completed<br />
DV Colony Storage 26" 34176 ILI 2010 Completed<br />
DQ South Welda 26" 11032 ILI 2010 Completed<br />
W Hoxie to Ogallah 245989 ILI 2010<br />
Completed<br />
DB Elk City 62741 PT 2010 In Progress<br />
Total<br />
1663110 Ft<br />
314.98 Miles
2010 Non-HCA Integrity Testing<br />
62
Elk City Storage Field Pressure Test<br />
63
Gary Hines<br />
64<br />
MANAGER,<br />
GAS MANAGEMENT
Topics of the Day<br />
• CSI <strong>Gas</strong> Quality Report Changes<br />
• Operationally Available Capacity Reports<br />
• SSC Daily Operational Status Report<br />
• Planned Service Outages (Maintenance)<br />
• <strong>Pipeline</strong> Integrity Constraints & Timing<br />
65
CSI <strong>Gas</strong> Quality Report Changes<br />
• Updates for NAESB 1.9 Changes<br />
◦ Adding “Wobbe” Index<br />
◦ Adding Hydrocarbon Dewpoint (HCDP)<br />
• Rearranging data – more logical<br />
• Changes under Discussion, GHG Reporting<br />
Requirements<br />
◦ Molecular Weight<br />
◦ Carbon Content<br />
66
Operationally Available Capacity Reports<br />
• Currently Two Reports Available<br />
◦ CSI028 – Available Capacity By Segment<br />
◦ CSI035 – Available Capacity By Location<br />
• Integration of Two Reports to One<br />
◦ CSI035 – Available Capacity By Location<br />
Two additional Location Types Added<br />
Mainline (Compressor Station Constraints)<br />
<strong>Pipeline</strong> Segment (<strong>Pipeline</strong> Segment Constraints)<br />
Report Searchable by Location Type<br />
67
SSC Daily Operational Status Report<br />
• CSI028 – Daily Operational Status Report<br />
◦ Non-NAESB, Customer Driven<br />
• Information To Provide<br />
◦ System Constraints<br />
<strong>Pipeline</strong><br />
Compressor Station<br />
◦ Physical Storage Inventory (EIA Reported)<br />
◦ Availability of Services<br />
◦ Other Information<br />
• Potential To Develop CSI Distribution List<br />
◦ Daily Distribution Early AM<br />
68
Planned Service Outages (Maintenance)<br />
• Semi-Monthly CSI Postings<br />
• Emailed to “PSO” Distribution List Members<br />
◦ Available if not currently being received<br />
• Remaining 2010 Maintenance<br />
◦ October 26 th through the 28 th – Hesston Station Constraint<br />
<strong>Pipeline</strong> Integrity Work<br />
Affects LS130 (KH), LS490 (RH), LS140 (Hesston-Ottawa)<br />
CSI Posting #3596<br />
◦ November 8 th through the 12 th – Edmond Station Constraint<br />
Compressor Station Maintenance<br />
Affects LS340, LS 385, LS390, and portions of LS400<br />
• South of Edmond<br />
69
Planned Service Outages (Maintenance)<br />
• Remaining 2010 Maintenance – Cont’d<br />
70<br />
◦ <strong>Pipeline</strong> Integrity work<br />
LS250 – St. Joe<br />
<strong>Pipeline</strong> Pigging Activities<br />
LS490 – Rawlins Hesston<br />
Awaiting in-line inspection final reports
<strong>Pipeline</strong> Integrity Constraints & Timing<br />
71<br />
• Typical Planning Process for In-Line Inspection (ILI) Tool (“<strong>Pipeline</strong><br />
Pig”) Runs<br />
1. Determine runs based on regulatory requirements (initial, follow up risk<br />
based, etc.)<br />
2. Prioritize runs with <strong>Gas</strong> Control, Operations, Engineering staff<br />
3. Provide proposed schedule to ILI tool vendor<br />
4. Revisit prioritization based on tool availability<br />
5. Determine what impacts to customers there might be based on proposed<br />
tool runs<br />
6. Determine capacity constraints to run tools (tool specific)<br />
7. Commercial Services/<strong>Gas</strong> Control to post tool run schedules when capacity<br />
limitations are required<br />
8. Inevitably, some ILI tools travel across country boundaries and get stuck in<br />
International Customs – Loop back to Step 3
<strong>Pipeline</strong> Integrity Tools<br />
• ILI Tools Available<br />
◦ Multiple tools now available for different integrity needs<br />
<br />
<br />
<br />
<br />
<br />
<br />
<br />
<br />
Geometric – XYZ Mapping utilizing inertial navigation units<br />
CDP – Corrosion Detection Pig<br />
AFD – Axial (along the direction of the tool) Flaw Detection<br />
EMAT – Electro-Magnetic Acoustic Transducer<br />
Stress Corrosion Cracking (SCC)<br />
Disbonded Coating<br />
Combination Tools<br />
Not available for all tools listed above<br />
◦ Some are speed (flow) dependent to establish best results<br />
◦ Multiple tool runs may be required if they cannot be combined in to one<br />
tool<br />
<br />
72<br />
Results in potentially longer period of time for constraints
<strong>Pipeline</strong> Integrity Timing<br />
• Run ILI Tools<br />
◦ Run Geometry & Gage Tools<br />
<br />
Determines ability for ILI “smart” tools to pass through the pipeline<br />
◦ Run ILI Tool(s)<br />
<br />
<br />
One to many days depending on integrity data needs<br />
Data check after each tool run<br />
• Receive Preliminary Report Data<br />
◦ Typically 30-45 Days from tool run date(s)<br />
◦ Initial determination of integrity issues to be resolved<br />
◦ “Non-certified” results from vendor<br />
• Receive Final Report Data<br />
73<br />
◦ Typically 60-90 Days from tool run date(s)<br />
◦ “Certified” results from vendor<br />
◦ <strong>Star</strong>ts a clock for required repairs
<strong>Pipeline</strong> Integrity Timing – Cont’d<br />
• Immediate Conditions<br />
◦ Anomalies meeting certain criteria found in High Consequence Areas<br />
(HCAs) or based on the discretion of <strong>Pipeline</strong> Compliance and Design<br />
Engineering<br />
Option I: Make required repairs within 5 days of receipt of Final Report<br />
Option II: Reduce operating pressure by 20% of highest operating pressure since<br />
tool run<br />
Potentially requires capacity reduction if pipeline runs at a high load factor<br />
Pressure reduction required until anomaly is repaired<br />
• Other Conditions<br />
◦ One Year Conditions<br />
◦ Monitored Conditions<br />
◦ Scheduled Conditions<br />
74
<strong>Pipeline</strong> Integrity Timing – Cont’d<br />
• Timing Is Everything<br />
◦ Tool Run Dates<br />
◦ Preliminary Tool Run Results<br />
◦ Final Tool Run Results<br />
◦ Balanced Needs Approach for Internal & External Parties<br />
• Murphy’s Law<br />
◦ Inevitable It Seems<br />
◦ Reducing His Odds<br />
• Ensuring a Safe, Reliable, & Efficient <strong>Pipeline</strong><br />
System!!<br />
75
David Bristow<br />
76<br />
MANAGER,<br />
SCHEDULING & BILLING
Curtailment Through Pools– Current State<br />
77<br />
• Rights are pushed up from the take-away<br />
transportation agreement(s)<br />
• Once into pool transactions, rights are determined<br />
by pro rata calculations and are traced through<br />
pool(s) to determine initial receipt to be cut<br />
• These calculations limit shipper control of cuts<br />
• If curtailment routine fails, curtailment can’t be done<br />
manually within the cycle timeline constraints<br />
• Difficult to precisely state how reductions were made<br />
due to complex programming calculations
Curtailment Through Pools – Possible State<br />
• Under the curtailment process being considered, a<br />
shipper will indicate how the rights are pushed up<br />
within contractual terms<br />
• Will require additional piece of information on<br />
nomination – utilizing the Package ID field<br />
• Ranking will be as important as ever –<br />
differentiation will be enhance efficiency<br />
• Cuts can be made manually if curtailment routine<br />
fails<br />
78
Curtailment Through Pools - Possible State<br />
79<br />
• For the shipper that uses only their own pooling<br />
agreement(s), indicating the rank will not change the<br />
way a cut will work<br />
• When cuts are made, the rankings will provide a<br />
clearer route to take the curtailment back to the takeaway<br />
agreement(s)<br />
• Representatives can explain reductions to curtailed<br />
shipper
Ranking<br />
80<br />
it’s the new black
Jim Neukam<br />
81<br />
MANAGER,<br />
BUSINESS DEVELOPMENT
BD Responsibilities<br />
• <strong>Gas</strong> Supply & Interconnects<br />
◦ Identify, evaluate, and pursue gas supply opportunities<br />
◦ Manage Customer Interconnect Process<br />
◦ Research and assess gas supply studies to ensure<br />
adequate gas supply<br />
◦ Update CSI <strong>Gas</strong> Supplier Listing<br />
82<br />
82
<strong>Gas</strong> Supplies –2010 <strong>Inc</strong>remental Volumes<br />
83<br />
Location Name Location Line Segment<br />
County/State<br />
Design<br />
dth/d<br />
In-Service<br />
Mustang <strong>Gas</strong> Products 16955<br />
Edmond<br />
Superior <strong>Pipeline</strong> –<br />
Ford Co.<br />
IACX Energy –<br />
East Newkirk<br />
16956<br />
Hugoton<br />
16968<br />
Blackwell<br />
Noble Energy - Lilli 16967<br />
Rawlins<br />
405 – Garfield, OK 10,000 March 2010<br />
130 – Ford, KS 50,000 July 2010<br />
335 – Kay, OK 750 August 2010<br />
490 – Weld, CO 12,000 October 2010<br />
Currently there are four other projects being assessed as viable new<br />
supply points.<br />
83
CSI <strong>Gas</strong> Supplier Listing<br />
84<br />
Contact –<br />
Robbie Clark<br />
270-852-4577<br />
Or<br />
Edie Murdoch<br />
270-852-4557
BD Responsibilities (Cont’d)<br />
85<br />
• Growth Opportunities<br />
◦ Identify, evaluate, and pursue new opportunities and<br />
incremental markets<br />
◦ Collaborate with Customers on creative business<br />
opportunities<br />
◦ Research gas industry projects and competitive business<br />
initiatives<br />
◦ Oversee projects in compliance with regulations and<br />
contractual obligations<br />
85
Growth Opportunities<br />
86<br />
• Access additional<br />
<strong>Gas</strong> Supply from<br />
the Rockies<br />
Production<br />
◦ Niobrara Shale<br />
◦ Niobrara Chalk<br />
WYOMING<br />
Niobrara<br />
Shale<br />
NEBRASKA<br />
Niobrara<br />
Chalk<br />
COLORADO<br />
KANSAS<br />
86
Growth Opportunities<br />
87<br />
• Access <strong>Gas</strong><br />
Supply from the<br />
New Developing<br />
Production in<br />
Oklahoma &<br />
Texas –<br />
◦ Cana Woodford<br />
Shale<br />
◦ Granite Wash<br />
◦ Cleveland,<br />
Tonkawa, &<br />
Mississippian<br />
TEXAS<br />
OKLAHOMA<br />
Cleveland, Tonkawa &<br />
Mississippian Plays<br />
Granite Wash Play<br />
Cana<br />
Woodford<br />
Shale Play<br />
87
Growth Opportunities<br />
88<br />
• Opportunities<br />
for New Flow<br />
Paths – Hub<br />
Services<br />
◦ NNG Kiowa<br />
Delivery<br />
◦ WIC Riner<br />
Delivery<br />
◦ Additional<br />
Oklahoma<br />
Receipts &<br />
Deliveries<br />
88
Growth Opportunities<br />
• <strong>Gas</strong> Storage Expansion – Evaluate Additional<br />
Opportunities<br />
89<br />
• <strong>Inc</strong>remental Firm Deliveries – Evaluate Additional<br />
Opportunities<br />
89
Matt McCoy<br />
90<br />
SUPERVISOR,<br />
GAS CONTROL
Customer Satisfaction<br />
91<br />
• Thank You for taking the time to provide us with<br />
such valuable feedback!!!<br />
• “To be the best pipeline in North America”<br />
• 2 Surveys:<br />
• Energy Insights<br />
• Provides <strong>Southern</strong> <strong>Star</strong> with the in-depth customized<br />
feedback we use to enhance our service offerings to you<br />
• New Internet Module<br />
• Mastio<br />
• Industry wide survey that gives <strong>Southern</strong> <strong>Star</strong> the “big<br />
picture” view and how we compare to other similar pipelines<br />
being measured against the same metrics
Energy Insights – 2010 Survey<br />
• <strong>Gas</strong> Supply on <strong>Southern</strong> <strong>Star</strong><br />
• 85% of Supply Received is Direct Connected<br />
• Williams Partners Echo Springs, BP Jayhawk, Enbridge<br />
Hobart, etc.<br />
• There are many exciting opportunities!<br />
92<br />
• Capacity Release<br />
• Focus Group to help post NAESB 1.9
Mastio – 5 Most Important Attributes<br />
93<br />
2008 2009<br />
#1 Reliable gas transportation. #1 Reliable gas transportation.<br />
#2 Accurate scheduled gas volumes. #2 Accurate scheduled gas volumes.<br />
#3 Accuracy of gas metering systems. #3 Honest, forthright communications.<br />
#4 Honest, forthright communications. #4 Accuracy of gas metering systems.<br />
#5 Representatives are accessible. #5 Representatives are accessible.<br />
SSCGP’s Performance<br />
Attribute 2008 Score 2008 Rank 2009 Score 2009 Rank<br />
Reliable gas transportation. 9.36 1 9.33 1<br />
Accurate scheduled gas volumes. 8.93 4 8.98 2<br />
Honest, forthright communications. 8.67 1 9 1<br />
Accuracy of gas metering systems. 8.82 1 8.96 2<br />
Representatives are accessible. 8.41 5 8.88 2
CSI Enhancements – “Contact Us”<br />
94
CSI Enhancements – “Help & FAQ’s”<br />
95
CSI Enhancements – “Favorite 10 Reports”<br />
96
Philip Rullman<br />
97<br />
DIRECTOR,<br />
COMMERCIAL SERVICES
<strong>Southern</strong> <strong>Star</strong> <strong>Central</strong> Vision<br />
“To be the best pipeline in North America”<br />
98<br />
◦ Safe, Reliable, Efficient Operations<br />
◦ Exceptional Customer Service<br />
◦ Maximized Shareholder Value<br />
◦ Workforce Excellence
Our Goal – “We want to get better”<br />
99<br />
Feedback Time<br />
Customer Meetings<br />
Do we meet or Exceed your<br />
Expectations<br />
Meeting Format<br />
Do you like this format<br />
Information<br />
Is the Material Relevant<br />
What can we do Better