Annual Reports

  • 10-K (Nov 15, 2017)
  • 10-K (Nov 15, 2016)
  • 10-K (Nov 24, 2015)
  • 10-K (Nov 25, 2014)
  • 10-K (May 15, 2014)
  • 10-K (Nov 26, 2013)

 
Quarterly Reports

 
8-K

 
Other

SPIRE INC 10-K 2014
LG and LGC -2014.09.30-10K














UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C.


FORM 10-K

ANNUAL REPORT

For the Fiscal Year Ended September 30, 2014




 
 
 
 
 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549

FORM 10-K
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K
(Mark One)
[ X ]
ANNUAL REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2014
 
OR
[ ]
TRANSITION REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition Period from to

Commission File Number
 
Registrant, Address and Telephone Number
 
State of Incorporation
 
I.R.S. Employer Identification Number
1-16681
 
The Laclede Group, Inc.
720 Olive Street
St. Louis, MO 63101
Telephone Number 314-342-0500
 
Missouri
 
74-2976504
1-1822
 
Laclede Gas Company
720 Olive Street
St. Louis, MO 63101
Telephone Number 314-342-0500
 
Missouri
 
43-0368139

Securities registered pursuant to Section 12(b) of the Act

 
 
Title of Each Class
Name of Each Exchange On Which
Registered
The Laclede Group, Inc.
Common Stock $1.00 par value
New York Stock Exchange
Laclede Gas Company
None
Not applicable

Securities registered pursuant to Section 12(g) of the Act:

The Laclede Group, Inc.    Yes [ ]        No [ X ]
Laclede Gas Company    Yes [ ]        No [ X ]

Indicate by check mark whether each registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

The Laclede Group, Inc.    Yes [ X ]        No [ ]
Laclede Gas Company    Yes [ ]        No [ X ]

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the act.

The Laclede Group, Inc.    Yes [ ]        No [ X ]
Laclede Gas Company    Yes [ ]        No [ X ]

Indicate by check mark whether each registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such report), and (2) has been subject to such filing requirements for the past 90 days.

The Laclede Group, Inc.    Yes [ X ]        No [ ]
Laclede Gas Company    Yes [ X ]        No [ ]
Indicate by check mark whether each registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

The Laclede Group, Inc.    [ X ]        
Laclede Gas Company    [ X ]        

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K.

The Laclede Group, Inc.    [ X ]
Laclede Gas Company    [ X ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 
Large
accelerated
filer
 
Accelerated
filer
 
Non-
accelerated
filer
 
Smaller
reporting
company
The Laclede Group, Inc.
X
 
 
 
 
 
 
Laclede Gas Company
 
 
 
 
X
 
 

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

The Laclede Group, Inc.    Yes [ ]        No [ X ]
Laclede Gas Company    Yes [ ]        No [ X ]

The aggregate market value of the voting stock held by non-affiliates of The Laclede Group, Inc. amounted to $1,452,654,866
as of March 31, 2014. All of Laclede Gas Company's equity securities are owned by The Laclede Group, Inc., its parent company and a 1934 Act Reporting Company. Laclede Gas Company meets the conditions set forth in General Instructions I(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format specified in General Instructions I(2) to Form 10-K.

The number of shares outstanding of each registrant’s common stock as of November 21, 2014 was as follows:
The Laclede Group, Inc.
 
Common Stock, par value $1.00 per share
 
43,212,824

Laclede Gas Company
 
Common Stock, par value $1.00 per share (all owned by The Laclede Group, Inc.)
 
24,577


Document Incorporated by Reference:
Portions of Proxy Statement for Laclede Group, Inc. dated December 19, 2014 — Part III Index to Exhibits is found on page 140.

This combined Form 10-K represents separate filings by The Laclede Group, Inc. and Laclede Gas Company. Information contained herein relating to an individual registrant is filed by that registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrant, except that information relating to Laclede Gas Company is also attributed to The Laclede Group, Inc.
 
 
 
 
 





TABLE OF CONTENTS
Page No.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

3


GLOSSARY OF KEY TERMS
Alagasco
Alabama Gas Corporation or Alabama Utility
MGE
Missouri Gas Energy
Alabama Utility
Alabama Gas Corporation or Alagasco; the utility serving the Alabama region
MGE PSA
Missouri Gas Energy Purchase and Sale Agreement
AOCI
Accumulated other comprehensive income
Missouri Utility
Laclede Gas Company, including Missouri Gas Energy (MGE), the utility serving the Missouri region
APSC
Alabama Public Service Commission
MMBtu
Million British thermal unit
ASC
Accounting Standards Codification
MDPU
Massachusetts Department of Public Utilities
APUC
Algonquin Power and Utilities Corp.
MoPSC
Missouri Public Service Commission or MPSC
Bcf
Billion cubic feet
MRT
Mississippi River Transmission LLC
CAM
Cost Allocation Manual
NEG
New England Gas Company
CCM
Cost Control Mechanism
NYSE
New York Stock Exchange
CNG
Compressed Natural Gas
NYMEX
New York Mercantile Exchange, Inc.
EPA
US Environmental Protection Agency
OCI
Other comprehensive income
ESR
Enhanced Stability Reserve
OTCBB
Over-the-counter bulletin board
ETE
Energy Transfers Equity, LP
PEPL
Panhandle Eastern Pipe Line Company, LP
FASB
Financial Accounting Standards Board
PGA
Purchased Gas Adjustment
FERC
Federal Energy Regulatory Commission
Plaza Mass
Plaza Massachusetts Acquisition, Inc.
FIFO
First-in, first-out
PP&E
Property, plant, and equipment
GAAP
Accounting principles generally accepted in the United States of America
REX
Rockies Express Pipeline, LLC
Gas Utility
Operating segment including the regulated operations of Laclede Gas Company (Missouri Utility) and Alabama Gas Corporation (Alabama Utility)
RSE
Rate Stabilization and Equalization
Gas Marketing
Operating segment including Laclede Energy Resources (LER), a subsidiary engaged in the non-regulated marketing of natural gas and related activities
SEC
US Securities and Exchange Commission
GSA
Gas supply adjustment
SPA
Stock Purchase Agreement with Energen to purchase 100% of the common shares of Alabama Gas Corporation (Alagasco)
ICE
ICE Clear Europe
Spire
Laclede Group's compressed natural gas fueling solutions business
ISRS
Infrastructure System Replacement Surcharge
Southern Natural Gas
Southern Natural Gas Company, LLC
LER
Laclede Energy Resources, Inc.
Southern Star
Southern Star Central Gas Pipeline, Inc.
LG
The Laclede Group, Inc.
SUG
Southern Union Company
LGC
Laclede Gas Company
TGIT
Tallgrass Interstate Gas Transmission, LLC
LIBOR
London Inter-Bank Offered Rate
TSR
Total shareholder return
LIFO
Last-in, first-out
Transco
Transcontinental Gas Pipe Line Company, LLC
LNG
Liquefied natural gas
US
United States
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

4


PART I
FORWARD-LOOKING STATEMENTS
Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our current expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:
weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;
volatility in gas prices, particularly sudden and sustained changes in natural gas prices, including the related impact on margin deposits associated with the use of natural gas derivative instruments;
the impact of changes and volatility in natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;
changes in gas supply and pipeline availability, including decisions by natural gas producers to reduce production or shut in producing natural gas wells, expiration of existing supply and transportation arrangements that are not replaced with contracts with similar terms and pricing, as well as other changes that impact supply for and access to the markets in which our subsidiaries transact business;
legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting
allowed rates of return
incentive regulation
industry structure
purchased gas adjustment provisions
rate design structure and implementation
regulatory assets
non-regulated and affiliate transactions
franchise renewals
environmental or safety matters, including the potential impact of legislative and regulatory actions related to climate change and pipeline safety
taxes
pension and other postretirement benefit liabilities and funding obligations
accounting standards;
the results of litigation;
the availability and access, in general, of funds to meet our debt obligations prior to or when they become due and to fund our operations and necessary capital expenditures, either through (i) cash on hand, (ii) operating cash flow, or (iii) access to the capital or credit markets;
retention of, ability to attract, ability to collect from, and conservation efforts of, customers;
our ability to comply with all covenants in our indentures and credit facilities any violations of which, if not cured in a timely manner, could trigger a default of our obligations under cross-default;
capital and energy commodity market conditions, including the ability to obtain funds with reasonable terms for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;
discovery of material weakness in internal controls; and
employee workforce issues, including but not limited to labor disputes and future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets.
Readers are urged to consider the risks, uncertainties, and other factors that could affect our business as described in this report. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. We do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement in light of future events.

5


ITEM 1. BUSINESS
OVERVIEW
The Laclede Group, Inc. (Laclede Group or the Company) is a public utility holding company formed through a corporate restructuring that became effective October 1, 2001. The Company has two key business segments: Gas Utility and Gas Marketing.
The Gas Utility segment includes the regulated operations of Laclede Gas Company (Laclede Gas, the Missouri Utility) and Alabama Gas Corporation (Alagasco or the Alabama Utility) (together with Laclede Gas, the Utilities). Laclede Gas is a public utility engaged in the purchase, retail distribution and sale of natural gas, is the largest natural gas distribution utility in Missouri, serving more than 1.1 million residential, commercial and industrial customers, and is headquartered in St. Louis, Missouri. The Missouri Utility serves St. Louis and eastern Missouri through its legacy Laclede Gas assets and serves Kansas City and western Missouri through Missouri Gas Energy (MGE), whose assets were acquired by Laclede Gas on September 1, 2013. Alagasco is a public utility engaged in the purchase, retail distribution and sale of natural gas principally in central and north Alabama, serving more than 0.4 million residential, commercial and industrial customers with primary offices located in Birmingham, Alabama. The Company purchased 100% of the common shares of Alagasco from Energen Corporation (Energen) in the fourth quarter of 2014. The acquisition date (Closing Date) was September 2, 2014, with an effective time under the Stock Purchase Agreement (SPA) of 11:59 p.m. on August 31, 2014. The purchase price for the Alagasco acquisition remains subject to certain post-closing adjustments, which at this time are not expected to be material.
The Gas Marketing segment includes Laclede Energy Resources, Inc. (LER), a 100% owned subsidiary engaged in the marketing of natural gas and related activities on a non-regulated basis.
As of September 30, 2014, Laclede Group had 3,152 employees, including 24 part-time employees, Laclede Gas had 1,929 employees, including 7 part-time employees, and Alagasco had 943 employees.
The business of the Utilities is subject to seasonal fluctuations with the peak period occurring in the winter season. Consolidated operating revenues contributed by each segment for the last three fiscal years are presented below. For more detailed financial information regarding the segments, see Note 14, Information By Operating Segment, of the Notes to the Financial Statements.
($ Millions)
2014
 
2013
 
2012
Gas Utility
$
1,462.6

 
$
847.2

 
$
763.5

Gas Marketing
164.6

 
169.8

 
362.0

Total Operating Revenues
$
1,627.2

 
$
1,017.0

 
$
1,125.5

2014 Gas Utility operating revenues include twelve months of MGE revenues and one month of Alagasco revenues. 2013 Gas Utility operating revenues include one month of MGE revenues.
Laclede Group’s common stock is listed on the NYSE and trades under the ticker symbol “LG.”
The following table reflects Laclede Group shares issued during the periods indicated:
 
2014
 
2013
Common Stock Issuance
10,350,000

 
10,005,000

DRIP
33,667

 
44,074

Equity Incentive Plan
97,902

 
108,331

Total Shares Issued
10,481,569

 
10,157,405

Shares were issued during 2014 to effect the acquisition of 100% of the common shares of Alagasco. Shares were also issued at historically consistent levels for Laclede Group's Dividend Reinvestment and Stock Purchase Plan (DRIP) and its Equity Incentive Plan. Shares were issued during 2013 to effect the acquisition of the MGE assets as well as historically consistent levels for Laclede Group's DRIP and its Equity Incentive Plan.
Laclede Gas issued shares to the Laclede Group in both fiscal 2013 and fiscal 2014. For more detailed common stock information of Laclede Group and Laclede Gas, see Item 5. Market for Registrant's Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity Securities.

6


The information the Laclede Group, Laclede Gas and Alagasco file or furnish to the Securities and Exchange Commission (SEC), including annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and their amendments, and proxy statements are available under SEC Filings in the Investor Services section of Laclede Group's website, www.TheLacledeGroup.com, as soon as reasonably practical after the information is filed with or furnished to the SEC. Information contained on Laclede Group's website is not incorporated by reference in this report.
GAS UTILITY
Natural Gas Supply
The Utilities' fundamental gas supply strategy is to meet the two-fold objective of 1) ensuring that the gas supplies it acquires are dependable and will be delivered when needed and 2) insofar as is compatible with that dependability, purchasing gas that is economically priced. In structuring their natural gas supply portfolio, the Utilities continue to focus on natural gas assets that are strategically positioned to meet the Utilities' primary objectives.
Laclede Gas
Laclede Gas focuses its gas supply portfolio around a number of large natural gas suppliers with equity ownership or control of assets strategically situated to complement its regionally diverse firm transportation arrangements. Laclede Gas utilizes both Mid-Continent and Gulf Coast gas sources to provide a level of supply diversity that facilitates the optimization of pricing differentials as well as protecting against the potential of regional supply disruptions. MGE utilizes both Mid-Continent and Rocky Mountain gas sources to provide a level of supply diversity that accesses low cost supplies while providing a natural gas price arbitrage.
In fiscal year 2014, Laclede Gas purchased natural gas from 43 different suppliers to meet current gas sales and storage injection requirements. Laclede Gas entered into firm agreements with suppliers including major producers and marketers providing flexibility to meet the temperature sensitive needs of its customers. Natural gas purchased by Laclede Gas for delivery to its service area through the Enable Mississippi River Transmission LLC (MRT) system totaled 67.6 billion cubic feet (Bcf). Laclede Gas also holds firm transportation on several other interstate pipeline systems that provide access to gas supplies upstream of MRT. In addition to deliveries from MRT, 55.3 Bcf was purchased on the Southern Star Central Gas Pipeline, Inc. (Southern Star), 10.7 Bcf of gas was purchased on MoGas Pipeline LLC (MoGas), 3.0 Bcf on the Tallgrass Interstate Gas Transmission, LLC (TGIT) system, 2.1 Bcf on the Panhandle Eastern Pipe Line Company, LP (PEPL) system, 0.7 Bcf on the Rockies Express Pipeline, LLC (REX) system, and 0.1 Bcf on the KPC Pipeline (KPC) system. Some of Laclede Gas’ commercial and industrial customers purchased their own gas with Laclede Gas transporting 43.4 Bcf to them through its distribution system.
The fiscal year 2014 peak day sendout of natural gas to Laclede Gas customers in both eastern and western Missouri, including transportation customers, occurred on January 6, 2014. The average temperature was negative 2.0 degrees Fahrenheit in St. Louis and negative 3.0 degrees Fahrenheit in Kansas City. On that day, the Missouri Utility's customers consumed 1.814 Bcf of natural gas. For eastern Missouri, about 65% of this peak day demand was met with natural gas transported to St. Louis through the MRT, MO Gas, and Southern Star transportation systems, and the other 35% was met from Laclede Gas' on-system storage and peak shaving resources. For western Missouri, this peak day demand was met with natural gas transported to Kansas City through the Southern Star, PEPL, TGIT, and REX transportation systems.
Alagasco
Alagasco’s distribution system is connected to two major interstate natural gas pipeline systems, Southern Natural Gas Company, L.L.C. (Southern Natural Gas) and Transcontinental Gas Pipe Line Company, LLC (Transco). It is also connected to two intrastate natural gas pipeline systems and to Alagasco's four liquefied natural gas (LNG) facilities.
Alagasco purchases natural gas from various natural gas producers and marketers. Certain volumes are purchased under firm contractual commitments with other volumes purchased on a spot market basis. The purchased volumes are delivered to Alagasco’s system using a variety of firm transportation, interruptible transportation and storage capacity arrangements designed to meet the system’s varying levels of demand. Alagasco’s LNG facilities can provide the system with up to an additional 0.2 Bcf of natural gas to meet peak day demand.
In calendar year 2014 through September 30, 2014, Alagasco purchased natural gas from 18 different suppliers to meet current gas sales, storage injection, and LNG liquefaction requirements, of which eight are under long term supply agreements. Approximately 46.5 Bcf was transported by Southern Natural Gas, 4.4 Bcf by Transco, and 3.9 Bcf through intrastate pipelines to the Alagasco delivery points for its residential, commercial, and industrial customers.
The 2014 calendar year peak day send out for Alagasco was 0.62 Bcf on January 6, 2014, when the average temperature was 15 degrees Fahrenheit in Birmingham, of which 55% was met with supplies transported through Southern Natural Gas,

7


Transco and intrastate facilities, 28% with Alagasco's LNG peak shaving facilities, and 17% with upstream underground storage assets.
Natural Gas Storage
Laclede Gas
Laclede Gas has a contractual right to store 21.6 Bcf of gas in MRT’s storage facility located in Unionville, Louisiana, 16.3 Bcf of gas storage in Southern Star system storage facilities located in Kansas and Oklahoma, and 1.4 Bcf of firm storage on PEPL’s system storage. MRT’s tariffs allow injections into storage from May 16 through November 15 and require the withdrawal from storage of all but 2.1 Bcf from November 16 through May 15. Southern Star tariffs allow both injections and withdrawals into storage year round with ratchets that restrict the associated flows dependent upon the underlying inventory level per the contracts.
In addition, Laclede Gas supplements flowing pipeline gas with natural gas withdrawn from its own underground storage field located in St. Louis and St. Charles Counties in Missouri. The field is designed to provide 0.3 Bcf of natural gas withdrawals on a peak day and annual withdrawals of approximately 4.0 Bcf of gas based on the inventory level that Laclede Gas plans to maintain.
Alagasco
Alagasco has a contractual right to store 12.5 Bcf of gas with Southern Natural Gas, 0.2 Bcf of gas with Transco and 0.2 Bcf with Tennessee Gas Pipeline. In addition, the Company has 1.8 Bcf of LNG storage.
Regulatory Matters
For details on regulatory matters, see Note 15, Regulatory Matters, of the Notes to the Financial Statements.
Other Pertinent Matters
The Missouri Utility is the only distributor of natural gas within its franchised service areas, while the Alabama Utility is the main distributor of natural gas in its service areas. The principal competition for the Utilities comes from the local electric companies. Other competitors in the service areas include suppliers of fuel oil, coal, propane, natural gas pipelines that can directly connect to large volume customers, and for the Missouri Utility, district steam systems in the downtown areas of both St. Louis and Kansas City. Coal is price competitive as a fuel source for very large boiler plant loads, but environmental requirements for coal have shifted the economic advantage to natural gas. Oil and propane can be used to fuel boiler loads and certain direct-fired process applications, but these fuels require on-site storage, thus limiting their competitiveness. In certain cases, district steam has been competitive with gas for downtown St. Louis and Kansas City area heating users.
Laclede Gas' residential, commercial, and small industrial markets represented approximately 91% of its operating revenue for fiscal 2014. Alagasco's residential, commercial, and small industrial markets represented approximately 86% of its operating revenue for the twelve months ended September 30, 2014. Given the current level of natural gas supply and market conditions, the Utilities believe that the relative comparison of natural gas equipment and operating costs with those of competitive fuels will not change significantly in the foreseeable future, and that these markets will continue to be supplied by natural gas. In new multi-family and commercial rental markets, the Missouri Utility's competitive exposure is presently limited to space and water heating applications. Certain alternative heating systems can be cost competitive in traditional markets.
Laclede Gas offers gas transportation service to its large-user industrial and commercial customers. The tariff approved for that type of service produces a margin similar to that which the Missouri Utility would have received under its regular sales rates. Alagasco’s transportation tariff allows the Alabama Utility to transport gas for large commercial and industrial customers rather than buying and reselling it to them and is based on the Alabama Utility’s sales profit margin so that operating margins are unaffected. During 2014, substantially all of Alagasco’s large commercial and industrial customer deliveries involved the transportation of customer-owned gas.
The Utilities are subject to various environmental laws and regulations that, to date, have not materially affected the Utilities' or the Company’s financial position and results of operations. For a detailed discussion of environmental matters, see Note 16, Commitment and Contingencies, of the Notes to the Financial Statements.
Union Agreements
For its legacy eastern Missouri business, Laclede Gas has labor agreements with Locals 884, 11-6 and 11-194 of the United Steel, Paper and Forestry, Rubber, Manufacturing, Energy, Allied-Industrial and Service Workers International Union (USW), which represent approximately 67% of Laclede Gas’ employees. On February 14, 2014, the agreements with Locals 11-6 and

8


11-194 were extended through midnight on July 31, 2015. Laclede Gas and Local 884 have a labor agreement that expires on midnight on July 31, 2015.
With respect to its MGE operations in western Missouri, Laclede Gas has labor agreements with Local 53 of the International Brotherhood of Electrical Workers (IBEW), Locals 12561, 14228 and 11-267 of the USW and Gas Workers Metal Trades Local Union 781-Kansas City and Local 781-Monett of the United Association of Journeymen and Apprentices of the Plumbing and Pipe Fitting Industry of the United States and Canada, which represent approximately 75% of MGE employees. On April 25, 2014, Laclede Gas and IBEW Local 53 reached a tentative agreement on a new contract that will expire at midnight on July 31, 2016. The tentative agreement was ratified by the IBEW membership on April 29, 2014. On May 28, 2014, Laclede Gas and USW Locals 12561, 14228 and 11-267 along with Gas Workers Local 781 KC and Local 781 Monett reached tentative agreement on new labor contracts that expire at midnight on July 31, 2016. The tentative agreements were ratified by the memberships of the various unions on May 31, 2014.
Alagasco has labor agreements with three unions. Local Unions 12030, 12030-A of the United Steelworkers and Local Union 548 of the United Association of Gas Fitters, which together make up approximately 42% of Alagasco’s employees. Local Union 12030’s contract, covering 230 employees, expires at midnight on December 18, 2014. Local Union 12030-A’s contract, covering 65 employees, expires at midnight on April 30, 2017 and Local Union 548’s contract covering 121 employees expires at midnight on June 30, 2016. Alagasco and USW Local Union 12030 commenced contract negotiations in mid-November 2014.
Operating Revenues and Customer Information
Revenues and therms sold and transported for the Gas Utility segment for the last three fiscal years are as follows (before intersegment eliminations):
Gas Utility Operating Revenues
 
 
 
 
 
($ Millions)
2014 *
 
2013 **
 
2012
Residential
$
974.3

 
$
556.8

 
$
487.5

Commercial & Industrial
357.1

 
184.1

 
161.9

Interruptible
2.1

 
3.5

 
2.1

Transportation
32.4

 
15.3

 
14.1

Off-System and Capacity Release
79.5

 
90.2

 
92.5

Other
22.4

 
7.9

 
6.6

Total
$
1,467.8

 
$
857.8

 
$
764.7

Gas Utility Therms Sold and Transported
 
 

 
 
(Millions)
2014 *
 
2013 **
 
2012
Residential
952.9

 
496.6

 
385.3

Commercial & Industrial
435.6

 
229.6

 
183.6

Interruptible
3.5

 
3.1

 
3.0

Transportation
484.6

 
160.4

 
146.1

System Therms Sold and Transported
1,876.6

 
889.7

 
718.0

Off-System
125.8

 
229.4

 
314.5

Total Therms Sold and Transported
2,002.4

 
1,119.1

 
1,032.5

 
 
 
 
 
 
 
*
Includes MGE for the twelve months ended September 30, 2014 and Alagasco for the one month ended September 30, 2014.
**
Includes MGE for the one month ended September 30, 2013.

9


The following table presents our Gas Utility customers as of September 30 for the last three fiscal years:
Gas Utility Customers
2014 *
 
2013 **
 
2012
Residential
1,427,375

 
1,027,556

 
588,061

Commercial & Industrial
134,838

 
100,335

 
39,741

Interruptible
18

 
17

 
15

Transportation
911

 
628

 
140

Total Customers
1,563,142

 
1,128,536

 
627,957

 
 
 
 
 
 
 
*
The number of customers for 2014 is based on average customers over the twelve months ended September 30, 2014, including Alagasco customers for the one month of Laclede Group ownership. Previous methodology was a point in time customer count as of September 30, 2013 and 2012, which did not capture seasonal customers. The average customer methodology will be utilized going forward.
**
Includes MGE for the one month ended September 30, 2013.
Laclede Gas has franchises in nearly all of the 236 Missouri communities where it provides service with terms varying from five years to an indefinite duration. Generally, a franchise allows Laclede Gas, among other things, to install pipes and construct other facilities in the community. All of the franchises are free from unduly burdensome restrictions and are adequate for the conduct of Laclede Gas Company's current public utility business in the State of Missouri. In recent years, although certain franchise agreements have expired, including Clayton, North Kansas City, Cameron, and Riverside, Laclede Gas has continued to provide service in those communities without formal franchises.
Alagasco has franchises in nearly all of the 186 Alabama communities where it provides service with terms varying from five years to an indefinite duration. Generally, a franchise allows Alagasco, among other things, to install pipes and construct other facilities in the community. All of the franchises are free from unduly burdensome restrictions and are adequate for the conduct of Alagasco's current public utility business in the State of Alabama.
GAS MARKETING
LER is engaged in the marketing of natural gas and providing energy services to both on-system utility transportation customers and customers outside of the Missouri Utility’s traditional service area. During fiscal year 2014, LER utilized 14 interstate and intrastate pipelines and 98 suppliers to market natural gas to its customers primarily in the Midwest. LER served more than 230 retail customers and 90 wholesale customers. Through its retail operations, LER offers natural gas marketing services to large commercial and industrial customers, while its wholesale business consists of buying and selling natural gas to other marketers, producers, utilities, power generators, pipelines, and municipalities. Wholesale activities currently represent a majority of LER’s total business.
In the course of its business, LER enters into agreements to purchase natural gas at a future date in order to lock up supply to cover future sales commitments to its customers. To secure access to the markets it serves, LER contracts for transportation capacity on various pipelines from both pipeline companies and through the secondary capacity market from third parties. Throughout fiscal year 2014, LER held approximately 0.4 Bcf per day of firm transportation capacity. In addition, to ensure reliability of service and to provide operational flexibility, LER enters into firm storage contracts and interruptible park and loan transactions with various companies, where it is able to buy and retain gas to be delivered at a future date, at which time LER sells the natural gas to third parties. As of September 30, 2014, LER has contracted for approximately 4.8 Bcf of such storage and park and loan capacity for the 2014-2015 winter period.
LER’s strategy is to leverage its market expertise and risk management skills to manage and optimize the value of its portfolio of commodity, transportation, park and loan, and storage contracts while controlling costs and acting on new marketplace opportunities. Fiscal year 2014 was very profitable for LER due to extreme price volatility and basis differentials (pricing differences between supply regions) that occurred during the 2014 winter period caused by significantly colder than normal weather in and around the Midwest and the corresponding pipeline operational constraints related thereto. During that period of extreme conditions, LER was able to reliably serve its firm markets and incrementally serve others in the upper Midwest that were experiencing significantly higher than expected demand.
Looking forward, market conditions appear to be less profitable than last year with expectations of more normal winter weather and an increase in nationwide gas production. Although year over year nationwide natural gas storage inventory levels are lower than last year’s level, higher year over year flowing production levels are expected to reliably meet this winter's needs absent a repeat of last year’s extreme weather. Going forward, LER continues to look for new opportunities, concentrating its efforts on growing supply and demand areas in and around the Midwest.

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OTHER
The principal driver of the Other segment results for fiscal 2014 and fiscal 2013 have been costs associated with acquisition activity. Fiscal 2014 results include expenses related to MGE integration and transaction expenses of the Alagasco acquisition totaling $13.6, net of tax. In fiscal 2013, the Other segment included $10.5, net of tax, of transaction and integration expenses relating to the acquisition of substantially all the assets and liabilities of MGE.
Other also includes Laclede Pipeline Company, a 100% owned subsidiary of Laclede Group, which operates a propane pipeline under Federal Energy Regulatory Commission (FERC) jurisdiction. This pipeline allows Laclede Gas to receive propane that is vaporized to supplement its natural gas supply and meet peak demands on its distribution system. Laclede Pipeline Company also provides transportation services to third parties.
Other additionally includes Laclede Group’s subsidiaries that are engaged in, among other activities, oil production, real estate development, compression of natural gas, and financial investments in other enterprises. These operations are conducted through seven subsidiaries. The Other category also includes Laclede Gas' non-regulated propane services business which involves providing propane-related services and storage to third parties and its affiliate, Laclede Pipeline Company. Beginning July 1, 2013, propane-related services are included within Gas Utility operations pursuant to Laclede Gas' rate case.

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ITEM 1A. RISK FACTORS
Laclede Group’s and the Utilities' business and financial results are subject to a number of risks and uncertainties, including those set forth below. The risks described below are those the Company and the Utilities consider to be material. When considering any investment in Laclede Group or the Utilities' securities, investors should carefully consider the following information, as well as information contained in the caption "Forward-Looking Statements," Item 7A, and other documents Laclede Group and Laclede Gas file with the SEC. This list is not exhaustive, and Laclede Group's and the Utilities' respective management places no priority or likelihood based on the risk descriptions, order of presentation or grouping by subsidiary. All references to dollar amounts are in millions.
RISKS AND UNCERTAINTIES THAT RELATE TO THE BUSINESS AND FINANCIAL RESULTS OF LACLEDE GROUP AND ITS SUBSIDIARIES
As a holding company, Laclede Group depends on its operating subsidiaries to meet its financial obligations.
Laclede Group is a holding company with no significant assets other than the stock of its operating subsidiaries and cash investments. Laclede Group, and the Missouri Utility prior to Laclede Group’s formation, have paid dividends continuously since 1946. Laclede Group’s ability to pay dividends to its shareholders is dependent on the ability of its subsidiaries to generate sufficient net income and cash flows to pay upstream dividends and make loans or loan repayments. In addition, because it is a holding company and the substantial portion of its assets are represented by its holdings in the Utilities, the risks faced by the Utilities as described under RISKS THAT RELATE TO THE GAS UTILITY SEGMENT below may also adversely affect Laclede Group’s cash flows, liquidity, financial condition and results of operations.
A downgrade in Laclede Group’s and/or its subsidiaries' credit ratings may negatively affect its ability to access capital.
Currently, Laclede Group and its utility subsidiaries have investment grade credit ratings, which are subject to review and change by the rating agencies. On December 16, 2013, Standard & Poor’s lowered its debt ratings for Alagasco from investment grade with a stable outlook to investment grade with a negative outlook. In April 2014, upon the announcement of Laclede Group’s intent to acquire Alagasco, Standard & Poor’s upgraded the outlook to “positive.” Upon the completion of the acquisition by Laclede Group, Standard & Poor’s upgraded Alagasco's debt ratings to A-, stable outlook. Laclede Group, Laclede Gas and Alagasco each have a working capital line of credit to meet their short-term liquidity needs. Laclede Group’s line of credit may also be used to meet the liquidity needs of any of its subsidiaries. If the rating agencies lowered the credit rating at any of these entities, particularly below investment grade, it might significantly limit such entity’s ability to secure new or additional credit facilities and would increase its costs of borrowing. Laclede Group’s or the Utilities’ ability to borrow under current or new credit facilities and costs of that borrowing have a direct impact on their ability to execute their operating strategies. In the fourth quarter of 2014, Laclede Group issued its first public debt and received its first senior unsecured debt ratings. Standard & Poor’s rated Laclede Group debt BBB+, one notch lower than its issuer rating of A-, while Fitch also rated the Laclede Group debt at BBB+, equal to its issuer rating, and Moody’s (which does not use issuer ratings) rated the Laclede Group debt at Baa2. These rating levels have no specific implications for Laclede Group's corporate funding ability or our ability to access the capital markets, nor do they trigger any collateralization requirements under Laclede Group's corporate guarantees. There is no assurance that such credit ratings for any of the Laclede Group companies will remain in effect for any given period of time or that such ratings will not be lowered, suspended or withdrawn entirely by the rating agencies, if, in each rating agency’s judgment, circumstances so warrant.
Unexpected losses may adversely affect Laclede Group’s or its subsidiaries financial condition and results of operations.
As with most businesses, there are operations and business risks inherent in the activities of Laclede Group’s subsidiaries. If, in the normal course of business, Laclede Group or any of its subsidiaries becomes a party to litigation, such litigation could result in substantial monetary judgments, fines, or penalties or be resolved on unfavorable terms. In accordance with customary practice, Laclede Group and its subsidiaries maintain insurance against a significant portion of, but not all, risks and losses. In addition, in the normal course of its operations, Laclede Group and its subsidiaries may be exposed to loss from other sources, such as bad debt expense or the failure of a counterparty to meet its financial obligations. Laclede Group and its operating companies employ many strategies to gain assurance that such risks are appropriately managed, mitigated, or insured, as appropriate. To the extent a loss is not fully covered by insurance or other risk mitigation strategies, that loss could adversely affect the Company’s and/or its subsidiaries' financial condition and results of operations.

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Increased inter-dependence on technology may adversely hinder Laclede Group’s and its subsidiaries' business operations and affect their financial condition and results of operations if such technologies fail or are compromised.
Over the last several years, Laclede Group and its subsidiaries have implemented a variety of technological tools including both Company-owned information technology and technological services provided by outside parties. In fiscal year 2013, the Company completed its implementation of a Company-wide enterprise resource planning (ERP) system. These tools and systems support critical functions including Laclede Group and its subsidiaries' integrated planning, scheduling and dispatching of field resources, its automated meter reading system, customer care and billing, procurement and accounts payable, operational plant logistics, management reporting, and external financial reporting. The failure of these or other similarly important technologies, or the Company’s or Laclede Gas' inability to have these technologies supported, updated, expanded, or integrated into other technologies, could hinder its business operations and adversely impact its financial condition and results of operations.
Although the Company and its subsidiaries have, when possible, developed alternative sources of technology and built redundancy into their computer networks and tools, there can be no assurance that these efforts to date would protect against all potential issues related to the loss of any such technologies or the Utilities’ use of such technologies.
Laclede Gas has also completed the acquisition of the assets and liabilities of MGE in Kansas City. Through fiscal 2015, Laclede Gas will be integrating MGE’s data into its systems.
The Company recently completed the acquisition of the common stock of Alagasco. Alagasco utilizes a different ERP system which will remain in place pending review of the Company's long-term ERP needs during the integration process. The Company continues to evaluate Alagasco’s security controls, both process and tool based.
Furthermore, the Company and its subsidiaries are subject to cyber-security risks primarily related to breaches of security pertaining to sensitive customer, employee, and vendor information maintained by the Company and its subsidiaries in the normal course of business, as well as breaches in the technology that manages natural gas distribution operations and other business processes. A loss of confidential or proprietary data or security breaches of other technology business tools could adversely affect the Company’s and its subsidiaries' reputation, diminish customer confidence, disrupt operations, and subject the Company and its subsidiaries to possible financial liability, any of which could have a material effect on the Company’s and its subsidiaries' financial condition and results of operations. The Company and its subsidiaries closely monitor both preventive and detective measures to manage these risks and maintains cyber risk insurance to mitigate a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these cyber events is not fully covered by insurance, it could adversely affect the Company’s and its subsidiaries' financial condition and results of operations.
Resources expended to pursue business acquisitions, investments or other business arrangements may adversely affect Laclede Group’s financial position and results of operations and return on investments made may not meet expectations.
From time to time, Laclede Group may seek to grow through strategic acquisitions, investments or other business arrangements, including the recent MGE and Alagasco acquisitions, the opening of public compressed natural gas (CNG) stations or other future opportunities. Attractive acquisition candidates may be difficult to acquire on economically acceptable terms. It is possible for Laclede Group to expend considerable resources pursuing an acquisition candidate, but for a variety of reasons such as changes in economic conditions, changes in the acquisition candidate’s business or concerns arising out of due diligence review, decide not to consummate a definitive transaction. To the extent that acquisitions are made, such acquisitions involve a number of risks, including but not limited to, the assumption of material liabilities, the diversion of management’s attention from daily operations to the integration of the acquisition, difficulties in assimilation and retention of employees, securing adequate capital to support the transaction, and regulatory approval. Uncertainties exist in assessing the value, risks, profitability, and liabilities associated with certain businesses or assets and there is a possibility that anticipated operating and financial synergies expected to result from an acquisition do not develop. The failure to complete an acquisition successfully, or to integrate future acquisitions that it may choose to undertake could have an adverse effect on its financial condition, results of operations and the market’s perception of the Company’s execution of its strategy.
In order to manage and diversify the risks of certain development projects, Laclede Group may use partnerships or other investments. Such business arrangements may limit Laclede Group’s ability to fully direct the management and policies of the business relationship. These arrangements may cause additional risks such as operating agreements limiting Laclede Group's control or Laclede Group's ability to appropriately value the business drivers or assets of the business arrangement. While Laclede Group would pursue strategies to mitigate these risks and enforce its interests, these risks may adversely impact the projects and Laclede Group’s financial condition, results of operations and cash flows.
In addition, to the extent Laclede Group engages in any of the above activities together with or through one or more of its subsidiaries, including the Utilities, such subsidiaries may face the same risks.


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Workforce risks may affect the Company's financial results.
The Company and its subsidiaries are subject to various workforce risks, including, but not limited to, the risk that it will be unable to attract and retain qualified personnel; that it will be unable to effectively transfer the knowledge and expertise of an aging workforce to new personnel as those workers retire; and that it will be unable to reach collective bargaining arrangements with the unions that represent certain of its workers, which could result in work stoppages.
Changes in accounting standards may adversely impact the Utilities’ financial condition and results of operations.
Laclede Group and its subsidiaries are subject to changes in US Generally Accepted Accounting Principles (GAAP), SEC regulations and other interpretations of financial reporting requirements for public utilities.  Neither the Company nor any of its subsidiaries have any control over the impact these changes may have on their financial condition or results of operations nor the timing of such changes. The potential issues associated with rate-regulated accounting, along with other potential changes to GAAP, that the US Financial Accounting Standards Board (FASB) continues to consider may be significant.
RISKS RELATED TO THE COMPANY'S AND ITS SUBSIDIARIES' ACQUISITION AND INTEGRATION ACTIVITIES
As a result of recent acquisitions, the Company and its subsidiaries are subject to risks related to a higher level of indebtedness.
In connection with the Alagasco and MGE acquisitions, Laclede Group and Laclede Gas incurred additional debt to pay a portion of the acquisition cost and transaction expenses. On August 19, 2014 Laclede Group issued unsecured debt in the aggregate principal amount of $625.0 to finance the acquisition of Alagasco. On August 13, 2013, Laclede Gas issued debt in the aggregate principal amount of $450.0 to finance the acquisition of MGE. Laclede Group's total consolidated indebtedness as of September 30, 2014 was $2,138.1 ($287.1 of short-term borrowings and $1,851.0 of long-term debt) and Laclede Gas' total indebtedness as of September 30, 2014 was $1,046.5 ($238.6 of short-term borrowings and $807.9 of long-term debt).
Laclede Group’s and Laclede Gas' debt service obligations with respect to this increased indebtedness could have an adverse impact on their earnings and cash flows (which after the acquisitions include the earnings and cash flows of MGE and, in the case of Laclede Group, Alagasco) for as long as the indebtedness is outstanding. Among other risks, the increase in indebtedness may:
make it more difficult for Laclede Group or Laclede Gas to pay or refinance their debts as they become due during adverse economic and industry conditions;
limit the Company’s or Laclede Gas' flexibility to pursue other strategic opportunities or react to changes in its business and the industry in which they operate and, consequently, place them at a competitive disadvantage to competitors with less debt;
require an increased portion of the Company’s or Laclede Gas' cash flows from operations of their respective subsidiaries to be used for debt service payments, thereby reducing the availability of their cash flows to fund working capital, capital expenditures, dividend payments and other general corporate purposes;
result in a downgrade in the credit rating of Laclede Group’s or the Utilities’ indebtedness, which could limit the Utilities’ ability to borrow additional funds or increase the interest rates applicable to Utilities’ indebtedness;
result in higher interest expense in the event of an increase in market interest rates for both long-term debt and short-term commercial paper or bank loans at variable rates;
reduce the amount of credit available to support hedging activities; and
require that additional terms, conditions or covenants be placed on the Company or Laclede Gas.
Based upon current levels of operations, Laclede Group or Laclede Gas expect to be able to generate sufficient cash through earnings on a consolidated basis or through refinancing to make all of the principal and interest payments when such payments are due under their existing credit agreements, indentures and other instruments governing outstanding indebtedness; but there can be no assurance that Laclede Group or Laclede Gas will be able to repay or refinance such borrowings and obligations in future periods.
In addition, in order to maintain investment-grade credit ratings, Laclede Group and Laclede Gas may consider it appropriate to reduce the amount of indebtedness outstanding following the acquisitions. This may be accomplished in several ways, including, in the case of Laclede Group, issuing additional shares of common stock or securities convertible into shares of common stock, or in the case of Laclede Group or Laclede Gas, reducing discretionary uses of cash or a combination of these and other measures. Issuances of additional shares of common stock or securities convertible into shares of common stock would have the effect of diluting the ownership percentage that shareholders hold in the Company, increase the Company’s dividend payment obligations and might reduce the reported earnings per share.

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The acquisition of MGE and/or Alagasco may not achieve its intended results, including anticipated efficiencies and cost savings.
Although the Company and its subsidiaries expect that the acquisition of MGE and Alagasco will result in various benefits, including a significant cost savings and other financial and operational benefits, there can be no assurance regarding when or the extent to which the Company and its subsidiaries will be able to realize these benefits. Achieving the anticipated benefits, including cost savings, is subject to a number of uncertainties, including whether the assets acquired can be operated in the manner the Company and its subsidiaries intended. Events outside of the control of the Company and its subsidiaries, including but not limited to regulatory changes or developments, could also adversely affect their ability to realize the anticipated benefits from the MGE and Alagasco acquisitions.
Thus the integration of MGE and Alagasco may be unpredictable, subject to delays or changed circumstances, and the Company and its subsidiaries can give no assurance that the acquisitions will perform in accordance with their expectations or that their expectations with respect to integration or cost savings as a result of the MGE and Alagasco acquisitions will materialize. In addition, the anticipated costs to the Company and its subsidiaries to achieve the integration of MGE and Alagasco may differ significantly from their current estimates. The integration may place an additional burden on management and internal resources, and the diversion of management’s attention during the integration process could have an adverse effect on the Company's and its subsidiaries' business, financial condition and expected operating results.
In connection with the MGE and the Alagasco acquisitions, Laclede Gas and Laclede Group, respectively, recorded goodwill and long-lived assets that could become impaired and adversely affect its financial condition and results of operations.
Laclede Group and Laclede Gas will assess goodwill for impairment annually or more frequently if events or circumstances occur that would more likely than not reduce the fair value of a reporting unit below its carrying value. The Company and Laclede Gas will assess their long-lived assets for impairment whenever events or circumstances indicate that an asset’s carrying amount may not be recoverable. To the extent the value of goodwill or long-lived assets becomes impaired, the Company and Laclede Gas may be required to incur impairment charges that could have a material impact on its results of operations. No impairment of long-lived assets was recorded during 2014 or 2013.
 Since interest rates are a key component, among other assumptions, in the models used to estimate the fair values of the Company's reporting units, as interest rates rise, the calculated fair values decrease and future impairments may occur. Due to the subjectivity of the assumptions and estimates underlying the impairment analysis, Laclede Group and Laclede Gas cannot provide assurance that future analysis will not result in impairment. These assumptions and estimates include projected cash flows, current and future rates for contracted capacity, growth rates, weighted average cost of capital and market multiples. For additional information, see Item 7, “Critical Accounting Policies.”
RISKS THAT RELATE TO THE GAS UTILITY SEGMENT
Regulation of the Utilities’ businesses may impact rates they are able to charge, costs, and profitability.
The Utilities are subject to regulation by federal, state and local regulatory authorities. At the state level, the Utilities are regulated by regulatory authorities in Missouri by the MoPSC and in Alabama by the APSC. The state regulatory authorities regulate many aspects of the Utilities’ distribution operations, including construction and maintenance of facilities, operations, safety, the rates that the Utilities may charge customers, the terms of service to their customers, transactions with their affiliates, and the rate of return that they are allowed to realize; as well as the accounting treatment for certain aspects of their operations. For further discussion of these accounting matters, see Critical Accounting Policies pertaining to the Utilities’ operations.
The Utilities’ ability to obtain and timely implement rate increases and rate supplements to maintain the current rate of return is subject to regulatory review and approval. There can be no assurance that they will be able to obtain rate increases or rate supplements or continue earning the current authorized rates of return. Furthermore, in accordance with a MoPSC’s Unanimous Stipulation and Agreement, the Missouri Utility will not file a general rate case for non-gas costs prior to October 1, 2015 unless a significant, unusual event impacts any of its operations. The first Missouri Utility general rate case filed in Missouri after October 1, 2015, requires that it be for both the legacy Laclede Gas and the MGE operations. Alagasco’s rate setting process, Rate Stabilization and Equalization (RSE), is subject to regulation by the APSC and is implemented pursuant to an APSC order that will continue beyond September 30, 2018, unless the APSC enters an order to the contrary in a manner consistent with the law. Under the current RSE order, Alagasco is allowed to earn a return on average common equity between 10.5% and 10.95%. Quarterly reviews are conducted by the APSC and if it is determined that Alagasco will exceed the allowed range of return, rates are reduced to bring the projected return within the allowed range.  Rates can only be increased once a year effective December 1. Alagasco’s year-end equity under RSE is limited to 56.5% of total capitalization, subject to certain adjustments. The RSE order includes a Cost Control Mechanism (CCM) which requires Alagasco’s operation and maintenance expenses to be within an allowed index range based on inflation-adjusted from 2007 actual operation and

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maintenance (O&M) expenses.  If O&M expenses exceed the index range, 75% of the amount over the range is returned to customers through future rate adjustments.
The Utilities could incur additional costs if required to adjust to new laws or regulations, revisions to existing laws or regulations or changes in interpretations of existing laws or regulations such as the Dodd-Frank Act. In addition, as the regulatory environment for the natural gas industry increases in complexity, the risk of inadvertent noncompliance could also increase. If the Utilities fail to comply with applicable laws and regulations, whether existing or new, they could be subject to fines, penalties or other enforcement action by the authorities that regulate Utilities’ operations.
The Utilities are involved in legal or administrative proceedings before various courts and governmental bodies that could adversely affect their results of operations, cash flows and financial condition.
The Utilities are involved in legal or administrative proceedings before various courts and governmental bodies with respect to general claims, rates, environmental issues, gas cost prudence reviews and other matters. Adverse decisions regarding these matters, to the extent they require the Utilities to make payments in excess of amounts provided for in their financial statements, or to the extent they are not covered by insurance, could adversely affect the Utilities’ results of operations, cash flows and financial condition.
The Utilities’ liquidity may be adversely affected by delays in recovery of their costs, due to regulation.
In the normal course of business, there may be a lag between when the Utilities incur increases in certain of their costs and the time in which those costs are considered for recovery in the ratemaking process. Cash requirements for increased operating costs, increased funding levels of defined benefit pension and postretirement costs, capital expenditures, and other increases in the costs of doing business may require outlays of cash prior to the authorization of increases in rates charged to customers, as approved by the MoPSC and APSC. Accordingly, the Utilities’ liquidity may be adversely impacted to the extent higher costs are not timely recovered from their customers. In accordance with a MoPSC Unanimous Stipulation and Agreement, the Missouri Utility will not file a general rate case for non-gas costs prior to October 1, 2015 unless a significant, unusual event impacts any of its operations. The first Missouri Utility general rate case filed in Missouri after October 1, 2015, is required to be for both the legacy Laclede Gas and the MGE operations.
The Utilities’ ability to meet their customers’ natural gas requirements may be impaired if contracted gas supplies, interstate pipeline and/or storage services are not available or delivered in a timely manner.
In order to meet their customers’ annual and seasonal natural gas demands, the Utilities must obtain sufficient supplies, interstate pipeline capacity, and storage capacity. If they are unable to obtain these, either from their suppliers’ inability to deliver the contracted commodity or the inability to secure replacement quantities, the Utilities’ financial condition and results of operations may be adversely impacted. If a substantial disruption in interstate natural gas pipelines’ transmission and storage capacity were to occur during periods of heavy demand, the Utilities’ financial results could be adversely impacted.
The Utilities’ liquidity and, in certain circumstances, Utilities’ results of operations may be adversely affected by the cost of purchasing natural gas during periods in which natural gas prices are rising significantly.
The Missouri Utility's tariff rate schedules contain Purchased Gas Adjustment (PGA) clauses and the Alabama Utility’s tariff rate schedule contains a Gas Supply Adjustment (GSA) rider that permit the Utilities to file for rate adjustments to recover the cost of purchased gas. Changes in the cost of purchased gas are flowed through to customers and may affect uncollectible amounts and cash flows and can therefore impact the amount of capital resources.
Currently, the Missouri Utility is allowed to adjust the gas cost component of its rates up to four times each year while the Alabama Utility may adjust its gas cost component of its rates on a monthly basis. The Missouri Utility must make a mandatory gas cost adjustment at the beginning of the winter, in November, and during the next twelve months it may make up to three additional discretionary gas cost adjustments, so long as each of these adjustments is separated by at least two months.
The MoPSC typically approves the Missouri Utility’s PGA changes on an interim basis, subject to refund and the outcome of a subsequent audit and prudence review. Due to such review process, there is a risk of a disallowance of full recovery of these costs. Any material disallowance of purchased gas costs would adversely affect revenues. Increases in the prices the Missouri Utility charges for gas may also adversely affect revenues because they could lead customers to reduce usage and cause some customers to have trouble paying the resulting higher bills. These higher prices may increase bad debt expenses and ultimately reduce earnings. The Missouri Utility has used short-term borrowings in the past to finance storage inventories and purchased gas costs, and expects to do so in the future. Rapid increases in the price of purchased gas may result in an increase in short-term debt.

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To lower financial exposure to commodity price fluctuations, the Missouri Utility enters into contracts to hedge the forward commodity price of its natural gas supplies. As part of this strategy, the Missouri Utility may use fixed-price, forward, physical purchase contracts, swaps, futures, and option contracts. However, the Missouri Utility does not hedge the entire exposure of energy assets or positions to market price volatility, and the coverage will vary over time. Any costs, gains, or losses experienced through hedging procedures, including carrying costs, generally flow through the PGA clause, thereby limiting the Missouri Utility’s exposure to earnings volatility. However, variations in the timing of collections of such gas costs under the PGA clause and the effect of cash payments for margin deposits associated with the Missouri Utility’s use of natural gas derivative instruments may cause short-term cash requirements to vary. These procedures remain subject to prudence review by the MoPSC.
The Utilities may be adversely affected by economic conditions.
Periods of slowed economic activity generally result in decreased energy consumption, particularly by industrial and large commercial companies, a loss of existing customers, fewer new customers especially in newly constructed buildings. As a consequence, national or regional recessions or other downturns in economic activity could adversely affect the Utilities’ revenues and cash flows or restrict their future growth. Economic conditions in Utilities’ service territory may also adversely impact the Utilities’ ability to collect Utilities’ accounts receivable resulting in an increase in bad debt expenses.
Environmental laws and regulations may require significant expenditures or increase operating costs.
The Utilities are subject to federal, state and local environmental laws and regulations affecting many aspects of their present and future operations. These laws and regulations require the Utilities to obtain and comply with a wide variety of environmental licenses, permits, inspections, and approvals. Failure to comply with these laws and regulations and failure to obtain any required permits and licenses may result in costs to the Utilities in the form of fines, penalties or business interruptions, which may be material. In addition, existing environmental laws and regulations could be revised or reinterpreted and/or new laws and regulations could be adopted or become applicable to the Utilities or their facilities, thereby impacting the Utilities’ cost of compliance. The discovery of presently unknown environmental conditions, including former manufactured gas plant sites, and claims against the Utilities under environmental laws and regulations may result in expenditures and liabilities, which could be material. To the extent environmental compliance costs are not fully covered by insurance or recovered in rates from the Utilities’ customers, those costs may have an adverse effect on the Utilities’ financial condition and results of operations.
The Utilities are subject to pipeline safety and system integrity laws and regulations that may require significant expenditures or significant increases in operating costs.
Such laws and regulations affect various aspects of the Utilities’ present and future operations. These laws and regulations require the Utilities maintain pipeline safety and system integrity by identifying and reducing pipeline risks. Compliance with these laws and regulations, or future changes in these laws and regulations, may result in increased capital, operating and other costs which may not be recoverable in a timely manner from customers in rates.
Failure to comply may result in fines, penalties, or injunctive measures that would not be recoverable from customers in rates and could result in a material effect on the Utilities’ financial condition and results of operations.
Transporting, distributing, and storing natural gas and transporting and storing propane involves numerous risks that may result in accidents and other operating risks and costs.
There are inherent in gas distribution activities a variety of hazards and operations risks, such as leaks, accidental explosions, including third party damages, and mechanical problems, which could cause substantial financial losses. In addition, these risks could result in serious injury to employees and non-employees, loss of human life, significant damage to property, environmental pollution, impairment of operations, and substantial losses to the Utilities. The location of pipelines and storage facilities near populated areas, including residential areas, commercial business centers, and industrial sites, could increase the level of damages resulting from these risks. Similar risks also exist for the Missouri Utility's propane storage and transmission operations. These activities may subject the Utilities to litigation or administrative proceedings from time to time. Such litigation or proceedings could result in substantial monetary judgments, fines, or penalties against the Utilities or be resolved on unfavorable terms. The Utilities are subject to Federal and State laws and regulations requiring the Utilities to maintain certain safety and system integrity measures by identifying and managing storage and pipeline risks. Compliance with these laws and regulations, or future changes in these laws and regulations, may result in increased capital, operating and other costs which may not be recoverable in a timely manner from customers in rates. In accordance with customary industry practices, the Utilities maintain insurance against a significant portion, but not all, of these risks and losses. To the extent that the occurrence of any of these events is not fully covered by insurance, it could adversely affect the Utilities’ financial condition and results of operations.

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Because of the highly competitive nature of its business, the Utilities may not be able to retain existing customers or acquire new customers, which would have an adverse impact on its businesses, operating results and financial conditions.
Both the Missouri Utility and the Alabama Utility face the risk that customers may bypass gas distribution services by gaining distribution directly from interstate pipelines. The Utilities cannot provide any assurance that increased competition or other changes in legislation, regulation or policies will not have a material adverse effect on their business, financial condition or results of operation.
The Utilities compete with distributors offering a broad range of services and prices, from full-service distributors to those offering delivery only. The Utilities also compete for retail customers with suppliers of alternative energy products, principally propane and electricity. If they are unable to compete effectively, the Utilities may lose existing customers and/or fail to acquire new customers, which would have a material adverse effect on their business, operating results and financial condition.
Changes in the wholesale costs of purchased natural gas supplies may adversely impact the Utilities’ competitive position compared with alternative energy sources.
Changes in wholesale natural gas prices compared with prices for electricity, fuel oil, coal, propane, or other energy sources may affect the Utilities’ retention of natural gas customers and may adversely impact their financial condition and results of operations.
Significantly warmer-than-normal weather conditions, the effects of global warming and climate change, and other factors that influence customer usage may affect the Utilities’ sale of heating energy and adversely impact their financial position and results of operations.
The Utilities’ earnings are primarily generated by the sale of heating energy. The Missouri Utility has weather mitigation rate designs and the Alabama Utility has customer use adjustments, each of which is approved by the respective state regulatory body, which provide better assurance of the recovery of each Utilities’ fixed costs and margins during winter months despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage.
However, significantly warmer-than-normal weather conditions in the Utilities’ service areas and other factors, such as global warming, climate change and alternative energy sources, may result in reduced profitability and decreased cash flows attributable to lower gas sales. Furthermore, continuation of the weather mitigation rate design at Laclede Gas, the rate design where distribution costs are recovered predominantly through fixed monthly charges at MGE or the Rate Stabilization and Equalization (RSE) at Alagasco are subject to regulatory discretion. In addition, the promulgation of regulations by the EPA or the potential enactment of Congressional legislation addressing global warming and climate change may result in future additional compliance costs that could impact the Utilities’ financial conditions and results of operations.
Regional supply/demand fluctuations and changes in national pipeline infrastructure, as well as regulatory discretion, may adversely affect the Missouri Utility's ability to profit from off-system sales and capacity release.
The Missouri Utility's income from off-system sales and capacity release is subject to fluctuations in market conditions and changing supply and demand conditions in areas the Missouri Utility holds pipeline capacity rights. Specific factors impacting the Missouri Utility’s income from off-system sales and capacity release include the availability of attractively-priced natural gas supply, availability of pipeline capacity, and market demand. Income from off-system sales and capacity release is shared with customers. The Missouri Utility is allowed to retain 15% to 25% of the first $6.0 in annual income earned (depending on the level of income earned) and 30% of income exceeding $6.0 annually. In accordance with an agreement approved by the MoPSC, Laclede Gas deferred, until fiscal year 2017, its ability to retain 15% of the first $2.0. MGE is allowed to retain 15% to 25% of the first $3.6 in annual income earned (depending on the level of income earned) and 30% of income exceeding $3.6 annually. The Missouri Utility’s ability to retain such income in the future is subject to regulatory discretion in a base rate proceeding.
Catastrophic events may adversely affect the Utilities’ facilities and operations.
Catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes, tropical storms, terrorist acts, pandemic illnesses or other similar occurrences could adversely affect the Utilities’ facilities and operations. The Utilities have emergency planning and training programs in place to respond to events that could cause business interruptions. However, unanticipated events or a combination of events, failure in resources needed to respond to events, or slow or inadequate response to events may have an adverse impact on the Utilities’ operations, financial condition, and results of operations. The availability of insurance covering catastrophic events may be limited or may result in higher deductibles, higher premiums, and more restrictive policy terms.

18


RISKS THAT RELATE TO THE GAS MARKETING SEGMENT
Increased competition, fluctuations in natural gas commodity prices, expiration of supply and transportation arrangements, and pipeline infrastructure projects may adversely impact LER’s future profitability.
Competition in the marketplace and fluctuations in natural gas commodity prices have a direct impact on LER’s business. Changing market conditions and prices, the narrowing of regional and seasonal price differentials, and limited future price volatility may adversely impact LER’s sales margins or affect LER’s ability to procure gas supplies and/or to serve certain customers, which may reduce sales profitability and/or increase certain credit requirements caused by reductions in netting capability. Also, LER’s profitability may be impacted by the effects of the expiration, in the normal course of business, of certain of its natural gas supply contracts if those contracts cannot be replaced and/or renewed with arrangements with similar terms and pricing. Although the Federal Energy Regulatory Commission (FERC) regulates the interstate transportation of natural gas and establishes the general terms and conditions under which LER may use interstate gas pipeline capacity to purchase and transport natural gas, LER must occasionally renegotiate its transportation agreements with a concentrated group of pipeline companies. Renegotiated terms of new agreements, or increases in FERC-authorized rates of existing agreements, may impact LER’s future profitability. Profitability may also be adversely impacted if pipeline capacity or future storage capacity secured by LER is not fully utilized and/or its costs are not fully recovered.
Reduced access to credit and/or capital markets may prevent LER from executing operating strategies.
LER relies on its cash flows, netting capability, parental guarantees, and access to Laclede Group’s liquidity resources to satisfy its credit and working capital requirements. LER’s ability to rely on parental guarantees is dependent upon Laclede Group’s financial condition and credit ratings. If the rating agencies lowered Laclede Group’s credit ratings, particularly below investment grade, counterparty acceptance of parental guarantees may diminish, resulting in decreased availability of credit. Additionally, under such circumstances, certain counterparties may require LER to provide prepayments or cash deposits, amounts of which would be dependent upon natural gas market conditions. Reduced access to credit or increased credit requirements, which may also be caused by factors such as higher overall natural gas prices, may limit LER’s ability to enter into certain transactions. In addition, LER has concentrations of counterparty credit risk in that a significant portion of its transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. LER also has concentrations of credit risk in certain individually significant counterparties. LER closely monitors its credit exposure and, although uncollectible amounts have not been significant, increased counterparty defaults are possible and may result in financial losses and/or capital limitations.
Risk management policies, including the use of derivative instruments, may not fully protect LER’s sales and results of operations from volatility and may result in financial losses.
In the course of its business, LER enters into contracts to purchase and sell natural gas at fixed prices and index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed price commitments.
LER currently manages the commodity price risk associated with fixed-price commitments for the purchase or sale of natural gas by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of natural gas futures, options, and swap contracts traded on or cleared through the NYMEX and ICE to lock in margins. These exchange-traded/cleared contracts may be designated as cash flow hedges of forecasted transactions. However, market conditions and regional price changes may cause ineffective portions of matched positions to result in financial losses. Additionally, to the extent that LER’s natural gas contracts are classified as trading activities or do not otherwise qualify for the normal purchases or normal sales designation (or the designation is not elected), the contracts are recorded as derivatives at fair value each period. Accordingly, the associated gains and losses are reported directly in earnings and may cause volatility in results of operations. Gains or losses (realized and unrealized) on certain wholesale purchase and sale contracts, consisting of those classified as trading activities, are required to be presented on a net basis (instead of a gross basis) in the statements of consolidated income. Such presentation could result in volatility in the Company’s operating revenues.
LER’s ability to meet its customers’ natural gas requirements may be impaired if contracted gas supplies and interstate pipeline services are not available or delivered in a timely manner.
LER’s ability to deliver natural gas to its customers is contingent upon the ability of natural gas producers, other gas marketers, and interstate pipelines to fulfill delivery obligations to LER under firm contracts. If these counterparties fail to perform, they have a contractual obligation to reimburse LER for adverse consequences. LER will attempt to use such reimbursements to

19


obtain the necessary supplies so that LER may fulfill its customer obligations. To the extent that it is unable to obtain the necessary supplies, LER’s financial position and results of operations may be adversely impacted.
Regulatory and legislative developments pertaining to the energy industry may adversely impact LER’s results of operations, financial condition and cash flows.
LER’s business is non-regulated in that the rates it charges its customers are not established by or subject to approval by any regulatory body. However, LER is subject to various laws and regulations affecting the energy industry. New regulatory and legislative actions may adversely impact LER’s results of operations, financial condition, and cash flows by potentially reducing customer growth opportunities and/or increasing the costs of doing business.
LER could incur additional costs to comply with new laws and regulations, such as the Dodd-Frank Act. In addition, as the regulatory environment for the natural gas industry increases in complexity, the risk of inadvertent noncompliance could also increase. If LER fails to comply with applicable laws and regulations, whether existing or new ones, it could be subject to fines, penalties or other enforcement action by the authorities that regulate its operations.
ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 2. PROPERTIES
Laclede Gas
The principal properties of Laclede Gas consist of more than 30,000 miles of gas main and related service pipes, meters, and regulators. Laclede Gas has an underground storage facility, 16 operating centers, and other related properties, some of which are leased. Substantially all of Laclede Gas' utility plant is subject to the liens of its mortgage. MGE has 13 operating centers, and other related properties some of which are leased.
All of the properties of Laclede Gas are held in fee, or by easement, or under lease agreements. The principal lease agreements include underground storage rights that are of indefinite duration, the downtown St. Louis office building and MGE's Kansas City, Missouri office building. The current lease on the downtown St. Louis office building extends through February 2015. The Company has chosen not to exercise the option to renew the current downtown St. Louis office space. Consistent with our growth strategy, Laclede Group has leased approximately 127,000 rentable square feet of office space in the 700 Market Street building in downtown St. Louis to serve as the Company's primary office space. The lease commences in early 2015, and has an initial term of 20 years, with up to four options to renew for additional five year terms. Additionally, Laclede Group has leased approximately 35,000 rentable square feet of office space at 800 Market Street. The lease commences in early 2015, and has an initial term of 10 years, with up to two options to renew for additional five year terms. The current lease on MGE's Kansas City office lease extends through November 30, 2015 with the option to renew for four additional terms of five years each. Laclede Gas entered into an agreement to sell the Forest Park property, which closed on May 14, 2014. As part of the agreement Laclede Gas leased back the property for a term that expires March 31, 2015.
Alagasco
The primary offices of Alagasco are located in leased office space in Birmingham, Alabama. The lease extends through February 28, 2018 and there is no option for renewal.
The properties of Alagasco consist primarily of its gas distribution system, which includes approximately 11,000 miles of main and approximately 12,000 miles of service lines, odorization and regulation facilities, and customer meters. Alagasco also has two LNG facilities, thirteen operation centers, two business centers, and other related property and equipment, some of which are leased by Alagasco.
For further information on the Utilities' leases see Note 16, Commitments and Contingencies, of the Notes to the Financial Statements.
Other properties of Laclede Group, including LER, do not constitute a significant portion of its properties.



20


ITEM 3. LEGAL PROCEEDINGS
For a description of pending regulatory matters of Laclede Group, see Note 15, Regulatory Matters, of the Notes to the Financial Statements. For a description of environmental matters, see Note 16, Commitments and Contingencies, of the Notes to the Financial Statements.
Laclede Group and its subsidiaries are involved in litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes the final outcome will not have a material effect on the consolidated financial position or results of operations reflected in the consolidated financial statements presented herein.

21


EXECUTIVE OFFICERS OF THE REGISTRANT – Listed below are executive officers as defined by the SEC for Laclede Group and Laclede Gas. Their ages, at September 30, 2014, and positions are listed below along with their business experience during the past five years.
Name, Age, and Position with Company *
Appointed (1)
 
 
 
 
S. Sitherwood, Age 54
 
 
 
 
 
 
Laclede Group
 
 
 
President and Chief Executive Officer
February 2012
 
President (2)
 
September 2011
 
 
 
 
 
Laclede Gas
 
 
 
Chairman of the Board and Chief Executive Officer (2)
October 2012
 
Chairman of the Board, Chief Executive Officer and President
February 2012
 
 
 
 
S. L. Lindsey, Age 48
 
 
 
 
 
 
Laclede Group
 
 
 
Executive Vice President, Chief Operating Officer, Distribution Operations
October 2012
 
 
 
 
 
Laclede Gas
 
 
 
President (3)
October 2012
 
 
 
 
S. P. Rasche, Age 54
 
 
 
 
 
 
Laclede Group
 
 
 
Executive Vice President, Chief Financial Officer
November 2013
 
Senior Vice President, Chief Financial Officer
October 2013
 
Senior Vice President, Finance and Accounting
May 2012
 
 
 
 
 
Laclede Gas
 
 
 
Chief Financial Officer
May 2012
 
Vice President, Finance (4)
November 2009
 
 
 
 
M. C. Darrell, Age 56
 
 
 
 
 
 
Laclede Group
 
 
 
Senior Vice President, General Counsel and Chief Compliance Officer
May 2012
 
General Counsel (5)
May 2004
 
 
 
 
 
 
 
 

22



M. C. Kullman, Age 54
 
 
 
 
 
 
Laclede Group
 
 
 
Senior Vice President, Chief Administrative Officer and Corporate Secretary
May 2012
 
Chief Governance Officer and Corporate Secretary
February 2004
 
 
 
 
 
Laclede Gas
 
 
 
Senior Vice President, Assistant Corporate Secretary
October 2013
 
Corporate Secretary
May 2012
 
Chief Governance Officer and Corporate Secretary
February 2004
 
 
 
 
L. C. Dowdy, Age 58
 
 
Laclede Group
 
 
 
Senior Vice President, External Affairs, Corporate Communications and Marketing (6)
January 2014
 
 
 
 
 
Laclede Gas
 
 
 
Senior Vice President
January 2014
 
 
 
 
M. R. Spotanski, Age 54
 
 
 
 
 
 
Laclede Group
 
 
 
Senior Vice President, Chief Integration and Innovation Officer (7)
May 2012
 
 
 
 
*
The information provided relates to the Company and its principal subsidiaries. Many of the executive officers have served or currently serve as officers or directors for other subsidiaries of the Company.

(1)
Officers of Laclede Group [and Laclede Gas] are normally reappointed at the Board of Directors in November of each year.
(2)
Ms. Sitherwood served as President of Atlanta Gas Light Company, Chattanooga Gas Company, and Florida City Gas, all of which are subsidiaries of AGL Resources, Inc., from November 2004 to September 2011. During that time, she also served as Senior Vice President of Southern Operations for AGL Resources, Inc. From September 2011 to February 2012, Ms. Sitherwood served as President of The Laclede Group, Inc. and became its President and Chief Executive Officer effective February 1, 2012.
(3)
Mr. Lindsey served as Senior Vice President, Southern Operations of AGL Resources, Inc. and President of its Atlanta Gas Light, Chattanooga Gas and Florida City Gas subsidiaries from December 2011 to October 2012. He also served as Vice President and General Manager of Atlanta Gas Light and Chattanooga Gas from 2005 to 2011.
(4)
Mr. Rasche served as the Chief Financial Officer for TLC Vision Corporation from 2004 to May 2009.
(5)
Mr. Darrell served as Senior Vice President and General Counsel of Laclede Gas Company from October 2007 to July 2012.
(6)
Mr. Dowdy served as Partner at the law firm McKenna Long & Aldridge LLP until December 2013.
(7)
Mr. Spotanski served as Senior Vice President – Operations and Marketing of Laclede Gas Company from October 2007 to July 2012. On September 30, 2014, Mr. Spotanski announced his retirement from the Company effective January 1, 2015.




23


PART II

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS, AND ISSUER PURCHASES OF EQUITY SECURITIES
Laclede Group
Laclede Group’s common stock trades on The New York Stock Exchange under the symbol “LG.” The high and the low sales price for the common stock for each quarter in the two most recent fiscal years are:
 
2014
2013
 
High
Low
High
Low
1st Quarter
$
47.82

$
43.96

$
44.04

$
37.35

2nd Quarter
47.48

43.95

42.89

37.43

3rd Quarter
48.75

44.75

48.50

41.83

4th Quarter
49.95

45.36

47.84

42.84

The number of holders of record as of September 30, 2014 was 3,809.
Dividends declared on the common stock for the two most recent fiscal years were:
 
2014
2013
1st Quarter
$
0.440

$
0.425

2nd Quarter
0.440

0.425

3rd Quarter
0.440

0.425

4th Quarter
0.440

0.425

For disclosures related to securities authorized for issuance under equity compensation plans, see Item 12, page 94.
During the three months ended September 30, 2014, the only repurchases of our common stock were pursuant to elections by employees to have shares of stock withheld to cover employee tax withholding obligations upon the vesting of performance-based and time-vested restricted stock and stock units. The following table provides information on those repurchases:
Period
Total Number of Shares Purchases
Average Price Paid Per Share
Total Number of Shares Purchased as Part of Publicly Announced Plans
Maximum Number of Shares that May Yet be Purchased Under the Plans
July 1, 2014 – July 31, 2014
$—
August 1, 2014 – August 31, 2014
$—
September 1, 2014 – September 30, 2014
793
$49.49
Total
793
$49.49
Laclede Gas
Laclede Gas common stock is owned by its parent, The Laclede Group, Inc., and is not traded on any stock exchange.
Dividends declared on the common stock for the two most recent fiscal years were:
 
2014
2013
1st Quarter
$
586.08

$
747.77

2nd Quarter
587.16

748.56

3rd Quarter
587.14

1,080.54

4th Quarter
773.05

592.87

Laclede Gas' mortgage contains several restrictions on its ability to pay cash dividends on its common stock, as described in further detail in Note 5, Stockholder’s Equity, of the Notes to the Financial Statements.


24


Laclede Group periodically purchases common stock of Laclede Gas with the price set at the book value of Laclede Gas common stock as of the most recently completed fiscal quarter. The details on sales of common stock of Laclede Gas to Laclede Group during the past three fiscal years are set forth below:
Date of Sale
Aggregate Purchase Price (millions)
 
Number of Shares
 
 
 
 
2012
 
 
 
December 13, 2011
$
0.4

 
11

February 8, 2012
0.7

 
18

May 14, 2012
0.9

 
22

August 14, 2012
0.7

 
18

September 12, 2012
40.0

 
1,018

 
 
 
 
2013
 
 
 
December 13, 2012
$
0.8

 
21

March 13, 2013
0.9

 
22

May 10, 2013
0.2

 
5

August 8, 2013
0.4

 
9

August 30, 2013
430.0

 
10,581

September 30, 2013
45.0

 
1,107

 
 
 
 
2014
 
 
 
December 10, 2013
$
0.3

 
9

February 6, 2014
0.4

 
9

May 12, 2014
0.4

 
10

Exemption from registration for the sale of stock was claimed under section 4(a)(2) of the Securities Act of 1933.

25


ITEM 6. SELECTED FINANCIAL DATA
The Laclede Group, Inc.
 
Fiscal Years Ended September 30
($ Millions, Except Per Share Amounts)
2014 (1)
 
2013 (2)
 
2012
 
2011
 
2010
Statements of Income data
 
 
 
 
 
 
 
 
 
Total operating revenues
$
1,627.2

 
$
1,017.0

 
$
1,125.5

 
$
1,603.3

 
$
1,735.0

Net Income
84.6

 
52.8

 
62.6

 
63.8

 
54.0

Common Stock data
 
 
 
 
 
 
 
 
 
Diluted Earnings Per Share of Common Stock
$
2.35

 
$
2.02

 
$
2.79

 
$
2.86

 
$
2.43

Dividends Declared Per Share of Common Stock
1.76

 
1.70

 
1.66

 
1.62

 
1.58

Statements of Financial Position data
 
 
 
 
 
 
 
 
 
Total Assets
$
5,074.0

 
$
3,125.4

 
$
1,880.3

 
$
1,783.1

 
$
1,840.2

Long-Term Debt (less current portion)
1,851.0

 
912.7

 
339.4

 
364.4

 
364.3

Consolidated Net Economic Earnings Data (3)
 
 
 
 
 
 
 
 
 
Net Income (GAAP)
$
84.6

 
$
52.8

 
$
62.6

 
$
63.8

 
$
54.0

   Unrealized (gain) loss on energy-related derivatives
(0.9
)
 
0.5

 
(0.3
)
 
(1.4
)
 
2.2

   Lower of cost or market inventory adjustments
(0.7
)
 
0.9

 

 

 

Realized (gain) loss on economic hedges prior to the sale of the physical commodity
(0.2
)
 

 
0.2

 

 

   Acquisition, divestiture and restructuring activities
17.3

 
10.8

 
0.1

 

 

Net Economic Earnings (Non-GAAP)
$
100.1

 
$
65.0

 
$
62.6

 
$
62.4

 
$
56.2

Diluted Earnings per Share of Common Stock:
 
 
 
 
 
 
 
 
 
Net Income (GAAP)
$
2.35

 
$
2.02

 
$
2.79

 
$
2.86

 
$
2.43

   Unrealized loss (gain) on energy-related derivatives
(0.02
)
 
0.02

 
(0.02
)
 
(0.07
)
 
0.09

   Lower of cost or market inventory adjustments
(0.02
)
 
0.03

 

 

 

Realized (gain) loss on economic hedges prior to the sale of the physical commodity
(0.01
)
 

 
0.01

 

 

   Acquisition, divestiture and restructuring activities
0.48

 
0.42

 
0.01

 

 

   Weighted Average Shares Adjustment
0.27

 
0.38

 

 

 

Net Economic Earnings (Non-GAAP)
$
3.05

 
$
2.87

 
$
2.79

 
$
2.79

 
$
2.52

(1) Effective August 31, 2014, the Company completed the purchase from Energen of 100% of the outstanding common stock of Alagasco for approximately $1,600.0. Laclede Group funded the purchase price with a combination of the issuance of approximately 10.4 million shares of common stock and approximately 2.8 million equity units completed on June 11, 2014, the issuance by Laclede Group of $625.0 aggregate principal amount of senior notes on August 19, 2014, and cash from operations. The purchase price for the Alagasco acquisition remains subject to certain customary post-closing adjustments, which at this time are not expected to be material.
(2) Effective September 1, 2013, Laclede Gas completed the purchase from Southern Union Company, an affiliate of Energy Transfer Equity, L.P. and Energy Transfer Partners, L.P., of substantially all of the assets and liabilities of MGE, a utility engaged in the distribution of natural gas on a regulated basis in western Missouri for $940.2. The acquisition was supported by a combination of the issuance of approximately 10 million shares of common stock completed on May 29, 2013 and the issuance by Laclede Gas of $450.0 of first mortgage bonds on August 13, 2013.
(3) This section contains the non-GAAP financial measures of net economic earnings and net economic earnings per share. Net economic earnings per share are calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted earnings per share calculation.
2014 net economic earnings per share excludes the impact of the June 2014 equity offerings to fund the acquisition of Alagasco, but includes the May 2013 equity offering to fund the MGE acquisition. The weighted-average diluted shares used in the net economic earnings per share calculation for the fiscal year ended September 30, 2014 was 32.7 compared to 35.9 in the GAAP EPS calculation.
2013 net economic earnings per share excludes the impact of the May 2013 equity offering to fund the acquisition of MGE. The weighted-average diluted shares used in the net economic earnings per share calculation for the fiscal year ended September 30, 2013 was 22.5 compared to 26.0 in the GAAP EPS calculation.
For more information on economics earnings data, refer to the Earnings section of Management's Discussion and Analysis of Financial Condition and Results of Operations on page 28.

26


ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
($ in millions, except for per share amounts)
THE LACLEDE GROUP, INC.
INTRODUCTION
This section analyzes the financial condition and results of operations of Laclede Group and Laclede Gas, a 100% owned subsidiary of the Company. It includes management’s view of factors that affect its business, explanations of past financial results including changes in earnings and costs from the prior year periods, and their effects on the Company’s and Laclede Gas' overall financial condition and liquidity. Reference is made to “Part I. Item 1A. Risk Factors” and “Cautionary Statement Regarding Forward-Looking Statements,” which describe important factors that could cause actual results to differ from expectations and non-historical information contained herein. In addition, the following discussion should be read in conjunction with the audited consolidated financial statements and accompanying notes thereto of Laclede Group and Laclede Gas included in “Item 8. Financial Statements and Supplementary Data.”
The Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Company’s consolidated financial statements, Laclede Gas financial statements and the notes thereto.
RESULTS OF OPERATIONS
Overview
The Company has two key business segments: Gas Utility and Gas Marketing. Laclede Group’s earnings are primarily derived from its Gas Utility segment, which reflects the regulated activities of the Utilities. The Gas Utility segment consists of the regulated businesses of Laclede Gas and Alagasco.
Gas Utility - Laclede Gas
Laclede Gas is Missouri’s largest natural gas distribution company. Laclede Gas is regulated by the Missouri Public Service Commission and serves St. Louis and eastern Missouri through its legacy Laclede Gas assets and serves Kansas City and western Missouri through its MGE assets, which were acquired on September 1, 2013. Laclede Gas delivers natural gas to retail customers at rates and in accordance with tariffs authorized by the MoPSC. The earnings of Laclede Gas are primarily generated by the sale of heating energy. Laclede Gas' weather mitigation rate design and MGE's straight fixed variable rate design lessen the impact of weather volatility on its customers during cold winters and stabilizes Laclede Gas' earnings. Due to the seasonal nature of the business of Laclede Gas, Laclede Group’s earnings are typically concentrated during the heating season of November through April each fiscal year, although earnings for MGE are less seasonal than earnings from Laclede Gas due to MGE's rate design, which recovers fixed costs more evenly throughout the year.
On December 14, 2012, Laclede Group, through two 100% owned subsidiaries, Plaza Missouri Acquisition, Inc. (Plaza Missouri) and Plaza Massachusetts Acquisition, Inc. (Plaza Mass), entered into acquisition agreements to acquire from Southern Union Company (SUG) substantially all of the assets and liabilities of MGE and New England Gas Company (NEG). Subsequently, on January 11, 2013, the Company and Plaza Missouri, with consent of SUG, entered into an agreement with Laclede Gas to assign the MGE agreement to Laclede Gas. On February 11, 2013, the Company entered into an agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary, through its acquisition of the stock of Plaza Mass, to acquire the Company's rights to purchase the assets of NEG, subject to certain approvals and conditions. On December 20, 2013, the Company closed the sale of Plaza Mass to an APUC subsidiary and received $11.0 from APUC. On December 24, 2013, the Massachusetts Attorney General filed a Motion for Clarification/Reconsideration with the MDPU claiming, among other things, that legislative approval was required for a transfer of utility assets. On March 26, 2014, the MDPU issued an order denying the Attorney General's motion. The Attorney General did not appeal, thus the MDPU's order approving the sale of NEG is final.
On July 2, 2013, Laclede Gas and other parties to the case filed a Unanimous Stipulation and Agreement with the MoPSC that authorized Laclede Gas to complete the acquisition of MGE, subject to certain conditions, including restrictions relative to the timing of filing for general rate increases and reporting requirements. This Unanimous Stipulation and Agreement was approved by the MoPSC on July 17, 2013. Effective September 1, 2013, Laclede Gas closed on the purchase of MGE assets and liabilities.
Gas Utility - Alagasco
On August 31, 2014, the Company purchased from Energen 100% of the outstanding common stock of Alagasco, with the purchase price for the Alagasco acquisition remaining subject to certain customary post-closing adjustments, which at this time are not expected to be material. Alagasco is the largest natural gas distribution utility in the state of Alabama.

27


Alagasco purchases natural gas through interstate and intrastate suppliers and distributes the purchased gas through its distribution facilities for sale to residential, commercial, and industrial customers and other end-users of natural gas. Alagasco also provides transportation services to large industrial and commercial customers located on its distribution system. These transportation customers, using Alagasco as their agent or acting on their own, purchase gas directly from marketers or suppliers and arrange for delivery of the gas into the Alagasco distribution system. Alagasco charges a fee to transport such customer-owned gas through its distribution system to the customers’ facilities.
Alagasco’s service territory is located in central and north Alabama and includes 186 cities and communities in 32 counties. The aggregate population of the counties served by Alagasco is estimated to be 3.0 million. Among the cities served by Alagasco are Birmingham, the center of the largest metropolitan area in Alabama, and Montgomery, the state capital. During 2014, Alagasco served an average of 391,840 residential customers and 31,236 commercial, industrial and transportation customers. The Alagasco distribution system includes approximately 23,000 miles of main, service lines, odorization regulation facilities, and customer meters.
Gas Marketing
Laclede Energy Resources, Inc. is engaged in the marketing of natural gas and related activities on a non-regulated basis and is reported in the Gas Marketing segment. LER markets natural gas to both on-system utility transportation customers and customers outside of Laclede Gas’ traditional service territory, including large retail and wholesale customers. LER’s operations and customer base are more subject to fluctuations in market conditions than the Utilities. LER entered into a new 10 year contract for 1 Bcf of natural gas storage effective August 1, 2013 and has an additional 1 Bcf storage contracted through January 2016.
Business Evaluation Factors
Based on the nature of the business of the Company and its subsidiaries, as well as current economic conditions, management focuses on the following key variables in evaluating the financial condition and results of operations and managing the business:
Gas Utility Segment:
the Utilities' ability to recover the costs of purchasing and distributing natural gas from their customers;
the impact of weather and other factors, such as customer conservation, on revenues and expenses;
changes in the regulatory environment at the federal, state, and local levels, as well as decisions by regulators, that impact the Utilities' ability to earn its authorized rate of return in all service territories they serve;
the Utilities' ability to access credit markets and maintain working capital sufficient to meet operating requirements;
the effect of natural gas price volatility on the business; and
the ability to integrate the operations of all acquisitions.
Gas Marketing Segment:
the risks of competition;
fluctuations in natural gas prices;
new national pipeline infrastructure projects;
the ability to procure firm transportation and storage services at reasonable rates;
credit and/or capital market access;
counterparty risks; and
the effect of natural gas price volatility on the business.
Further information regarding how management seeks to manage these key variables is discussed below.
Gas Utility
The Utilities provide reliable natural gas services at a reasonable cost, while maintaining and building secure and dependable infrastructures. The Utilities’ strategies focus on improving both performance and the ability to recover their authorized distribution costs and rates of return. The Utilities' distribution costs are the essential, primarily fixed, expenditures it must incur to operate and maintain more than 53,000 miles of mains and services comprising the natural gas distribution systems and related storage facilities for Laclede Gas and Alagasco.

28


The Utilities' distribution costs include wages and employee benefit costs, depreciation and maintenance expenses, and other regulated utility operating expenses, excluding natural and propane gas expense. Distribution costs are considered in the rate-making process, and recovery of these types of costs is included in revenues generated through the Utilities' tariff rates. Laclede Gas' tariff rates are approved by the MoPSC, whereas Alagasco's tariff rates are approved by the APSC. Laclede Gas also has an off-system sales and capacity release income stream that is regulated by tariff.
Laclede Gas’ income from off-system sales and capacity release remains subject to fluctuations in market conditions. Laclede Gas is allowed to retain the following annual income (shown by legacy business):
Laclede Gas
 
 
Pre-tax Income
Customer Share
Company Share
First $2 million
100%
—%
Next $2 million
80%
20%
Next $2 million
75%
25%
Amounts exceeding $6 million
70%
30%
 
 
 
MGE
 
 
Pre-tax Income
Customer Share
Company Share
First $1.2 million
85%
15%
Next $1.2 million
80%
20%
Next $1.2 million
75%
25%
Amounts exceeding $3.6 million
70%
30%
Some of the factors impacting the level of off-system sales include the availability and cost of Laclede Gas’ natural gas supply, the weather in its service area, and the weather in other markets. When Laclede Gas’ service area experiences warmer-than-normal weather, while other markets experience colder weather or supply constraints, some of the utility’s natural gas supply is available for off-system sales. See the Regulatory and Other Matters section on page 42 of this report for additional information on Laclede Gas' off-system sales.
Laclede Gas and Alagasco work actively to reduce the impact of wholesale natural gas price volatility on their costs by strategically structuring their natural gas supply portfolios to increase their gas supply availability and pricing alternatives and through the use of derivative instruments to protect their customers from significant changes in the commodity price of natural gas. Nevertheless, the overall cost of purchased gas remains subject to fluctuations in market conditions. Laclede Gas’ Purchased Gas Adjustment (PGA) clause and Alagasco's GSA rider allows the Utilities to flow through to customers, subject to prudence review by the MoPSC and APSC, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of derivative instruments to hedge the purchase price of natural gas, as well as gas inventory carrying costs. As of September 30, 2014, Laclede Gas had active derivative positions, but Alagasco has had no derivative instrument activity since 2010. The Utilities believe they will continue to be able to obtain sufficient gas supply. The price of natural gas supplies and other economic conditions may affect sales volumes, due to the conservation efforts of customers, and cash flows associated with the timing of collection of gas costs and related accounts receivable from customers.
Both Laclede Gas and Alagasco rely on both short-term credit and long-term capital markets, as well as cash flows from operations, to satisfy their seasonal cash requirements and fund their capital expenditures. The Utilities' ability to issue commercial paper, access their lines of credit, issue long-term bonds, or to obtain new lines of credit is dependent on current conditions in the credit and capital markets. Management focuses on maintaining a strong balance sheet and believes it currently has adequate access to credit and capital markets and will have sufficient capital resources to meet their foreseeable obligations. See the Liquidity and Capital Resources section on page 44 for additional information.
Gas Marketing
LER provides both on-system Laclede Gas transportation customers and customers outside of Laclede Gas' traditional service area with another choice in non-regulated natural gas suppliers. LER utilizes its natural gas supply agreements, transportation agreements, park and loan agreements, storage agreements, and other executory contracts to support a variety of services to its customers at competitive prices. It closely monitors and manages the natural gas commodity price and volatility risks associated with providing such services to its customers through the use of a variety of risk management activities, including the use of exchange-traded/cleared derivative instruments and other contractual arrangements. LER is committed to managing commodity price risk, while it seeks to expand the services that it now provides. Nevertheless, income from LER’s operations is more subject to fluctuations in market conditions than Laclede Gas’ operations.

29


LER’s business is directly impacted by the effects of competition in the marketplace, the impacts of new pipeline infrastructure and surplus natural gas supplies on natural gas commodity prices. Management expects that LER's net economic earnings (a non-GAAP measure, as discussed below) will continue to be negatively impacted by the expiration of favorable long-term natural gas supply contracts, the last of which expired on October 31, 2013. For fiscal 2014, this impact was more than offset by higher margins achieved due to higher price volatility and basis differentials (pricing differences between supply regions) that stemmed from the unusually cold winter.
In addition to its operating cash flows, LER relies on Laclede Group’s parental guarantees to secure its purchase and sales obligations of natural gas. LER also has access to Laclede Group’s liquidity resources. A large portion of LER’s receivables are from customers in the energy industry. LER also enters into netting arrangements with many of its energy counterparties to reduce overall credit and collateral exposure. Although LER’s uncollectible amounts are closely monitored and have not been significant, increases in uncollectible amounts from customers are possible and could adversely affect LER’s liquidity and results.
LER carefully monitors the creditworthiness of counterparties to its transactions. LER performs in-house credit reviews of potential customers and may require credit assurances such as prepayments, letters of credit, or parental guarantees when appropriate. Credit limits for customers are established and monitored.
As a result of pipeline infrastructure, optimization activities and increased gas supply, and an abundance of natural gas supply, LER cannot be certain that all of its wholesale purchase and sale transactions will settle physically. As such, certain transactions entered into in fiscal year 2014 are designated as trading activities for financial reporting purposes, due to their settlement characteristics, rather than elected for normal purchases or normal sales designations under generally accepted accounting principles (GAAP). Results of operations from trading activities are reported on a net basis in Gas Marketing Operating Revenues, which may cause volatility in the Company’s operating revenues, but has no effect on operating income or net income.
In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. In accordance with GAAP, some of LER’s purchase and sale transactions are not recognized in earnings until the natural gas is physically delivered, while other energy-related transactions, including those designated as trading activities, are required to be accounted for as derivatives, with the changes in their fair value (representing unrealized gains or losses) recorded in earnings in periods prior to settlement. Because related transactions of a purchase and sale strategy may be accounted for differently, there may be timing differences in the recognition of earnings under GAAP and economic earnings realized upon settlement. The Company reports both GAAP and net economic earnings (non-GAAP), as discussed below.


30


EARNINGS
Net income reported by the Laclede Group and Laclede Gas are determined in accordance with accounting principles generally accepted in the United States of America (GAAP). Management also uses the non-GAAP measures of net economic earnings, net economic earnings per share - diluted and operating margin when internally evaluating results of operations. These internal non-GAAP operating metrics should not be considered as an alternative to, or more meaningful than, GAAP measures such as net income.
Non-GAAP Measures - Net Economic Earnings and Net Economic Earnings Per Share
Net Economic Earnings and Net Economic Earnings Per Share are non-GAAP measures that exclude from net income the after-tax impacts of fair value accounting and timing adjustments associated with energy-related transactions as well as acquisition, divestiture, and restructuring activities. These fair value and timing adjustments are made in instances where the accounting treatment differs from the economic substance of the underlying transaction, including the following:
Net unrealized gains and losses on energy-related derivatives that are required by GAAP fair value accounting associated with current changes in the fair value of financial and physical transactions prior to their completion and settlement. These unrealized gains and losses result primarily from two sources:
1)
changes in the fair values of physical and/or financial derivatives prior to the period of settlement; and,
2)
ineffective portions of accounting hedges, required to be recorded in earnings prior to settlement, due to differences in commodity price changes between the locations of the forecasted physical purchase or sale transactions and the locations of the underlying hedge instruments;
Lower of cost or market adjustments to the carrying value of commodity inventories resulting when the market price of the commodity falls below its original cost, to the extent that those commodities are economically hedged; and
Realized gains and losses resulting from the settlement of economic hedges prior to the sale of the physical commodity.
Additionally, management excludes acquisition, divestiture, and restructuring activities when evaluating on-going performance.
These adjustments eliminate the impact of timing differences and the impact of current changes in the fair value of financial and physical transactions prior to their completion and settlement. Unrealized gains or losses are recorded in each period until being replaced with the actual gains or losses realized when the associated physical transaction(s) occur. While management uses these non-GAAP measures to evaluate both the Utilities and LER, the net effect of adjustments on the Utilities' earnings are minimal. This is due to gains or losses on Laclede Gas' natural gas derivative instruments being deferred pursuant to its PGA clause, as authorized by the MoPSC; and gains or losses on any Alagasco natural gas derivative instruments being deferred pursuant to its GSA rider, as authorized by the APSC.
Management believes that excluding the earnings volatility caused by recognizing changes in fair value prior to settlement and other timing differences associated with related purchase and sale transactions provides a useful representation of the economic effects of only the actual settled transactions and their effects on results of operations. In addition, management excludes the impact related to unique acquisition, divestiture, and restructuring activities when evaluating on-going performance, and therefore excludes these impacts from net economic earnings. Net economic earnings per share also excludes the impact of the May 2013 and June 2014 equity offerings to fund the acquisitions of MGE and Alagasco. Management believes that this presentation provides a useful representation of operating performance by facilitating comparisons of year-over-year results. The definition and measurement of net economic earnings provided above is consistent with that used by management and the Board of Directors in assessing the Company's and Laclede Gas' performance as well as determining performance under the Company's and Laclede Gas' incentive compensation plans. Further, the Company believes this better enables an investor to view the Company's and Laclede Gas' performance in that period on a basis that would be comparable to prior periods.
Reconciliations of net economic earnings and net economic earnings per share to the Company's most directly comparable GAAP measures are provided on the following pages.
Non-GAAP Measure - Operating Margin
In addition to operating revenues and operating expenses, management also uses the non-GAAP measure of operating margin when evaluating result of operations, as shown in the table below. The Utilities pass on to their customers (subject to prudence review by the MoPSC and APSC) increases and decreases in the wholesale cost of natural gas in accordance with their PGA clauses (Missouri Utility) and GSA rider (Alabama Utility). The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes and gross receipts tax expense, which are calculated as a percentage of revenues, with the same amount, excluding immaterial timing differences,

31


included in revenues, has no direct effect on operating income. As these costs are included in revenue and operating expenses and management does not have any control over these amounts for the Utilities, management believes that beginning with operating margins is a more useful measure. In addition, it is management's belief that operating margins and the remaining operating expenses that calculate operating income is a more useful measure in assessing the Company's and the Utilities' performance as management has more ability to influence control over these revenues and expenses.

32


Overview – Net Income (Loss)
 
($ Millions, except per share amounts)
Gas Utility
 
 Gas Marketing
 
Other
 
 
Consolidated
 
Per Share Amounts
Year Ended September 30, 2014
 
 
 
 
 
 
 
 
 
 
Net Income (Loss) (GAAP)
$
87.1

 
$
12.2

 
$
(14.7
)
 
$
84.6

 
$
2.35

 
Unrealized loss (gain) on energy-related derivatives*
0.2

 
(1.1
)
 

 
(0.9
)
 
(0.02
)
 
Lower of cost or market inventory adjustments*

 
(0.7
)
 

 
(0.7
)
 
(0.02
)
 
Realized (gain) loss on economic hedges prior
     to the sale of the physical commodity*

 
(0.2
)
 

 
(0.2
)
 
(0.01
)
 
Acquisition, divestiture and restructuring activities*
5.5

 

 
11.8

 
17.3

 
0.48

 
Weighted Average Shares Adjustment **
 
 
 
 
 
 
 
 
0.27

 
Net Economic Earnings (Losses) (Non-GAAP)
$
92.8

 
$
10.2

 
$
(2.9
)
 
$
100.1

 
$
3.05

 
 
 
 
 
 
 
 
 
 
 
Year Ended September 30, 2013
 
 
 
 
 
 
 
 
 
 
Net Income (Loss) (GAAP)
$
56.3

 
$
7.6

 
$
(11.1
)
 
$
52.8

 
$
2.02

 
Unrealized loss on energy-related derivatives*
0.1

 
0.4

 

 
0.5

 
0.02

 
Lower of cost or market inventory adjustments*

 
0.9

 

 
0.9

 
0.03

 
Acquisition, divestiture and restructuring activities*
0.3

 

 
10.5

 
10.8

 
0.42

 
Weighted Average Shares Adjustment ***
 
 
 
 
 
 
 
 
0.38

 
Net Economic Earnings (Losses) (Non-GAAP)
$
56.7

 
$
8.9

 
$
(0.6
)
 
$
65.0

 
$
2.87

 
 
 
 
 
 
 
 
 
 
 
Year Ended September 30, 2012
 
 
 
 
 
 
 
 
 
 
Net Income (GAAP)
$
48.2

 
$
12.3

 
$
2.1

 
$
62.6

 
$
2.79

 
Unrealized (gain) loss on energy-related derivatives*
(0.1
)
 
(0.2
)
 

 
(0.3
)
 
(0.02
)
 
Realized loss on economic hedges prior
     to the sale of the physical commodity*

 
0.2

 

 
0.2

 
0.01

 
Less: Acquisition, divestiture and restructuring activities*

 

 
0.1

 
0.1

 
0.01

 
Net Economic Earnings (Non-GAAP)
$
48.1

 
$
12.3

 
$
2.2

 
$
62.6

 
$
2.79

*
Amounts presented net of income taxes. Income taxes are calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of the pre-tax reconciling items.
**
2014 net economic earnings per share exclude the impact of the June 2014 equity offerings to fund the acquisition of Alagasco, but includes the May 2013 equity offering to fund the MGE acquisition. The weighted-average diluted shares used in the net economic earnings per share calculation for the fiscal year ended September 30, 2014 was 32.7 compared to 35.9 in the GAAP EPS calculation.
***
2013 net economic earnings per share excludes the impact of the May 2013 equity offering to fund the acquisition of MGE. The weighted-average diluted shares used in the net economic earnings per share calculation for the fiscal year ended September 30, 2013 was 22.5 compared to 26.0 in the GAAP EPS calculation.
2014 vs. 2013
Consolidated
Laclede Group’s net income was $84.6 in fiscal year 2014, including a net loss of $2.9 relating to Alagasco's operations for the month ended September30, 2014, compared with $52.8 in fiscal year 2013. Basic and diluted earnings per share were $2.36 and $2.35 respectively for fiscal year 2014 compared with basic and diluted earnings per share of $2.03 and $2.02 respectively for fiscal year 2013. Net economic earnings were $100.1 in fiscal year 2014, compared with $65.0 in fiscal year 2013. Net economic earnings per share were $3.05 in fiscal year 2014, compared with $2.87 for fiscal year 2013. GAAP earnings increased in fiscal year 2014 compared to fiscal year 2013 primarily due to improved results in Laclede Group's Gas Utility segment, which reflects the inclusion of a full year of MGE operations, improved earnings from the Gas Marketing Segment and the impact of colder weather in fiscal 2014, partially offset by Alagasco acquisition costs and MGE integration costs incurred during the year.

33


Gas Utility
Gas Utility net income and net economic earnings increased by $30.8 and $36.1, respectively, in 2014, compared to 2013. The increases to net income and net economic earnings were primarily due to higher operating margin (a non-GAAP measure, as discussed below) of $222.3, which reflects the inclusion of MGE operating margin of $186.5 and Alagasco operating margin of $14.8. These increases were partially offset by an increase in other operating expenses of $124.9, including MGE other operating expenses of $103.5, Alagasco other operating expenses of $14.2, an increase in depreciation and amortization expenses totaling $34.1, including MGE depreciation and amortization expenses totaling $26.0 and Alagasco depreciation and amortization of $3.9, higher interest expense totaling $12.6, and increased income tax expenses of $14.5.
Gas Marketing
Gas Marketing reported GAAP earnings totaling $12.2, an increase of $4.6 compared with the same period last year. Net economic earnings for fiscal year 2014 increased $1.3 from fiscal year 2013. The increases in net income and net economic earnings were primarily attributable to increases in operating margin, as discussed in the Gas Marketing section below.
Other
Other net income and other net economic earnings decreased $3.6 and $2.3, respectively, compared with the same period last year. The decrease in net income is primarily due to expenses attributable to the Alagasco acquisition in fiscal year 2014 being higher than the expenses attributable to the MGE and NEG transactions in 2013.
Operating Revenues and Operating Expenses
Reconciliations of operating margin to the most directly comparable GAAP measure are shown below.
($ Millions)
Gas Utility
Gas Marketing
Other
Eliminations
 
Consolidated
Year Ended September 30, 2014
 
 
 
 
 
 
Operating Revenues
$
1,467.8

$
246.6

$
3.8

$
(91.0
)
$
1,627.2

 
Natural and propane gas expense
821.8

220.4


(90.2
)
952.0

 
Gross receipts tax expense
75.2

0.2



75.4

 
Operating margin (non-GAAP)
570.8

26.0

3.8

(0.8
)
599.8

 
Depreciation and amortization
82.4

0.4

0.5


83.3

 
Other operating expenses
325.5

5.4

20.0

(0.8
)
350.1

 
Operating income (Loss) (GAAP)
$
162.9

$
20.2

$
(16.7
)
$

$
166.4

 
 
 
 
 
 
 
Year Ended September 30, 2013
 

 

 

 
 

 
Operating revenues
$
857.8

$
189.4

$
6.2

$
(36.4
)
$
1,017.0

 
Natural and propane gas expense
469.1

171.6

1.3

(35.7
)
606.3

 
Gross receipts tax expense
40.2

0.1



40.3

 
Operating margin (non-GAAP)
348.5

17.7

4.9

(0.7
)
370.4

 
Depreciation and amortization
48.3

0.3

0.7


49.3

 
Other operating expenses
200.6

4.6

20.1

(0.7
)
224.6

 
Operating income (Loss) (GAAP)
$
99.6

$
12.8

$
(15.9
)
$

$
96.5

 
 
 
 
 
 
 
Year Ended September 30, 2012
 

 

 

 
 

 
Operating revenues
$
764.7

$
373.5

$
4.9

$
(17.6
)
$
1,125.5

 
Natural and propane gas expense
414.8

348.4


(17.6
)
745.6

 
Gross receipts tax expense
35.5

0.1



35.6

 
Operating margin (non-GAAP)
314.4

25.0

4.9


344.3

 
Depreciation and amortization
40.7

0.3

0.3


41.3

 
Other operating expenses
185.6

4.5

2.3


192.4

 
Operating income (GAAP)
$
88.1

$
20.2

$
2.3

$

$
110.6


34


Consolidated
Laclede Group reported operating revenues of $1,627.2 for the fiscal year ended September 30, 2014 compared with $1,017.0 for the same period last year. Laclede Group's operating margin increased $229.4 for the twelve months ended September 30, 2014, compared to the same period last year primarily due to higher Gas Utility operating margin, and growth in the operating margin reported by Gas Marketing as discussed below. Other operating expenses and depreciation and amortization increased $125.5 and $34.0, respectively, for the twelve months ended September 30, 2014 as compared to the same period last year. These increases were primarily due to the incremental impact of eleven additional months of MGE other operating expenses and depreciation and amortization expenses in fiscal 2014 totaling $103.5 and $26.0, respectively, as well as the inclusion of one month of Alagasco operating expenses and depreciation and amortization of $14.2 and $3.9, respectively. The remaining increase in other operating expenses was due to the impact of colder weather reflected in the higher provision for uncollectible accounts, and higher maintenance and employee-related expenses. The remaining increase in depreciation and amortization was associated with capital spending in fiscal 2014.
Gas Utility
Operating Revenues - Gas Utility Operating Revenues for fiscal year 2014 increased $610.0, compared to fiscal year 2013, was primarily attributable to the following factors:
($ Millions)
 
Higher system sales volumes and other variations
$
66.3

Lower wholesale gas costs passed on to Utility customers
(9.4
)
Lower off-system sales volumes
(11.7
)
Propane Utility
9.2

Gross receipts tax
3.7

New customer revenue from MGE acquisition
532.2

New customer revenue from Alagasco acquisition
19.7

Total Variation
$
610.0

Temperatures experienced in Laclede Gas' service area during 2014 were 13.3% colder than the same period last year, and 11.4% colder than normal. Total system therms sold and transported were 1,876.6 million for fiscal year 2014 compared with 889.7 million for fiscal year 2013. Total off-system therms sold and transported outside of Laclede Gas' service area were 125.8 million for fiscal year 2014 compared with 229.4 million for fiscal year 2013. This decrease was due to colder temperatures and increased heating demand in our services areas, reducing the gas supply resources available for off-system sales or capacity release.
Operating Margin - Gas Utility operating margin was $570.8 for fiscal year 2014, a $222.3 increase over the same period last year. The increase was attributable to the following factors:
($ Millions)
 
Operating margin from MGE
$
186.5

Operating margin from Alagasco
14.8

Cold weather impact - higher therms sold and transported
11.9

Propane utility sales
6.1

Gross receipts tax
3.0

Total Variation
$
222.3

The increase was primarily attributable to the acquisitions of MGE and Alagasco totaling $186.5 and $14.8 respectively. The higher system sales volume driven by the 13.3% colder weather in the Laclede Gas service area contributed to $11.9 of the increase. $6.1 of the increase was the result of propane utility sales, with the remaining $3.0 the result of all other minor variations.
Operating Expenses - Gas Utility other operating expenses in fiscal year 2014 increased $124.9 from fiscal year 2013. Of the $124.9 increase, $103.5 is attributable to the MGE acquisition and $14.2 is the result of the Alagasco acquisition. The remaining increase in other operating expenses was due to the impact of colder weather reflected in the higher provision for uncollectible accounts, higher maintenance costs and employee-related expenses. Excluding the acquisition impact of $29.9, depreciation and amortization expense increased $4.2 primarily due to additional depreciable property.

35


Gas Marketing
Operating Revenues - Gas Marketing operating revenue for the twelve months ended September 30, 2014 increased $57.2 from the same period last year due to higher volumes sold and higher per unit gas sales prices. Higher gas sales prices were driven by the colder weather that resulted in a constrained pipeline infrastructure creating higher market volatility between differing regions.
Operating Margin - Gas Marketing operating margin was $26.0 for fiscal year 2014, an $8.3 increase compared to the same period last year. The increase in operating margin was primarily attributable to higher price volatility and basis differentials (pricing differences between supply regions) that stemmed from unusually cold winter. These higher weather-related margins offset lower run-rate margins versus the prior year, reflecting the expiration of two favorable gas supply contracts during 2013 and early 2014.
Other
Operating Revenue and Operating Expenses - Other operating revenue decreased $2.4 primarily due to the prior year having a one-time sale of propane inventory by Laclede Pipeline totaling $1.7. Other operating expenses decreased $0.1 primarily due to the Alagasco acquisition-related expenses discussed above being lower than the MGE acquisition related expenses incurred in the comparative prior year period.
Interest Charges
Interest charges during fiscal year 2014 increased $17.6 from fiscal year 2013. The increase was primarily due to the December 2012, March 2013, August 2013 and August 2014 issuances of additional long-term debt of $25.0, $100.0, $450.0 and $625.0, respectively, the June 2014 issuance of equity units totaling $143.8, offset by the early bond redemption of $80.0, 6.35% first mortgage bonds on January 6, 2014, and the October 2012 maturity of $25.0, 6.5% first mortgage bonds. The assumption of Alagasco debt contributed $1.3 to the increase in interest expense.
Average short-term interest rates were 0.5% and 0.3% for fiscal years 2014 and 2013, respectively. Average short-term borrowings were $82.3 and $34.2 for fiscal years 2014 and 2013, respectively.
Income Taxes
Income tax expense increased $14.7 in fiscal year 2014 from fiscal year 2013 primarily due to higher taxable income, slightly higher effective tax rates, and other minor variations.
2013 vs. 2012
Consolidated
Laclede Group’s net income was $52.8 in fiscal year 2013, including net income of $1.8 related to MGE, compared with $62.6 in fiscal year 2012. Basic and diluted earnings per share were $2.03 and $2.02 respectively for fiscal year 2013 compared with basic and diluted earnings per share of $2.80 and $2.79 respectively for fiscal year 2012. Net economic earnings were $65.0 in fiscal year 2013, compared with $62.6 in fiscal year 2012. Net economic earnings per share were $2.87 in fiscal year 2013, compared with $2.79 for fiscal year 2012. Earnings decreased in fiscal year 2013 compared to fiscal year 2012 primarily due to acquisition costs incurred during the period recorded in Other partially offset by higher income reported by Gas Utility. Additionally, earnings were impacted by decreased income from the Gas Marketing Segment. The increase is primarily attributed to acquisition related items that are excluded from net economic earnings.
Gas Utility
Gas Utility net income and net economic earnings increased by $8.1 and $8.6, respectively, in 2013, compared with 2012. Of the $8.1 increase in net income, $1.8 is attributed to the acquisition of MGE. The remaining increase was primarily due to (on a pre-tax basis) higher operating margin (a non-GAAP measure, as discussed below) of $18.9. These benefits were partially offset by higher depreciation and amortization expenses totaling $5.0, higher operation and maintenance expenses totaling $4.0, and higher interest expense totaling $1.0.

36


Gas Marketing
Gas Marketing reported GAAP earnings totaling $7.6, a decrease of $4.7 compared with the same period in 2012 Net economic earnings for fiscal year 2013 decreased $3.4 from fiscal year 2012. The decreases in net income and net economic earnings were primarily attributable to decreases in operating margin, as discussed below. On a GAAP basis, LER's results were further impacted by the effect of higher net unrealized losses from certain of LER's energy-related derivative contracts and the impact of lower of cost or market inventory adjustments.
Other
Other net income and other net economic earnings decreased $13.2 and $2.8, respectively, compared with fiscal 2012. The decrease in net income is primarily due to incremental expenses in fiscal year 2013 as compared to fiscal year 2012 attributable to the acquisition of MGE and pending acquisition of NEG from SUG totaling $10.5, net of tax, and other minor variations.
Operating Revenues and Operating Expenses
Reconciliations of the Company's operating margin to the most directly comparable GAAP measure are shown below.
Consolidated
Laclede Group reported operating revenues of $1,017.0 for the fiscal year ended September 30, 2013 compared with $1,125.5 for the same period in 2012. Laclede Group's operating margin increased $26.1 for the twelve months ended September 30, 2013, compared to the same period in 2012 primarily due to higher Gas Utility operating margin, partially offset by lower operating margin reported by Gas Marketing as discussed below. Remaining operating expenses were $273.9 for the twelve months end September 30, 2013 compared with $233.7 in the prior year. The increase was primarily due to additional expenses related to MGE, as well as, higher depreciation and amortization expenses totaling $5.0 and higher operation and maintenance expenses totaling $4.0.
Gas Utility
Operating Revenues - Gas Utility Operating Revenues for fiscal year 2013 increased $93.1, compared to fiscal year 2012, was primarily attributable to the following factors:
($ Millions)
 
Higher system sales volumes and other variations
$
101.3

Lower wholesale gas costs passed on to Utility customers
(30.6
)
Lower off-system sales volumes
(24.0
)
Higher prices charged for off-system sales
19.9

New customer revenue from MGE acquisition
22.0

Higher ISRS revenues
4.5

Total Variation
$
93.1

Temperatures experienced in Laclede Gas' service area during 2013 were 35.8% colder than in 2012, which were the warmest on record. Total system therms sold and transported to Laclede customers within its service territory were 889.7 million for fiscal year 2013 compared with 718.0 million for fiscal year 2012. Total off-system therms sold and transported outside of Laclede Gas' service area were 229.4 million for fiscal year 2013 compared with 314.5 million for fiscal year 2012.
Operating Margin - Gas Utility operating margin was $348.5 for fiscal year 2013, a $34.1 increase over the same period in the prior year. Of the $34.1 increase, $15.2 is attributed to the acquisition of MGE. The remaining increase is primarily due to increased sales margins reflecting colder weather this year totaling $13.3, higher Infrastructure System Replacement Surcharge (ISRS) revenues totaling $4.5, and other minor variations of $1.1.
Operating Expenses - Remaining operating expenses in fiscal year 2013 increased $22.6 from fiscal year 2012. Other operation and maintenance expenses increased $4.0 primarily due to increased compensation and benefits, maintenance, IT and professional fees, partially offset by a lower provision for uncollectible accounts and a decrease in customer accounts expenses. Depreciation and amortization expense increased $5.0 primarily due to additional depreciable property. Taxes, other than income and gross receipts tax, increased $1.0 primarily due to higher payroll taxes related to aforementioned employee expenses. The remaining increase is attributed to the acquisition of MGE.

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Gas Marketing
Operating Revenues - Gas Marketing operating revenues decreased $184.1 primarily due to the effect of recording certain transactions on a net basis, instead of a gross basis, partially offset by higher per unit gas prices and increases in volumes purchased and sold.
Operating Margin - Gas Marketing operating margin was $17.7 for fiscal year 2013, a $7.3 decrease compared to the same period in the prior year. The decrease in operating margin was primarily attributable to low price volatility and basis differentials in the current natural gas market, the expiration of a favorable supply contract, and lower of cost or market inventory adjustments. These factors were partially offset by the effect of higher volumes purchased and sold.
Other
Operating Revenue and Operating Expenses - Other operating revenue increased $1.3 primarily due to the sale of propane inventory by Laclede Pipeline totaling $1.7 in fiscal year 2013. Other operating expenses increased $19.5 primarily due to the acquisition-related expenses discussed above and expenses associated with the propane sale.

Interest Charges
Interest charges during fiscal year 2013 increased $3.7 from fiscal year 2012 primarily due to expenses associated with the Company's bridge loan facility and higher interest from the issuance of long-term debt, partially offset by a reduction in interest charges related to the recognition of previously unrecognized tax benefits. The higher interest on long-term debt reflects the net effect of the December 2012, March 2013, and August 2013 issuances of additional long-term debt of $25.0, $100.0, and $450.0, respectively, and the October 2012 maturity of $25.0 of 6 1/2% first mortgage bonds. Average short-term interest rates were 0.3% for both fiscal years 2013 and 2012. Average short-term borrowings were $34.2 and $43.8 for fiscal years 2013 and 2012, respectively.
Income Taxes
Income tax expense decreased $8.7 in fiscal year 2013 from fiscal year 2012 primarily due to lower pre-tax income, various property-related deductions and other minor variations.
CRITICAL ACCOUNTING POLICIES
Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources are based upon our consolidated financial statements, which have been prepared in accordance with GAAP, which requires that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. We believe the following represent the more significant items requiring the use of judgment and estimates in preparing our consolidated financial statements:
Regulatory Accounting – The Utilities account for their regulated operations in accordance with FASB ASC Topic 980, “Regulated Operations.” This Topic sets forth the application of GAAP for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of this accounting guidance require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of these regulatory accounting principles and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. Management believes the following represent the more significant items recorded through the application of this accounting guidance:
PGA Clause - Laclede Gas' PGA clauses allows Laclede Gas and MGE to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies, including the costs, cost reductions, and related carrying costs associated with the utility’s use of natural gas derivative instruments to hedge the purchase price of natural gas. The difference between actual costs incurred and costs recovered through the application of the PGA clauses are recorded as regulatory assets and regulatory liabilities that are recovered

38


or refunded in a subsequent period. The PGA clauses also permit the application of carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of derivative instruments, and also provide for a portion of income from off-system sales and capacity release revenues to be flowed through to customers. Laclede Gas' PGA clause also authorizes the utility to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season.
GSA Rider - Alagasco’s rate schedules for natural gas distribution charges contain a GSA rider, established in 1993, which permits the pass-through to customers of changes in the cost of gas supply. Alagasco’s tariff provides a temperature adjustment mechanism, also included in the GSA, that is designed to moderate the impact of departures from normal temperatures on Alagasco’s earnings. The temperature adjustment applies primarily to residential, small commercial and small industrial customers. Other non-temperature weather related conditions that may affect customer usage are not included in the temperature adjustment. In prior years, Alagasco entered into cash flow derivative commodity instruments to hedge its exposure to price fluctuations on its gas supply. Alagasco recognizes all derivatives at fair value as either assets or liabilities on the balance sheet. Any realized gains or losses are passed through to customers using the mechanisms of the GSA rider in accordance with Alagasco’s APSC approved tariff and are recognized as a regulatory asset or regulatory liability. All derivative commodity instruments in a gain position are valued on a discounted basis incorporating an estimate of performance risk specific to each related counterparty. Derivative commodity instruments in a loss position are valued on a discounted basis incorporating an estimate of performance risk specific to Alagasco. Alagasco currently has no active derivative positions.

Goodwill – Goodwill is measured as the excess of the acquisition-date fair value of the consideration transferred over the amount of acquisition-date identifiable assets acquired net of assumed liabilities. As part of the MGE acquisition Laclede Group recorded $247.1 of goodwill on the September 1, 2013 acquisition date. During fiscal 2014 final reconciliations of purchase price were completed (refer to Note 2, Acquisitions, of the Notes to the Financial Statements), which effectively reduced Laclede Gas' purchase price of MGE to $940.2 and reduced goodwill related to the transaction from $247.1 to $210.2. As part of the Alagasco acquisition, the Company recorded $727.6 of goodwill on August 31, 2014. Goodwill is tested for impairment on an annual basis, or more frequently if circumstances surrounding the goodwill valuation change. The goodwill impairment test compares the fair value of a reporting unit, or operating segment, to its carrying amount, including goodwill. Goodwill associated with the MGE transaction was evaluated for impairment in July 2014. Goodwill impairment testing on Alagasco will commence in 2015.
Employee Benefits and Postretirement Obligations – Pension and postretirement obligations are calculated by actuarial consultants that utilize several statistical factors and other assumptions provided by management related to future events, such as discount rates, returns on plan assets, compensation increases, and mortality rates. For the Utilities, the amount of expense recognized and the amounts reflected in other comprehensive income are dependent upon the regulatory treatment provided for such costs, as discussed further below. Certain liabilities related to group medical benefits and workers’ compensation claims, portions of which are self-insured and/or contain “stop-loss” coverage with third-party insurers to limit exposure, are established based on historical trends.
The amount of net periodic pension and other postretirement benefit cost recognized in the financial statements related to the Utilities' qualified pension plans and other postretirement benefit plans is based upon allowances, as approved by the MoPSC (for Laclede Gas) and as approved by the APSC (for Alagasco). The allowances have been established in the rate-making process for the recovery of these costs from customers. The differences between these amounts and actual pension and other postretirement benefit costs incurred for financial reporting purposes are deferred as regulatory assets or regulatory liabilities. GAAP also requires that changes that affect the funded status of pension and other postretirement benefit plans, but that are not yet required to be recognized as components of pension and other postretirement benefit cost, be reflected in other comprehensive income. For the Utilities' qualified pension plans and other postretirement benefit plans, amounts that would otherwise be reflected in other comprehensive income are deferred with entries to regulatory assets or regulatory liabilities.

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The table below reflects the sensitivity of Laclede Group's plans to potential changes in key assumptions:
Pension Plan Benefits:
 
 
 
 
 
 
Actuarial Assumptions
 
Increase/(Decrease)
 
Estimated Increase/(Decrease) to Projected Benefit Obligation (Millions)
 
Estimated Increase/ (Decrease) to Annual Net Pension Cost* (Millions)
Discount Rate
 
0.25
 %
 
$
(18.0
)
 
$
0.3

 
 
(0.25
)%
 
18.6

 
(0.3
)
Rate of Future Compensation Increase
 
0.25
 %
 
12.2

 
0.4

 
 
(0.25
)%
 
(12.2
)
 
(0.4
)
Expected Return on Plan Assets
 
0.25
 %
 

 
(0.9
)
 
 
(0.25
)%
 

 
0.9

 
 
 
 
 
 
 
Postretirement Benefits:
 
 
 
 
 
 
Actuarial Assumptions
 
Increase/(Decrease)
 
Estimated Increase/(Decrease) to Projected Postretirement Benefit Obligation (Millions)
 
Estimated Increase/(Decrease) to Annual Net Postretirement Benefit Cost* (Millions)
Discount Rate
 
0.25
 %
 
$
(6.8
)
 
$
(0.2
)
 
 
(0.25
)%
 
7.2

 
0.2

Expected Return on Plan Assets
 
0.25
 %
 

 
(0.3
)
 
 
(0.25
)%
 

 
0.3

Annual Medical Cost Trend
 
1.00
 %