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STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES IN THE ...
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June 1, 2016 STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES IN THE MATTER OF THE PETITION OF : SOUTH JERSEY GAS COMPANY : TO REVISE THE LEVEL OF ITS BASIC GAS SUPPLY SERVICE (“BGSS”) : CHARGE AND TO REVISE THE LEVEL : OF ITS CONSERVATION INCENTIVE : PROGRAM (“CIP”) CHARGES FOR THE : YEAR ENDING SEPTEMBER 30, 2017 : BPU DOCKET NO. ______________ CASE SUMMARY, PETITION, TESTIMONY AND EXHIBITS
Transcript of STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES IN THE ...
June 1, 2016
STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES
IN THE MATTER OF THE PETITION OF : SOUTH JERSEY GAS COMPANY : TO REVISE THE LEVEL OF ITS BASIC GAS SUPPLY SERVICE (“BGSS”) : CHARGE AND TO REVISE THE LEVEL : OF ITS CONSERVATION INCENTIVE : PROGRAM (“CIP”) CHARGES FOR THE : YEAR ENDING SEPTEMBER 30, 2017 : BPU DOCKET NO. ______________
CASE SUMMARY, PETITION, TESTIMONY AND EXHIBITS
TABLE OF CONTENTS
1) Case Summary 2) Petition and Public Notice 3) BGSS
BGSS Minimum Filing Requirement No. Testimony of Kenneth J. Barcia………….………………...1
Exhibits: KJB-1………………………………………………. 2, 5 KJB-2………………………………………………. 5, 7 KJB-3………………………………………………. 5, 7 KJB-4……………………………………………….N/A KJB-5……………………………………………….5, 6 KJB-6……………………………………………….5, 6 KJB-7……………………………………………….N/A KJB-8…………………………………………….2, 5, 6 KJB-9………………………………………………….7 KJB-10……………………………………………..N/A KJB-11……………………………………………..…1
Testimony of Timothy W. Rundall………………………..1
Exhibits: TWR-1………………………………………………. 14 TWR-2…………………………………………..……. 8 TWR-3………………………………………………. 12
TWR-4……………………………………………......14 TWR-5……………………………………………..8, 11
TWR-6…………………………………………..……. 4 TWR-7………………………………………………. 15 TWR-8………………………………….………….…..4 TWR-9………………………………………………. 11 TWR-10.…….………………………………………. 13 TWR-11……………………………………………... 17 Workpapers
2016-2017 – Kenneth J. Barcia Input Pages………………………………………….....5 KJB-5A……………………………………….…....5, 12 KJB-5B……………………………………….……5, 12 KJB-5C……………………………………….……5, 12 KJB-5D……………………………….……………5, 12 KJB-6A…………………………………………..…5, 6 KJB-7A………………………………………….….…5 KJB-9A……………..………………………………5, 6
TABLE OF CONTENTS (continued)
BGSS Minimum Filing Requirement No.
2015-2016 – Kenneth J. Barcia
Input Pages……………………………..……….……5 KJB-2A…………………………….………………5, 6 KJB-2B…………………………….……………..….5 KJB-2C………………………………………….….10 KJB-5………………………………………….…5, 12 KJB-5A……………………………………….….5, 12 KJB-5B…………………………………………..5, 12 KJB-5C……..........................................................5, 12 KJB-5D………………………………………......5, 12 KJB-6………………………………….………….5, 6 KJB-6A.……………………………….………….5, 6
2015-2016 – Timothy W. Rundall TWR-1.……………………….……………..….…...8 TWR-2.………………….……………….....………8
4) CIP Testimony of Bruce S. Grossman
Exhibits: BSG-1 BSG-2
Testimony of Daniel P. Yardley Exhibits: DPY-1 DPY-2
DPY-3 DPY-4 DPY-5 DPY-6 DPY-7 DPY-8
STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES
IN THE MATTER OF THE PETITION OF SOUTH JERSEY GAS COMPANY TO REVISE THE LEVEL OF ITS BASIC GAS SUPPLY SERVICE (BGSS) CHARGE AND TO REVISE THE LEVEL OF ITS CONSERVATION INCENTIVE PROGRAM (CIP) CHARGES FOR THE YEAR ENDING SEPTEMBER 30, 2017
:::::
CASE SUMMARY
BPU DOCKET NO.
TO THE HONORABLE COMMISSIONERS OF THE BOARD OF PUBLIC UTILITIES:
By this Petition, South Jersey Gas Company (“South Jersey”) seeks authorization to
decrease the current level of its Periodic Basic Gas Supply Service (“BGSS”) charge and
increase the current level of its Conservation Incentive Program (“CIP”) charge.
The BGSS permits South Jersey to pass through to its customers increases or decreases in
the cost of purchased gas. The BGSS clause provides no profit to South Jersey. By this Petition,
South Jersey proposes to decrease its current periodic BGSS charge of $0.529214 per therm,
including taxes, to $0.354703 per therm, including taxes, for the BGSS year ending September
30, 2017. This will decrease the bill of a residential customer utilizing 100 therms of gas during
a winter heating month by $17.45 or 14.5%.
The CIP program is an incentive based conservation program. It requires South Jersey to
limit its recovery from customers of non-weather related margin revenue loss to the level of
BGSS cost reductions South Jersey is able to effect. By this Petition, South Jersey Gas seeks
authorization to increase the level of its conservation incentive program CIP charges and
implement the following CIP charges:
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RSG Non-Heating: $0.026628 per therm RSG Heating: $0.073013 per therm GSG: $0.058332 per therm GSG-LV: $0.017676 per therm
This will increase the bill of a residential heating customer utilizing 100 therms of gas
during a winter month by $13.20 or 11%.
The combined effect of these BGSS and CIP rate changes, if approved, for a residential
heating customer utilizing 100 therms of gas during a month, would be a decrease of $4.25 or
3.5%.
STATE OF NEW JERSEY BOARD OF PUBLIC UTILITIES
IN THE MATTER OF THE PETITION OF SOUTH JERSEY GAS COMPANY TO REVISE THE LEVEL OF ITS BASIC GAS SUPPLY SERVICE (“BGSS”) CHARGE AND TO REVISE THE LEVEL OF ITS CONSERVATION INCENTIVE PROGRAM (“CIP”) CHARGES FOR THE YEAR ENDING SEPTEMBER 30, 2017
:::::
PETITION
BPU DOCKET NO.
TO THE HONORABLE COMMISSIONERS OF THE BOARD OF PUBLIC UTILITIES:
Petitioner, South Jersey Gas Company (sometimes hereinafter referred to as "South
Jersey," "Petitioner," or "Company"), a public utility corporation of the State of New Jersey, with
its principal office at One South Jersey Plaza, Folsom, New Jersey, hereby petitions this
Honorable Board (sometimes hereinafter referred to as “BPU” or "Board") for authority to: 1)
decrease the level of its Periodic Basic Gas Supply Service (“BGSS”) charge; and 2) increase the
level of its Conservation Incentive Program (“CIP”) charge for the year ending September 30,
2017.
I. BACKGROUND
1. South Jersey is engaged in the transmission, distribution, transportation, and sale
of natural gas within its defined service territory within the State of New Jersey. Said service
territory includes all or portions of the following Counties: Atlantic, Burlington, Camden, Cape
May, Cumberland, Gloucester and Salem. Within its service territory South Jersey serves
approximately 375,000 customers.
II. BGSS BACKGROUND
2. On January 5, 1978, the Board, in combined Docket Nos. 769-988 and
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7712-1161, approved the adoption of a levelized Raw Materials Adjustment Clause for the
Company, effective for the period January 1, 1978 through October 31, 1978. The clause
subsequently became referred to as the "Levelized Gas Adjustment Clause" or "LGAC". It was
understood that after October 31, 1978 the clause would be adjusted annually, and each such
adjustment would be effective for a twelve-month period, generally commencing each November
1, from and after November 1, 1978. Each year thereafter, such an adjustment was made.
3. The LGAC mechanism was replaced by the BGSS price structure in the Board’s
Order Approving BGSS Price Structure, Docket No. GX01050304, dated January 6, 2003 (“2003
BGSS Order”).
4. Attached to the 2003 BGSS Order was “Attachment A”, which the Board
approved and incorporated therein.
5. Attachment A provided for the creation of a BGSS pricing mechanism,
consisting of a Monthly BGSS pricing mechanism and a Periodic BGSS pricing mechanism.
The applicability of Monthly and Periodic BGSS pricing was subsequently modified in South
Jersey’s base rate case (Docket No. GR03080683) and Global Settlement (Docket Nos.
GR03080683, et al.) approved by the Board on March 27, 2006.
6. As to South Jersey, all Residential Sales (Rate Schedule RSG) customers, and all
General Service Sales (Rate Schedule GSG) customers using less than 5,000 therms annually,
are served under the Periodic BGSS pricing mechanism.
7. The 2003 BGSS Order required that South Jersey file its annual BGSS filing by
June 1 of each year, with a request to implement its Periodic BGSS charge on or before October
1 of that year.
8. The 2003 BGSS Order also provided that South Jersey may file two self-
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implementing Periodic BGSS charge increases, to be effective on December 1 of the same
calendar year following implementation of a new Periodic BGSS Charge and on February 1 of
the following year. Each such self-implementing increase may not exceed five percent (5%) of
the average 100 therm residential bill.
9. In Docket No. GR02090645, South Jersey, the Division of the Ratepayer
Advocate, and the Staff of the Board executed a “Settlement – BGSS Minimum Filing
Requirements” on May 7, 2003 (the “2003 Settlement”). The Settlement was accepted by Board
Order dated June 29, 2003.
10. This Petition complies with the Minimum Filing Requirements (“MFRs”) set
forth in the 2003 Settlement.
11. On June 1, 2015, South Jersey made its annual BGSS filing in Docket No.
GR15060642, proposing to decrease the periodic BGSS charge from its then current level of
$0.650270 per therm to $0.529214 per therm, including taxes.
12. By Order dated March 23, 2016, the Board approved a Stipulation of Settlement
to finalize South Jersey’s periodic BGSS charge of $0.529214 per therm, including taxes, subject
to refund with interest on any net over-recovered BGSS balance. The Board also approved, on a
final basis, the following: (1) the gas cost portion of the Company’s D-2 charge for Rate
Schedule LVS at $16.545047 per Mcf (including taxes); (2) the gas cost portion of the firm D-2
charges at $15.581692 per Mcf (including taxes), and the limited firm D-2 charges at $8.272524
per Mcf (including taxes) for Rate Schedule EGS-LV; (3) the gas cost portion of the D-2 charge
at $8.272524 per Mcf (including taxes) for Rate Schedule FES; and (4) the monthly BGSS non-
commodity rate applicable to Rate Schedules GSG, GSG-LV, EGS, LVS and EGS-LV at
$0.133252 per therm (including taxes).
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III. REQUESTED PERIODIC BGSS CHARGE
13. By the present Petition, South Jersey is proposing to decrease its current Periodic
BGSS charge from $0.529214 (including taxes) to $0.354703 (including taxes) for the period
beginning October 1, 2016 and ending September 30, 2017. This Petition is based upon 7
months of actual data, and 17 months of estimated data. Petitioner proposes to update this
information as this matter proceeds.
14. South Jersey has included a credit to BGSS gas costs of $11.7 million, which was
derived from the Board’s approved margin sharing formula applicable to off-system sales,
interruptible sales and transportation, and capacity releases.
15. The projected pipeline demand type costs reflected in this filing pertaining to the
purchase, storage and transportation of gas on the Transcontinental Gas Pipeline Company, LLC
(“Transco”), Columbia Gas Transmission, LLC (“Columbia”), and Dominion Transmission, Inc.
(“Dominion”) pipeline systems reflect each pipelines’ most recent FERC approved jurisdictional
rates.
16. Commodity charges to be experienced by South Jersey during the BGSS year
ending September 30, 2017 have been projected utilizing: (1) the New York Mercantile
Exchange strip pricing, as of May 10, 2016; and (2) estimated indices at the various locations
where South Jersey expects to purchase gas during the forthcoming BGSS year.
17. LNG costs are based upon the delivered cost of LNG using the NYMEX as of
May 10, 2016, along with costs related to processing natural gas into liquefied natural gas. In
response to the changes in the LNG marketplace in 2012, the Company decided to construct,
own and operate its own liquefaction facility at South Jersey’s McKee City, LNG facility to
ensure that LNG is available at a prudent cost and not subject to marketplace pressures. The
5
LNG liquefaction facility is under construction and expected to be in service during the fourth
quarter of 2016.
18. In summary, by this Petition, South Jersey seeks authority to decrease the level of
its Periodic BGSS charge to $0.354703 per therm (including taxes). South Jersey also seeks
authority to increase the Monthly BGSS non-commodity rate component to $0.138898 per therm
(including taxes), resulting in an increase of $0.005646 from the current rate.
IV. BEST VALUE PURCHASING POLICY
19. The Company's proposal in this Petition again reflects its best value purchasing
policy. Pursuant to this policy, it is the Company's goal to purchase the minimum priced gas
supplies feasible within the guidelines of security of supply and capacity and system integrity.
South Jersey intends to continue to pursue its policy to ensure the safest, most secure service to
its customers, at reasonable prices, for this BGSS year and into the future.
20. The BGSS provides no profit to the Company. It merely allows the Company to
pass through to its customers increases and decreases in the costs of gas and associated taxes
experienced by the Company.
21. In support of the BGSS portion of this Petition, Petitioner incorporates the
following testimony, exhibits, and work papers:
A. Prepared Direct Testimony of Kenneth J. Barcia, Manager, Rates and Revenue Requirements; and
B. Prepared Direct Testimony of Timothy W. Rundall, Senior Director, Gas Supply and Allocations
22. In support of the BGSS petition, Petitioner incorporates the attached Table of
Contents demonstrating compliance with the MFRs.
V. CIP BACKGROUND AND PROPOSAL
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23. On October 12, 2006, the Board, in combined Docket Nos. GR05121019 and
GR05121020, adopted a stipulation (“CIP Stipulation”) implementing the Conservation
Incentive Program (“CIP”) for South Jersey on a three-year, Pilot Program basis. The CIP
Program was then extended until September 30, 2013, with an additional automatic one year
extension, by Board Order dated January 21, 2010 in combined Docket Nos. GR05121019 and
GR05121020.
24. On May 21, 2014, the Board approved the continuation of the CIP, with certain
modifications, as set forth in more detail in the Stipulation executed by the parties in Docket No.
GR13030185 (the “CIP Continuation Stipulation”). The changes approved by the Board became
effective with the CIP year beginning October 1, 2014 and are reflected in this proceeding.
25. To promote conservation, the CIP program was devised as an incentive-based
program in which South Jersey was required to limit the recovery of non-weather related margin
revenue loss to the level of BGSS cost reductions South Jersey is able to achieve. Because of
these BGSS savings, customer bills will not increase as a result of the Company’s recovery of
such non-weather margin revenue losses through the CIP mechanism.
26. The CIP Continuation Stipulation approved by the Board established a Modified
BGSS Savings Test with three categories of BGSS savings: (1) permanent savings achieved
through permanent capacity releases or contract terminations; (2) gas cost savings from
reductions of capacity on a long-term basis, i.e. for periods of at least one year; and (3) savings
associated with avoided capacity costs to meet residential customer growth.
27. The attached Prepared Direct Testimony of Daniel P. Yardley demonstrates that
sufficient BGSS savings exist to support South Jersey’s proposed CIP charge.
28. The CIP Stipulation also provided that South Jersey would implement a package
7
of incremental conservation programs designed to aid customers in reducing their costs of
natural gas. Furthermore, South Jersey committed to assess the need to develop and implement
future programs, if appropriate.
29. In the CIP Continuation Stipulation, South Jersey agreed to provide five hundred
thousand dollars ($500,000) annually of shareholder money to fund CIP programs. The CIP
Continuation Stipulation further provided that in any year in which the $500,000 was not
expended, the difference between $500,000 and the actual amount spent will be carried over and
added to the amount to be spent in the following year.
30. The attached Direct Testimony of Bruce S. Grossman, Program Manager,
Residential Energy Efficiency Education and Consulting for South Jersey, explains the
Company’s incurred and projected CIP expenditures for the 2015-2016 CIP Year. South Jersey
projects that it will invest $500,000 in conservation programs by September 30, 2016.
31. It was agreed in the CIP Stipulation that South Jersey would make an annual CIP
filing based upon seven months of actual data and five months of projected data, to be filed on or
before June 1 of each year. The filing is to document actual results, perform the required CIP
collection tests, and propose the new CIP rate. This Petition is in conformity with these
provisions of the CIP Stipulation.
32. Rider M of the Company’s tariff contains a Board approved Return-on-Equity
(“ROE”) limitation on recoveries from customers pursuant to the CIP, consistent with South
Jersey’s former Temperature Adjustment Clause (“TAC”) (the “ROE Test”). Under this
provision, the CIP may not contribute toward earnings in excess of a 9.75% ROE. After
recovery of the CIP margin revenues, South Jersey’s ROE for the period October 1, 2015
through September 30, 2016 is projected to be 7.72%. As a result, the ROE test will not act as a
8
limitation on South Jersey’s recovery through the CIP for the forthcoming 2016-2017 CIP year.
This projected ROE is calculated on Schedule A to this Petition and is verified by Kenneth J.
Barcia, Manager, Rates and Revenue Requirements.
33. The Company’s CIP tariff also contains benchmarks for customer usage by
customer class. The CIP is calculated on a class-by-class basis by comparing actual usage for
the CIP year to the benchmark usage. The difference, either positive or negative, is then
multiplied by revenue margins per customer class, and the result is divided by forecasted sales
units. The result, either positive or negative, is then either a charge or credit to the CIP on a
class-by-class basis.
34. The CIP charge was initially set at $0.000 for the period October 1, 2006 through
September 30, 2007 and, thereafter, annual petitions were filed to adjust the CIP charge.
35. On June 1, 2015, South Jersey filed its petition in Docket No. GR15060642
seeking to establish provisional CIP rates for the October 1, 2015 to September 30, 2016 CIP
year. On September 21, 2015, the Board issued its Order in Docket No. GR15060642,
provisionally accepting CIP rates, subject to review. Pursuant to this September 21, 2015 Order,
the provisional CIP rates implemented were:
RSG Non Heating ($0.099971) RSG Heating ($0.058946) GSG ($0.031700) GSG-LV ($0.025487)
36. By Order dated March 23, 2016, the Board approved a Stipulation of Settlement
to finalize the CIP rates in Docket No. GR15060642.
37. In this Petition, South Jersey proposes to establish the CIP rates for the period
9
October 1, 2016 through September 30, 2017. The proposed CIP rates are as follows:
RSG Non Heating $0.026628 RSG Heating $0.073013 GSG $0.058332 GSG-LV $0.017676
38. In computing the non-weather CIP value, the margin impact of weather is first to
be deducted from the total CIP charge or credit. The weather-related component of the CIP is
recovered through the CIP. However, this portion is not subject to the Modified BGSS Savings
Test. By this Petition, South Jersey seeks to recover $21.9 million of weather-related margin
revenues. The non-weather related CIP component shall be subject to a dual eligibility test
comprised of the Modified BGSS Savings Test and a Margin Revenue Test established in the
CIP Continuation Stipulation. In order to be eligible for recovery, non-weather related CIP
impacts must pass both cost recovery tests. Amounts that do not pass one or both tests may still
be recoverable in future years.
39. South Jersey’s non-weather related margin is $5.8 million. This was established
by subtracting the weather related component of $21.9 million, from the total CIP amount of
$27.7 million. Thus, by this Petition, South Jersey seeks to recover total non-weather related
margin revenue through the CIP totaling $5.8 million.
40. South Jersey has provided BGSS savings information in the Prepared Direct
Testimony of Timothy W. Rundall and Daniel P. Yardley. South Jersey’s permanent BGSS
savings realized from the permanent capacity releases or contract terminations (Category One of
the Modified BGSS Savings Test) total $2.2 million per year. BGSS savings realized from gas
cost savings from reductions of capacity on a long-term basis (Category Two of the Modified
BGSS Savings Test) total $6.1 million. BGSS savings realized from avoided capacity costs to
meet residential customer growth (Category Three of the Modified BGSS Savings Test) total
10
$260,288. Therefore, the total BGSS savings for the 2016-2017 CIP year is $8.6 million. This
amount exceeds the $5.8 million of non-weather related margin revenue that will be recovered
through the CIP, thus the Modified BGSS Savings Test has been met.
41. As explained in Mr. Yardley’s testimony, variable margin revenues also exceed
the $5.8 million of non-weather related margin revenue that will be recovered through the CIP,
thus the Margin Revenue Test has also been met.
42. In the present proceeding, South Jersey is comparing customer usage for the
period October 1, 2015 through September 30, 2016 against the benchmark. The difference is to
be recovered for the BGSS year October 1, 2016 through September 30, 2017.
43. In support of the Company’s CIP proposal in this Petition, Petitioner incorporates
the following testimony, exhibits, and work papers:
A. Prepared Direct Testimony of Bruce S. Grossman, Program Manager, Residential Energy Efficiency Education and Consulting, South Jersey;
B. Prepared Direct Testimony of Daniel P. Yardley, Principal, Yardley & Associates; and
C. Schedule A – South Jersey Gas Company ROE Calculation
44. The effect of the proposed CIP change, if approved, for a residential heating
customer utilizing 100 therms of gas in a month would be an increase of $13.20 or 11%.
45. The combined effect of the proposed BGSS and CIP changes, if approved, for a
residential heating customer utilizing 100 therms of gas in a month would be a decrease of $4.25
or 3.5%.
VI. MISCELLANEOUS
46. A draft Notice of Filing and Public Hearing is attached hereto, as Schedule B.
47. South Jersey has served notice and a copy of this Petition upon Director, Division
of Rate Counsel, 140 East Front Street – 4th Floor, Trenton, New Jersey 08625.
4
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SCHEDULE A
NOTICE OF FILING OF PETITION AND OF PUBLIC HEARING
IN THE MATTER OF THE PETITION OF SOUTH JERSEY GAS COMPANY TO REVISE THE LEVEL OF ITS BASIC GAS SUPPLY SERVICE (“BGSS”) CHARGE; AND TO REVISE THE LEVEL OF ITS
CONSERVATION INCENTIVE PROGRAM (“CIP”) CHARGES FOR THE YEAR ENDING SEPTEMBER 30, 2017
B.P.U. Docket No. _____________
NOTICE IS HEREBY GIVEN that, on June 1, 2016, South Jersey Gas Company (“SJG” or “South Jersey”) filed its combined 2016-2017 Basic Gas Supply Service (“BGSS”) and Conservation Incentive Program (“CIP”) petition
with the New Jersey Board of Public Utilities (“Board”). The BGSS component of the petition was filed pursuant to the “Order Approving BGSS Price Structure” issued by the Board on January 6, 2003, in Docket No. GX01050304 (Generic BGSS Order). BGSS rates are designed to recover South Jersey’s cost of gas applicable to customers who purchase gas from South Jersey. The Company earns no profit from BGSS. The CIP component of the petition sought a price adjustment for all applicable service customers. The CIP is an incentive-based program that requires South Jersey Gas to reduce gas supply related costs and limits recovery of non-weather related revenue loss to the level of gas supply costs savings achieved. Pursuant to its filings, SJG requested that the Board allow it to change its BGSS and CIP Charges. The impact of the Company's combined proposals on the overall bills for gas service for a residential heating customer using 100 therms in a month would be a decrease of $4.25, or 3.54 percent, resulting from SJG’s proposed BGSS decrease of $17.45 per month, or 14.5 percent, on a 100 therm bill and SJG’s proposed CIP increase of $13.20, or 11.0 percent, on a 100 therm bill. The chart below demonstrates the impact of the BGSS and CIP rate changes:
Rates Change Proposed Therm Bill as of Bill as of
Customer Type Level June 1, 2016 October 1, 2016 Amount Percent Residential Heat Sales 100 $120.20 $115.95 $(4.25) (3.5)% Residential Non-Heat Sales 15 $25.60 $24.88 $(0.72) (2.8)% General Service 500 $540.91 $498.67 $(42.24) (7.8)% General Service - LV 15,646 $11,263.60 $11,938.93 $675.33 6.0%
TAKE FURTHER NOTICE that other changes in SJG’s price for BGSS service may also occur if SJG elects to adjust its BGSS rates upward upon thirty days notice with the Board Staff and the Rate Counsel, pursuant to the Generic BGSS Order in Docket No. GX01050304. Any such self-implementing increases will be limited to a maximum of 5 percent of the total residential bill, effective December 1, 2016, and to a maximum of 5 percent of the total residential bill, effective February 1, 2017, as demonstrated in the chart below.
Rates Change Proposed Bill Including December Therm Bill as of and February
Customer Type Level October 1, 2016 5 Percent Increases Amount Percent Residential Heat Sales 100 $115.95 $127.83 $11.88 10.2% Residential Non-Heat Sales 15 $24.88 $26.66 $1.78 7.2% General Service 500 $498.67 $558.13 $59.46 11.9% General Service - LV 15,646 $11,938.93 $11,938.93 $0 0%
Further, these self-implementing increases will be provisional and subject to true-up in connection with the subsequent annual BGSS filing. Pursuant to the BGSS Order, SJG is permitted to decrease its BGSS rate at any
SCHEDULE B
time upon five days notice and supporting documentation to the Board of Public Utilities and the Division of Rate Counsel. The Board has the statutory authority to establish the BGSS and CIP Charges at levels it finds just and reasonable. Therefore, the Board may establish the BGSS and CIP Charges at levels other than those proposed by SJG. SJG’s natural gas costs addressed in this petition will remain subject to audit by the Board, and Board approval shall not preclude or prohibit the Board from taking any such actions deemed appropriate as a result of any such audit. Copies of the Company’s filing are available for inspection at the Company offices located at One South Jersey Plaza, Folsom, New Jersey 08037, or at the Board of Public Utilities, 44 South Clinton Avenue, 9th floor, Trenton, New Jersey 08625-0350. The Company’s filing may also be found on the South Jersey Gas Website at www.southjersegas.com/for-my-home/current-regulatory-filings.html. NOTICE is further given that public hearings have been scheduled at the following date, times, and place on the Company’s above-mentioned requests:
___________________ at 4:30 and 5:30 PM
Voorhees Township, Municipal Court Voorhees Town Center
Voorhees, New Jersey 08043 (located directly across from Township Library at 203 Laurel Road)
The public is invited to attend and interested persons will be permitted to testify and/or make a statement of their views on the proposed increases/decreases. In order to encourage full participation in this opportunity for public comment, please submit any requests for needed accommodations, including interpreter, listening devices or mobility assistance, 48 hours prior to these hearings. In addition, members of the public may submit written comments concerning the petition to the Board regardless of whether they attend a hearing by addressing them to: Irene Kim Asbury, Secretary, Board of Public Utilities, 44 S. Clinton Avenue, P.O. Box 350, Trenton, NJ 08625-0350.
SOUTH JERSEY GAS COMPANY By: Jeffrey E. DuBois, President
SCHEDULE B
DIRECT TESTIMONY 1 OF 2
KENNETH J. BARCIA 3 MANAGER, RATES AND REVENUE REQUIREMENTS 4
SOUTH JERSEY GAS COMPANY 5 JUNE 2016 6
7
I. INTRODUCTION 8
Q. Please state your name, affiliation and business address. 9
A. My Name is Kenneth J. Barcia, and I am the Manager of Rates and Revenue 10
Requirements for South Jersey Gas Company (“South Jersey” or “SJG” or the 11
“Company”). My business address is South Jersey Gas, One South Jersey Plaza, 12
Route 54, Folsom, NJ 08037. 13
14
Q. Please summarize your educational and professional background. 15
A. I joined South Jersey Industries, Inc. (“SJI”) in December 2011, as Risk 16
Management Project Specialist. In March of 2013, I was promoted to Credit 17
Manager of the Risk Management Department of SJI. Most recently, in May of 18
2015, I accepted my current role as Manager, Rates and Revenue Requirements 19
with South Jersey. Prior to my employment with South Jersey, I held various 20
positions in the engineering and accounting fields. I hold a Bachelor of Science 21
degree in Environmental Engineering and in Accounting, both from Temple 22
University, 1992 and 2002, respectively. I am a member of the American Gas 23
Association (AGA), where I serve on the State Affairs Committee, and the New 24
Jersey Utilities Association (NJUA), where I serve on the Finance and Regulations 25
Committee. 26
2
In my current role, I manage the daily activity of the Company’s Rates and Revenue 1
Requirements department and provide support and strategic direction regarding rate 2
and revenue related filings before the Board of Public Utilities (“BPU” or “Board”). 3
I also assist with the development and interpretation of the Company’s tariff. 4
5
Q. What is the purpose of your testimony? 6
A. The purpose of my testimony in this proceeding is to: (1) review the actual results 7
of the Basic Gas Supply Service (“BGSS”) Clause for the 2015-2016 year; (2) 8
present the projected gas costs and recoveries in the 2016-2017 BGSS Clause 9
(“BGSSC”) year; (3) support the BGSS charges proposed to become effective 10
October 1, 2016; and (4) support proposed revisions to South Jersey’s tariff. 11
12
II. REGULATORY HISTORY 13
Q. Please describe the regulatory history of the Basic Gas Supply Service 14
(“BGSS”) Clause? 15
A. On January 6, 2003, the Board issued its “Order Approving BGSS Price Structure” 16
(“BGSS Order”). The BGSS Order directed the gas distribution companies to 17
immediately implement the BGSS pricing mechanism, which consists of the 18
Monthly BGSS charge and the Periodic BGSS charge. 19
The Monthly BGSS charge is currently applicable to all Rate Schedule GSG sales 20
customers having an annualized usage of 5,000 therms or more and to all sales 21
customers served under Rate Schedules GSG-LV, LVS, EGS and EGS-LV. South 22
Jersey’s Monthly BGSS charge was implemented March 1, 2003, and is filed with 23
3
the Board each month utilizing the BGSS pricing formula approved by the BGSS 1
Order. 2
The Periodic BGSS charge is currently applicable to all sales customers served 3
under Rate Schedule RSG, and all Rate Schedule GSG sales customers having an 4
annualized usage of less than 5,000 therms. 5
The BGSS Order requires the gas utilities to make a BGSS filing with the Board 6
each year by June 1, with the intention that the Periodic BGSS charge would be 7
effective on October 1 of each year. As a result of the BGSS Order, South Jersey 8
also has the discretion to file notice for two self-implementing rate increases to the 9
Periodic BGSS charge, to be effective on or about December 1 and/or February 1, 10
following the October 1 effective date. 11
On May 7, 2003, in Docket No. GR02090645, the parties to the proceeding entered 12
into a Settlement regarding the minimum filing requirements for the annual BGSSC 13
proceedings. This settlement was approved by Board Order dated June 29, 2003. 14
Annual BGSS filings since 2003 have followed this process. A table of contents 15
has been submitted with South Jersey’s Petition in this proceeding, which also 16
serves as a reference demonstrating that the Exhibits and work papers submitted 17
with the Petition meet each of the minimum filing requirements. 18
On June 1, 2015, South Jersey made its annual filing in Docket No. GR15060642, 19
where it proposed to decrease its periodic BGSS charge from the then current rate 20
of $0.650270 per therm, to $0.529214 per therm, both inclusive of taxes. 21
4
By Order dated September 21, 2015, the Board approved a Stipulation of 1
Settlement approving a Periodic BGSS Rate of $0.529214 per therm, including 2
taxes, on a provisional basis. 3
By Order dated March 23, 2016, the Board approved a Stipulation of Settlement to 4
finalize this BGSS rate for the 2015-2016 BGSS year. 5
6
III. BGSS RATES CALCULATION 7
Q. Please describe how the 2016/2017 BGSS Rates are calculated? 8
A. Exhibit KJB-1 demonstrates the derivation of the proposed Periodic BGSS charge 9
of $0.354703, which consists of commodity, deferred balance, and non-commodity 10
gas cost rate components. It starts with a projected commodity cost of gas of 11
$82,828,036, shown on line 8, which includes South Jersey’s approved line loss of 12
1.43%. This results in a BGSS commodity rate of $0.305646 per therm, excluding 13
taxes, when dividing the commodity cost of gas by the applicable sales volumes. 14
Next, the projected total over-recovered deferred balance of $(8,274,019) is shown 15
on line 20. Line 22 identifies the applicable sales volumes utilized to derive the net 16
deferred balance rate of $(0.030532) per therm, excluding taxes, which is shown on 17
Line 24. Lastly, the non-commodity costs, shown on line 32, are $15,082,499 for 18
the Periodic BGSS customers and $4,999,984 for the Monthly BGSS customers. 19
The associated volumes and non-commodity cost rates are shown on lines 34 and 20
36, respectively. 21
22
5
Q. Is South Jersey proposing a decrease or an increase to its 2016/2017 Periodic 1
BGSS Rate? 2
A. In summary, South Jersey is proposing a decrease of $0.174511 to its Periodic 3
BGSS rate. As reflected in Exhibit KJB-1, South Jersey has calculated the Periodic 4
BGSS rate to be set at $0.330770 per therm, excluding taxes, or $0.354703 per 5
therm, including taxes, for Rate Schedule RSG, and for Rate Schedule GSG 6
Customers whose annual usage is less than 5,000 therms. This represents a 7
decrease of $17.45, or 14.5%, to a typical residential heating customer bill, based 8
on 100 therms of consumption during a month. 9
The proposed Periodic BGSS charge would recover commodity, non-commodity 10
gas costs, and the projected deferred balance. The Periodic BGSS charge would 11
consist of a BGSS commodity rate of $0.305646 per therm, a deferred balance 12
component of $(0.030532) per therm, and a BGSS non-commodity rate of 13
$0.055656 per therm, all excluding taxes. 14
Moreover, since Rate Schedules GSG-LV, EGS, LVS and EGS-LV customers, and 15
Rate Schedule GSG customers whose annual consumption is 5,000 therms or 16
greater, recover some or all of their fixed gas costs through their Monthly BGSS 17
charge, as prescribed in South Jersey’s tariff (Rider A), the calculated Monthly 18
BGSS non-commodity rate component would be $0.138898 per therm, including 19
taxes, which is an increase of $0.005646 from the current rate of $0.133252. 20
Pursuant to Rate Schedule LVS, Special Provision (n) of the Company’s currently 21
approved Tariff, the gas cost portion of the Firm D-2 charge is composed of the 22
system weighted average interstate pipeline demand charge plus the system 23
6
weighted average gas reservation charge as of October 1 of each year, plus 1
applicable taxes. Pursuant to Rate Schedule EGS-LV, Special Provision (f), of the 2
Company’s currently approved tariff, the gas cost portion of the Firm D-2 charge is 3
composed of the highest pipeline demand cost imposed upon the Company by any 4
interstate pipeline applicable October 1 of each year, plus applicable taxes. The 5
Firm FES and Limited Firm EGS-LV gas cost portion of the D-2 rate is one-half the 6
weighted average of all interstate pipeline demand charges applicable to the 7
Company at October 1 of each year, plus applicable taxes. 8
Therefore, in accordance with South Jersey’s tariff, South Jersey proposes that the 9
gas cost portion of the D-2 charge for Rate Schedule LVS be set at $15.958901 per 10
Mcf, including taxes. South Jersey also proposes that the gas cost portion of the 11
Firm D-2 charge for Rate Schedule EGS-LV would remain unchanged at 12
$15.581692 per Mcf, including taxes. Lastly, South Jersey proposes that the gas 13
cost portion of the Limited Firm D-2 and Firm D-2 charges for Rate Schedules 14
EGS-LV and FES, respectively, be set at $7.979450 per Mcf, including taxes. 15
16
IV. REVIEW OF 2015-2016 BGSS YEAR 17
Q. Please provide a summary of Actual and Projected Results related to the 2015- 18
2016 BGSS Clause? 19
A. Exhibit KJB-2 is a summary of actual and projected results for the twelve month 20
period ending September 30, 2016. It reflects a projected over-recovery as of 21
September 30, 2016 of $(8,274,019). This exhibit reflects $62,406 in pipeline 22
7
refunds and $25,944,370 in credits from interruptible sales, interruptible 1
transportation, off-system sales, and off-system and on-system capacity releases. 2
Section A of Exhibit KJB-2, entitled Natural Gas, shows the cost of natural gas 3
purchased by South Jersey on Line 9. This amount is increased by the cost of 4
withdrawals from inventory, and is reduced by the cost of gas injected into 5
inventory during the period, as the BGSSC is only charged for commodity gas costs 6
upon its actual usage, not its purchase. Lastly, this amount is then increased or 7
decreased as a result of the marketer imbalance for the month. 8
Section B of Exhibit KJB-2, entitled Supplemental Gas, identifies the cost of 9
liquefied natural gas (“LNG”) utilized during the period. 10
Section C of Exhibit KJB-2, entitled Cost Reductions, provides reductions to the 11
cost of gas applicable to the BGSSC. These reductions include the applicable cost 12
of gas sold under the Company’s interruptible rate schedules and off-system sales, 13
pipeline refunds, company use gas, and gas cost credits derived from interruptible 14
sales, interruptible transportation, off-system sales, and off-system and on-system 15
capacity releases utilizing the Board approved sharing formulas. Sections A, B, and 16
C are summarized in Section D as the Total Gas Cost to BGSS (line 29). 17
Section D of Exhibit KJB-2, entitled Cost Recovery, demonstrates that the total 18
projected cost of gas to the BGSSC of $94,084,375 (line 29), less the projected 19
recoveries of $139,420,267 (lines 30 and 31), plus a Periodic BGSS customer bill 20
credit of $18,685,891 given in January 2016 (line 32), less the cumulative under-21
recovery beginning balance of $18,375,982 (line 36), results in a projected 22
8
Cumulative Over-Recovery Ending Balance of $(8,274,019) (line 38) at September 1
30, 2016. 2
3
Q. What is the Projected Carrying Cost associated with the 2015-2016 BGSS 4
Clause? 5
A. Exhibit KJB-3 is a statement of projected accrued interest on the BGSSC. This 6
Exhibit reflects the monthly calculation of interest on the average cumulative 7
BGSSC balance. Column 2 shows the monthly BGSSC activity. Column 3 reflects 8
the cumulative under or over-recovered balance at the end of each month. Column 9
4 is the average of the current month’s and prior months’ cumulative balance. 10
Column 5 is the overall rate of return on rate base, shown on a monthly basis, which 11
was utilized to establish base rates in the Company’s most recent base rate case. 12
Column 6 shows the monthly interest, while Column 7 shows the cumulative 13
interest. Exhibit KJB-3, line 36, shows that the projected total annual interest to be 14
credited to the BGSSC is $0.00. The Board policy as to South Jersey’s interest rate 15
was set forth in Docket No. GR87091101. In that Docket, the Board determined 16
that the overall rate of return last used to set South Jersey’s base rates was the 17
proper interest rate for inclusion in the BGSSC calculation. In Docket No. 18
GR89080731, the Board ruled that the monthly offset methodology was the proper 19
methodology for calculating BGSSC interest. 20
21
22
23
9
V. PROJECTION OF THE 2016-2017 BGSSC YEAR 1
Q. Can the Company please provide a projection and summary of the 2016 – 2017 2
BGSS Clause year? 3
A. The analysis of the gas costs and recoveries for the 2016-2017 BGSS Clause year is 4
detailed on Exhibits KJB-4 through KJB-10 of my testimony. This analysis is 5
composed of the following sub-sections: 6
Exhibit - KJB-4 2016-2017 BGSSC Summary
Exhibit - KJB-5 Projected Gas Cost to BGSSC
Exhibit - KJB-6 Monthly Interruptible/Off-System Capacity Release Credit
Exhibit - KJB-7 BGSSC Recoveries Utilizing Current Rates
Exhibit - KJB-8 BGSSC Cost Recovery Allocation
Exhibit - KJB-9 Proof of BGSSC Recovery
Exhibit - KJB-10 Projected Carrying Cost on 2016-2017 BGSSC
7 Exhibit KJB-4 begins with the projected September 30, 2016 over-recovery of 8
$(8,274,019). As reflected in Exhibit KJB-4, line 7, no interest is projected to be 9
credited to the Clause during the 2015-2016 BGSS year. Line 11 of Exhibit KJB-4 10
shows the projected cost of gas for the 2016-2017 BGSS Clause year to be 11
$149,197,424. The derivation of this figure is shown on Exhibit KJB-5. There will 12
be a credit to gas costs of $11,703,842, as calculated on Exhibit KJB-6, derived 13
from the projected pre-tax margins on interruptible sales, interruptible 14
transportation, off-system sales, and capacity releases. The projected net cost of gas 15
of $129,219,563 is then compared to the projected total cost recoveries of 16
$173,125,434 at current rates, shown on Exhibit KJB-7. The BGSSC should be 17
decreased by the $43,905,871 balance on Exhibit KJB-4, (line 19), or $47,082,636 18
including applicable taxes on Exhibit KJB-4, (line 25). 19
10
1
Q. What are the Projected Gas Costs to BGSSC? 2
A. Exhibit KJB-5 provides a breakdown of the cost components that are projected for 3
the 2016-2017 BGSS Year. This Exhibit reflects the total gas costs, storage 4
injection and withdrawal costs, LNG costs and Company use gas. These costs total 5
$149,197,424 (line 24), which is the projected cost of gas send out. 6
7
Q. Can the Company provide detail for the Monthly Interruptible, Off-System 8
and Capacity Release Credit? 9
A. Exhibit KJB-6 details the derivation of the credit to gas costs from interruptible 10
sales, interruptible transportation, off-system sales, and off-system and on-system 11
capacity releases. South Jersey included a credit to BGSS gas costs of $11,703,842 12
(line 18), which was derived from the Board’s approved margin sharing formula in 13
South Jersey’s base rate case order dated July 8, 2004 (Docket No. GR03080683). 14
The sharing formula provides for 85% of pre-tax margins to be credited to the 15
BGSSC, and 15% to South Jersey. 16
17
Q. What is South Jersey’s calculation for monthly BGSSC Recoveries? 18
A. Exhibit KJB-7 demonstrates the calculation of monthly recoveries utilizing current 19
rates. Based on current rates, the BGSSC cost recoveries are projected to be 20
$173,125,434 (line 62). In developing the cost recovery calculation, firm therm 21
sales and firm transportation volumes are multiplied by the currently applicable unit 22
11
recovery rates, as reflected in my work papers, to determine BGSSC cost 1
recoveries. 2
Anticipated therm sales to residential, commercial, and small industrial customers 3
are based upon normal temperatures, projected customer levels and usage factors. 4
Projected therm sales to customers subscribing to Rate Schedules LVS, EGS-LV, 5
and FES are predicated upon individual customers’ contracts or the anticipated 6
levels of such contracts. 7
8
Q. Please explain the Company’s BGSS Clause Cost Recovery Allocation? 9
A. Exhibit KJB-8 shows the elements making up the commodity and non-commodity 10
gas cost components and the deferred balance at September 30, 2016. Line 9 of this 11
Exhibit reflects the commodity cost of natural gas purchased by South Jersey. It 12
does not include the cost of gas associated with interruptible or off-system sales. 13
This amount is then reduced by the cost of gas injected into inventory during the 14
period, as the BGSSC is only charged for commodity gas costs upon its actual 15
usage, not its purchase. Next, it is increased by the cost of withdrawals from 16
inventory. The variable costs of storage and LNG commodity costs are also added 17
to the result. Lastly, the recoveries applicable to commodity costs are credited to 18
the commodity cost of gas. These recoveries include Monthly BGSS and FES 19
sales, and sales from South Jersey’s Rate Schedules YLS and SLS. 20
Line 29 of Exhibit KJB-8 shows the projected over recovered balance at September 21
30, 2016. 22
12
As reflected on Exhibit KJB-8, the Company allocated the non-commodity costs 1
and applicable credits between the Periodic and Monthly priced BGSS customers. 2
The allocation is based on each groups’ (Periodic and Monthly priced) respective 3
anticipated sales volumes. 4
The non-commodity charges consist of the annual pipeline and storage demand 5
charges. These costs are netted with applicable credits, refunds, and recoveries, to 6
derive the total non-commodity costs. Credits include those applicable to company 7
use gas, pipeline refunds, interruptible sales and transportation, off-system sales and 8
on-system and off-system capacity releases. Recoveries include balancing charges 9
applicable to customers subscribing to Rate Schedules RSG, GSG, GSG-LV, CTS, 10
LVS, EGS, and EGS-LV. Recoveries also include the D-2 gas cost component 11
applicable to sales customers subscribing to Rate Schedules LVS, EGS-LV and 12
FES, as shown on line 53. Currently, line 53 of Exhibit KJB-8 reflects only the D-2 13
gas cost component recoveries of Rate Schedule FES, as all of South Jersey’s LVS 14
and EGS-LV customers are transporting. 15
16
Q. Please provide a summary of projected Proof of Recovery for the 2016-2017 17
BGSS Clause Year? 18
A. Exhibit KJB-9 provides a projected summary of the 2016-2017 BGSSC year on a 19
proof of recovery basis, based on South Jersey’s calculated $0.354703 per therm 20
rate, including taxes. Exhibit KJB-9 also provides a summary by month of the 21
2016-2017 BGSSC based upon the calculated gas cost levels, credits thereto and 22
13
gas cost recoveries. In short, this Exhibit shows that the 2016-2017 BGSS year 1
will end with a near zero balance, as shown on line 38, at September 30, 2017. 2
3
Q. What is the Projected Carrying Cost associated with the 2016-2017 BGSS 4
Clause Year? 5
A. Exhibit KJB-10 is a statement of projected accrued interest related to the 2016-2017 6
BGSS Clause Year. This Exhibit reflects the projected balances and interest 7
projected for the 2016-2017 year. Exhibit KJB-10, line 36, demonstrates that there 8
is projected interest of $307,396 due to the rate payers for the 2016-2017 BGSS 9
Year. 10
11
VI. TARIFF CHANGES 12
Q. Please provide the Company’s proposed tariff pages with all proposed 13
changes? 14
A. Exhibit KJB-11 consists of the proposed tariff pages reflecting South Jersey’s 15
proposed changes to its Periodic BGSS charge and D-2 gas cost component for Rate 16
Schedules LVS, EGS-LV and FES. All tariff pages in Exhibit KJB-11 have been 17
black lined for review purposes. 18
19
Q. Does this conclude your Testimony? 20
A. Yes, it does. 21
1 2 3 4 5C
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er M
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220
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ery
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tion
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ural
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)8 9
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al F
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erru
ptib
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nd O
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$18,
999,
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$16,
873,
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$9,8
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3$1
0,50
2,66
7$1
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5$1
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0,33
1,83
0$9
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$137
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ter
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ce$4
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$131
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$130
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$2,4
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$350
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$340
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$681
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$1,9
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53$7
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1$9
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17 18 19S
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and
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terr
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Sub
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to R
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7 B
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4 5O
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9,92
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80,0
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7,13
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and
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33 34T
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27,9
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35 36 37
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$124
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$125
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$549
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$1,4
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$830
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$419
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$270
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$237
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$549
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$375
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$770
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$2,1
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$12,
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$52,
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$79,
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028
$25,
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$22,
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$42,
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$90
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over
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94$2
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21,3
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72$4
71,8
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,796
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42G
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$2,2
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$2,1
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$569
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$257
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$420
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$471
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$503
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$11,
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839
43G
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& G
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$45,
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$100
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$221
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$323
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$273
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$323
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$178
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$91,
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$40,
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$65
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$73,
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$78,
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18,1
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44,6
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,976
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47E
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Mon
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over
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6$3
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2949
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- B
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$0$0
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$350
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$0$0
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$3,2
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$38,
400
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$5,0
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8$8
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$167
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53 54R
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9$7
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1$1
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9,91
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55G
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$17,
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$18,
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$19,
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$19,
817
$17,
206
$18,
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$221
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$5,6
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$5,5
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$5,6
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$71,
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over
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8$1
51,7
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89,8
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8,27
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7,27
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5,73
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59E
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$26,
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349
$15,
024
$14,
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$17,
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$12,
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$16,
441
$10,
939
$227
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60T
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and
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S R
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$259
,685
$406
,268
$589
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$815
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$797
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$658
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$416
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$292
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$249
,095
$208
,248
$211
,138
$237
,308
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43,0
5061 62
Tot
al B
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t Rec
over
y$5
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$10,
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681
$20,
852,
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$31,
471,
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$29,
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949
$28,
071,
424
$17,
692,
421
$8,9
53,5
60$6
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$4,4
75,9
97$4
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$4,7
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6 7 8C
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ion
s (K
JB-5
, Lin
e 8
)(2
7,0
02
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9)
$
1
1W
ithd
raw
als
(K
JB-5
, Lin
e 1
0)
16
,12
0,3
35
$
1
2S
tora
ge
-Va
riab
le C
ost
s (W
ork
pa
pe
r K
JB-5
B, P
ag
e 3
, Lin
e 4
1)
1,5
62
,01
5$
1
3L
NG
With
dra
wa
l Co
sts
(KJB
-5, L
ine
12
less
TW
R-2
, Pa
ge
2, L
ine
39
)2
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2,5
27
$
14
FE
S R
eco
verie
s -
Co
mm
od
it y C
ha
rge
s (W
ork
pa
pe
r K
JB-9
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e 1
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e 3
4)
(2,7
47
,81
2)
$
1
5G
SG
- M
on
thl y
BG
SS
Re
cove
ries
- C
om
mo
dity
Ch
arg
es
(Wo
rkp
ap
er
KJB
-9A
, Pa
ge
1, L
ine
54
)(1
1,8
51
,83
9)
$
1
6E
GS
-LV
Firm
- M
on
thl y
BG
SS
Re
cove
ries
- C
om
mo
dity
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arg
es
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rkp
ap
er
KJB
-9A
, Pa
ge
2, L
ine
11
)-
$
1
7E
GS
- M
on
thl y
BG
SS
Re
cove
ries
- C
om
mo
dity
Ch
arg
es
(Wo
rkp
ap
er
KJB
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, Pa
ge
2, L
ine
19
)(3
09
)$
18
EG
S-L
V L
td F
irm -
Mo
nth
l y B
GS
S R
eco
verie
s -
Co
mm
od
ity C
ha
rge
s (W
ork
pa
pe
r K
JB-9
A, P
ag
e 2
, Lin
e 7
)-
$
1
9Y
ard
an
d S
tre
et L
i gh
ting
Re
cove
ries
(Wo
rkp
ap
er
KJB
-9A
, Pa
ge
2, L
ine
23
)(3
8,4
00
)$
20
21
To
tal C
om
mo
dit
y C
os
t8
2,8
28
,03
6$
22
23
Ap
plic
ab
le S
ale
s V
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me
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70
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3,2
72
24
25
BG
SS
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mm
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ity
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te P
er
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erm
0.3
05
64
6$
2
62
72
8D
EF
ER
RE
D B
AL
AN
CE
29
De
ferr
ed
Un
de
r/(O
ver)
Re
cove
red
Ba
lan
ce (
KJB
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ine
36
)(8
,27
4,0
19
)$
30
31
Fo
reca
ste
d A
ccru
ed
Inte
rest
on
20
15
-20
16
BG
SS
C (
KJB
-3 L
ine
36
)-
$
3
23
3T
ota
l De
ferr
ed
Un
de
r/(O
ver)
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cove
red
Ba
lan
ce(8
,27
4,0
19
)$
34
35
Ap
plic
ab
le S
ale
s V
olu
me
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70
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72
36
37
De
ferr
ed
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lan
ce
Ra
te P
er
Th
erm
(0.0
30
53
2)
$
38
39
NO
N-C
OM
MO
DIT
Y C
OS
T4
04
1C
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RG
ES
42
An
nu
al P
ipe
line
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d S
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De
ma
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es
(Wo
rkp
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er
KJB
-5B
, Pa
ge
3, L
ine
40
)4
5,3
45
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8$
6,4
59
,29
2$
43
To
tal N
on
-Co
mm
od
ity
Ch
arg
es
45
,34
5,0
88
$
6
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9,2
92
$
4
44
5C
RE
DIT
S/R
EF
UN
DS
/RE
CO
VE
RIE
S4
6C
om
pa
ny
Use
/Ad
min
istr
atio
n (
KJB
-5, L
ine
22
)(7
3,3
52
)$
47
Inte
rru
ptib
le/O
ff-S
yste
m a
nd
On
-Sys
tem
Sa
les
Cre
dits
(K
JB-6
, Lin
e 1
8)
(10
,24
4,5
34
)$
(1,4
59
,30
8)
$
48
CT
S R
eco
verie
s -
Ba
lan
cin
g C
ha
rge
(W
ork
pa
pe
r K
JB-7
A, L
ine
33
an
d W
ork
pa
pe
r In
pu
t Are
a, L
ine
57
)(7
1,1
23
)$
49
RS
G-F
SS
& R
SG
-FT
Re
cove
ries
- B
ala
nci
ng
Ch
arg
e (
Wo
rkp
ap
er
KJB
-9A
, Pa
ge
1, L
ine
13
)(1
2,9
20
,76
7)
$
5
0G
SG
-FS
S &
GS
G-F
T R
eco
verie
s -
Ba
lan
cin
g C
ha
rge
(W
ork
pa
pe
r K
JB-9
A, P
ag
e 1
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e 1
8)
(4,9
93
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9)
$
5
1G
SG
-LV
-FT
Re
cove
ries
- B
ala
nci
ng
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arg
e (
Wo
rkp
ap
er
KJB
-9A
, Pa
ge
1, L
ine
22
)(1
,28
9,9
26
)$
52
LV
S-F
T R
eco
verie
s -
Ba
lan
cin
g C
ha
rge
s (W
ork
pa
pe
r K
JB-7
A, L
ine
33
an
d W
ork
pa
pe
r In
pu
t Are
a, L
ine
46
)(2
21
,46
4)
$
53
FE
S, L
VS
, & E
GS
-LV
- D
em
an
d C
ha
r ge
Re
cove
ries
(W
ork
pa
pe
r K
JB-9
A, P
ag
e 1
, Lin
e 3
8)
(22
0,1
96
)$
5
4E
GS
-LV
Firm
& L
td-F
irm R
eco
verie
s -
Ba
lan
cin
g C
ha
rge
(W
ork
pa
pe
r K
JB-7
A, L
ine
34
an
d In
pu
t Are
a, L
ine
s 4
5 &
52
) (2
27
,26
9)
$
55
To
tal C
red
its
/Re
fun
ds
/Re
co
ve
rie
s(3
0,2
62
,58
9)
$
(1
,45
9,3
08
)$
5
65
75
8T
ota
l No
n-C
om
mo
dit
y C
os
t1
5,0
82
,49
9$
4,9
99
,98
4$
59
60
Ap
plic
ab
le S
ale
s V
olu
me
s2
70
,99
3,2
72
38
,60
2,2
98
61
62
BG
SS
No
n-C
om
mo
dit
y C
os
t R
ate
Pe
r T
he
rm0
.05
56
56
$
0.1
29
52
6$
63
64
65
66
TO
TA
L B
GS
S C
HA
RG
ES
PE
R T
HE
RM
(E
xc
lud
ing
Ta
xe
s)
0.3
30
77
0$
0
.12
95
26
$
67
68
TO
TA
L B
GS
S C
HA
RG
ES
PE
R T
HE
RM
(In
clu
din
g T
ax
es
)0
.35
47
03
$
0.1
38
89
8$
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
Y2
01
6 -
20
17
BG
SS
C C
ost
Re
cove
r y A
lloca
tion
KJB-8
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
220
16-2
017
BG
SS
C3
Pro
of o
f B
GS
SC
Rec
over
y4 5
Pro
ject
edP
roje
cted
Pro
ject
edP
roje
cted
Pro
ject
edP
roje
cted
Pro
ject
edP
roje
cted
Pro
ject
edP
roje
cted
Pro
ject
edP
roje
cted
6O
ct-1
6N
ov-
16
De
c-1
6Ja
n-1
7F
eb
-17
Ma
r-1
7A
pr-
17
Ma
y-1
7Ju
n-1
7Ju
l-17
Au
g-1
7S
ep
-17
Tot
al7
Sec
tion
A (
Nat
ural
Gas
)8 9
Tot
al F
irm
, Int
erru
ptib
le, a
nd O
ff-S
yste
m S
ales
CO
G$1
1,04
3,25
8$1
4,14
5,55
2$1
8,94
7,48
1$2
1,56
6,73
1$2
1,05
7,35
5$1
8,89
7,30
0$1
5,17
3,12
8$1
3,28
2,16
1$1
2,61
9,45
9$1
2,56
5,92
6$1
2,71
8,11
2$1
1,83
2,78
0$1
83,8
49,2
4210
Mar
kete
r Im
bal
ance
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
$011
Tot
al S
tora
ge
With
draw
als
Cos
ts$0
$1,1
54,2
58$3
,372
,699
$5,1
41,8
37$4
,010
,680
$1,8
88,3
01$5
52,5
61$0
$0$0
$0$0
$16,
120,
335
12T
otal
Sto
rag
e In
ject
ions
Cos
ts
$1,6
49,3
45$3
33,6
35$3
88,2
13$4
60,3
68$4
33,2
52$0
$3,9
54,6
93$4
,079
,106
$3,9
82,4
26$3
,971
,887
$3,9
44,9
70$3
,805
,075
$27,
002,
969
13 14S
ectio
n B
(S
upp
lem
enta
l Gas
)15 16
LNG
With
draw
al C
osts
$0$1
23,9
43$3
00,5
41$7
52,4
92$6
13,4
25$4
83,6
23$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$2
,622
,527
17 18 19S
ectio
n C
(C
ost R
educ
tions
)20 21
Cos
t of
Gas
Inte
rrup
tible
and
Off
-Sys
tem
Sal
es$1
,138
,785
$1,6
00,2
00$1
,838
,920
$4,8
03,4
50$4
,330
,657
$4,7
16,5
14$1
,281
,422
$1,3
16,6
68$1
,287
,450
$1,3
47,1
05$1
,351
,290
$1,3
05,9
00$2
6,31
8,36
022
Pip
elin
e R
efun
ds &
Dem
and
Cha
rge
Red
uctio
n$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
23C
omp
any
Use
Adm
in C
ost
$5,0
94$5
,094
$7,1
31$1
0,18
8$1
0,18
8$8
,150
$5,0
94$4
,075
$4,0
75$5
,094
$5,0
94$4
,075
$73,
352
24In
terr
uptib
le/O
ff-S
yste
m/C
apac
ity R
elea
se C
redi
t$5
06,6
74$7
79,8
74$1
,244
,204
$1,6
97,6
95$1
,583
,599
$1,7
16,8
67$7
00,4
20$7
02,2
18$6
95,0
67$6
94,5
61$6
91,6
73$6
90,9
90$1
1,70
3,84
225 26 27
Sec
tion
D (
Cos
t Rec
over
y)28 29
Tot
al G
as C
ost T
o B
GS
SC
$7,7
43,3
60$1
2,70
4,95
0$1
9,14
2,25
3$2
0,48
9,35
9$1
9,32
3,76
5$1
4,82
7,69
4$9
,842
,144
$7,2
38,1
78$6
,708
,524
$6,6
05,3
63$6
,783
,169
$6,0
84,8
24$1
37,4
93,5
8230
Tot
al A
lloca
ted
Cos
t Rec
over
y$1
,269
,704
$2,3
48,2
45$4
,471
,889
$6,7
02,4
82$6
,104
,553
$6,3
13,3
24$3
,726
,689
$2,1
15,6
75$1
,720
,472
$1,5
66,6
41$1
,656
,367
$1,5
87,4
71$3
9,58
3,51
131
Tot
al B
GS
SC
Rec
over
y$2
,722
,697
$5,7
78,8
10$1
0,99
4,98
3$1
6,62
5,35
0$1
5,93
1,88
6$1
4,60
7,04
9$9
,373
,392
$4,5
89,4
48$2
,924
,174
$1,9
54,4
70$
1,99
7,75
7$2
,136
,428
$89,
636,
445
32B
ill C
redi
t$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
33M
onth
ly (
Ove
r) /
Und
er R
ecov
ery
$3,7
50,9
60$4
,577
,896
$3,6
75,3
81($
2,83
8,47
3)($
2,71
2,67
5)($
6,09
2,67
9)($
3,25
7,93
8)$5
33,0
55$2
,063
,878
$3,0
84,2
52$3
,129
,045
$2,3
60,9
25$8
,273
,626
34 35 36C
umul
ativ
e (O
ver)
/ U
nder
Rec
over
y B
egin
ning
Bal
ance
($8,
274,
019)
($4,
523,
059)
$54,
837
$3,7
30,2
18$8
91,7
45($
1,82
0,93
0)($
7,91
3,60
9)($
11,1
71,5
46)
($10
,638
,492
)($
8,57
4,61
4)($
5,49
0,36
2)($
2,36
1,31
7)($
8,27
4,01
9)37
Inte
rest
Acc
rued
- O
wed
to C
usto
mer
s on
201
5-20
16 B
GS
SC
$0$0
38C
umul
ativ
e (O
ver)
/Und
er R
ecov
ery
End
ing
Bal
ance
($4,
523,
059)
$54,
837
$3,7
30,2
18$8
91,7
45($
1,82
0,93
0)($
7,91
3,60
9)($
11,1
71,5
46)
($10
,638
,492
)($
8,57
4,61
4)($
5,49
0,36
2)($
2,36
1,31
7)($
393)
($39
3) KJB-9
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
220
16 -
201
7 B
GS
SC
3P
roje
cted
Car
ryin
g C
ost B
GS
SC
4 5(1
)(2
)(3
)(4
)(5
)(6
)(7
)
6M
onth
Mon
thly
(O
ver)
/Und
er A
ctiv
ity
Cum
ulat
ive
(Ove
r)/U
nder
B
alan
ce
Ave
rage
(O
ver)
/Und
er
Bal
ance
Inte
rest
Rat
eM
onth
ly In
tere
stC
umul
ativ
e In
tere
st7 8
Beg
inni
ng B
alan
ce:
($8,
274,
019)
9 10O
ct-1
6$3
,750
,960
($4,
523,
059)
($6,
398,
539)
0.59
17%
($37
,858
)($
37,8
58)
11 12N
ov-1
6$4
,577
,896
$54,
837
($2,
234,
111)
0.59
17%
($13
,218
)($
51,0
77)
13 14D
ec-1
6$3
,675
,381
$3,7
30,2
18$1
,892
,527
0.59
17%
$11,
197
($39
,879
)15 16
Jan-
17($
2,83
8,47
3)$8
91,7
45$2
,310
,981
0.59
17%
$13,
673
($26
,206
)17 18
Feb
-17
($2,
712,
675)
($1,
820,
930)
($46
4,59
2)0.
5917
%($
2,74
9)($
28,9
55)
19 20M
ar-1
7($
6,09
2,67
9)($
7,91
3,60
9)($
4,86
7,26
9)0.
5917
%($
28,7
98)
($57
,753
)21 22
Apr
-17
($3,
257,
938)
($11
,171
,546
)($
9,54
2,57
8)0.
5917
%($
56,4
60)
($11
4,21
3)23 24
May
-17
$533
,055
($10
,638
,492
)($
10,9
05,0
19)
0.59
17%
($64
,521
)($
178,
734)
25 26Ju
n-17
$2,0
63,8
78($
8,57
4,61
4)($
9,60
6,55
3)0.
5917
%($
56,8
39)
($23
5,57
3)27 28
Jul-1
7$3
,084
,252
($5,
490,
362)
($7,
032,
488)
0.59
17%
($41
,609
)($
277,
182)
29 30A
ug-1
7$3
,129
,045
($2,
361,
317)
($3,
925,
840)
0.59
17%
($23
,228
)($
300,
410)
31 32S
ep-1
7$2
,360
,925
($39
3)($
1,18
0,85
5)0.
5917
%($
6,98
7)($
307,
396)
33 34C
umul
ativ
e N
et In
tere
st o
n U
nder
Rec
over
ed B
alan
ce$0
35 36N
et In
tere
st C
redi
t to
Rat
epay
ers
($30
7,39
6)37 38 39 40
Pur
suan
t to
Doc
ket N
os. G
R87
0911
01 a
nd G
R89
0807
31, t
he C
ompa
ny is
util
izin
g th
e m
onth
ly o
ffse
t met
hodo
logy
.
KJB-10
SOUTH JERSEY GAS COMPANY Sixth Revised Sheet No. 28
B.P.U.N.J. No. 11 - GAS Superseding Fifth Revised Sheet No. 28
Issued _______________________ Effective with service rendered by South Jersey Gas Company, on and after _______________ J. DuBois, President
Filed pursuant to Order in Docket No. ________________ of the Board of Public Utilities, State of New Jersey, dated _____________
LARGE VOLUME SERVICE (LVS) (continued)
Basic Gas Supply Service (“BGSS”) Charge: Demand Charge: D-2: $15.95890116.545047 per Mcf of Contract Demand. Volumetric Charge:
C-2: See Rider “A” of this Tariff. Limited Firm:
Customer Charge:
$107.0000 per month Delivery Charge:
(a) All consumption for customers who elected to transfer from Firm Sales Service to Firm Transportation Service
Volumetric Charge:
C-1FT: $.142529 per therm
(b) All consumption for customers who elect Firm Sales Service Volumetric Charge: C-1FT: $.142529 per therm
Basic Gas Supply Service (“BGSS”) Charge: Volumetric Charge:
C-2: See Rider “A” of this Tariff. PRICE TO COMPARE: The Company will provide the Price to Compare for an LVS customer, at said customer’s request. LINE LOSS: Line Loss shall be 1.43% as provided in Special Provision (h).
KJB-11 Page 1 of 21
SOUTH JERSEY GAS COMPANY Sixth Revised Sheet No. 33
B.P.U.N.J. No. 11 - GAS Superseding Fifth Revised Sheet No. 33
Issued ___________________ Effective with service rendered by South Jersey Gas Company, on and after________________ J. DuBois, President
Filed pursuant to Order in Docket No. _______________of the Board of Public Utilities, State of New Jersey, dated ________________
FIRM ELECTRIC SERVICE (FES)
APPLICABLE TO USE OF SERVICE FOR: All gas that is purchased or transported to generate electricity. Provided, however, that in order to qualify for this Rate Schedule FES, a customer must have a Winter Daily Contract Demand of 1,000 Mcf per day or more, or a Summer Daily Contract Demand of 2,000 Mcf per day or more, or both. To be eligible for Firm Transportation Service under this Rate Schedule FES, a customer must hold clear and marketable title to gas that is made available for delivery to customer’s facility on the Company’s system.
CHARACTER OF SERVICE:
Firm Sales Service and Firm Transportation Service.
MONTHLY RATE (1) (2)
WINTER (November – March):
Demand Charge: D-1 $3.100000 per Mcf of Winter Daily Contract Demand D-2 $7.9794508.272524 per Mcf of Daily Billing Determinant or $0 for Firm Transportation
customers
Volumetric Charge: C-1: $.041329 per therm of consumption
C-2: FES Monthly Commodity Rate, pursuant to Rider “A” and Special Provision (x), OR Customer Owned Gas Clause, Rider “D”
C-3: $.174300 per therm of consumption C-4: Escalator Rate – Charge may change monthly pursuant to Standard Gas Service Addendum.
Minimum Bill: The monthly D-1 and D-2 charges, irrespective of use. SUMMER (April – October):
Demand Charge: D-1 $3.1000 per Mcf of Summer Daily Contract Demand
D-2 $7.9794508.272524 per Mcf of Daily Billing Determinant or $0 for Firm Transportation customers
Volumetric Charge: C-1: $.041329 per therm of consumption
C-2: FES Monthly Commodity Rate, pursuant to Rider “A” and Special Provision (x), OR Customer Owned Gas Clause, Rider “D”
C-3: $.174300 per therm of consumption C-4: Escalator Rate – Charge may change monthly pursuant to Standard Gas Service Addendum.
(1) Please refer to Appendix A for components of Monthly Rates. (2) Please refer to Special Provision (p)
KJB-11 Page 2 of 21
SOUTH JERSEY GAS COMPANY Sixth Revised Sheet No. 45
B.P.U.N.J. No. 11 - GAS Superseding Fifth Revised Sheet No. 45
Issued _________________ Effective with service rendered by South Jersey Gas Company, on and after ________________ J. DuBois, President
Filed pursuant to Order in Docket No. ________________ of the Board of Public Utilities, State of New Jersey, dated ______________
ELECTRIC GENERATION SERVICE – LARGE VOLUME (EGS-LV)
APPLICABLE TO USE OF SERVICE FOR:
All commercial and industrial electric generation facilities; all Prime Movers and all engine driven equipment (whether or not used for electric generation). Provided, however, that in order to be eligible for this Rate Schedule EGS-LV, a customer must have a Firm Daily Contract Demand of 200 Mcf per day or more. To be eligible for Firm Transportation Service under this Rate Schedule EGS-LVS, a customer must hold clear and marketable title to gas that is made available for delivery to customer’s facility on the Company’s system.
CHARACTER OF SERVICE:
Firm Sales Service, Firm Transportation Service, Limited Firm Sales Service and Limited Firm Transportation Service.
MONTHLY RATE: (1)
Customer Charge: $192.60 per month FIRM:
Demand Charges: (2)
D-1 $20.795922 per Mcf of Firm Daily Contract Demand. D-2 $15.581692 per Mcf of Firm Daily Contract Demand or $0 for Firm Transportation
customers.
Volumetric Charge: C-1: $.041329 per therm of consumption
C-2: As depicted in the Monthly BGSS Subrider of Rider “A” of this Tariff, OR Customer Owned Gas Clause, Rider “D”
Minimum Bill: Monthly D-1 and D-2 charges, irrespective of use.
LIMITED FIRM:
Demand Charge: D-2 $7.9794508.272524 per Mcf of Limited Firm Daily Contract Demand or $0 for
Limited Firm Transportation customers
Volumetric Charge: (2) C-1: $.041329 per therm of consumption
C-2: As depicted in the Monthly BGSS Subrider of Rider “A” of this Tariff, OR Customer Owned Gas Clause, Rider “D”
C-3 $.174300 per therm for all consumption within Limited Firm Contract Demand level.1
(1) Please refer to Appendix A for components of Monthly Rates. (2) Please refer to Special Provision (j).
KJB-11 Page 3 of 21
SOUTH JERSEY GAS COMPANY Twenty-First Revised Sheet No. 67
B.P.U.N.J. No. 11 - GAS Superseding Twentieth Sheet No. 67
Issued ____________________ Effective with service rendered by South Jersey Gas Company, on and after _______________ J. DuBois, President
Filed pursuant to Order in Docket No. _____________ of the Board of Public Utilities, State of New Jersey, dated ________________
RIDER “A”
BASIC GAS SUPPLY SERVICE CLAUSE (“BGSSC”)
APPLICABLE TO: Rate Schedule RSG - Residential Service
Rate Schedule GSG - General Service Rate Schedule GSG-LV - General Service – Large Volume Rate Schedule LVS - Large Volume Service Rate Schedule FES - Firm Electric Service Rate Schedule EGS - Electric Generation Service Rate Schedule EGS-LV - Electric Generation Service - Large Volume Rate Schedule NGV - Natural Gas Vehicle
APPLICABLE RATES: Periodic BGSS Subrider (Effective October 1, 20165)1: BGSS Rate Before BGSS Rate With Rate Schedule Taxes (per therm) Taxes (per therm) RSG $0.330770493507 $0.354703529214 GSG (under 5,000 therms) $0.330770493507 $0.354703529214
Monthly BGSS Subrider (Effective May 1, 2016): BGSS Rate Before BGSS Rate With Rate Schedule Taxes (per therm) Taxes (per therm) LVS C-2 $0.264339 $0.283465 FES $0.189114 $0.202797 EGS $0.313375 $0.336048 EGS-LV Firm C-2 $0.267194 $0.286527 EGS-LV Limited Firm C-2 $0.288857 $0.309756 GSG-LV $0.313375 $0.336048 GSG (5,000 therms or greater) $0.313375 $0.336048 NGV $0.313375 $0.336048 The above Periodic and Monthly BGSS rates shall include the BGSS cost savings established in Rider “M” to this Tariff.
FILING:
This Subrider shall be applicable to all customers served under Rate Schedules RSG, and those GSG customers who do not meet the “Monthly Threshhold”. This Periodic BGSS Subrider shall recover gas costs associated with service to customers served under this Subrider.
1 Reflects currently approved Total BGSS Rate.
KJB-11 Page 4 of 21
SOUTH JERSEY GAS COMPANY Second Revised Sheet No. 70
B.P.U.N.J. No. 11 - GAS Superseding First Revised Sheet No. 70
Issued ____________________ Effective with service rendered by South Jersey Gas Company, on and after ________________ J. DuBois, President
Filed pursuant to Order in Docket No. ______________of the Board of Public Utilities, State of New Jersey, dated __________________
RIDER “A” BASIC GAS SUPPLY SERVICE CLAUSE (“BGSSC”)
(Continued) The Company will file self-implementing Monthly BGSS rates on the second day following the close of trading of the NYMEX Henry Hub gas contracts for each month. Within each monthly filing, the Company will provide the following:
(1) Documentation regarding the NYMEX Henry Hub close; (2) Supporting schedules that document the actual/projected costs and sales volumes used to derive the monthly gas cost factor; and
MONTHLY FORMULA:
The formula for determining the Monthly BGSS rate shall be the sum of the following:
(1) The Company will calculate a Commodity Cost which will be comprised of the sum of arithmetic average of
(i) the closing price of the NYMEX Henry Hub gas contract for the following month and
(ii) the weighted average of the estimated Index Prices, for the respective locations at which the Company purchases its gas, to be published in Inside FERC’s Gas Market Report for the remaining BGSS Year. Further, the calculation will not include hedging.
(2) An estimate shall be made of the variable costs of transportation and fuel and line loss for the subject month, to the extent not included in (1), above
(3) A Non-Commodity Cost component that includes gas costs other than the Commodity Cost of Gas, including but not limited to all fixed pipeline costs, fixed supplier costs, fixed storage costs, pipeline refunds and similar credits, and other credits directed by the Board. The Non-Commodity Cost component shall be calculated on an equal per-therm basis for the entire BGSS Year. This subparagraph (3) is not applicable to FES customers. The result of the calculation from the Monthly Formula above shall be adjusted for Rate Schedules LVS and EGS-LV (Firm and Limited Firm) to derive the Monthly BGSS Rates by deducting therefrom the volumetric equivalent of the D-2 charges within the respective Rates Schedules. Said deductions shall be as follows:
D-2 Deduction Rate Schedule Including Taxes LVS $.050721052584 EGS-LV Firm $.049522 EGS-LV Limited Firm $.025361026292
KJB-11 Page 5 of 21
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RA
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sto
me
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27
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sic
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s S
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71
KJB-11 Page 9 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 5
GE
NE
RA
L S
ER
VIC
E-L
V (
GS
G-L
V)
OT
HE
RG
EN
ER
AL
SE
RV
ICE
- L
V F
TS
(G
SG
-LV
-FT
)B
AS
E R
AT
EB
GS
SR
IDE
RS
PU
AN
J S
AL
ES
TA
XT
AR
IFF
RA
TE
Cu
sto
me
r C
ha
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15
0.0
00
00
01
0.5
00
00
01
60
.50
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D-1
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ma
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arg
e9
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30
00
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.63
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(0.0
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76
8)
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7)
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7)
De
live
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:
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48
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live
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96
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86
KJB-11 Page 10 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_P
ag
e 6
CO
MP
RE
HE
NS
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TR
AN
SP
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CT
S)
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RB
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AN
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BU
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PR
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LY
KJB-11 Page 11 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_P
ag
e 7
LA
RG
E V
OL
UM
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VIC
E (
LV
S)
OT
HE
RB
AS
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AT
EB
GS
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AN
J S
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XT
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BU
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PR
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LY
KJB-11 Page 12 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 8
OT
HE
RL
AR
GE
VO
LU
ME
FIR
M S
AL
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SE
RV
(L
VS
FS
S)
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Cu
sto
me
r C
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90
0.0
00
00
06
3.0
00
00
09
63
.00
00
00
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sic
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s S
up
ply
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rvic
e (
BG
SS
):
C-2
BG
SS
R
AT
E S
ET
MO
NT
HL
Y
D
-2 D
EM
AN
D C
HA
RG
E1
4.8
82
12
00
.03
27
41
1.0
44
04
01
5.9
58
90
1
De
live
ry C
ha
rge
:
D-1
DE
MA
ND
CH
AR
GE
14
.88
42
00
1.0
41
90
01
5.9
26
10
0
C-1
VO
LU
ME
TR
IC C
HA
RG
E:
C
-1 C
OS
T O
F S
ER
VIC
E0
.03
45
70
0.0
02
42
00
.03
69
90
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
45
70
0.0
00
00
00
.03
85
69
0.0
00
06
30
.00
51
17
0.0
78
31
9
BS
-1 A
LL
TH
ER
MS
0.0
11
80
00
.00
00
00
0.0
00
80
00
.01
26
00
Lim
ite
d F
irm
Cu
sto
me
r C
ha
rge
10
0.0
00
00
07
.00
00
00
10
7.0
00
00
0
De
live
ry C
ha
rge
:C
-1 F
T V
OL
UM
ET
RIC
CH
AR
GE
:
C-1
CO
ST
OF
SE
RV
ICE
0.0
94
60
00
.00
66
00
0.1
01
20
0
SB
C:
C
LE
P
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
R
AC
0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9
US
F0
.01
01
00
0.0
00
00
00
.00
07
00
0.0
10
80
0T
ota
l SB
C0
.03
17
60
0.0
00
04
80
.00
22
19
0.0
34
02
7
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.09
46
0.0
00
00
00
.03
85
69
0.0
00
06
30
.00
92
97
0.1
42
52
9
BS
-1 A
LL
TH
ER
MS
0.0
11
80
00
.00
00
00
0.0
00
80
00
.01
26
00
BS
-1 (
Op
t O
ut
Pro
visi
on
) A
LL
TH
ER
MS
0.0
02
50
00
.00
00
00
0.0
00
20
00
.00
27
00
BU
Y-O
UT
PR
ICE
RA
TE
SE
T M
ON
TH
LY
KJB-11 Page 13 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 9
OT
HE
RB
AS
E R
AT
EB
GS
SR
IDE
RS
PU
AN
J S
AL
ES
TA
XT
AR
IFF
RA
TE
EL
EC
TR
IC G
EN
ER
AT
ION
SE
RV
ICE
(E
GS
)C
om
me
rcia
l/In
du
str
ial
Cu
sto
me
r C
ha
rge
25
.00
00
00
1.7
50
00
02
6.7
50
00
0
D-1
DE
MA
ND
6.5
00
00
00
.45
50
00
6.9
55
00
0
Ba
sic
Ga
s S
up
ply
Se
rvic
e (
BG
SS
):R
AT
E S
ET
MO
NT
HL
Y
De
live
ry C
ha
rge
- W
inte
r S
ea
so
n (
No
v -
Ma
r)C
OS
T O
F S
ER
VIC
E0
.11
56
38
0.0
08
09
50
.12
37
33
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
S &
FT
S)
0.1
15
63
80
.04
71
00
0.0
38
56
90
.00
01
63
0.0
14
09
20
.21
55
62
.
De
live
ry C
ha
rge
- S
um
me
r S
ea
so
n (
Ap
r -
Oc
t)
CO
ST
OF
SE
RV
ICE
0.0
85
63
80
.00
59
95
0.0
91
63
3
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
S &
FT
S)
0.0
85
63
80
.04
71
00
0.0
38
56
90
.00
01
63
0.0
11
99
20
.18
34
62
KJB-11 Page 14 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 10
OT
HE
RB
AS
E R
AT
EB
GS
SR
IDE
RS
PU
AN
J S
AL
ES
TA
XT
AR
IFF
RA
TE
EL
EC
TR
IC G
EN
ER
AT
ION
SE
RV
ICE
(E
GS
)R
es
ide
nti
al
Cu
sto
me
r C
ha
rge
9.0
00
00
00
.63
00
00
9.6
30
00
0
Ba
sic
Ga
s S
up
ply
Se
rvic
e (
BG
SS
):0
.33
07
70
0.0
00
72
80
.02
32
05
0.3
54
70
3
De
live
ry C
ha
rge
CO
ST
OF
SE
RV
ICE
0.1
22
10
00
.00
86
00
0.1
30
70
0
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
S &
FT
S)
0.1
22
10
00
.04
71
00
0.0
38
56
90
.00
01
63
0.0
14
59
70
.22
25
29
KJB-11 Page 15 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 11
OT
HE
RE
LE
CT
RIC
GE
NE
RA
TIO
N S
ER
VIC
E-L
V (
EG
S-L
V)
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Fir
mC
us
tom
er
Ch
arg
e1
80
.00
00
00
12
.60
00
00
19
2.6
00
00
0
D-1
DE
MA
ND
(R
ate
is
ne
go
tia
ted
. S
ho
wn
he
re i
s t
he
be
nc
hm
ark
ra
te.)
19
.43
54
41
1.3
60
48
12
0.7
95
92
2
D-2
DE
MA
ND
BG
SS
(ap
pli
ca
ble
to
Sa
les
Cu
sto
me
rs O
nly
)1
4.5
30
36
20
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19
67
1.0
19
36
31
5.5
81
69
2
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-2
BG
SS
RA
TE
SE
T M
ON
TH
LY
BS
C "
I" C
AS
H O
UT
CH
AR
GE
(C
RE
DIT
)R
AT
E S
ET
MO
NT
HL
YB
S-1
AL
L T
HE
RM
S0
.01
18
00
0.0
00
00
00
.00
08
00
0.0
12
60
0B
S-1
(O
pt
Ou
t P
rovi
sio
n)
AL
L T
HE
RM
S0
.00
25
00
0.0
00
00
00
.00
02
00
0.0
02
70
0
Lim
ite
d F
irm
D-2
DE
MA
ND
BG
SS
(ap
pli
ca
ble
to
Sa
les
Cu
sto
me
rs O
nly
)7
.44
10
60
0.0
16
37
00
.52
20
20
7.9
79
45
0
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-3
All
Th
erm
s (R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
chm
ark
ra
te.)
0.1
62
90
00
.01
14
00
0.1
74
30
0
C-2
BG
SS
RA
TE
SE
T M
ON
TH
LY
BS
C "
I" C
AS
H O
UT
CH
AR
GE
(C
RE
DIT
)R
AT
E S
ET
MO
NT
HL
YB
S-1
AL
L T
HE
RM
S0
.01
18
00
0.0
00
00
00
.00
08
00
0.0
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60
0B
S-1
(O
pt
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t P
rovi
sio
n)
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L T
HE
RM
S0
.00
25
00
0.0
00
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02
00
0.0
02
70
0
KJB-11 Page 16 of 21
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- E
ffe
cti
ve _
__
__
__
__
__
__
__
__
__
_
Pag
e 12
FIR
M E
LE
CT
RIC
SA
LE
S (
FE
S)
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Win
ter
D-1
DE
MA
ND
(R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
chm
ark
ra
te.)
2.8
97
20
00
.20
28
00
3.1
00
00
0
D-2
DE
MA
ND
BG
SS
(ap
plic
ab
le t
o S
ale
s C
ust
om
ers
On
ly)
7.4
41
06
00
.01
63
70
0.5
22
02
07
.97
94
50
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
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27
38
C-1
RA
C0
.00
97
81
0.0
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02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
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00
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0.0
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70
00
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08
00
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ET
0.0
06
80
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00
15
0.0
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47
80
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73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
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26
97
0.0
41
32
9
C-3
All
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00
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00
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30
0
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ala
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To
be
de
term
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d a
s p
resc
rib
ed
in t
he
Co
mp
an
y's
Ta
riff
)R
AT
E S
ET
MO
NT
HL
YC
-2 B
GS
S/C
OG
CR
AT
E S
ET
MO
NT
HL
YB
SC
"I"
CA
SH
OU
T C
HA
RG
E (
CR
ED
IT)
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TE
SE
T M
ON
TH
LY
Su
mm
er
D-1
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MA
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e b
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2.8
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20
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00
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0
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(ap
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o S
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s C
ust
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ers
On
ly)
7.4
41
06
00
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63
70
0.5
22
02
07
.97
94
50
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
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97
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0.0
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02
20
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06
86
0.0
10
48
9C
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0.0
10
10
00
.00
00
00
0.0
00
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00
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08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
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47
80
.00
73
02
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tal
C-1
VO
LU
ME
TR
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HA
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69
0.0
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06
30
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97
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9
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mp
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AT
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HL
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KJB-11 Page 20 of 21
SOUTH JERSEY GAS COMPANYSchedule of Rate Components
Appendix A - Effective ____________________
Page 16
Heat Residential Rate Schedule:
RSG FSS RSG-FTS Difference
BGSS 0.354703 0.000000 0.354703Cost of Service 0.544643 0.544643 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000CIP (0.058946) (0.058946) 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.931219 0.576516 0.354703
NonHeat Residential Rate Schedule:
RSG FSS RSG-FTS Difference
BGSS 0.354703 0.000000 0.354703CIP (0.099971) (0.099971) 0.000000Cost of Service 0.544643 0.544643 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.890194 0.535491 0.354703
GSG
(Under 5,000 therms annually)
GSG FSS GSG-FTS Difference
BGSS 0.354703 0.000000 0.354703CIP (0.031700) (0.031700) 0.000000Cost of Service 0.435152 0.435152 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.848974 0.494271 0.354703
GSG
(5,000 therms annually or greater)
GSG FSS GSG-FTS Difference
BGSS 0.336048 0.000000 0.336048CIP (0.031700) (0.031700) 0.000000Cost of Service 0.435152 0.435152 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.830319 0.494271 0.336048
GSG-LV
Prior to 7/15/97
GSG-LV FSS GSG-LV-FTS Difference
BGSS 0.336048 0.000000 0.336048CIP (0.025487) (0.025487) 0.000000Cost of Service 0.236867 0.236867 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.638247 0.302199 0.336048
KJB-11 Page 21 of 21
- 1 -
PREPARED DIRECT TESTIMONY
OF TIMOTHY W. RUNDALL
SENIOR DIRECTOR, GAS SUPPLY AND ALLOCATIONS JUNE 2016
I. INTRODUCTION 1
My name is Timothy W. Rundall and my business address is One South Jersey 2
Plaza, Folsom, New Jersey 08037. I graduated from Stockton State College (now 3
Stockton University) in 1992 with a Bachelor of Science Degree in Accounting. 4
After graduation while working for Rimm, Lavinsky, Horowitz and Pollard LLC, I 5
was licensed as a Certified Public Accountant (CPA) in the state of New Jersey. In 6
October 1996, after holding positions in the field of accounting, I was employed as 7
a Rate Analyst by South Jersey Gas Company (“South Jersey” or “the Company”). 8
In October 1997, I accepted a position in the Gas Supply Department as a Natural 9
Gas Trader. I have subsequently advanced through a number of positions of 10
increasing responsibility and in May of 2016 I was promoted to my current position 11
of Senior Director, Gas Supply and Off-System Sales. My current responsibilities 12
encompass all aspects of the Gas Supply Department, the Off-System Sales 13
Division, the Transportation Department and the Allocations Department. 14
15
II. PURPOSE OF TESTIMONY 16
In terms of the current gas supply portfolio the purpose of my testimony is to 17
proffer and explain: (a) the Company's projected gas send-out requirements and the 18
- 2 -
utilization of gas supplies to meet those requirements, as shown in Exhibit TWR-1; 1
and (b) the associated gas costs shown in Exhibits TWR-2 and Exhibit TWR-3. 2
I will also address the Company’s hedging activities and Conservation Incentive 3
Program (“CIP”) savings, as well as the anticipated and realized refunds. 4
5
III. GAS SUPPLY AND REQUIREMENTS FORECAST 6
The gas quantities shown on Exhibit TWR-1 are based upon a mixture of gas 7
supply sources determined by the Company to yield the best gas cost mixture while 8
providing security of supply and system integrity. The Company utilized the New 9
York Mercantile Exchange (NYMEX) Strip Pricing as of May 10, 2016, currently 10
hedged positions and contractual agreements when determining the prices and 11
quantities of gas, which are shown on Exhibits TWR-2 and Exhibit TWR-3. 12
For the 2016-2017 BGSS year, we are projecting in Exhibit TWR-1 that firm 13
customer requirements and projected storage injections will be met essentially 14
through annual, seasonal and short term purchases from third-party sellers on the 15
Transcontinental Gas Pipe Line Company, LLC (“Transco”) and Columbia Gas 16
Transmission, LLC (“Columbia”) pipeline systems of 11.1 MMDts and 17.0 17
MMDts, respectively; pipeline storage withdrawals of 7.9 MMDts and Liquefied 18
Natural Gas (LNG) of 0.4 MMDts. 19
Prior and Prospective Supply and Requirements 20
The data shown on Exhibit TWR-4 (page 1 of 3), provides the actual 21
requirements and supplies by component on an annual, heating season and 22
non-heating season basis, for the two prior gas supply years (November 2013 23
- 3 -
– October 2014 and November 2014 – October 2015). The data shown on 1
Exhibit TWR-4 (page 2 of 3), provides information for the reconciliation 2
period (November 2015 – October 2016), including actual data for November 3
2015 – March 2016 heating season and data estimated for April 2016 – 4
October 2016 non-heating season. Exhibit TWR-1 provides prospective 5
information on the October 2016 – September 2017 BGSS year, while Exhibit 6
TWR-4 (page 3 of 3) provides the same information on a prospective basis for 7
the subsequent gas supply year (November 2017 – October 2018). 8
Supplies on Transco 9
Transco is South Jersey's largest supplier of pipeline gas and it is also the 10
provider of six (6) of the eight (8) gas storage services reflected in Exhibit 11
TWR-1. 12
Additionally, the Company has a winter season peaking transportation service 13
with Transco, which is available for the period December 1 through the last 14
day of February of each year under Rate Schedule PSFT [referred to on line 15
34 in Exhibit TWR-1 (page 2 of 2) as Spot Purchases on Transco PSFT]. 16
Supplies on Columbia 17
Columbia is South Jersey’s second largest provider of interstate pipeline 18
services. The Company holds one firm transportation service with Columbia 19
under Rate Schedule FTS, and one long-term firm transportation service under 20
Rate Schedules NTS. In addition, South Jersey subscribes to a firm storage 21
service under Columbia’s Rate Schedule FSS along with an associated firm 22
storage transportation service under Rate Schedule SST. 23
- 4 -
The Company’s maximum daily quantity (MDQ) for its FTS service is 22,511 1
Dts/day and its MDQ with its NTS service is 22,511 Dts/day, for a combined 2
deliverability of 45,022 Dts/day. Each of the referenced services is available 3
on a year round basis. 4
In October 2012, the Company entered into a Precedent Agreement with 5
Columbia Gas Transmission, LLC to secure pipeline capacity on their East 6
Side Expansion Project (ESEP). The ESEP and other potential gas supply 7
portfolio changes are discussed in detail in the “New Long Term Agreements” 8
portion of my testimony. 9
Supplies on Dominion 10
The Company’s Dominion Transmission, Inc. (“Dominion”) GSS storage 11
service provides for the delivery of up to 10,000 Dts/day during the winter 12
season. This storage supply is moved to the city gate via a Transco Leidy Line 13
transportation service. 14
Pipeline Storage Services 15
Exhibit TWR-1 (page 1 of 2) also reflects the injection of direct purchase gas 16
into storage services during the 2017 summer season. Exhibit TWR-1 (page 2 17
of 2) shows that the net amount of gas projected to be withdrawn from 18
pipeline storage services to meet the Company’s requirements during the 19
2016-2017 winter season will total approximately 7.9 MMDts. 20
21
22
23
- 5 -
Liquefied Natural Gas (LNG) 1
In Exhibit TWR-1 (page 2 of 2, line 17), the Company is projecting that its 2
LNG send-out requirement during the 2016-2017 BGSS year will be 406,940 3
Dts. 4
South Jersey requires a stable LNG supply source to maintain gas service to 5
its customers during the winter season to meet peak send-out requirements, 6
and to stand ready to supply its customers should an interruption of gas 7
supplies occur on the system of one or more of its pipeline suppliers. The 8
critical nature of the LNG facility was especially evident during the 2013-14 9
winter season, when LNG was vaporized on 29 days for a total quantity of 10
359,260 Mcf, and the 2014-15 winter season, when LNG was vaporized on 22 11
days for a total quantity of 347,140 Mcf. Additionally, LNG may be called 12
upon to stabilize pressures in the gas distribution system on the eastern side of 13
the Company's service territory. 14
South Jersey has historically secured its LNG supply requirements through a 15
competitive bidding process that takes place during the summer. LNG 16
supplies would be delivered to the Company’s McKee City facility by 17
truckloads, the number of which can vary from year to year but regularly 18
require over 200 truckloads during the April-October timeframe. In recent 19
years, it has become increasingly difficult for the Company to secure reliable 20
and cost effective LNG supplies. LNG has become an attractive fuel choice 21
for a variety of transportation applications, which has increased competition 22
for LNG supply with traditional users like South Jersey. Suppliers have 23
- 6 -
continued to indicate that the seasonal nature of South Jersey’s LNG purchase 1
requirements do not fit the business model these suppliers have adopted, 2
therefore the Company has been faced with either unacceptably high demand 3
charges or supply agreements that volumetrically do not meet our 4
requirements. 5
In response to the change in the LNG marketplace, the Company determined 6
in 2013 that owning and operating its own liquefaction facility was the most 7
appropriate path forward. The Company relies on 75,000 dts/day of LNG to 8
meet design day requirements and relies on LNG to provide adequate 9
operating pressure during extremely cold weather, thus LNG plays a critical 10
role for South Jersey. The Company determined that owning and operating its 11
own liquefaction facility would ensure that LNG is available at a prudent cost 12
and not subject to marketplace pressures which have already created reliability 13
of supply and cost issues. Construction of a liquefaction facility at South 14
Jersey’s McKee City facility is underway with an expected in-service date 15
during the fourth quarter of 2016. This will enable SJG to utilize the new 16
liquefaction facility for the 2016-2017 winter season. 17
18
IV. COST OF GAS 19
The Company has direct connections with two interstate pipeline companies, 20
Transco and Columbia. South Jersey also secures firm storage and transportation 21
services from Dominion, whose pipeline system is located upstream of the Transco 22
- 7 -
system. Natural gas stored and transported by Dominion is delivered into Transco’s 1
Leidy Line system for ultimate delivery to South Jersey. 2
Market Responsive Pipeline Supplies 3
South Jersey intends to utilize the "open access" status of its pipeline suppliers 4
to the maximum extent possible to facilitate its ongoing policy of best-value 5
gas purchasing, with consideration given to security of supply along with 6
contractual obligations and hedged supplies. With this objective, South Jersey 7
is projecting that all of the natural gas purchases reflected in Exhibit TWR-1 8
(page 2 of 2) for the 2016-2017 BGSS year will be priced on a market 9
responsive basis with the exception of those hedged purchases made under the 10
provisions of the Company’s Commodity Purchasing Guidelines, which are 11
attached hereto as Confidential Exhibit TWR-5. Confidential Exhibit TWR-5 12
will be provided to Board Staff and the Division of Rate Counsel upon 13
execution of a mutually acceptable Non-Disclosure Agreement. 14
Demand Charges 15
The projected pipeline demand type charges shown in Exhibit TWR-2 16
associated with the purchase of storage and transportation services on the 17
Transco, Columbia and Dominion pipeline systems reflect the currently 18
effective FERC approved jurisdictional rates as contained in each pipeline’s 19
FERC Gas Tariff. These rates were held constant throughout the BGSS year. 20
Commodity Charges 21
The delivered commodity gas prices reflected in Exhibit TWR-2 for the 2016-22
2017 BGSS year were derived based on the Company's Commodity 23
- 8 -
Purchasing Guidelines, which are explained in Confidential Exhibit TWR-5. 1
These guidelines were developed with a number of goals in mind. These goals 2
included the management of price risk through diversity of purchases, 3
providing a framework from which sound purchasing decisions can be made, 4
and the establishment of criteria for price hedging. 5
The commodity prices in Exhibit TWR-2 for gas purchased and delivered 6
under Transco Rate Schedules FT and PSFT, along with gas purchased and 7
delivered on Columbia Rate Schedules FTS and NTS, were based on the 8
average of the NYMEX close as of May 10, 2016, along with the estimated 9
production and market area indices at the various locations where we expect 10
to purchase gas during the BGSS year. The estimates of indices were 11
gathered from industry publications along with discussions held with other 12
market participants including brokers, marketers and other GDCs. 13
Additionally, any currently hedged positions as shown in the quarterly 14
hedging report most recently filed with the Board are included in the 15
commodity price estimate. Also incorporated in these commodity prices are 16
the appropriate pipeline fuel retainage and transportation costs assessed when 17
delivering gas to South Jersey’s city gate stations. 18
LNG Commodity Charges 19
The commodity price of the LNG as shown in Exhibit TWR-3 was based on 20
the delivered cost of LNG using the NYMEX strip on May 10, 2016, along 21
with costs related to processing natural gas into liquefied natural gas. 22
23
- 9 -
Affiliate Gas Supply Transactions 1
Please refer to Confidential Exhibit TWR-10 for details, including date, rate 2
and terms of all gas and capacity sales as of April 2016 to our affiliate South 3
Jersey Resources Group (“SJRG”), for the current BGSS year. Confidential 4
Exhibit TWR-10 will be provided to Board Staff and the Division of Rate 5
Counsel upon execution of a mutually acceptable Non-Disclosure Agreement. 6
Should market opportunities present themselves, we would expect additional 7
transactions in order to maximize Company assets. 8
Design Day Analysis 9
South Jersey, like other gas utilities, must plan to meet customer needs on a 10
design day (or a day in which our service area would experience an average 11
daily temperature of 2 degrees Fahrenheit or 63 heating degree days). Exhibit 12
TWR-6 represents the Company’s design day forecast (“Design Day 13
Forecast”) as compared to Company entitlements for the 2016-17 through 14
2020-21 winter seasons. This forecast is used by South Jersey to evaluate its 15
ability to meet customer requirements on the projected coldest day scenario, 16
which is based on South Jersey’s actual experience in January 1994. For the 17
purposes of this analysis, the Company updated the forecasting model to 18
incorporate updated customer growth rates for residential and commercial 19
customers and updated heating use factors. Incorporating the most recent 20
available data into the Design Day model will provide a reflection of the 21
effects that the energy efficiency programs and the conservation incentive 22
programs have had in recent years, and are projected to have in future years. 23
- 10 -
Also attached hereto as Exhibit TWR-7, are the Company’s five (5) highest 1
send-out days for the last three winter seasons. 2
In the Global Settlement (BPU Docket No. GR03080683, et. al.) South Jersey 3
agreed to revise its design day analysis to include in the calculation of demand 4
requirements, design day volumes associated with customers served under all 5
sales rate schedules and transportation customers served under Rate Schedules 6
RSG, GSG, GSG-LV, EGS, LVS, CTS and EGS-LV. In addition, South 7
Jersey agreed to exclude from design day planning, design day volumes 8
associated with transportation customers served under rate schedules LVS, 9
CTS and EGS-LV that opt-out of the right or entitlement to have base load 10
provided by the Company in accordance with provisions of our tariff. To 11
date, all eligible customers served under rate schedules LVS, CTS and EGS-12
LV have opted out and this has been reflected in the design day forecast. 13
For design day planning purposes, South Jersey will rely upon 100% of the 14
daily projected transportation volumes (not acquire backup capacity) 15
associated with transportation customers served under rate schedules RSG, 16
GSG, GSG-LV and EGS, along with those customers, if any, served under 17
rate schedules LVS, CTS and EGS-LV who do not opt-out if their volumes 18
are less than or equal to 105,000 Dts/d. Should South Jersey project that the 19
transportation market associated with these rate schedules will exceed 105,000 20
Dts/d, then South Jersey will rely on 50% of transportation volumes 21
associated with RSG, GSG, GSG-LV and EGS (as well as those customers, if 22
any, served under rate schedules LVS, CTS and EGS-LV who do not opt-out) 23
- 11 -
transportation customers that exceed 105,000 Dts/d. Exhibit TWR-6 details 1
the Company’s design day requirements as compared to available capacity 2
entitlements through the 2019-20 winter season. 3
New Long Term Agreements 4
Columbia Capacity 5
As stated in previous filings, the Company has been evaluating, and continues 6
to evaluate interstate pipeline expansions as a means to alleviate the reliance 7
on city gate supplies, which are delivered on a secondary basis, to meet a 8
Design Day. Following the review and evaluation of a number of supply 9
options, the Company concluded that Columbia Gas Transmission, LLC’s 10
East Side Expansion Project (ESEP) provided the best overall value in terms 11
of demand charges and access to comparatively low cost supply. As a result of 12
the analysis, in October 2012 the Company entered into a Precedent 13
Agreement with Columbia to secure pipeline capacity on their ESEP. The 14
ESEP will provide South Jersey access to supplies from the Tennessee Gas 15
Pipeline, which has previously not been accessible with South Jersey’s 16
existing portfolio of capacity. In January 2015 the Company signed a FTS 17
Service Agreement related to the ESEP. On November 1, 2015 50,000 Dts/d 18
of ESEP capacity went into service and will increase by 10,000 Dts/d each 19
November 1 until the full contractual volume of 70,000 Dts/d is reached 20
November 1, 2017. The negotiated reservation rate for this service is 21
$13.512/Dth/Month and the contract term will be 15 years from the in-service 22
date. 23
- 12 -
PennEast Capacity 1
In August of 2014 the Company entered into a Precedent Agreement for firm 2
transportation capacity with PennEast Pipeline Company, LLC (“PennEast”). 3
The Company requested a Maximum Daily Firm Transportation Quantity 4
(MDQ) of 105,000 Dth/d, which qualified the Company as a Foundation 5
Shipper and for the Most Favored Nation Rate Provision. If PennEast were to 6
negotiate a lower rate with any other shipper, the Most Favored Nation Rate 7
Provision provides that South Jersey would also pay the lower rate. The 8
reservation rate is $0.45/Dth/Day and the in-service date is expected to be in 9
the 3rd or 4th quarter of 2018. This unique opportunity will provide access 10
(receipt points) to supplies in at several locations in Luzerne County, PA and 11
deliver those supplies to Transco in Mercer County, NJ where they can be 12
moved to SJG’s city gate on existing capacity acquired in Transco’s Central 13
New Jersey Expansion Project (CNJEP) in 2005. Currently the receipt points 14
of the capacity acquired in the CNJEP are located in Transco’s Zone 6. 15
Transco’s Zone 6 supplies have been subjected to considerable volatility 16
during the 2013-14 and 2014-15 winter seasons, leading to higher commodity 17
prices in those locations. Additionally, since February 2015, Transco has 18
identified the Marcus Hook Lateral (where all SJG Transco Meter Stations are 19
located) as a constraint point on their system, which has further exacerbated 20
price volatility in the market area. South Jersey’s requested MDQ of 105,000 21
Dth/d on the PennEast project, matching the MDQ held on Transco’s CNJEP, 22
will benefit South Jersey’s customers by providing access to significantly 23
- 13 -
lower priced commodity. In addition, the discounted supplies provided by 1
the PennEast/CNJEP path may provide an opportunity to make additional 2
supply portfolio changes that could potentially provide additional cost savings 3
for BGSS customers above and beyond the PennEast/CNJEP path commodity 4
savings. 5
Tennessee Capacity 6
In December of 2014, the Company entered into a Precedent Agreement for 7
firm transportation capacity with Tennessee Gas Pipeline, LLC. The 8
Company requested a MDQ of 78,000 Dth/d. The reservation rate is 9
$12.166/Dth/Month and the expected in-service date is June 1, 2018. This 10
capacity will provide access (receipt points) to supplies along Tennessee’s 11
pipeline 300 line, with the Primary Receipt Point of Gibson in Wayne County, 12
PA and deliver those supplies to Columbia in Pike County, PA where they can 13
be moved to SJG’s city gate on capacity acquired in Colombia’s ESEP, 14
discussed above. South Jersey’s requested MDQ of 78,000 Dth/d on the 15
Tennessee project matches the MDQ on Columbia’s ESEP, plus some 16
additional Columbia capacity held by the Company. 17
Cabot Supply 18
In January 2015 South Jersey entered into three (3) long term supply 19
agreements directly associated with the new pipeline capacity agreements 20
identified above that will provide significantly discounted supply and offset 21
the demand and variable charges associated with those new capacity 22
agreements. The first agreement provides supply into the Tennessee 300 line 23
- 14 -
at Gibson, which will be moved to the Tennessee/Columbia interconnect, then 1
transported to SJG’s city gate via Columbia. This supply is priced at NYMEX 2
last day settle less $0.88. The commodity price has been negotiated to offset 3
the per Dth demand charge on both the Tennessee capacity and the Columbia 4
ESEP capacity and land at SJG’s city gate flat to NYMEX. The delivery 5
period begins November 2018 and continues for 10 years. 6
The second agreement provides supply into the PennEast project, which will 7
be moved to the PennEast/Transco interconnect, then transported to SJG’s city 8
gate via Transco. This supply is priced at NYMEX last day settle less $0.61. 9
The commodity price has also been negotiated to offset the per Dth demand 10
charge for both the PennEast capacity and Transco’s CNJEP capacity, and 11
land at SJG’s city gate flat to NYMEX. The delivery period begins on the in-12
service date of the PennEast project and continues for 10 years. 13
These two supply agreements are priced to offset the pipeline demand and 14
variable charges on the PennEast and Transco pipelines on which they will 15
flow. The commodity will deliver into South Jersey’s system at the monthly 16
NYMEX settle flat, net of pipeline demand and variable costs. This pricing 17
structure will prompt these pipeline paths to operate at the highest load factor 18
in the SJG portfolio. The unique and innovative structure of these two supply 19
agreements will provide BGSS customers with significant savings for years 20
into the future. 21
The third agreement provides winter only supply into the PennEast project, 22
which will be moved to the PennEast/Transco interconnect, then transported 23
- 15 -
to SJG’s city gate via Transco. This supply is priced at Leidy Transco 1
Receipts inside FERC Index plus $0.03 per Dth. The Leidy Transco Index 2
has been among the lowest priced indices in the country and, based on the 3
volume of Marcellus gas projected to come on line in the future, the Company 4
anticipates that the index will remain low relative to other locations for the 5
foreseeable future. The delivery period begins on the in-service date of the 6
PennEast project and continues for 10 years. 7
Supplier Refunds 8
The Company’s actual and projected supplier refunds for both the 2015-2016 9
and 2016-2017 BGSS years are shown in Exhibit TWR-8 on page 1 of 2 and 10
page 2 of 2, respectively. The refunds shown for 2015-2016 reflect 11
miscellaneous pipeline rate adjustments and the sharing of penalty revenues 12
with non-penalized shippers. The Company is not anticipating any significant 13
refunds during the 2016-2017 BGSS year at this time. 14
15
V. HEDGING PROGRAM 16
Overview 17
South Jersey Gas manages its hedging program in accordance with the 18
Commodity Purchasing Guidelines contained in its Financial and Physical 19
Natural Gas Transaction Risk Management Policy and Procedures (“Policy 20
and Procedures”) reviewed and approved by the Company’s Risk 21
Management Committee (RMC). South Jersey’s RMC is responsible for 22
approving and reviewing these hedging programs, while the Gas Supply 23
- 16 -
Department is responsible for executing the hedging strategies outlined in the 1
Policy and Procedures. 2
The intent of the hedging program and strategies is to provide commodity 3
price stabilization at the lowest reasonable cost. South Jersey’s hedging 4
program consists of the following four hedging strategies: 1) A Non-5
Discretionary Strategy - the Company purchases two and 1/2 futures contracts 6
per month for the 18 month period beginning with the 7th month and 7
continuing through the 24th month of the current NYMEX strip; 2) A 8
Planalytics Strategy - the Company purchases futures contracts based on 9
suggestions from the Planalytics Energy Buyer hedging tool; 3) A Storage 10
Incentive Mechanism (“SIM”) Strategy - the Company purchases futures 11
contracts for the summer injection period establishing a benchmark and then 12
manages the physical injections to improve upon the benchmark; and 4) A 13
Discretionary Strategy - the Company exercises managerial discretion to 14
utilize futures, options, fixed priced physical, or other derivatives when 15
deemed appropriate. 16
All hedging gains and losses, as well as the cost of any derivatives and related 17
transaction fees, are passed through the BGSS clause and as such are subject 18
to periodic review by the BPU. Speculative trading is not practiced by the 19
Company. 20
Reporting 21
The Gas Supply Department prepares and distributes, on a quarterly basis, a 22
detailed report of hedging positions for the current and prospective BGSS 23
- 17 -
years. The reports are presented to and reviewed by South Jersey’s RMC and 1
are provided to the BPU as is required. The reports contain the details of each 2
hedging strategy and a summary of all hedging strategies, including the 3
percentage of BGSS send-out currently hedged. 4
The four most recent quarterly hedging reports as of March 2016 are 5
contained in exhibit TWR-9. 6
7
VI. COST REDUCTION INITIATIVES 8
Current and Anticipated Conservation Incentive Program Actions 9
By Order dated May 21, 2014 in Docket No. GR13030185 (the “CIP 10
Continuation Order”), the Board approved the continuation of the Company’s 11
Conservation Incentive Program (CIP), with certain modifications, that 12
became effective with the CIP accrual year beginning October 1, 2014. Those 13
modifications, which include the Modified BGSS Savings Test, have been 14
reflected in this CIP filing and are discussed in more detail in the Prepared 15
Direct Testimony of Daniel P. Yardley. 16
Savings for the 2016 -2017 BGSS year include $2,243,369 of Category One 17
Permanent BGSS Savings, which are defined in the CIP Continuation Order 18
as permanent savings realized from their respective permanent capacity 19
releases and contract terminations The CIP Continuation Order identified 20
Category One Permanent BGSS Savings of $2,587,948, which included 21
$1,704,736 of savings associated with the termination of the SS-1 storage 22
service provided by Transco and Dominion. When the Company permanently 23
- 18 -
discontinued the Dominion transportation and Transco storage service, the 1
remaining Transco firm transportation portion of the service was not 2
permanently released. The value of $344,579 associated with this remaining 3
Transco firm transportation service should not have been included in the 4
calculation of Category One Permanent BGSS Savings associated with the 5
SS-1 service termination. The correct Category One Permanent BGSS Savings 6
is $2,243,369 and will be recognized in all future filings. 7
Anticipated Category Two eligible BGSS savings for the 2016-17 BGSS 8
include the following capacity releases: 20,000 dts/d Transco FTF capacity; 9
10,000 dts/d of Transco Long Haul capacity; 19,029 dts/d of Columbia FSS 10
withdrawal capacity; and 8,671 dts/d of Columbia FTS capacity. Category 11
Two BGSS savings also include $913,800 in commodity savings from a 12
negotiated change in receipt location of Columbia capacity. Theses anticipated 13
Category Two releases represent a cross section of South Jersey’s portfolio of 14
assets. 15
Category Three BGSS savings associated with avoided capacity costs to meet 16
residential customer growth total $260,288. This amount has been calculated 17
as set forth in the Board’s Order in Docket No. GR13030185 and is supported 18
by the Direct Testimony of Daniel P. Yardley. 19
The total anticipated Category One, Two and Three savings eligible for the 20
BGSS savings test for the 2016-2017 BGSS is $8.6 million. 21
22
23
- 19 -
VII. FEDERAL ENERGY REGULATORY COMISSION (FERC) PIPELINE 1 ACTIVITES 2
3 A summary of FERC proceedings which may impact BGSS costs during the 4
applicable periods is attached as Exhibit TWR-11. This schedule reflects 5
those proceedings that may have an operational and/or cost affect on the 6
services that South Jersey receives from its pipeline suppliers. 7
8
VIII. CONCLUSION 9
This testimony highlights activities the Company is undertaking to optimize the use 10
of its gas supply portfolio and to minimize and stabilize costs to its customers. For 11
the reasons set forth in this testimony the Board should approve the Company’s 12
proposed BGSS and CIP rates. 13
1 2 3 4 5O
ct-1
6N
ov-1
6D
ec-1
6Ja
n-17
Feb
-17
Mar
-17
Apr
-17
May
-17
Jun-
17Ju
l-17
Aug
-17
Sep
-17
Tot
al6 7
Util
ity S
endo
ut1,
370,
119
2,89
0,86
24,
676,
835
5,27
4,93
24,
612,
659
3,58
2,35
01,
810,
968
945,
586
603,
104
590,
928
612,
419
611,
725
27,5
82,4
878
GS
G-L
V -
Mon
thly
BG
SS
173,
567
417,
630
702,
392
581,
771
776,
415
391,
728
264,
797
69,2
2413
8,85
315
7,19
019
2,59
449
,965
3,91
6,12
69
EG
S-L
V -
Firm
- M
onth
ly B
GS
S0
00
00
00
00
00
00
10E
GS
-LV
- L
imite
d F
irm -
Mon
thly
BG
SS
00
00
00
00
00
00
011
EG
S -
Mon
thly
BG
SS
1011
117
77
78
88
1010
106
12F
ES
- L
imite
d F
irm73
,045
48,6
965,
073
25,3
6342
,609
55,7
9855
,798
81,1
6121
3,04
713
1,88
613
1,88
676
,088
940,
448
13LV
S -
Mon
thly
BG
SS
00
00
00
00
00
00
014
Tot
al F
irm S
endo
ut1,
616,
740
3,35
7,19
95,
384,
310
5,88
2,07
35,
431,
691
4,02
9,88
32,
131,
570
1,09
5,97
995
5,01
288
0,01
293
6,90
973
7,78
832
,439
,167
15 16N
et S
tora
ge In
ject
ions
17 18T
rans
co S
-277
00
00
015
,000
15,0
0020
,460
21,6
4236
,642
31,2
2314
0,04
419
Tra
nsco
SS
-2 (
2)72
,827
00
00
034
1,91
032
8,66
929
7,61
529
3,56
127
3,51
322
9,40
71,
837,
502
20T
rans
co E
SS
23,3
010
00
00
31,8
1831
,817
41,0
1043
,331
43,3
3141
,010
255,
615
21T
rans
co G
SS
192,
640
00
00
023
8,76
724
6,24
723
7,57
921
0,38
021
0,38
020
3,12
91,
539,
122
22T
rans
co L
NG
(LG
A)
00
00
00
35,3
0336
,378
35,3
0336
,378
36,3
7835
,303
215,
042
23T
rans
co L
SS
(2)
97,5
780
00
00
204,
000
210,
800
202,
920
204,
000
198,
280
204,
000
1,32
1,57
824
Col
umbi
a F
SS
226,
732
00
00
046
3,53
136
9,23
434
3,58
734
3,58
734
3,58
736
0,01
02,
450,
269
25D
omin
ion
GS
S49
,935
00
00
063
,450
72,8
5070
,500
72,8
5072
,850
70,5
0047
2,93
526
Com
pany
LN
G0
107,
037
102,
818
107,
818
102,
817
00
00
00
042
0,49
027
ES
S C
ompr
esso
r F
uel 0
.0%
00
00
00
00
00
00
028
GS
S C
ompr
esso
r F
uel 2
.84%
5,63
10
00
00
6,97
97,
198
6,94
46,
149
6,14
95,
937
44,9
8729
SS
-2 C
ompr
esso
r F
uel 0
.71%
521
00
00
02,
445
2,35
02,
128
2,09
91,
956
1,64
013
,139
30LS
S C
ompr
esso
r F
uel 1
.54%
1,52
60
00
00
3,19
13,
297
3,17
43,
191
3,10
13,
191
20,6
7131
LGA
Com
pres
sor
Fue
l 23.
3%0
00
00
010
,724
11,0
5110
,724
11,0
5111
,051
10,7
2465
,325
32C
olum
bia
FS
S C
ompr
esso
r F
uel 0
.15%
295
00
00
069
655
551
651
651
654
13,
635
33T
rans
co S
-2 C
ompr
esso
r F
uel 0
.64%
10
00
00
9797
132
139
236
201
903
34D
omin
ion
GS
S C
ompr
esso
r F
uel 1
.95%
993
00
00
01,
262
1,44
91,
402
1,44
91,
449
1,40
29,
406
35C
olum
bia
SS
T C
ompr
esso
r F
uel 2
.042
%4,
431
00
00
09,
663
7,69
77,
162
7,16
27,
162
7,50
550
,782
36 37T
otal
Sto
rage
Inje
ctio
ns67
6,48
810
7,03
710
2,81
810
7,81
810
2,81
70
1,42
8,83
51,
344,
689
1,28
1,15
61,
257,
485
1,24
6,58
11,
205,
722
8,86
1,44
538 39
Tot
al R
equi
rem
ents
2,29
3,22
73,
464,
236
5,48
7,12
85,
989,
891
5,53
4,50
84,
029,
883
3,56
0,40
52,
440,
668
2,23
6,16
82,
137,
497
2,18
3,49
01,
943,
510
41,3
00,6
12
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
Y20
16 -
201
7 B
GS
SC
Req
uire
men
t & S
uppl
y
TWR-1 PAGE 1 OF 2
1 2 3 4 5O
ct-1
6N
ov-1
6D
ec-1
6Ja
n-17
Feb
-17
Mar
-17
Apr
-17
May
-17
Jun-
17Ju
l-17
Aug
-17
Sep
-17
Tot
al6 7
Net
Sto
rage
With
draw
als
8 9T
rans
co S
-20
048
,267
48,2
6743
,433
00
00
00
013
9,96
710
Tra
nsco
SS
-2 (
2)0
86,8
1242
3,62
149
7,33
344
9,20
430
7,70
60
00
00
01,
764,
675
11T
rans
co E
SS
00
014
6,36
385
,952
00
00
00
023
2,31
512
Tra
nsco
GS
S0
81,9
4216
3,88
459
2,10
630
8,55
010
0,00
010
0,00
00
00
00
1,34
6,48
213
Tra
nsco
LN
G (
LGA
)0
00
141,
030
63,0
4010
,972
00
00
00
215,
042
14T
rans
co L
SS
(2)
012
0,00
031
2,00
036
0,00
022
8,00
020
4,00
00
00
00
01,
224,
000
15C
olum
bia
FS
S0
244,
792
515,
687
557,
583
582,
314
223,
161
100,
000
00
00
02,
223,
537
16D
omin
ion
GS
S0
010
0,00
014
0,00
014
0,80
042
,200
00
00
00
423,
000
17C
ompa
ny L
NG
015
,000
41,5
8111
3,92
910
0,33
079
,100
9,50
09,
500
9,50
09,
500
9,50
09,
500
406,
940
18S
-2 C
ompr
esso
r F
uel 2
.17%
00
(1,0
47)
(1,0
47)
(942
)0
00
00
00
(3,0
36)
19S
S-2
Com
pres
sor
Fue
l 1.2
2%0
(1,0
59)
(5,1
68)
(6,0
67)
(5,4
80)
(3,7
54)
00
00
00
(21,
528)
20LS
S C
ompr
esso
r F
uel 0
.24%
0(2
88)
(749
)(8
64)
(547
)(4
90)
00
00
00
(2,9
38)
21G
SS
Com
pres
sor
Fue
l 0.0
%0
00
00
00
00
00
00
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r F
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00
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Col
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ST
Com
pres
sor
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l 2.0
42%
0(4
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00
00
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25 26T
otal
Sto
rage
With
draw
als
054
2,19
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2,57
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71,
982,
763
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337
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500
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27 28P
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& S
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tal S
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29S
pot P
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ases
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EP
665,
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2,95
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230
Spo
t Pur
chas
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Col
umbi
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7,54
8
43
8,24
0
58
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58
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58
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41
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0
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41
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40
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ases
- T
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co90
3,34
6
11
0,42
2
41
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7
21
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51
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3
1,59
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5
83
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5
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0
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71
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6
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pot P
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ases
- T
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co L
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300,
000
450,
000
600,
000
600,
000
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000
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000
100,
000
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000
100,
000
100,
000
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000
3,45
0,00
033
Spo
t Pur
chas
es -
FE
S &
Mon
thly
BG
SS
246,
621
466,
338
707,
475
607,
141
819,
032
447,
533
320,
602
150,
393
351,
908
289,
084
324,
490
126,
063
4,85
6,68
034
Spo
t Pur
chas
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n T
rans
co P
SF
T0
093
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6284
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00
00
00
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035
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d N
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al G
as (
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)0
107,
037
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818
107,
818
102,
817
00
00
00
042
0,49
036
Tot
al P
ipel
ine
& S
uppl
emen
tal S
uppl
ies
2,29
3,22
72,
922,
037
3,89
9,58
23,
412,
644
3,55
1,74
63,
071,
546
3,35
2,94
72,
431,
168
2,22
6,66
82,
127,
997
2,17
3,99
01,
934,
010
33,3
97,5
6237 38
Tot
al S
uppl
y2,
293,
227
3,46
4,23
65,
487,
128
5,98
9,89
15,
534,
508
4,02
9,88
33,
560,
405
2,44
0,66
82,
236,
168
2,13
7,49
72,
183,
490
1,94
3,51
041
,30
0,61
2
Req
uire
men
t & S
uppl
y
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
Y20
16 -
201
7 B
GS
SC
TWR-1 PAGE 2 OF 2
1 2 3 4 5O
ct-1
6N
ov-1
6D
ec-1
6Ja
n-17
Feb
-17
Mar
-17
Apr
-17
May
-17
Jun-
17Ju
l-17
Aug
-17
Sep
-17
6 7 8T
rans
co F
T Z
ON
E B
AS
ED
RE
SV
$0.477
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7$0
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79
Tra
nsco
FT
LO
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HA
UL
CA
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EL.
CR
ED
IT
$0.000
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010
Tra
nsco
S-2
DE
MA
ND
$0.145
1$0
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1$0
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111
Tra
nsco
S-2
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Y$0
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012
Tra
nsco
S-2
IN
$0.033
9$0
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913
Tra
nsco
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OU
T$0
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.049
114 15
Tra
nsco
SS
-2 D
EM
AN
D$0
.281
6$0
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6$0
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616
Tra
nsco
SS
-2 C
AP
AC
ITY
$0.000
9$0
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917
Tra
nsco
SS
-2 I
N$0
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718
Tra
nsco
SS
-2 O
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$0.031
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719 20
Tra
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821
Tra
nsco
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S C
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$0.000
5$0
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522
Tra
nsco
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823
Tra
nsco
GS
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$0.041
9$0
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924 25
Tra
nsco
ES
S D
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126
Tra
nsco
ES
S C
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ITY
$0.002
5$0
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527
Tra
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ES
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128
Tra
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ES
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$0.041
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129 30
Tra
nsco
LS
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D$0
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2$0
.152
231
Tra
nsco
LS
S C
AP
AC
ITY
$0.000
6$0
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6$0
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632
Tra
nsco
LS
S I
N$0
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733
Tra
nsco
LS
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$0.021
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234 35
Tra
nsco
LN
G (
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D$0
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836
Tra
nsco
LN
G (
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AP
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$0.006
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737
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nsco
LN
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$0.305
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538
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539 40
Pla
naly
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Ann
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s$3
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stre
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$5,000
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SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
Y20
16 -
201
7 B
GS
SC
Pip
elin
e P
ricin
g
TWR-2 PAGE 1 OF 2
1 2 3 4 5O
ct-1
6N
ov-1
6D
ec-1
6Ja
n-17
Feb
-17
Mar
-17
Apr
-17
May
-17
Jun-
17Ju
l-17
Aug
-17
Sep
-17
6T
RA
NS
CO
FT
DE
MA
ND
#10
1359
9$0
.130
9$0
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9$0
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9$0
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9$0
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97 8 9 10
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tem
CO
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er D
T$2
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.041
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0$2
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0$2
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0$2
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0$2
.906
0$2
.902
011
Com
mod
ity P
urch
ases
- T
rans
co (
FE
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Mon
thly
BG
SS
)$2
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0$2
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0$2
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0$3
.003
0$3
.012
0$3
.008
012
Com
mod
ity P
urch
ases
- T
rans
co L
eidy
#10
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9$2
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3$2
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1$2
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5$3
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1$2
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.918
3$2
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413 14
Tra
nsco
PS
FT
Tra
nspo
rtat
ion
DE
MA
ND
$0.000
0$0
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0$0
.951
3$0
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3$0
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3$0
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0$0
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0$0
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0$0
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015
Tra
nsco
FT
CN
JEP
DE
MA
ND
$0.130
9$0
.130
9$0
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9$0
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9$0
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916
Com
mod
ity P
urch
ases
- T
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co P
SF
T$2
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0$2
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0$2
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0$2
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.003
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.008
017
Tra
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FT
F D
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D #
1013
598
$0.000
0$0
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018
Com
mod
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urch
ases
- C
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t Sid
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roje
ct$2
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019
Com
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- C
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$2.449
0$2
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0$2
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0$2
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020
Col
umbi
a F
TS
DE
MA
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#15
6147
and
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$6.095
0$6
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021
Col
umbi
a G
as N
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DE
MA
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$7.605
0$7
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022
Col
umbi
a F
SS
DE
MA
ND
MD
SQ
$1.509
0$1
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023
Col
umbi
a F
SS
DE
MA
ND
SC
Q$0
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824
Col
umbi
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SS
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$0.015
3$0
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325
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umbi
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T$0
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326
Col
umbi
a S
ST
DE
MA
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$5.295
0$5
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.295
027
Col
umbi
a S
ST
IN$0
.015
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TWR-2 PAGE 2 OF 2
SOUTH JERSEY GAS COMPANY
Projected Supplemental Gas Supplies - Winter Peaking
LNG
1 2 3 4 5 6 7
LNG NYMEX Variable/Basis Del'd Total LNG TotalProduced Close On Costs to Commodity Commodity Production LNG
(DTS) 10-May-16 City Gate ($/Dt) Costs Variable Costs
($/Dt) (3 + 4) (1 x 4) Costs (5 + 6)
Oct 2016 0 $2.459 $0.000 $0.000 $0 $0 $0
Nov 2016 107,037 $2.672 $0.445 $3.117 $333,634 $215,000 $548,634
Dec 2016 102,818 $2.965 $0.811 $3.776 $388,241 $215,000 $603,241
Jan 2017 107,818 $3.096 $1.174 $4.270 $460,383 $215,000 $675,383
Feb 2017 102,817 $3.089 $1.125 $4.214 $433,271 $215,000 $648,271
Mar 2017 0 $3.039 $0.000 $0.000 $0 $0 $0
Apr 2017 0 $2.850 $0.000 $0.000 $0 $0 $0
May 2017 0 $2.835 $0.000 $0.000 $0 $0 $0
Jun 2017 0 $2.865 $0.000 $0.000 $0 $0 $0
Jul 2017 0 $2.900 $0.000 $0.000 $0 $0 $0
Aug 2017 0 $2.909 $0.000 $0.000 $0 $0 $0
Sep 2017 0 $2.905 $0.000 $0.000 $0 $0 $0.
Totals 420,490 $2.8820 $0.888 $3.842 $1,615,529 $860,000 $2,475,529
TWR-3
12 SOUTH JERSEY GAS COMPANY3 ACTUAL ANNUAL REQUIREMENTS AND SUPPLIES4 NOVEMBER 2013 THROUGH OCTOBER 2015567 Quantities in MDts8 1 2 3 5 6 79
1011 Nov 2013 through Oct 2014 Nov 2014 through Oct 20151213 Actual Actual Actual Actual Actual Actual1415 Heating Non-Heat Heating Non-Heat16 FIRM REQUIREMENTS Annual Season Season Annual Season Season17 Residential 24,140 19,097 5,043 26,103 21,030 5,07318 Commercial 5,256 3,924 1,333 5,817 4,447 1,37019 Commercial Large Volume 618 405 213 635 480 15520 Industrial 290 231 59 491 294 19721 Company Use and Unaccounted For 1,594 1,193 401 1,243 2,031 -78822 Firm Electric Service 1,017 429 588 1,474 231 1,24323 Electric Generation - LV 0 0 0 1 0 124 Electric Generation - Monthly BGSS 0 0 0 0 0 025 BSC 0 0 0 0 0 02627 TOTAL FIRM SENDOUT EXCLUDING TRANSPORTATION (lines 17 thru 25) 32,916 25,278 7,638 35,764 28,514 7,2512829 Firm Transportation (FT) 33,973 17,043 16,930 28,728 15,365 13,3623031 TOTAL FIRM SENDOUT AND TRANSPORTATION (lines 27+29) 66,889 42,321 24,568 64,492 43,879 20,6133233 Interruptible Sales, Interruptible Transportation and Off-System Sales 10,615 5,869 4,745 14,380 8,069 6,3123435 TOTAL SENDOUT, TRANSPORTATION AND OFF-SYSTEM SALES (line 31+33) 77,503 48,190 29,313 78,873 51,948 26,9243637 Storage Injections 7,880 817 7,063 7,959 732 7,2273839 TOTAL REQUIREMENTS (lines 35+37) 85,383 49,007 36,376 86,831 52,680 34,1524041 AVAILABLE SUPPLIES42 Spot Direct Purchases - Transco & Columbia FT & City Gate 39,909 22,533 17,375 48,282 30,019 18,26343 LNG 529 447 83 485 422 6444 PSE&G Net Exchange 0 0 0 0 0 045 Peaking Supply 1,807 1,807 0 0 0 046 Transportation Gas (Firm & Interruptible) 35,706 17,175 18,530 30,667 15,649 15,0184748 TOTAL SUPPLIES EXCLUDING STORAGE (lines 43 thru 47) 77,950 41,962 35,988 79,434 46,089 33,3454950 Storage Withdrawals 7,760 7,228 532 7,397 6,590 8075152 TOTAL SUPPLIES AND STORAGE (lines 49+51) 85,710 49,190 36,520 86,831 52,680 34,152
TWR-4 Page 1 of 3
12 SOUTH JERSEY GAS COMPANY3 ANNUAL REQUIREMENTS AND SUPPLIES4 NOVEMBER 2015 THROUGH OCTOBER 20165 ACTUAL HEATING SEASON - ESTIMATED NON-HEATING SEASON678 Quantities in MDts9 1 2 3
101112 Nov 2015 through Oct 2016131415 Estimated Actual Estimated1617 Heating Non-Heat18 FIRM REQUIREMENTS Annual Season Season19 Residential 15,163 15,163 020 Commercial 2,735 2,735 021 Commercial LV 225 225 022 Industrial 66 66 023 Company Use and Unaccounted For 0 0 024 Firm Electric Service 282 282 025 Electric Generation - Large Volume 23 23 026 Total Summer Season Utility Load Normal Weather Requirements Inc. Firm Transportation 11,199 0 11,1992728 TOTAL FIRM SENDOUT REQUIREMENTS (lines 19 thru 26) 29,694 18,494 11,1992930 Firm Transportation (FT) 12,612 12,612 03132 TOTAL FIRM SENDOUT AND TRANSPORTATION (lines 28+30) 42,306 31,106 11,1993334 Available For Interruptible and Off-System Sales (WS Actual - SS lines 53-32-38) 59,799 10,277 49,5233536 TOTAL SENDOUT, TRANSPORTATION AND OFF-SYSTEM SALES (line 32+34) 102,105 41,383 60,7223738 Storage Injections 8,943 1,259 7,6833940 TOTAL REQUIREMENTS - NORMAL WEATHER (lines 36+38) 111,048 42,642 68,4064142 AVAILABLE SUPPLIES43 Spot Direct Purchases - Transco & Columbia FT & City Gate 51,967 16,798 35,16944 LNG 278 211 6745 PSE&G Net Exchange 0 0 046 Peaking Supply 0 0 047 Columbia ESEP 13,943 3,243 10,70048 Transportation Gas (WS Actual - SS up to 105,000 dts/d) 37,397 14,927 22,4704950 TOTAL SUPPLIES EXCLUDING STORAGE (lines 43 thru 48) 103,585 35,179 68,4065152 Storage Withdrawals 7,463 7,463 05354 TOTAL SUPPLIES PLUS STORAGE (lines 50+52) 111,048 42,642 68,406
TWR-4 Page 2 of 3
12 SOUTH JERSEY GAS COMPANY3 ANNUAL REQUIREMENTS AND SUPPLIES4 NOVEMBER 2017 THROUGH OCTOBER 20185 EXCLUDES OPT-OUT CUSTOMERS67 Quantities in MDts8 1 2 39
1011 Nov 2017 through Oct 2018121314 Estimated Estimated Estimated1516 Heating Non-Heat17 Annual Season Season18 TOTAL FIRM SENDOUT AND TRANSPORTATION REQUIREMENTS (EXCLUDES OPT-OUT) 41,685 30,151 11,5331920 Storage Injections Based on Full Contract Quantities 7,683 0 7,6832122 TOTAL SENDOUT AND TRANS. REQUIREMENTS - NORMAL WEATHER (lines 18+20) 49,368 30,151 19,2172324 Firm Sendout and Transportation Requirements Added for Design Weather 6,264 6,264 02526 TOTAL SENDOUT AND TRANS. REQUIREMENTS - DESIGN WEATHER (lines 22+24) 55,632 36,415 19,2172728 AVAILABLE SUPPLIES29 Spot Purchases Based on Transco & Col. FT & City Gate Supplies - Cap. Reduced For CIP Releases 71,477 31,272 40,20530 LNG Withdrawals 434 368 6731 Peaking Service 920 920 032 Columbia East Side Expansion Project 25,550 10,570 14,98033 Transportation Gas (105,000 Dts per day) 38,325 15,855 22,4703435 TOTAL SUPPLIES EXCLUDING STORAGE (lines 29 thru 33) 136,706 58,984 77,7223637 Storage Withdrawals Full Contract Quantities 7,683 7,683 03839 TOTAL SUPPLIES PLUS STORAGE (lines 35+37) 144,389 66,668 77,7224041 WINTER RESERVE - NORMAL WEATHER (lines 39-22) 36,5174243 WINTER RESERVE - DESIGN WEATHER (lines 39-26) 30,2524445 Amount in Storage November 1 7,68346
TWR-4 Page 3 of 3
TWR-5
CONFIDENTIAL
1
2 SOUTH JERSEY GAS COMPANY3 DESIGN DAY FORECAST4 2016-17 THROUGH 2020-215
67 2016-17 2017-18 2018-19 2019-20 2020-218 Summary of Requirements vs Supplies9 Total Design Day Requirements 512,891 520,555 528,351 536,280 544,34610 Total Design Day Supplies 554,755 564,755 564,755 564,755 564,75511 Excess / (Shortfall) 41,864 44,200 36,404 28,475 20,409121314 Design Day Degree Days 63.0 63.0 63.0 63.0 63.01516 Quantity in Dts 2016-17 2017-18 2018-19 2019-20 2020-211718 Total Design Day Sendout Requirements 512,891 520,555 528,351 536,280 544,346
1920 Design Day Capacity Entitlements2122 Pipeline City Gate Long-Term Capacity Contract #23 Transco FT (Long-haul) 1003902 128,651 128,651 128,651 128,651 128,65124 Transco FT (Long-haul) 1002231 2,264 2,264 2,264 2,264 2,26425 Transco (PSFT) (Long-haul) 1005003 3,002 3,002 3,002 3,002 3,00226 Transco FT (Leidy Line) 1013599 41,608 41,608 41,608 41,608 41,60827 Transco FT (Leidy Line) 1044825 17,433 17,433 17,433 17,433 17,43328 Columbia NTS 39305 22,511 22,511 22,511 22,511 22,51129 Columbia FTS 38099 22,511 22,511 22,511 22,511 22,51130 Columbia FTS 156147 9,000 9,000 9,000 9,000 9,00031 Columbia FTS (ESEP) 161135 60,000 70,000 70,000 70,000 70,0003233 Total Pipeline Services (lines 23 thru 31) 306,980 316,980 316,980 316,980 316,9803435 Underground Storage Services36 Transco S-2 1,557 1,557 1,557 1,557 1,55737 Transco GSS 27,314 27,314 27,314 27,314 27,31438 Transco LSS 12,000 12,000 12,000 12,000 12,00039 Transco LG-A 15,670 15,670 15,670 15,670 15,67040 Transco SS-2 16,043 16,043 16,043 16,043 16,04341 Columbia FSS 52,891 52,891 52,891 52,891 52,8914243 Total Underground Storage (lines 36 thru 41) 125,475 125,475 125,475 125,475 125,4754445 Company Sources46 Company LNG (110,000 Mcf pro-rated @ 20 hours - converted to Dts) 75,000 75,000 75,000 75,000 75,0004748 Total Company Entitlement Sources (lines 33+43+46) 507,455 517,455 517,455 517,455 517,4554950 Company Entitlement Deficiency Before Transportation (48-18) (5,436) (3,100) (10,896) (18,825) (26,891)5152 Transportation Sources53 RSG-FT @ 100% of Jan 2017 Average Daily Load 14,810 14,810 14,810 14,810 14,81054 GSG-FT & GSG-LV-FT @ 100% of Jan 2017 Average Daily Load 42,069 42,069 42,069 42,069 42,0695556 Total Transportation Sources (lines 53+54) 56,879 56,879 56,879 56,879 56,8795758 Incremental Capacity Avialable From Transco CNJEP (105,000-line 56) 48,121 48,121 48,121 48,121 48,1215960 Total Transco CNJEP Capacity (lines 56+58) 105,000 105,000 105,000 105,000 105,0006162 Assets Released as Part of The Conservation Incentive Program63 Transco FT (Long Haul) (10,000) (10,000) (10,000) (10,000) (10,000)64 Transco FT (Leidy Line) (20,000) (20,000) (20,000) (20,000) (20,000)65 Columbia FTS (8,671) (8,671) (8,671) (8,671) (8,671)66 Columbia FSS (19,029) (19,029) (19,029) (19,029) (19,029)67 68 Total Assets Released as Part of the CIP (lines 63 thru 66) (57,700) (57,700) (57,700) (57,700) (57,700)6970 Total Net Design Day Supplies (lines 33+43+46+60+68) 554,755 564,755 564,755 564,755 564,755
7172 Excess / (Shortfall) Between Requirements & Entitlements (lines 70 -18) 41,864 44,200 36,404 28,475 20,4097374 Excess / (Shortfall) as a Percent of Sendout (lines 72/18) 8.2% 8.5% 6.9% 5.3% 3.7%
TWR-6
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TWR-7
SOUTH JERSEY GAS COMPANYSTATEMENT OF SIGNIFICANT ACTUAL AND ESTIMATED SUPPLIER REFUNDS
2015-2016 BGSS YEAR
Pipeline FERC Amount TotalDate Received or Supplier Docket No. Issue Refunded Monthly
Oct-15 Transco Tariff Penalty Sharing Refund $5,182.49 $5,182.49
Nov-15 - - - $0.00 $0.00
Dec-15 Transco Tariff Distribution of Penalties Collected $13,642.95Columbia Credit FTS Penalty Refund $43,430.00 $57,072.95
Jan-16 Transco Tariff Transco S-2 Storage Pass thru from TETCO $378.54Columbia Credit Columbia $227.76 $606.30
Feb-16 - - - $0.00 $0.00
Mar-16 - - - $0.00 $0.00
Apr-16 - - - $0.00 $0.00
May-16 - - - $0.00 $0.00
Jun-16 - - - $0.00 $0.00
Jul-16 - - - $0.00 $0.00
Aug-16 - - - $0.00 $0.00
Sep-16 - - - $0.00 $0.00
Total $62,861.74 $62,861.74
TWR-8 Page 1 of 2
SOUTH JERSEY GAS COMPANYSTATEMENT OF SIGNIFICANT ACTUAL AND ESTIMATED SUPPLIER REFUNDS
2016-2017 BGSS YEAR
Pipeline FERC Amount TotalDate Received or Supplier Docket No. Issue Refunded Monthly
Oct-16 - - - $0.00 $0.00
Nov-16 - - - $0.00 $0.00
Dec-16 - - - $0.00 $0.00
Jan-17 - - - $0.00 $0.00
Feb-17 - - - $0.00 $0.00
Mar-17 - - - $0.00 $0.00
Apr-17 - - - $0.00 $0.00
May-17 - - - $0.00 $0.00
Jun-17 Columbia RP16-314 Modernization Program Refund TBD TBD
Jul-17 - - - $0.00 $0.00
Aug-17 - - - $0.00 $0.00
Sep-17 - - - $0.00 $0.00
Total $0.00 $0.00
TWR-8 Page 2 of 2
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TWR-10
CONFIDENTIAL
FEDERAL REGULATORY FILINGS OF INTEREST TO THE COMPANY
Listed below are summaries of filings submitted to the Federal Energy Regulatory Commission (Commission), for review and approval, made by interstate pipeline suppliers which are of interest to the Company: ____________________________________________________________________________ Transco - Order No. 587-W Compliance Filing (Docket No. RP16-565-000) On February 1, 2016, Transco submitted revised tariff records to comply with FERC’s Order No. 587-W by incorporating into its tariff Version 3.0 of the business practice standards applicable to interstate natural gas pipelines and adopted by the Wholesale Gas Quadrant of the North American Energy Standard Board (NAESB). The Version 3.0 standards include new and revised standards supporting (1) gas-electric scheduling coordination, (2) the transition from common codes used by interstate pipelines to identify receipt and delivery locations to the use of proprietary codes, and (3) revisions to the capacity release standards regarding posting requirements for offers to purchase released capacity. The revised tariff records became effective on April 1, 2016. Transco - Order No. 587-W Second Compliance Filing (Docket No. RP16-565-001) On February 1, 2016, Transco filed revised tariff records to comply with the Commission’s Order No. 587-W to implement Version 3.0 of the NAESB-WGQ Standards to be effective on April 1, 2016. On March 29, 2016, the Commission issued an “Order on Filings in Compliance with Order Nos. 587-W and 809” in which Transco’s revised tariff records generally complied with the requirements of the Orders and accepted Transco’s filing effective April 1, 2016, conditioned upon Transco’s filing a revised tariff record incorporating certain modifications specified in the March 29 Order. On April 12, 2016, Transco filed the revised tariff record effective April 1, 2016.
Transco - Rate Schedule SS-2 Annual Inventory Adjustment (Docket No. RP16-859-000) On April 19, 2016, Transco submitted a filing in compliance with Section 8(c) of Transco’s Rate Schedule SS-2 which provides that Transco will track annually to its Rate Schedule SS-2 customers the adjustment made by National Fuel to Transco’s storage inventory under National Fuel’s Rate Schedule SS-1 related to transportation purchased by Transco under National Fuel’s Rate Schedule X-54. The adjustment to customers’ SS-2 storage inventory became effective May 1, 2016. Transco -Filing to Revise Procedures for Allocating Available Firm Capacity (Docket No. RP16-729-000) On March 18, 2016, Transco filed revisions to Section 49 of the General Terms and Conditions of its tariff, which sets forth procedures for allocating existing firm capacity
TWR-11 Page 1 of 3
that becomes available on its system. The proposed revisions would allow Transco to offer unsubscribed firm capacity through the solicitation of bids in an open season (as currently provided in Section 49), and/or to award unsubscribed capacity on a not unduly discriminatory basis to buyers that submit a valid request for capacity posted on Transco’s Unsubscribed Capacity Report. Transco requested that the revised tariff record be made effective on April 18, 2016.
Columbia Gas Transmission, LLC, - Modernization Program (Docket No. RP16-314-000) On December 18, 2015, Columbia filed a Stipulation and Agreement of Settlement (“Settlement”) representing an extension to its modernization program – a collaborative program between Columbia and its customers to address complex issues arising out of recent and anticipated changes in pipeline safety and environmental requirements, Columbia’s ongoing efforts to enhance pipeline safety and reliability of service, and the age of Columbia’s system. On March 17, 2016, the Commission approved the settlement on the basis that it is fair and reasonable and in the public interest. The Settlement provides for a base rate reduction applicable to specified transportation rate schedules. Effective January 1, 2016, to reflect the termination of Columbia’s obligations associated with its “Post Retirement Benefits Other Than Pensions” (“PBOP”), Columbia will reduce its base rates by approximately $8.4 million annually. Additionally, to reflect the amortization of the PBOP regulatory liability, Columbia will reduce its Base Rates by approximately $12.2 million annually. The filed tariff records reflect these rate reductions. As the base rate reductions are retroactive to January 1, 2016, shippers will realize the benefit of the rate reductions via a refund payment that will occur in the May 2016 billing cycle.
PennEast Pipeline Company, LLC (CP15-1-000)
On August 12, 2014 PennEast Pipeline Company, LLC (PennEast), announced plans to construct a greenfield interstate natural gas pipeline intended to bring lower cost natural gas produced in the Marcellus Shale region to customers in Pennsylvania and New Jersey. PennEast is a joint project of AGL Resources, NJR Pipeline Company, Public Service Power LLC, South Jersey Midstream, Spectra Energy Partners, and UGI Energy Services. The proposed 108 mile PennEast pipeline system will be designed to deliver up to approximately 1 Billion cubic feet of natural gas per day. The project will begin in Luzerne County in northeastern Pennsylvania and end at Transco’s Trenton-Woodbury interconnection in New Jersey.
TWR-11 Page 2 of 3
On October 7, 2014 PennEast submitted a request with the FERC to initiate an environmental review under the National Environmental Policy Act (NEPA) Pre-Filing Process. PennEast plans to file an application with the FERC for authorization of the project under Section 7(c) of the NGA following completion of the NEPA Pre-Filing Process. In March of 2016 PennEast received their Notice of Environmental Schedule from FERC, which details some key milestones in FERC’s comprehensive review of the project application.
SJG expects that the PennEast Project will create a lower, more stable price environment which will benefit all of its customers. PennEast capacity will also allow SJG to restructure its capacity portfolio to lower overall costs to its Basic Gas Supply Service customers. In addition, it will provide additional operational flexibility for SJG by connecting its distribution system to an additional upstream pipeline. Moreover, this capacity will enable the Company to continue its efforts to connect new incremental load to its distribution system, including several natural gas-fired power plants, in support of New Jersey’s Energy Master Plan. The Company has subscribed to 105,000 dts per day of PennEast capacity with and is expected to be in service by the fourth quarter 2018.
Tennessee Gas Pipeline Company, L.L.C. (CP16-4-000)
The Company is following Tennessee Gas Pipeline Company LLC’s (Tennessee) announced Orion Expansion Project (Orion). The project will consist of the construction of about 13 miles of new pipeline and looping along with compressor station modifications. The receipt point for this service is Tennessee’s Compressor Station #321 with a delivery point at Tennessee’s interconnect with Columbia at Milford located in Pike County, PA.
Pending regulatory approvals, Tennessee is planning to start construction in 2017 with an estimated completion in June 2018. SJG has subscribed to 78,000 dts per day of Orion capacity which will be used to feed its capacity acquired as part of Columbia’s ESEP.
TWR-11 Page 3 of 3
2016‐2017
WORKPAPERS
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2016-2017 WORKPAPER INPUT AREA
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2
2016-2017 WORKPAPER KJB-5A PAGE 1 of 2
1W
OR
KP
AP
ER
KJB
-5A
, P
age
2 o
f 2
2N
AT
UR
AL
GA
S D
ET
ER
MIN
AN
TS
3O
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S
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0,00
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(993
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012
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788
32,8
59,6
57
2016-2017 WORKPAPER KJB-5A PAGE 2 of 2
1W
OR
KP
AP
ER
KJB
-5B
, P
age
1 o
f 3
2S
UM
MA
RY
OF
NA
TU
RA
L G
AS
CO
ST
S3
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-16
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v-1
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16
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5,69
3 2016-2017 WORKPAPER KJB-5B PAGE 1 of 3
1W
OR
KP
AP
ER
KJB
-5B
, P
age
2 o
f 3
2S
UM
MA
RY
OF
NA
TU
RA
L G
AS
CO
ST
S3
Oct
-16
No
v-1
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16
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-17
Fe
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,882 2016-2017 WORKPAPER
KJB-5B PAGE 2 of 3
1W
OR
KP
AP
ER
KJB
-5B
, P
age
3 o
f 3
2S
UM
MA
RY
OF
NA
TU
RA
L G
AS
CO
ST
S3
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
4N
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,311
$918
,103
$286
,817
$285
,312
$288
,322
$291
,83
5$2
92,7
38$2
92,3
36$1
0,13
8,86
410
Dir
ect
Pur
chas
es -
FE
S &
Mon
thly
BG
SS
$629
,871
$1,2
92,6
88$2
,173
,364
$1,9
46,4
94$2
,620
,082
$1,4
08,8
33$9
46,4
18$4
41,5
53$1
,044
,111
$868
,119
$977
,365
$379
,199
$14,
728,
097
11S
pot
Pur
chas
es o
n T
rans
co P
SF
T$0
$0$2
85,8
86$2
98,3
57$2
68,8
95$0
$0$0
$0$0
$0$0
$853
,138
12P
eaki
ng S
uppl
y$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
13H
edgi
ng/(
Gai
n) L
oss
$280
,890
$171
,925
$7,9
85($
56,2
10)
($59
,500
)($
44,9
60)
$16,
525
$13,
700
($2,
925)
($20
,675
)($
30,0
75)
($31
,550
)$2
45,1
3014
Ant
ero
Com
mod
ity S
avin
gs($
93,0
00)
($54
,000
)($
55,8
00)
($55
,800
)($
50,4
00)
($55
,800
)($
90,0
00)
($93
,000
)($
90,0
00)
($93
,000
)($
93,0
00)
($90
,000
)($
913,
800)
15M
arcu
s H
ook
- W
oodb
ury
Late
ral
$7,6
14$7
,614
$7,6
14$7
,614
$7,6
14$7
,614
$7,6
14$7
,614
$7,6
14$7
,614
$7,6
14$7
,614
$91,
374
16S
tora
ge I
ncen
tive
Mec
hani
sm($
255,
000)
$0$0
$0$0
$0$0
$0$0
$0$0
$0($
255,
000)
17T
OT
AL
NA
TU
RA
L G
AS
PU
RC
HA
SE
S (
$)$5
,645
,548
$7,8
30,5
29$1
2,32
4,23
4$1
1,90
6,57
2$1
2,19
7,02
6$9
,717
,606
$9,6
35,0
02$7
,627
,002
$7,0
85,9
82$6
,883
,475
$7,0
31,7
62$6
,279
,749
$104
,164
,488
18 19P
UR
CH
AS
ED
NA
T G
AS
BR
EA
KD
OW
N (
Dt)
20 21 22S
pot
Pur
chas
es o
n C
olum
bia
- E
SE
P66
5,71
21,
350,
000
1,39
5,00
01,
395,
000
1,26
0,00
01,
395,
000
900,
000
930,
000
900,
000
930,
000
930,
000
900,
000
12,9
50,7
1223
Spo
t P
urch
ases
on
Col
umbi
a17
7,54
843
8,24
058
8,24
058
8,24
058
8,24
041
3,24
043
8,24
041
3,24
018
8,24
058
,240
58,2
4088
,240
4,03
8,18
824
Spo
t P
urch
ases
- T
rans
co90
3,34
611
0,42
241
2,98
721
,383
97,6
0151
5,77
31,
594,
105
837,
535
686,
520
750,
673
761,
260
719,
706
7,41
1,31
125
Spo
t P
urch
ases
- T
rans
co L
eidy
#10
1359
930
0,00
045
0,00
060
0,00
060
0,00
060
0,00
030
0,00
010
0,00
010
0,00
010
0,00
010
0,00
010
0,00
010
0,00
03,
450,
000
26D
irec
t P
urch
ases
- F
ES
& M
onth
ly B
GS
S24
6,62
146
6,33
870
7,47
560
7,14
181
9,03
244
7,53
332
0,60
215
0,39
335
1,90
828
9,08
432
4,49
012
6,06
34,
856,
680
27S
pot
Pur
chas
es o
n T
rans
co P
SF
T0
093
,062
93,0
6284
,056
00
00
00
027
0,18
028 29
TO
TA
L N
AT
L G
AS
PU
RC
HA
SE
D (
Dt)
2,29
3,22
7
2,81
5,00
0
3,
796,
764
3,30
4,82
6
3,
448,
929
3,
071,
546
3,
352,
947
2,
431,
168
2,
226,
668
2,
127,
997
2,
173,
990
1,
934,
010
32
,977
,072
30 31N
AT
UR
AL
GA
S C
OS
T P
ER
TH
ER
M32
Tot
al C
ost
Per
The
rm$0
.246
2$0
.278
2$0
.324
6$0
.360
3$0
.353
6$0
.316
4$0
.287
4$0
.313
7$0
.318
2$0
.323
5$0
.323
5$0
.324
7$0
.315
933 34
Tot
al C
ost
Per
The
rm E
xclu
ding
FE
S/M
onth
ly B
GS
S/I
njec
tions
$0.2
643
$0.2
784
$0.3
286
$0.3
692
$0.3
642
$0.3
166
$0.2
870
$0.3
158
$0.3
220
$0.3
250
$0.3
244
$0.3
233
$0.3
222
35 36In
ject
ed C
ost
Per
The
rm$0
.243
8$0
.271
0$0
.328
3$0
.371
3$0
.366
4$0
.318
4$0
.286
0$0
.314
4$0
.322
4$0
.328
2$0
.329
0$0
.328
1$0
.318
137
(Exc
ludi
ng F
MA
C,
Mon
thly
BG
SS
& A
ll H
edgi
ng &
SIM
S)
38 39S
UM
AR
Y O
F G
AS
CO
ST
S40
Pip
elin
e &
Sto
rage
Dem
and
$4,2
28,1
41$4
,483
,636
$4,5
22,5
35$4
,522
,535
$4,2
37,4
66$4
,434
,003
$4,1
83,7
27$4
,273
,612
$4,1
83,7
27$4
,273
,612
$4,2
73,6
12$4
,187
,775
$51,
804,
380
41S
tora
ge$3
0,78
3$2
31,1
88$2
61,7
91$3
34,1
74$2
92,2
05$2
9,17
7$7
2,97
7$6
4,87
9$6
2,30
1$6
1,73
4$6
1,44
8$5
9,35
7$1
,562
,015
42N
atur
al G
as P
urch
ases
*$5
,645
,548
$7,8
30,5
29$1
2,32
4,23
4$1
1,90
6,57
2$1
2,19
7,02
6$9
,717
,606
$9,6
35,0
02$7
,627
,002
$7,0
85,9
82$6
,883
,47
5$7
,031
,762
$6,2
79,7
49$1
04,1
64,4
8843 44
Tot
al G
as C
osts
$9,9
04,4
73$1
2,54
5,35
2$1
7,10
8,56
1$1
6,76
3,28
1$1
6,72
6,69
8$1
4,18
0,78
6$1
3,89
1,70
6$1
1,96
5,49
3$1
1,33
2,00
9$1
1,21
8,82
1$
11,3
66,8
22$1
0,52
6,88
0$1
57,5
30,8
8245 46
* E
xclu
des
Inte
rrup
tible
& O
SS
Nat
ural
Gas
Pur
chas
es
2016-2017 WORKPAPER KJB-5B PAGE 3 of 3
1W
OR
KP
AP
ER
KJB
-5C
, P
AG
E 1
OF
52
NA
TU
RA
L G
AS
IN
VE
NT
OR
Y -
IN
JEC
TIO
NS
3O
ct-1
6N
ov-
16
De
c-1
6Ja
n-1
7F
eb
-17
Ma
r-1
7A
pr-
17
Ma
y-1
7Ju
n-1
7Ju
l-17
Au
g-1
7S
ep
-17
Tot
al4
Net
Sto
rage
Inj
ectio
ns T
rans
co G
SS
198,
271
00
00
024
5,74
6
25
3,44
5
24
4,52
3
21
6,52
9
21
6,52
9
20
9,06
6
1,
584,
109
5
Pea
king
Sup
plie
s$2
.438
1$2
.710
4$3
.283
2$3
.712
9$3
.664
2$3
.183
6$2
.859
9$3
.144
4$3
.224
3$3
.282
4$3
.289
8$3
.281
16 7
GS
S I
njec
tion
Cos
t$4
83,4
05$0
$0$0
$0$0
$702
,809
$796
,932
$788
,416
$710
,735
$712
,337
$685
,966
$4,8
80,6
008 9
Net
Sto
rage
Inj
ectio
ns T
rans
co E
SS
23,3
01
00
00
031
,818
31,8
1741
,010
43
,331
43
,331
41
,010
25
5,61
5
10
Pea
king
Sup
plie
s$2
.438
1$2
.710
4$3
.283
2$3
.712
9$3
.664
2$3
.183
6$2
.859
9$3
.144
4$3
.224
3$3
.282
4$3
.289
8$3
.281
111 12
ES
S I
njec
tion
Cos
t$5
6,80
9$0
$0$0
$0$0
$90,
995
$100
,045
$132
,227
$142
,228
$142
,549
$134
,556
$799
,409
13 14N
et S
tora
ge I
njec
tions
Tra
nsco
LS
S99
,104
0
00
00
207,
191
214,
097
206,
094
207,
191
201,
381
207,
191
1,34
2,24
9
15P
eaki
ng S
uppl
ies
$2.4
381
$2.7
104
$3.2
832
$3.7
129
$3.6
642
$3.1
836
$2.8
599
$3.1
444
$3.2
243
$3.2
824
$3.2
898
$3.2
811
16 17LS
S I
njec
tion
Cos
t$2
41,6
25$0
$0$0
$0$0
$592
,546
$673
,207
$664
,509
$680
,084
$662
,503
$679
,814
$4,1
94,2
8818 19
Net
Sto
rage
Inj
ectio
ns T
rans
co S
S 2
73,3
480
00
00
344,
355
331,
019
299,
743
295,
660
275,
469
231,
047
1,85
0,64
1
20P
eaki
ng S
uppl
ies
$2.4
381
$2.7
104
$3.2
832
$3.7
129
$3.6
642
$3.1
836
$2.8
599
$3.1
444
$3.2
243
$3.2
824
$3.2
898
$3.2
811
21 22S
S 2
Sto
rage
Inj
ectio
ns C
ost
$178
,830
$0$0
$0$0
$0$9
84,8
21$1
,040
,856
$966
,461
$970
,474
$906
,238
$758
,088
$5,8
05,7
6923 24
Net
Sto
rage
Inj
ectio
ns D
omin
ion
GS
S50
,928
00
00
064
,712
74,2
9971
,902
74,2
9974
,299
71,9
0248
2,34
125
Pea
king
Sup
plie
s$2
.438
1$2
.710
4$3
.283
2$3
.712
9$3
.664
2$3
.183
6$2
.859
9$3
.144
4$3
.224
3$3
.282
4$3
.289
8$3
.281
126 27
Dom
inio
n G
SS
Sto
rage
Inj
ectio
ns C
ost
$124
,168
$0$0
$0$0
$0$1
85,0
70$2
33,6
26$2
31,8
34$2
43,8
79$2
44,4
29$2
35,9
18$1
,498
,922
28 29N
et S
tora
ge I
njec
tions
Tra
nsco
S-2
780
00
00
15,0
9715
,097
20,5
92
21,7
81
36,8
78
31,4
24
140,
947
30P
eaki
ng S
uppl
ies
$2.4
381
$2.7
104
$3.2
832
$3.7
129
$3.6
642
$3.1
836
$2.8
599
$3.1
444
$3.2
243
$3.2
824
$3.2
898
$3.2
811
31 32T
rans
co S
-2 S
tora
ge I
njec
tions
Cos
t$1
90$0
$0$0
$0$0
$43,
176
$47,
471
$66,
395
$71,
494
$121
,321
$103
,105
$453
,152
33 34N
et S
tora
ge
Inje
ctio
ns C
ol F
SS
& (
ME
P)
231,
458
00
00
047
3,89
0
37
7,48
6
35
1,26
5
35
1,26
5
35
1,26
5
36
8,05
6
2,
504,
686
35
Pea
king
Sup
plie
s$2
.438
1$2
.710
4$3
.283
2$3
.712
9$3
.664
2$3
.183
6$2
.859
9$3
.144
4$3
.224
3$3
.282
4$3
.289
8$3
.281
136 37
Col
FS
S S
tora
ge I
njec
tions
Cos
t$5
64,3
18$0
$0$0
$0$0
$1,3
55,2
77$1
,186
,968
$1,1
32,5
85$1
,152
,994
$1,1
55,5
93$1
,207
,627
$7,7
55,3
6138 39
Tot
al S
tora
ge I
njec
tions
Dt
676,
488
00
00
01,
382,
808
1,
297,
260
1,
235,
129
1,
210,
056
1,
199,
152
1,
159,
695
8,
160,
588
40 41
Tot
al S
tora
ge I
njec
tions
Cos
t$1
,649
,345
$0$0
$0$0
$0$3
,954
,693
$4,0
79,1
06$3
,982
,426
$3,9
71,8
87$3
,944
,970
$3,8
05,0
75$2
5,38
7,50
2 2016-2017 WORKPAPER KJB-5C PAGE 1 of 5
1W
OR
KP
AP
ER
KJB
-5C
, P
AG
E 2
OF
52
NA
TU
RA
L G
AS
IN
VE
NT
OR
Y3
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
4G
SS
Ope
ning
Bal
ance
1,15
3,84
2
1,34
6,48
2
1,
264,
540
1,10
0,65
6
50
8,55
0
20
0,00
0
10
0,00
0
23
8,76
7
48
5,01
4
72
2,59
3
93
2,97
3
1,
143,
353
5
Sto
rage
Inj
ectio
ns T
rans
co G
SS
192,
640
00
00
023
8,76
724
6,24
723
7,57
921
0,38
021
0,38
020
3,12
91,
539,
122
6 7G
SS
Inv
ento
ry S
ub T
otal
Dt
1,34
6,48
21,
346,
482
1,26
4,54
01,
100,
656
508,
550
200,
000
338,
767
485,
014
722,
593
932,
973
1,14
3,35
31,
346,
482
8N
et S
tora
ge W
ithdr
awal
s T
rans
co G
SS
081
,942
163,
884
592,
106
308,
550
100,
000
100,
000
00
00
01,
346,
482
9 10G
SS
Inv
ento
ry B
alan
ce1,
346,
482
1,
264,
540
1,10
0,65
6
50
8,55
0
20
0,00
0
10
0,00
0
23
8,76
7
48
5,01
4
72
2,59
3
93
2,97
3
1,
143,
353
1,
346,
482
11 12
GS
S I
nven
tory
Cos
t O
peni
ng B
alan
ce$2
,540
,748
$3,0
24,1
53$2
,840
,114
$2,4
72,0
36$1
,142
,186
$449
,193
$224
,597
$653
,646
$1,4
50,5
79$2
,238
,994
$2,9
49,7
29$3
,662
,066
13 14G
SS
Inj
ectio
n C
ost
$483
,405
$0$0
$0$0
$0$7
02,8
09$7
96,9
32$7
88,4
16$7
10,7
35$7
12,3
37$6
85,9
66$4
,880
,600
15 16G
SS
Inv
ento
ry C
ost
Sub
Tot
al$3
,024
,153
$3,0
24,1
53$2
,840
,114
$2,4
72,0
36$1
,142
,186
$449
,193
$927
,406
$1,4
50,5
79$2
,238
,994
$2,9
49,7
29$
3,66
2,06
6$4
,348
,033
17T
otal
GS
S S
tora
ge W
ithdr
awal
Cos
t$0
$184
,039
$368
,078
$1,3
29,8
50$6
92,9
93$2
24,5
97$2
73,7
59$0
$0$0
$0$0
$3,0
73,3
1618 19
Tot
al G
SS
Inv
ento
ry C
ost
Bal
ance
$3,0
24,1
53$2
,840
,114
$2,4
72,0
36$1
,142
,186
$449
,193
$224
,597
$653
,646
$1,4
50,5
79$2
,238
,994
$2,9
49,7
29
$3,6
62,0
66$4
,348
,033
20 21G
SS
Inv
ento
ry C
ost
Rat
e$2
.246
0$2
.246
0$2
.246
0$2
.246
0$2
.246
0$2
.246
0$2
.737
6$2
.990
8$3
.098
6$3
.161
6$3
.202
9$3
.229
222 23
ES
S O
peni
ng B
alan
ce20
9,01
423
2,31
423
2,31
423
2,31
485
,951
-1-1
31,8
1763
,634
104,
644
147,
974
191,
305
24S
tora
ge I
njec
tions
Tra
nsco
ES
S23
,301
00
00
031
,818
31,8
1741
,010
43,3
3143
,331
41,0
1025
5,61
525 26
ES
S I
nven
tory
Sub
Tot
al D
t23
2,31
423
2,31
423
2,31
423
2,31
485
,951
-131
,817
63,6
3410
4,64
414
7,97
419
1,30
523
2,31
427
Net
Sto
rage
With
draw
als
Tra
nsco
ES
S0
00
146,
363
85,9
520
00
00
00
232,
315
28 29E
SS
Inv
ento
ry B
alan
ce23
2,31
423
2,31
423
2,31
485
,951
-1-1
31,8
1763
,634
104,
644
147,
974
191,
305
232,
314
30 31E
SS
Inv
ento
ry C
ost
Ope
ning
Bal
ance
$532
,517
$589
,326
$589
,326
$589
,326
$218
,037
-$1
-$1
$90,
994
$191
,039
$323
,266
$465
,494
$608
,043
32 33E
SS
Inj
ectio
n C
ost
$56,
809
$0$0
$0$0
$0$9
0,99
5$1
00,0
45$1
32,2
27$1
42,2
28$1
42,5
49$1
34,5
56$7
99,4
0934 35
ES
S I
nven
tory
Cos
t S
ub T
otal
$589
,326
$589
,326
$589
,326
$589
,326
$218
,037
-$1
$90,
994
$191
,039
$323
,266
$465
,494
$608
,043
$742
,599
36T
otal
ES
S S
tora
ge W
ithdr
awal
Cos
t$0
$0$0
$371
,288
$218
,039
$0$0
$0$0
$0$0
$0$5
89,3
2737 38
Tot
al E
SS
Inv
ento
ry C
ost
Bal
$589
,326
$589
,326
$589
,326
$218
,037
-$1
-$1
$90,
994
$191
,039
$323
,266
$465
,494
$608
,043
$742
,599
39 40E
SS
Inv
ento
ry C
ost
Rat
e$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.859
9$3
.002
2$3
.089
2$3
.145
8$3
.178
4$3
.196
5
2016-2017 WORKPAPER KJB-5C PAGE 2 of 5
1W
OR
KP
AP
ER
KJB
-5C
, P
AG
E 3
OF
52
NA
TU
RA
L G
AS
IN
VE
NT
OR
Y3
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
4LS
S O
peni
ng B
alan
ce1,
126,
422
1,22
4,00
01,
104,
000
792,
000
432,
000
204,
000
020
4,00
041
4,80
061
7,72
082
1,72
01,
020,
000
5S
tora
ge I
njec
tions
Tra
nsco
LS
S97
,578
00
00
020
4,00
021
0,80
020
2,92
020
4,00
019
8,28
020
4,00
01,
321,
578
6 7LS
S I
nven
tory
Sub
Tot
al D
t1,
224,
000
1,22
4,00
01,
104,
000
792,
000
432,
000
204,
000
204,
000
414,
800
617,
720
821,
720
1,02
0,00
01,
224,
000
8N
et S
tora
ge W
ithdr
awal
s T
rans
co L
SS
012
0,00
031
2,00
036
0,00
022
8,00
020
4,00
00
00
00
01,
224,
000
9 10LS
S I
nven
tory
Bal
ance
1,22
4,00
01,
104,
000
792,
000
432,
000
204,
000
020
4,00
041
4,80
061
7,72
082
1,72
01,
020,
000
1,22
4,00
011 12
LSS
Inv
ento
ry C
ost
Ope
n B
alan
ce$2
,384
,560
$2,6
26,1
86$2
,368
,717
$1,6
99,2
97$9
26,8
89$4
37,6
98$0
$592
,546
$1,2
65,7
52$1
,930
,261
$2,6
10,3
45$3
,272
,848
13 14LS
S I
njec
tion
Cos
t$2
41,6
25$0
$0$0
$0$0
$592
,546
$673
,207
$664
,509
$680
,084
$662
,503
$679
,814
$4,1
94,2
8815 16
LSS
Inv
ento
ry C
ost
Sub
Tot
al$2
,626
,186
$2,6
26,1
86$2
,368
,717
$1,6
99,2
97$9
26,8
89$4
37,6
98$5
92,5
46$1
,265
,752
$1,9
30,2
61$2
,610
,345
$3,2
72,8
48$3
,952
,662
17T
otal
LS
S S
tora
ge W
ithdr
awal
Cos
t$0
$257
,469
$669
,420
$772
,408
$489
,191
$437
,698
$0$0
$0$0
$0$0
$2,6
26,1
8618 19
Tot
al L
SS
Inv
ento
ry C
ost
Bal
$2,6
26,1
86$2
,368
,717
$1,6
99,2
97$9
26,8
89$4
37,6
98$0
$592
,546
$1,2
65,7
52$1
,930
,261
$2,6
10,3
45$3
,272
,848
$3,
952,
662
20 21LS
S I
nven
tory
Cos
t R
ate
$2.1
456
$2.1
456
$2.1
456
$2.1
456
$2.1
456
$0.0
000
$2.9
046
$3.0
515
$3.1
248
$3.1
767
$3.2
087
$3.2
293
22 23S
S 2
Ope
ning
Bal
ance
1,69
1,84
81,
764,
675
1,67
7,86
41,
254,
243
756,
910
307,
706
034
1,91
067
0,57
996
8,19
41,
261,
755
1,53
5,26
824
Sto
rage
Inj
ectio
ns T
rans
co S
S 2
72,8
270
00
00
341,
910
328,
669
297,
615
293,
561
273,
513
229,
407
1,83
7,50
225 26
SS
2 I
nven
tory
Sub
Tot
al D
t1,
764,
675
1,76
4,67
51,
677,
864
1,25
4,24
375
6,91
030
7,70
634
1,91
067
0,57
996
8,19
41,
261,
755
1,53
5,26
81,
764,
675
27N
et S
tora
ge W
ithdr
awal
s T
rans
co S
S 2
086
,812
423,
621
497,
333
449,
204
307,
706
00
00
00
1,76
4,67
528 29
SS
2 I
nven
tory
Bal
ance
1,76
4,67
51,
677,
864
1,25
4,24
375
6,91
030
7,70
60
341,
910
670,
579
968,
194
1,26
1,75
51,
535,
268
1,76
4,67
530 31
SS
2 I
nven
tory
Cos
t O
pen
Bal
ance
$3,5
68,6
50$3
,747
,480
$3,5
63,1
26$2
,663
,521
$1,6
07,3
80$6
53,4
46$0
$984
,821
$2,0
25,6
77$2
,992
,138
$3,9
62,
613
$4,8
68,8
5132 33
SS
2 S
tora
ge I
njec
tions
Cos
t$1
78,8
30$0
$0$0
$0$0
$984
,821
$1,0
40,8
56$9
66,4
61$9
70,4
74$9
06,2
38$7
58,0
88$5
,805
,769
34 35S
S 2
Inv
ento
ry C
ost
Sub
Tot
al$3
,747
,480
$3,7
47,4
80$3
,563
,126
$2,6
63,5
21$1
,607
,380
$653
,446
$984
,821
$2,0
25,6
77$2
,992
,138
$3,9
62,6
13$4
,868
,851
$5,6
26,9
3936
Tot
al S
S 2
Sto
rage
With
draw
al C
ost
$0$1
84,3
54$8
99,6
05$1
,056
,141
$953
,934
$653
,446
$0$0
$0$0
$0$0
$3,7
47,4
8037 38
Tot
al S
S 2
Inv
ento
ry C
ost
Bal
$3,7
47,4
80$3
,563
,126
$2,6
63,5
21$1
,607
,380
$653
,446
$0$9
84,8
21$2
,025
,677
$2,9
92,1
38$3
,962
,613
$4,8
68,8
51$5
,626
,939
39 40S
S 2
Inv
ento
ry C
ost
Rat
e$2
.123
6$2
.123
6$2
.123
6$2
.123
6$2
.123
6$0
.000
0$2
.880
4$3
.020
8$3
.090
4$3
.140
6$3
.171
3$3
.188
741 42
Dom
inio
n G
SS
Ope
ning
Bal
ance
373,
065
423,
000
423,
000
323,
000
183,
000
42,2
000
63,4
5013
6,30
020
6,80
027
9,65
035
2,50
043
Inje
ctio
ns D
omin
ion
GS
S
Sto
rage
49,9
350
00
00
63,4
5072
,850
70,5
0072
,850
72,8
5070
,500
472,
935
44 45D
omin
ion
GS
S
Inv
ento
ry S
ub T
otal
Dt
423,
000
423,
000
423,
000
323,
000
183,
000
42,2
0063
,450
136,
300
206,
800
279,
650
352,
500
423,
000
46N
et S
tora
ge W
ithdr
awal
s D
omin
ion
GS
S
00
100,
000
140,
000
140,
800
42,2
000
00
00
042
3,00
047 48
Dom
inio
n G
SS
I
nven
tory
Bal
ance
423,
000
423,
000
323,
000
183,
000
42,2
000
63,4
5013
6,30
020
6,80
027
9,65
035
2,50
042
3,00
049 50
Dom
inio
n G
SS
I
nven
tory
Cos
t O
pen
Bal
ance
$786
,544
$910
,712
$910
,712
$695
,413
$393
,996
$90,
856
$0$1
85,0
70$4
18,6
96$6
50,5
29$8
94,4
08$1
,138
,837
51 52D
omin
ion
GS
S
S
tora
ge I
njec
tions
Cos
t$1
24,1
68$0
$0$0
$0$0
$185
,070
$233
,626
$231
,834
$243
,879
$244
,429
$235
,918
$1,4
98,9
2253 54
Dom
inio
n G
SS
In
vent
ory
Cos
t S
ub T
otal
$910
,712
$910
,712
$910
,712
$695
,413
$393
,996
$90,
856
$185
,070
$418
,696
$650
,529
$894
,408
$1,1
38,8
37$1
,374
,755
55T
otal
Equ
it S
tora
ge W
ithdr
awal
Cos
t$0
$0$2
15,2
98$3
01,4
18$3
03,1
40$9
0,85
6$0
$0$0
$0$0
$0$9
10,7
1256 57
Tot
al D
omin
ion
GS
S
Inv
ento
ry C
ost
Bal
ance
$910
,712
$910
,712
$695
,413
$393
,996
$90,
856
$0$1
85,0
70$4
18,6
96$6
50,5
29$8
94,4
08$1
,138
,83
7$1
,374
,755
58 59D
omin
ion
GS
S
Inv
ento
ry C
ost
Rat
e$2
.153
0$2
.153
0$2
.153
0$2
.153
0$2
.153
0$0
.000
0$2
.916
8$3
.071
9$3
.145
7$3
.198
3$3
.230
7$3
.250
0
2016-2017 WORKPAPER KJB-5C PAGE 3 of 5
1W
OR
KP
AP
ER
KJB
-5C
, P
AG
E 4
OF
52
NA
TU
RA
L G
AS
IN
VE
NT
OR
Y3
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
4T
rans
co S
-2 O
peni
ng B
alan
ce13
9,89
013
9,96
713
9,96
791
,700
43,4
330
015
,000
30,0
0050
,460
72,1
0210
8,74
45
Sto
rage
Inj
ectio
ns T
rans
co S
-277
00
00
015
,000
15,0
0020
,460
21,6
4236
,642
31,2
2314
0,04
46 7
Tra
nsco
S-2
Inv
ento
ry S
ub T
otal
Dt
139,
967
139,
967
139,
967
91,7
0043
,433
015
,000
30,0
0050
,460
72,1
0210
8,74
413
9,96
78
Net
Sto
rage
With
draw
als
Tra
nsco
S-2
00
48,2
6748
,267
43,4
330
00
00
00
139,
967
9 10T
rans
co S
-2 I
nven
tory
Bal
ance
139,
967
139,
967
91,7
0043
,433
00
15,0
0030
,000
50,4
6072
,102
108,
744
139,
967
11 12T
rans
co S
-2 I
nven
tory
Cos
t O
pen
Bal
ance
$310
,553
$310
,743
$310
,743
$203
,585
$96,
426
$0$0
$43,
176
$90,
647
$157
,042
$228
,536
$349
,857
13 14T
rans
co S
-2 S
tora
ge I
njec
tions
Cos
t$1
90$0
$0$0
$0$0
$43,
176
$47,
471
$66,
395
$71,
494
$121
,321
$103
,105
$453
,152
15 16T
rans
co S
-2 I
nven
tory
Cos
t S
ub T
otal
$310
,743
$310
,743
$310
,743
$203
,585
$96,
426
$0$4
3,17
6$9
0,64
7$1
57,0
42$2
28,5
36$3
49,8
57$4
52,9
6217
Tot
al T
rans
co S
-2 S
tora
ge W
ithdr
awal
Cos
t$0
$0$1
07,1
58$1
07,1
58$9
6,42
6$0
$0$0
$0$0
$0$0
$310
,743
18 19T
otal
Tra
ns S
-2 I
nven
tory
Cos
t B
al$3
10,7
43$3
10,7
43$2
03,5
85$9
6,42
6$0
$0$4
3,17
6$9
0,64
7$1
57,0
42$2
28,5
36$3
49,8
57$4
52,9
6220 21
Tra
nsco
S-2
Inv
ento
ry C
ost
Rat
e$2
.220
1$2
.220
1$2
.220
1$2
.220
1$0
.000
0$0
.000
0$2
.878
4$3
.021
6$3
.112
2$3
.169
6$3
.217
3$3
.236
222 23
Col
FS
S O
peni
ng B
alan
ce1,
996,
805
2,22
3,53
71,
978,
745
1,46
3,05
890
5,47
532
3,16
110
0,00
046
3,53
183
2,76
51,
176,
353
1,51
9,94
01,
863,
527
24S
tora
ge I
njec
tions
Col
umbi
a F
SS
& (
ME
P)
226,
732
00
00
046
3,53
136
9,23
434
3,58
734
3,58
734
3,58
736
0,01
02,
450,
269
25 26C
ol F
SS
Inv
ento
ry S
ub T
otal
Dt
2,22
3,53
72,
223,
537
1,97
8,74
51,
463,
058
905,
475
323,
161
563,
531
832,
765
1,17
6,35
31,
519,
940
1,86
3,52
72,
223,
537
27N
et S
tora
ge W
ithdr
awal
Col
FS
S &
(M
EP
)0
244,
792
515,
687
557,
583
582,
314
223,
161
100,
000
00
00
02,
223,
537
28 29C
ol F
SS
& (
ME
P)
Inve
ntor
y B
alan
ce2,
223,
537
1,97
8,74
51,
463,
058
905,
475
323,
161
100,
000
463,
531
832,
765
1,17
6,35
31,
519,
940
1,86
3,52
72,
223
,537
30 31C
ol F
SS
& (
ME
P)
Inve
ntor
y C
ost
Ope
n B
alan
ce$4
,235
,309
$4,7
99,6
27$4
,271
,230
$3,1
58,0
91$1
,954
,518
$697
,561
$215
,856
$1,2
92,3
31$2
,479
,300
$3,6
11,8
85$4
,764
,878
$5,9
20,4
7132 33
Col
FS
S S
tora
ge I
njec
tions
Cos
t$5
64,3
18$0
$0$0
$0$0
$1,3
55,2
77$1
,186
,968
$1,1
32,5
85$1
,152
,994
$1,1
55,5
93$1
,207
,627
$7,7
55,3
6134 35
Col
FS
S I
nven
tory
Cos
t S
ub T
otal
$4,7
99,6
27$4
,799
,627
$4,2
71,2
30$3
,158
,091
$1,9
54,5
18$6
97,5
61$1
,571
,133
$2,4
79,3
00$3
,611
,885
$4,7
64,
878
$5,9
20,4
71$7
,128
,098
36T
otal
Col
FS
S S
tora
ge W
ithdr
awal
Cos
t$0
$528
,396
$1,1
13,1
39$1
,203
,574
$1,2
56,9
57$4
81,7
05$2
78,8
02$0
$0$0
$0$0
$4,8
62,5
7237 38
Tot
al C
ol F
SS
& (
ME
P)
Inve
ntor
y C
ost
Bal
$4,7
99,6
27$4
,271
,230
$3,1
58,0
91$1
,954
,518
$697
,561
$215
,856
$1,2
92,3
31$2
,479
,300
$3,6
11,8
85
$4,7
64,8
78$5
,920
,471
$7,1
28,0
9839 40
Col
FS
S &
(M
EP
) In
vent
ory
Cos
t R
ate
$2.1
586
$2.1
586
$2.1
586
$2.1
586
$2.1
586
$2.1
586
$2.7
880
$2.9
772
$3.0
704
$3.1
349
$3.1
770
$3.2
057
41 42T
otal
Beg
inni
ng I
nven
tory
Dt
6,69
0,88
5
7,35
3,97
5
6,
820,
430
5,25
6,97
1
2,
915,
319
1,
077,
066
20
0,00
0
1,
358,
475
2,
633,
092
3,
846,
763
5,
036,
114
6,
214,
697
43 44
Tot
al E
ndin
g In
vent
ory
Dt
7,35
3,97
5
6,82
0,43
0
5,
256,
971
2,91
5,31
9
1,
077,
066
20
0,00
0
1,
358,
475
2,
633,
092
3,
846,
763
5,
036,
114
6,
214,
697
7,
353,
975
45 46
Tot
al B
egin
ning
Inv
ento
ry C
ost
$14,
358,
882
$16,
008,
226
$14,
853,
968
$11,
481,
269
$6,3
39,4
32$2
,328
,753
$440
,451
$3,8
42,5
84$7
,921
,689
$11
,904
,115
$15,
876,
003
$19,
820,
973
47 48T
otal
End
ing
Inve
ntor
y C
ost
$16,
008,
226
$14,
853,
968
$11,
481,
269
$6,3
39,4
32$2
,328
,753
$440
,451
$3,8
42,5
84$7
,921
,689
$11,
904,
115
$15,
876,
003
$19,
820,
973
$23,
626,
048
2016-2017 WORKPAPER KJB-5C PAGE 4 of 5
1W
OR
KP
AP
ER
KJB
-5C
, P
AG
E 5
OF
52
NA
TU
RA
L G
AS
IN
VE
NT
OR
Y -
WIT
HD
RA
WA
LS
3O
ct-1
6N
ov-
16
De
c-1
6Ja
n-1
7F
eb
-17
Ma
r-1
7A
pr-
17
Ma
y-1
7Ju
n-1
7Ju
l-17
Au
g-1
7S
ep
-17
Tot
al4
Net
Sto
rage
With
draw
als
Tra
nsco
GS
S0
81,9
4216
3,88
459
2,10
630
8,55
010
0,00
010
0,00
00
00
00
1,34
6,48
25 6
GS
S I
nven
tory
Cos
t R
ate
$2.2
460
$2.2
460
$2.2
460
$2.2
460
$2.2
460
$2.2
460
$2.7
376
$2.9
908
$3.0
986
$3.1
616
$3.2
029
$3.2
292
7 8T
otal
GS
S S
tora
ge W
ithdr
awal
Cos
t$0
$184
,039
$368
,078
$1,3
29,8
50$6
92,9
93$2
24,5
97$2
73,7
59$0
$0$0
$0$0
$3,0
73,3
169 10
Net
Sto
rage
With
draw
als
Tra
nsco
ES
S0
00
146,
363
85,9
520
00
00
00
232,
315
11 12E
SS
Inv
ento
ry C
ost
Rat
e$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.536
8$2
.859
9$3
.002
2$3
.089
2$3
.145
8$3
.178
4$3
.196
513 14
Tot
al E
SS
Sto
rage
With
draw
al C
ost
$0$0
$0$3
71,2
88$2
18,0
39$0
$0$0
$0$0
$0$0
$589
,327
15 16N
et S
tora
ge W
ithdr
awal
s T
rans
co L
SS
012
0,00
031
2,00
036
0,00
022
8,00
020
4,00
00
00
00
01,
224,
000
17 18LS
S I
nven
tory
Cos
t R
ate
$2.1
169
$2.1
456
$2.1
456
$2.1
456
$2.1
456
$2.1
456
$0.0
000
$2.9
046
$3.0
515
$3.1
248
$3.1
767
$3.2
087
19 20T
otal
LS
S S
tora
ge W
ithdr
awal
Cos
t$0
$257
,469
$669
,420
$772
,408
$489
,191
$437
,698
$0$0
$0$0
$0$0
$2,6
26,1
8621 22
Net
Sto
rage
With
draw
al T
rans
co S
S 2
086
,812
423,
621
497,
333
449,
204
307,
706
00
00
00
1,76
4,67
523 24
SS
2 I
nven
tory
Cos
t R
ate
$2.1
093
$2.1
236
$2.1
236
$2.1
236
$2.1
236
$2.1
236
$0.0
000
$2.8
804
$3.0
208
$3.0
904
$3.1
406
$3.1
713
25 26T
otal
SS
2 S
tora
ge W
ithdr
awal
Cos
t$0
$184
,354
$899
,605
$1,0
56,1
41$9
53,9
34$6
53,4
46$0
$0$0
$0$0
$0$3
,747
,480
27 28N
et S
tora
ge D
omin
ion
GS
S
00
100,
000
140,
000
140,
800
42,2
000
00
00
042
3,00
029 30
Dom
inio
n G
SS
I
nven
tory
Cos
t R
ate
$2.1
083
$2.1
530
$2.1
530
$2.1
530
$2.1
530
$2.1
530
$0.0
000
$2.9
168
$3.0
719
$3.1
457
$3.1
983
$3.2
307
31 32T
otal
Dom
inio
n G
SS
Sto
rage
With
draw
al C
ost
$0$0
$215
,298
$301
,418
$303
,140
$90,
856
$0$0
$0$0
$0$0
$910
,712
33 34N
et S
tora
ge W
ithdr
awal
s T
rans
co S
-20
048
,267
48,2
6743
,433
00
00
00
013
9,96
735 36
Tra
nsco
S-2
Inv
ento
ry C
ost
Rat
e$2
.220
0$2
.220
1$2
.220
1$2
.220
1$2
.220
1$0
.000
0$0
.000
0$2
.878
4$3
.021
6$3
.112
2$3
.169
6$3
.217
337 38
Tot
al T
rans
co S
-2 S
tora
ge W
ithdr
awal
Cos
t$0
$0$1
07,1
58$1
07,1
58$9
6,42
6$0
$0$0
$0$0
$0$0
$310
,743
39 40N
et S
tora
ge W
ithdr
awal
Col
FS
S &
(M
EP
)0
244,
792
515,
687
557,
583
582,
314
223,
161
100,
000
00
00
02,
223,
537
41 42C
ol F
SS
& (
ME
P)
Inve
ntor
y C
ost
Rat
e$2
.158
6$2
.158
6$2
.158
6$2
.158
6$2
.158
6$2
.158
6$2
.788
0$2
.977
2$3
.070
4$3
.134
9$3
.177
0$3
.205
743 44
Tot
al C
ol F
SS
Sto
rage
With
draw
al C
ost
$0$5
28,3
96$1
,113
,139
$1,2
03,5
74$1
,256
,957
$481
,705
$278
,802
$0$0
$0$0
$0$4
,862
,572
45 46T
otal
Sto
rage
With
draw
als
Dt
053
3,54
51,
563,
459
2,34
1,65
21,
838,
253
877,
066
200,
000
00
00
07,
353,
975
47 48T
otal
Sto
rage
With
draw
als
Cos
t$0
$1,1
54,2
58$3
,372
,699
$5,1
41,8
37$4
,010
,680
$1,8
88,3
01$5
52,5
61$0
$0$0
$0$0
$16,
120,
335 2016-2017 WORKPAPER
KJB-5C PAGE 5 of 5
1W
OR
KP
AP
ER
KJB
-5D
2L
NG
INV
EN
TO
RY
3O
ct-1
6N
ov-
16
De
c-1
6Ja
n-1
7F
eb
-17
Ma
r-1
7A
pr-
17
Ma
y-1
7Ju
n-1
7Ju
l-17
Au
g-1
7S
ep
-17
Tot
al4
Net
Sto
rag
e In
ject
ions
Com
pan
y LN
G-
10
7,03
7
10
2,81
8
10
7,81
8
10
2,81
7
-
00
00
00
420,
490
5LN
G R
ate
$0.0
000
$3.1
170
$3.7
757
$4.2
699
$4.2
138
$3.6
611
$3.2
888
$3.6
161
$3.7
079
$3.7
747
$3.7
833
$3.7
733
6 7T
otal
LN
G S
tora
ge
Inje
ctio
n C
ost
$0$3
33,6
35$3
88,2
13$4
60,3
68$4
33,2
52$0
$0$0
$0$0
$0$0
$1,6
15,4
678 9 10
LNG
Op
enin
g B
alan
ce In
vent
ory
250,
886
250,
886
342,
923
404,
160
398,
049
400,
536
321,
436
311,
936
302,
436
292,
936
283,
436
273,
936
11N
et S
tora
ge
Inje
ctio
ns C
omp
any
LNG
010
7,03
710
2,81
810
7,81
810
2,81
70
00
00
00
420,
490
12 13LN
G In
vent
ory
Sub
Tot
al25
0,88
635
7,92
344
5,74
151
1,97
850
0,86
640
0,53
632
1,43
631
1,93
630
2,43
629
2,93
628
3,43
627
3,93
614
Net
Sto
rag
e W
ithdr
awal
s C
omp
any
LNG
015
,000
41,5
8111
3,92
910
0,33
079
,100
9,50
09,
500
9,50
09,
500
9,50
09,
500
406,
940
15 16LN
G In
vent
ory
Bal
ance
250,
886
342,
923
404,
160
398,
049
400,
536
321,
436
311,
936
302,
436
292,
936
283,
436
273,
936
264,
436
17 18LN
G In
vent
ory
Cos
t Op
en B
alan
ce$2
,623
,842
$2,6
23,8
42$2
,833
,533
$2,9
21,2
05$2
,629
,081
$2,4
48,9
08$1
,965
,284
$1,9
07,2
01$1
,849
,117
$1,7
91,0
33$1
,732
,949
$1,6
74,8
6619 20
LNG
Inje
ctio
n C
ost
$0$3
33,6
35$3
88,2
13$4
60,3
68$4
33,2
52$0
$0$0
$0$0
$0$0
$1,6
15,4
6721 22
Tot
al L
NG
Inve
ntor
y C
ost S
ub T
otal
$2,6
23,8
42$2
,957
,477
$3,2
21,7
46$3
,381
,573
$3,0
62,3
33$2
,448
,908
$1,9
65,2
84$1
,907
,201
$1,8
49,1
17$1
,791
,033
$1,7
32,9
49$1
,674
,866
23T
otal
LN
G S
tora
ge
With
draw
al C
ost
$0$1
23,9
43$3
00,5
41$7
52,4
92$6
13,4
25$4
83,6
23$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$2
,622
,527
24 25T
otal
LN
G In
vent
ory
Cos
t Bal
ance
$2,6
23,8
42$2
,833
,533
$2,9
21,2
05$2
,629
,081
$2,4
48,9
08$1
,965
,284
$1,9
07,2
01$1
,849
,117
$1,7
91,0
33$1
,732
,949
$1,6
74,8
66$1
,616
,782
26 27E
ndin
g L
NG
Inve
ntor
y C
ost R
ate
$10.
4583
$8.2
629
$7.2
278
$6.6
049
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
28 29N
et S
tora
ge
With
draw
als
Com
pan
y LN
G0
15,0
0041
,581
113,
929
100,
330
79,1
009,
500
9,50
09,
500
9,50
09,
500
9,50
040
6,94
0
30 31
LNG
Inve
ntor
y C
ost R
ate
$10.
4583
$8.2
629
$7.2
278
$6.6
049
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
$6.1
141
32 33T
otal
LN
G S
tora
ge
With
draw
al C
ost
$0$1
23,9
43$3
00,5
41$7
52,4
92$6
13,4
25$4
83,6
23$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$5
8,08
4$2
,622
,527
2016-2017 WORKPAPER KJB-5D
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
220
16 -
201
7 B
GS
SC
3In
terr
up
tib
le In
com
e S
tate
men
t4 5
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
6V
olum
es7
IGS
00
00
592
961
250
250
00
00
2,05
38
ITS
66,2
5170
,798
76,7
3354
,891
50,4
4679
,167
83,1
3673
,872
70,0
0451
,695
40,3
5553
,995
771,
345
9 10T
otal
Vol
umes
66,2
5170
,798
76,7
3354
,891
51,0
3880
,128
83,3
8674
,122
70,0
0451
,695
40,3
5553
,995
773,
397
11 12R
even
ues
13IG
S$0
$0$0
$0$7
,991
$12,
915
$3,3
07$3
,303
$0$0
$0$0
$27,
516
14IT
S$2
0,14
0$2
1,52
3$2
3,32
7$1
6,68
7$1
5,33
5$2
4,06
7$2
5,27
3$2
2,45
7$2
1,28
1$1
5,71
5$1
2,26
8$1
6,41
5$2
34,4
8915 16
Tot
al R
even
ue$2
0,14
0$2
1,52
3$2
3,32
7$1
6,68
7$2
3,32
6$3
6,98
2$2
8,58
1$2
5,76
0$2
1,28
1$1
5,71
5$1
2,26
8$1
6,41
5$2
62,0
0517 18
Cos
t Of
Gas
Inte
rr S
ales
19IG
S$0
$0$0
$0$1
,857
$2,9
64$7
22$7
18$0
$0$0
$0$6
,260
20IT
S$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
21 22T
otal
Cos
t Of
Gas
Inte
rr S
ales
$0$0
$0$0
$1,8
57$2
,964
$722
$718
$0$0
$0$0
$6,2
6023 24
NJ
Sal
es T
ax, T
EF
A &
PU
A25
IGS
$0$0
$0$0
$539
$871
$223
$223
$0$0
$0$0
$1,8
5726
ITS
$287
$306
$332
$238
$218
$343
$360
$320
$303
$224
$175
$234
$3,3
3827 28
Tot
al R
even
ue T
axes
$287
$306
$332
$238
$757
$1,2
14$5
83$5
43$3
03$2
24$1
75$2
34$5
,195
29 30P
re-T
ax M
arg
in$1
9,85
4$2
1,21
6$2
2,99
5$1
6,44
9$2
0,71
2$3
2,80
4$2
7,27
6$2
4,50
0$2
0,97
8$1
5,49
2$1
2,09
3$1
6,18
1$2
50,5
50 2016-2017 WORKPAPER KJB-6A PAGE 1 of 3
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
220
16 -
201
7 B
GS
SC
3O
ff-S
yste
m S
ales
& C
apac
ity
Rel
ease
Inco
me
Sta
tem
ent
4 5 6 7O
ct-1
6N
ov-
16
De
c-1
6Ja
n-1
7F
eb
-17
Ma
r-1
7A
pr-
17
Ma
y-1
7Ju
n-1
7Ju
l-17
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$3.6
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676 2016-2017 WORKPAPER
KJB-6A PAGE 2 of 3
1 2IN
TE
RR
UP
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Oct
-16
No
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16
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40 2016-2017 WORKPAPER
KJB-6A PAGE 3 of 3
1W
OR
KP
AP
ER
KJ
B-7
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10
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33
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25
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34
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0 2016-2017 WORKPAPER KJB-7A
1W
OR
KP
AP
ER
KJB
-9A
, Pag
e 1
of
22
PR
OO
F O
F R
EC
OV
ER
Y3 4
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
5R
SG
The
rm S
ales
7,97
6,14
6
16
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,686
31,2
02,3
17
46
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45,2
76,4
24
40,7
56,3
23
26,6
55,5
21
13,0
25,1
95
8,29
2,34
3
5,42
7,96
5
4,92
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5,55
5,17
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209
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SG
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19
,220
,064
7
Ap
plic
able
The
rm S
ales
8,23
1,39
1
17
,470
,779
33,2
40,5
68
50
,262
,569
48,1
66,0
56
44,1
60,7
43
28,3
38,0
97
13,8
75,0
44
8,84
0,50
6
5,90
8,84
9
6,03
9,71
6
6,45
8,95
4
270,
993,
272
8 9 10B
alan
cin
g C
har
ges
:11
Ap
plic
. Sal
es V
olum
e R
SG
-FT
& R
SG
-Sal
es8,
734,
733
17,8
83,1
82
34
,069
,261
50,4
98,5
35
49
,321
,432
44
,348
,732
29
,020
,143
14
,178
,532
8,
921,
574
5,
944,
024
5,
348,
275
6,
057,
832
27
4,32
6,25
6
12
BS
C "
J" C
harg
e $0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
013
Tot
al B
SC
Cha
rges
for
RS
G-F
T &
RS
G-S
ales
$411
,406
$842
,298
$1,6
04,6
62$2
,378
,481
$2,3
23,0
39$2
,088
,825
$1,3
66,8
49$6
67,8
09$4
20,2
06$2
79,
964
$251
,904
$285
,324
$12,
920,
767
14 15 16A
pp
lic. S
ales
Vol
ume
GS
G-F
T &
GS
G-S
ales
3,46
9,63
0
6,
277,
490
11
,193
,481
18,0
97,0
35
17
,583
,320
17
,111
,785
9,
802,
748
5,
847,
890
3,
832,
308
3,
378,
517
4,
417,
148
5,
017,
499
10
6,02
8,85
1
17
BS
C "
J" C
harg
e $0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
018
Tot
al B
SC
Cha
rge
for
GS
G-F
T &
GS
G-S
ales
$163
,420
$295
,670
$527
,213
$852
,370
$828
,174
$805
,965
$461
,709
$275
,436
$180
,502
$159
,128
$208
,048
$236
,324
$4,9
93,9
5919 20
Ap
plic
. Sal
es V
olum
e G
SG
-LV
-FT
1,80
5,91
3
3,
221,
501
4,
031,
379
4,
701,
363
2,
897,
243
2,
433,
072
1,
237,
167
1,
216,
009
1,
395,
616
1,
606,
970
1,
486,
945
1,
353,
797
27
,386
,974
21
BS
C "
J" C
harg
e $0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
0$0
.047
100
$0.0
4710
022
Tot
al B
SC
Cha
rge
for
GS
G-L
V-F
T$8
5,05
8$1
51,7
33$1
89,8
78$2
21,4
34$1
36,4
60$1
14,5
98$5
8,27
1$5
7,27
4$6
5,73
4$7
5,68
8$7
0,03
5$6
3,76
4$1
,289
,926
23 240
00
00
00
00
00
00
25B
SC
"I"
Cha
rge
$0.0
1180
0$0
.011
800
$0.0
1180
0$0
.011
800
$0.0
1180
0$0
.011
800
$0.0
1180
0$0
.011
800
$0.0
1180
0$0
.011
800
$0.0
1180
0$0
.011
800
26T
otal
OP
T-I
N B
SC
Cha
rge
- R
ider
"I"
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
$027 28
13,1
77,9
36
15,8
14,7
77
22
,041
,376
21,8
75,9
17
20
,805
,991
21
,391
,826
17
,305
,772
14
,964
,341
15
,949
,235
15
,102
,279
15
,726
,120
13
,965
,423
20
8,12
0,99
2
29
BS
C "
I" C
harg
e $0
.002
500
$0.0
0250
0$0
.002
500
$0.0
0250
0$0
.002
500
$0.0
0250
0$0
.002
500
$0.0
0250
0$0
.002
500
$0.0
0250
0$0
.002
500
$0.0
0250
030
Tot
al O
PT
-OU
T B
SC
Cha
rge
- R
ider
"I"
$32,
945
$39,
537
$55,
103
$54,
690
$52,
015
$53,
480
$43,
264
$37,
411
$39,
873
$37,
756
$39,
315
$34,
914
$520
,302
31 32F
ES
The
rm S
ales
720,
000
48
0,00
0
50
,000
250,
000
420,
000
550,
000
550,
000
800,
000
2,10
0,00
0
1,30
0,00
0
1,30
0,00
0
750,
000
9,27
0,00
0
33C
-2 F
ES
Lim
ited
Fir
m$0
.255
400
$0.2
7720
0$0
.307
200
$0.3
2060
0$0
.319
900
$0.3
1480
0$0
.295
200
$0.2
9360
0$0
.296
700
$0.3
0030
0$0
.301
200
$0.3
0080
034
TO
TA
L F
ES
C-2
RE
CO
V.
$183
,888
$133
,056
$15,
360
$80,
150
$134
,358
$173
,140
$162
,360
$234
,880
$623
,070
$390
,390
$391
,560
$225
,600
$2,7
47,8
1235 36
FE
S D
-2 C
ontr
act D
eman
d2,
466
2,46
6
2,46
6
2,46
6
2,46
6
2,
466
2,46
6
2,
466
2,46
6
2,
466
2,46
6
2,
466
29,5
92
37F
ES
D-2
Rat
e$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
038
TO
TA
L F
ES
D-2
RE
CO
V.
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$18,
350
$220
,196
39 40LV
S D
-2 C
ontr
act D
eman
d0
00
00
00
00
00
00
41LV
S D
-2 R
ate
$14.
8821
20$1
4.88
2120
$14.
8821
20$1
4.88
2120
$14.
8821
20$1
4.88
2120
$14.
8821
20$1
4.88
2120
$14.
8821
20$1
4.88
2120
$14.
8821
20$1
4.88
2120
42T
OT
AL
LVS
D-2
Rec
over
ies
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
$043 44
EG
S-L
V-F
irm
D-2
Con
trac
t Dem
and
00
00
00
00
00
00
045
EG
S-L
V-F
irm
D-2
Rat
e$1
4.53
0362
$14.
5303
62$1
4.53
0362
$14.
5303
62$1
4.53
0362
$14.
5303
62$1
4.53
0362
$14.
5303
62$1
4.53
0362
$14.
5303
62$1
4.53
0362
$14.
5303
6246
TO
TA
L E
GS
-LV
-Fir
m D
-2 R
EC
OV
.$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
47 48E
GS
-LV
-Ltd
. Fir
m D
-2 C
ontr
act D
eman
d0
00
00
00
00
00
00
49E
GS
-LV
- Lt
d. F
irm
D-2
Rat
e$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
0$7
.441
060
$7.4
4106
050
TO
TA
L E
GS
-LV
- Lt
d. F
irm
FE
S D
-2 R
EC
OV
.$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
51 52G
SG
, GS
G-L
V, &
CN
G C
omm
odity
964,
858
2,
125,
158
4,
712,
508
6,
873,
132
5,
805,
016
6,
877,
237
3,
796,
933
1,
940,
987
86
6,92
0
1,
400,
872
1,
564,
598
1,
673,
041
38
,601
,258
53
Cos
t of
Gas
$0.2
5540
0$0
.277
200
$0.3
0720
0$0
.320
600
$0.3
1990
0$0
.314
800
$0.2
9520
0$0
.293
600
$0.2
9670
0$0
.300
300
$0.3
0120
0$0
.300
800
54G
SG
& G
SG
-LV
Com
mod
ity R
ecov
erie
s$2
46,4
25$5
89,0
94$1
,447
,683
$2,2
03,5
26$1
,857
,025
$2,1
64,9
54$1
,120
,855
$569
,874
$257
,215
$420
,682
$471
,257
$503
,251
$11,
851,
839
55 56G
SG
, GS
G-L
V, &
CN
G N
on C
omm
odity
964,
858
2,
125,
158
4,
712,
508
6,
873,
132
5,
805,
016
6,
877,
237
3,
796,
933
1,
940,
987
86
6,92
0
1,
400,
872
1,
564,
598
1,
673,
041
38
,601
,258
57
Cos
t of
Gas
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
58G
SG
& G
SG
-LV
Non
Com
mod
ity R
ecov
erie
s$1
24,9
74$2
75,2
63$6
10,3
92$8
90,2
49$7
51,9
00$8
90,7
81$4
91,8
02$2
51,4
08$1
12,2
89$1
81,4
49$2
02,6
56$2
16,7
02$4
,999
,867
OP
T-O
UT
Bal
anci
ng C
harg
e A
pp
lic. S
ales
Vol
ume
LVS
-F
T/C
TS
/EG
S-F
SS
/EG
S-F
T/E
GS
-LV
-FIR
M/L
TD
FIR
M
OP
T-I
N B
alan
cing
Cha
rge
Ap
plic
. Sal
es V
olum
e LV
S-
FT
/CT
S/E
GS
-LV
-FIR
M/L
TD
FIR
M
2016-2017 WORKPAPER KJB-9A PAGE 1 of 2
1W
OR
KP
AP
ER
KJB
-9A
, Pag
e 2
of
22
PR
OO
F O
F R
EC
OV
ER
Y3 4
Oct
-16
No
v-1
6D
ec-
16
Jan
-17
Fe
b-1
7M
ar-
17
Ap
r-1
7M
ay-
17
Jun
-17
Jul-1
7A
ug
-17
Se
p-1
7T
otal
5LV
S T
herm
Sal
es0
00
00
00
00
00
00
6C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$07
LVS
Rec
over
ies
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
$08 9
EG
S-L
V T
herm
Sal
es0
00
00
00
00
00
00
10C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$011
EG
S-L
V R
ecov
erie
s$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
12 13E
GS
-LV
Ltd
. The
rm S
ales
00
00
00
00
00
00
14C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$015
EG
S-L
V L
td. F
irm
Rec
over
ies
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
$016 17
EG
S -
Mon
thly
The
rm S
ales
100
11
0
11
0
70
70
70
70
80
80
80
100
100
1,
040
18C
ost o
f G
as$0
.255
400
$0.2
7720
0$0
.307
200
$0.3
2060
0$0
.319
900
$0.3
1480
0$0
.295
200
$0.2
9360
0$0
.296
700
$0.3
0030
0$0
.301
200
$0.3
0080
019
EG
S -
Mon
thly
Rec
over
ies
$26
$30
$34
$22
$22
$22
$21
$23
$24
$24
$30
$30
$309
20 21Y
ard
and
Str
eet L
ight
ing
The
rm S
ales
10,0
00
10,0
00
10
,000
10,0
00
10
,000
10
,000
10
,000
10
,000
10
,000
10
,000
10
,000
10
,000
12
0,00
0
22
Cos
t of
Gas
$0.3
2000
0$0
.320
000
$0.3
2000
0$0
.320
000
$0.3
2000
0$0
.320
000
$0.3
2000
0$0
.320
000
$0.3
2000
0$0
.320
000
$0.3
2000
0$0
.320
000
23Y
ard
and
Str
eet L
ight
ing
Rec
over
ies
$3,2
00$3
,200
$3,2
00$3
,200
$3,2
00$3
,200
$3,2
00$3
,200
$3,2
00$3
,200
$3,2
00$3
,200
$38,
400
24 25E
GS
-LV
Fir
m N
on C
omm
odity
00
00
00
00
00
00
26C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$027
EG
S-L
V F
irm
Non
Com
mod
ity R
ecov
erie
s$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
28 29E
GS
-LV
Ltd
Fir
m N
on C
omm
odity
00
00
00
00
00
00
30C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$031
EG
S-L
V L
td F
irm
Non
Com
mod
ity R
ecov
erie
s$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
32 33LV
S N
on C
omm
odity
00
00
00
00
00
00
34C
ost o
f G
as$0
$0$0
$0$0
$0$0
$0$0
$0$0
$035
LVS
Non
Com
mod
ity R
ecov
erie
s$0
$0$0
$0$0
$0$0
$0$0
$0$0
$0$0
36 37E
GS
Non
Com
mod
ity10
0
110
110
70
70
70
70
80
80
8010
010
0
1,04
0
38
Cos
t of
Gas
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
$0.1
2952
6$0
.129
526
39E
GS
Non
Com
mod
ity R
ecov
erie
s$1
3$1
4$1
4$9
$9$9
$9$1
0$1
0$1
0$1
3$1
3$1
3540 41 42 43
Tot
al A
lloca
ted
Cos
t Rec
over
y$1
,269
,704
$2,3
48,2
45$4
,471
,889
$6,7
02,4
82$6
,104
,553
$6,3
13,3
24$3
,726
,689
$2,1
15,6
75$1
,720
,472
$1,5
66,6
41$1
,656
,367
$1,5
87,4
71$3
9,58
3,51
1
44 45A
pp
licab
le B
GS
S S
ales
8,23
1,39
1
17
,470
,779
33,2
40,5
68
50
,262
,569
48,1
66,0
56
44,1
60,7
43
28,3
38,0
97
13,8
75,0
44
8,84
0,50
6
5,90
8,84
9
6,03
9,71
6
6,45
8,95
4
270,
993,
272
46B
GS
S C
ost R
ate
$0.3
3077
0$0
.330
770
$0.3
3077
0$0
.330
770
$0.3
3077
0$0
.330
770
$0.3
3077
0$0
.330
770
$0.3
3077
0$0
.330
770
$0.3
3077
0$0
.330
770
47T
otal
BG
SS
Rec
over
y$2
,722
,697
$5,7
78,8
10$1
0,99
4,98
3$1
6,62
5,35
0$1
5,93
1,88
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2015-2016 WORKPAPER KJB-2A PAGE 2 OF 2
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2015-2016 WORKPAPER KJB-5A PAGE 2 OF 2
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0 2015-2016 WORKPAPER KJB-5B PAGE 1 OF 3
1W
OR
KP
AP
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KJ
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Pa
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,61
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7,6
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$7
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4$
7,6
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$7
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93
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$1
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09
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5$
9,1
80
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8$
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39
,08
0$
8,5
60
,21
7 2015-2016 WORKPAPER KJB-5B PAGE 2 OF 3
1W
OR
KP
AP
ER
KJ
B-5
B,
Pa
ge
3 o
f 3
2S
UM
MA
RY
OF
NA
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Oct
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v-1
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15
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16
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16
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$1
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$1
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$1
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72
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93
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ntiv
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ech
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$6
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73
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59
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,27
9,5
33
$5
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47
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21
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48
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40
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8,2
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3,2
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Sp
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4,0
57
1,3
19
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21
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5,4
27
1,3
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60
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48
39
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80
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4
Dire
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urc
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22
8,9
44
36
9,2
25
51
2,2
56
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5,1
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(D
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ER
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$0
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$0
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$0
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$0
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63
$0
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$0
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$0
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55
$0
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To
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r T
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55
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87
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0.3
25
4$
0.2
93
6$
0.2
35
4$
0.2
95
5$
0.2
80
9$
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10
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01
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98
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$0
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$0
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83
$0
.19
22
$0
.20
12
$0
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$0
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37
(Exc
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on
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38
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39
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39
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17
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95
$9
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0,2
08
$9
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9,0
80
$8
,56
0,2
17
45
2015-2016 WORKPAPER KJB-5B PAGE 3 OF 3
1W
OR
KP
AP
ER
KJB
-5C
, PA
GE
1 O
F 5
2N
AT
UR
AL
GA
S IN
VE
NT
OR
Y -
INJE
CT
ION
S3
Oct
-15
No
v-1
5D
ec-
15
Jan
-16
Fe
b-1
6M
ar-
16
Ap
r-1
6M
ay-
16
Jun
-16
Jul-1
6A
ug
-16
Se
p-1
6T
otal
4N
et S
tora
ge
Inje
ctio
ns T
rans
co G
SS
108,
518
60
,885
119,
075
43,0
1918
,876
36,2
8715
4,19
2
20
5,84
6
21
3,82
4
18
9,99
3
17
9,46
0
20
1,10
0
1,
531,
076
5
Pea
king
Sup
plie
s$2
.578
0$1
.822
2$2
.500
8$2
.970
5$2
.630
2$1
.882
7$1
.922
2$2
.011
6$2
.175
3$2
.309
0$2
.380
9$2
.414
26 7
GS
S In
ject
ion
Cos
t$1
79,3
17$1
06,0
06$2
68,8
81$1
15,7
55$5
8,81
2$4
8,72
3$2
09,5
90$4
14,0
80$4
65,1
32$4
38,6
94$4
27,2
77$4
85,4
96$3
,217
,762
8 9N
et S
tora
ge
Inje
ctio
ns T
rans
co E
SS
25,4
66
11,9
8330
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00
11,3
7122
,848
11,0
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22
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17
,878
31
,748
20
6,10
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10
Pea
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.822
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.882
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211 12
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1,22
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$
66
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$
-$
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$14,
819
$41,
232
$22,
128
$44,
875
$52,
993
$42,
566
$76,
646
$432
,972
13 14N
et S
tora
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Inje
ctio
ns T
rans
co L
SS
80,9
60
00
00
018
3,60
0
21
4,09
7
20
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1
18
0,09
3
17
4,28
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17
4,88
7
1,
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922
15
Pea
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3$2
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0$2
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.414
216 17
LSS
Inje
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n C
ost
$119
,653
$0$0
$0$0
$0$2
46,2
45$4
30,6
78$4
54,6
40$4
15,8
35$4
14,9
53$4
22,2
12$2
,504
,215
18 19N
et S
tora
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Inje
ctio
ns T
rans
co S
S 2
112,
181
00
00
026
7,17
3
33
2,94
3
29
9,74
3
29
5,66
0
27
5,46
7
22
9,06
0
1,
812,
227
20
Pea
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s$2
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.822
2$2
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.970
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6$2
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3$2
.309
0$2
.380
9$2
.414
221 22
SS
2 S
tora
ge
Inje
ctio
ns C
ost
$181
,107
$0$0
$0$0
$0$3
55,3
56$6
69,7
48$6
52,0
31$6
82,6
79$6
55,8
59$5
52,9
97$3
,749
,777
23 24N
et S
tora
ge
Inje
ctio
ns D
omin
ion
GS
S0
00
00
081
,090
65,9
8556
,754
59,1
5059
,152
56,7
5137
8,88
225
Pea
king
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plie
s$2
.578
0$1
.822
2$2
.500
8$2
.970
5$2
.630
2$1
.882
7$1
.922
2$2
.011
6$2
.175
3$2
.309
0$2
.380
9$2
.414
226 27
Dom
inio
n G
SS
S
tora
ge
Inje
ctio
ns C
ost
$0$0
$0$0
$0$0
$115
,928
$132
,735
$123
,457
$136
,577
$140
,835
$137
,008
$786
,541
28 29N
et S
tora
ge
Inje
ctio
ns T
rans
co S
-219
80
00
00
17,7
6020
,250
26,1
11
27,3
01
27,3
03
21,9
02
140,
825
30P
eaki
ng S
upp
lies
$2.5
780
$1.8
222
$2.5
008
$2.9
705
$2.6
302
$1.8
827
$1.9
222
$2.0
116
$2.1
753
$2.3
090
$2.3
809
$2.4
142
31 32T
rans
co S
-2 S
tora
ge
Inje
ctio
ns C
ost
$402
$0$0
$0$0
$0$3
2,26
6$4
0,73
5$5
6,79
9$6
3,03
8$6
5,00
6$5
2,87
6$3
11,1
2233 34
Net
Sto
rag
e In
ject
ions
Col
FS
S &
(M
EP
)29
9,00
259
,758
220,
446
333,
801
182,
341
121,
382
476,
010
286,
555
286,
555
286,
555
286,
555
279,
912
3,11
8,87
2
35P
eaki
ng S
upp
lies
$2.5
780
$1.8
222
$2.5
008
$2.9
705
$2.6
302
$1.8
827
$1.9
222
$2.0
116
$2.1
753
$2.3
090
$2.3
809
$2.4
142
36 37C
ol F
SS
Sto
rag
e In
ject
ions
Cos
t$5
56,5
75$1
01,1
09$4
83,6
64$8
72,8
55$5
52,0
92$1
58,3
91$6
64,4
10$5
76,4
34$6
23,3
43$6
61,6
55$6
82,2
59$6
75,7
64$6
,608
,550
38 39T
otal
Sto
rag
e In
ject
ions
Dt
626,
325
132,
626
369,
747
376,
820
201,
217
169,
040
1,20
2,67
3
1,13
6,67
6
1,11
2,61
8
1,06
1,70
3
1,02
0,09
9
995,
360
8,40
4,90
4
40 41T
otal
Sto
rag
e In
ject
ions
Cos
t$1
,088
,276
$227
,364
$818
,788
$988
,609
$610
,903
$221
,932
$1,6
65,0
27$2
,286
,538
$2,4
20,2
77$2
,451
,471
$2,4
28,7
54$2
,402
,999
$17,
610,
940
2015-2016 WORKPAPER KJB-5C PAGE 1 of 5
1W
OR
KP
AP
ER
KJB
-5C
, PA
GE
2 O
F 5
2N
AT
UR
AL
GA
S IN
VE
NT
OR
Y3
Oct
-15
No
v-1
5D
ec-
15
Jan
-16
Fe
b-1
6M
ar-
16
Ap
r-1
6M
ay-
16
Jun
-16
Jul-1
6A
ug
-16
Se
p-1
6T
otal
4G
SS
Op
enin
g B
alan
ce1,
156,
904
1,23
7,05
2
1,23
4,38
8
1,
159,
346
857,
854
336,
550
199,
939
241,
741
391,
741
599,
492
784,
090
958,
453
5S
tora
ge
Inje
ctio
ns T
rans
co G
SS
108,
518
60,8
8511
9,07
543
,019
18,8
7636
,287
154,
192
200,
000
207,
751
184,
597
174,
363
195,
389
1,50
2,95
36 7
GS
S In
vent
ory
Sub
Tot
al D
t1,
265,
422
1,29
7,93
71,
353,
463
1,20
2,36
587
6,73
037
2,83
735
4,13
144
1,74
159
9,49
278
4,09
095
8,45
31,
153,
842
8N
et S
tora
ge
With
draw
als
Tra
nsco
GS
S28
,370
63,5
4919
4,11
734
4,51
154
0,18
017
2,89
811
2,39
050
,000
00
00
1,50
6,01
59 10
GS
S In
vent
ory
Bal
ance
1,23
7,05
2
1,
234,
388
1,
159,
346
857,
854
33
6,55
0
19
9,93
9
24
1,74
1
39
1,74
1
59
9,49
2
78
4,09
0
95
8,45
3
1,
153,
842
11 12
GS
S In
vent
ory
Cos
t Op
enin
g B
alan
ce$2
,446
,668
$2,5
66,7
14$2
,539
,954
$2,4
06,6
44$1
,801
,992
$714
,812
$386
,824
$402
,497
$724
,150
$1,1
89,2
81
$1,6
27,9
76$2
,055
,252
13 14G
SS
Inje
ctio
n C
ost
$179
,317
$106
,006
$268
,881
$115
,755
$58,
812
$48,
723
$209
,590
$414
,080
$465
,132
$438
,694
$427
,277
$485
,496
$3,2
17,7
6215 16
GS
S In
vent
ory
Cos
t Sub
Tot
al$2
,625
,985
$2,6
72,7
21$2
,808
,835
$2,5
22,3
99$1
,860
,803
$763
,534
$596
,414
$816
,577
$1,1
89,2
81$1
,627
,976
$2,0
55,2
52$2
,540
,748
17T
otal
GS
S S
tora
ge
With
draw
al C
ost
$59,
271
$132
,767
$402
,191
$720
,407
$1,1
45,9
92$3
76,7
10$1
93,9
18$9
2,42
7$0
$0$0
$0$3
,123
,682
18 19T
otal
GS
S In
vent
ory
Cos
t Bal
ance
$2,5
66,7
14$2
,539
,954
$2,4
06,6
44$1
,801
,992
$714
,812
$386
,824
$402
,497
$724
,150
$1,1
89,2
81$1
,627
,976
$2,
055,
252
$2,5
40,7
4820 21
GS
S In
vent
ory
Cos
t Rat
e$2
.074
9$2
.057
7$2
.075
9$2
.100
6$2
.123
9$1
.934
7$1
.665
0$1
.848
5$1
.983
8$2
.076
3$2
.144
3$2
.202
022 23
ES
S O
pen
ing
Bal
ance
203,
348
228,
814
198,
806
213,
397
213,
390
199,
425
210,
614
212,
947
208,
947
207,
577
210,
527
208,
405
24S
tora
ge
Inje
ctio
ns T
rans
co E
SS
25,4
6611
,983
30,2
260
011
,371
22,8
4811
,000
20,6
3022
,951
17,8
7831
,748
206,
100
25 26E
SS
Inve
ntor
y S
ub T
otal
Dt
228,
814
240,
797
229,
032
213,
397
213,
390
210,
796
233,
462
223,
947
229,
577
230,
527
228,
405
240,
153
27N
et S
tora
ge
With
draw
als
Tra
nsco
ES
S0
41,9
9115
,635
713
,965
182
20,5
1515
,000
22,0
0020
,000
20,0
0031
,140
200,
435
28 29E
SS
Inve
ntor
y B
alan
ce22
8,81
419
8,80
621
3,39
721
3,39
019
9,42
521
0,61
421
2,94
720
8,94
720
7,57
721
0,52
720
8,40
520
9,01
430 31
ES
S In
vent
ory
Cos
t Op
enin
g B
alan
ce$6
50,6
24$7
01,8
46$5
93,2
96$6
12,8
80$6
12,8
60$5
72,7
52$5
87,0
48$5
73,0
72$5
55,3
33$5
42,6
91$5
44,0
04$5
35,2
0732 33
ES
S In
ject
ion
Cos
t$5
1,22
2$2
0,24
9$6
6,24
3$0
$0$1
4,81
9$4
1,23
2$2
2,12
8$4
4,87
5$5
2,99
3$4
2,56
6$7
6,64
6$4
32,9
7234 35
ES
S In
vent
ory
Cos
t Sub
Tot
al$7
01,8
46$7
22,0
95$6
59,5
39$6
12,8
80$6
12,8
60$5
87,5
71$6
28,2
80$5
95,1
99$6
00,2
08$5
95,6
84$5
86,5
70$6
11,8
5336
Tot
al E
SS
Sto
rag
e W
ithdr
awal
Cos
t$0
$128
,799
$46,
660
$20
$40,
107
$523
$55,
208
$39,
867
$57,
517
$51,
680
$51,
362
$79,
336
$551
,079
37 38T
otal
ES
S In
vent
ory
Cos
t Bal
$701
,846
$593
,296
$612
,880
$612
,860
$572
,752
$587
,048
$573
,072
$555
,333
$542
,691
$544
,004
$535
,207
$532
,517
39 40E
SS
Inve
ntor
y C
ost R
ate
$3.0
673
$2.9
843
$2.8
720
$2.8
720
$2.8
720
$2.7
873
$2.6
911
$2.6
578
$2.6
144
$2.5
840
$2.5
681
$2.5
478
2015-2016 WORKPAPER KJB-5C PAGE 2 of 5
1W
OR
KP
AP
ER
KJB
-5C
, PA
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3 O
F 5
2N
AT
UR
AL
GA
S IN
VE
NT
OR
Y3
Oct
-15
No
v-1
5D
ec-
15
Jan
-16
Fe
b-1
6M
ar-
16
Ap
r-1
6M
ay-
16
Jun
-16
Jul-1
6A
ug
-16
Se
p-1
6T
otal
4LS
S O
pen
ing
Bal
ance
1,14
8,16
61,
229,
126
964,
111
699,
445
362,
495
142,
886
5,12
618
8,72
639
9,52
660
5,30
878
2,62
895
4,22
85
Sto
rag
e In
ject
ions
Tra
nsco
LS
S80
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00
00
018
3,60
021
0,80
020
5,78
217
7,32
017
1,60
017
2,19
41,
202,
256
6 7LS
S In
vent
ory
Sub
Tot
al D
t1,
229,
126
1,22
9,12
696
4,11
169
9,44
536
2,49
514
2,88
618
8,72
639
9,52
660
5,30
878
2,62
895
4,22
81,
126,
422
8N
et S
tora
ge
With
draw
als
Tra
nsco
LS
S0
265,
015
264,
666
336,
950
219,
609
137,
760
00
00
00
1,22
4,00
09 10
LSS
Inve
ntor
y B
alan
ce1,
229,
126
964,
111
699,
445
362,
495
142,
886
5,12
618
8,72
639
9,52
660
5,30
878
2,62
895
4,22
81,
126,
422
11 12LS
S In
vent
ory
Cos
t Op
en B
alan
ce$2
,016
,859
$2,1
36,5
12$1
,673
,928
$1,2
11,9
54$6
23,8
08$2
40,4
58-$
2$2
46,2
43$6
76,9
21$1
,131
,561
$1,5
47,3
95$1
,962
,348
13 14LS
S In
ject
ion
Cos
t$1
19,6
53$0
$0$0
$0$0
$246
,245
$430
,678
$454
,640
$415
,835
$414
,953
$422
,212
$2,5
04,2
1515 16
LSS
Inve
ntor
y C
ost S
ub T
otal
$2,1
36,5
12$2
,136
,512
$1,6
73,9
28$1
,211
,954
$623
,808
$240
,458
$246
,243
$676
,921
$1,1
31,5
61$1
,547
,395
$1,9
62,3
48$2
,384
,560
17T
otal
LS
S S
tora
ge
With
draw
al C
ost
$0$4
62,5
84$4
61,9
75$5
88,1
46$3
83,3
49$2
40,4
60$0
$0$0
$0$0
$0$2
,136
,514
18 19T
otal
LS
S In
vent
ory
Cos
t Bal
$2,1
36,5
12$1
,673
,928
$1,2
11,9
54$6
23,8
08$2
40,4
58-$
2$2
46,2
43$6
76,9
21$1
,131
,561
$1,5
47,3
95$1
,962
,348
$2,3
84,5
6020 21
LSS
Inve
ntor
y C
ost R
ate
$1.7
382
$1.7
362
$1.7
327
$1.7
209
$1.6
829
($0.
0004
)$1
.304
8$1
.694
3$1
.869
4$1
.977
2$2
.056
5$2
.116
922 23
SS
2 O
pen
ing
Bal
ance
1,65
4,46
91,
766,
650
1,51
0,18
21,
107,
056
641,
141
275,
361
1,97
526
9,14
859
9,72
789
7,34
21,
190,
903
1,46
4,41
424
Sto
rag
e In
ject
ions
Tra
nsco
SS
211
2,18
10
00
00
267,
173
330,
579
297,
615
293,
561
273,
511
227,
434
1,80
2,05
425 26
SS
2 In
vent
ory
Sub
Tot
al D
t1,
766,
650
1,76
6,65
01,
510,
182
1,10
7,05
664
1,14
127
5,36
126
9,14
859
9,72
789
7,34
21,
190,
903
1,46
4,41
41,
691,
848
27N
et S
tora
ge
With
draw
als
Tra
nsco
SS
20
256,
468
403,
126
465,
915
365,
780
273,
386
00
00
00
1,76
4,67
528 29
SS
2 In
vent
ory
Bal
ance
1,76
6,65
01,
510,
182
1,10
7,05
664
1,14
127
5,36
11,
975
269,
148
599,
727
897,
342
1,19
0,90
31,
464,
414
1,69
1,84
830 31
SS
2 In
vent
ory
Cos
t Op
en B
alan
ce$2
,960
,245
$3,1
41,3
52$2
,684
,813
$1,9
67,2
08$1
,137
,786
$486
,661
-$20
$355
,336
$1,0
25,0
84$1
,677
,115
$2,3
59,7
94$3
,015
,653
32 33S
S 2
Sto
rag
e In
ject
ions
Cos
t$1
81,1
07$0
$0$0
$0$0
$355
,356
$669
,748
$652
,031
$682
,679
$655
,859
$552
,997
$3,7
49,7
7734 35
SS
2 In
vent
ory
Cos
t Sub
Tot
al$3
,141
,352
$3,1
41,3
52$2
,684
,813
$1,9
67,2
08$1
,137
,786
$486
,661
$355
,336
$1,0
25,0
84$1
,677
,115
$2,3
59,7
94$3
,015
,653
$3,5
68,6
5036
Tot
al S
S 2
Sto
rag
e W
ithdr
awal
Cos
t$0
$456
,539
$717
,605
$829
,422
$651
,125
$486
,682
$0$0
$0$0
$0$0
$3,1
41,3
7237 38
Tot
al S
S 2
Inve
ntor
y C
ost B
al$3
,141
,352
$2,6
84,8
13$1
,967
,208
$1,1
37,7
86$4
86,6
61-$
20$3
55,3
36$1
,025
,084
$1,6
77,1
15$2
,359
,794
$3,0
15,6
53$3
,568
,650
39 40S
S 2
Inve
ntor
y C
ost R
ate
$1.7
781
$1.7
778
$1.7
770
$1.7
746
$1.7
674
($0.
0103
)$1
.320
2$1
.709
3$1
.869
0$1
.981
5$2
.059
3$2
.109
341 42
Dom
inio
n G
SS
O
pen
ing
Bal
ance
422,
990
422,
990
422,
990
422,
990
223,
443
73,7
42-1
081
,080
145,
778
201,
425
259,
422
317,
421
43In
ject
ions
Dom
inio
n G
SS
S
tora
ge
00
00
00
81,0
9064
,698
55,6
4757
,997
57,9
9955
,644
373,
075
44 45D
omin
ion
GS
S
Inve
ntor
y S
ub T
otal
Dt
422,
990
422,
990
422,
990
422,
990
223,
443
73,7
4281
,080
145,
778
201,
425
259,
422
317,
421
373,
065
46N
et S
tora
ge
With
draw
als
Dom
inio
n G
SS
0
00
199,
547
149,
701
73,7
520
00
00
042
3,00
047 48
Dom
inio
n G
SS
In
vent
ory
Bal
ance
422,
990
422,
990
422,
990
223,
443
73,7
42-1
081
,080
145,
778
201,
425
259,
422
317,
421
373,
065
49 50D
omin
ion
GS
S
Inve
ntor
y C
ost O
pen
Bal
ance
$727
,894
$727
,894
$727
,894
$727
,894
$384
,514
$126
,908
$3$1
15,9
31$2
48,6
67$3
72,1
24$5
08,7
01$
649,
536
51 52D
omin
ion
GS
S
Sto
rag
e In
ject
ions
Cos
t$0
$0$0
$0$0
$0$1
15,9
28$1
32,7
35$1
23,4
57$1
36,5
77$1
40,8
35$1
37,0
08$7
86,5
4153 54
Dom
inio
n G
SS
Inv
ento
ry C
ost S
ub T
otal
$727
,894
$727
,894
$727
,894
$727
,894
$384
,514
$126
,908
$115
,931
$248
,667
$372
,124
$508
,701
$649
,53
6$7
86,5
4455
Tot
al E
qui
t Sto
rag
e W
ithdr
awal
Cos
t$0
$0$0
$343
,380
$257
,605
$126
,905
$0$0
$0$0
$0$0
$727
,891
56 57T
otal
Dom
inio
n G
SS
In
vent
ory
Cos
t Bal
ance
$727
,894
$727
,894
$727
,894
$384
,514
$126
,908
$3$1
15,9
31$2
48,6
67$3
72,1
24$5
08,7
01$6
49,5
36$7
86,5
4458 59
Dom
inio
n G
SS
In
vent
ory
Cos
t Rat
e$1
.720
8$1
.720
8$1
.720
8$1
.720
9$1
.721
0($
0.32
52)
$1.4
298
$1.7
058
$1.8
475
$1.9
609
$2.0
463
$2.1
083
2015-2016 WORKPAPER KJB-5C PAGE 3 of 5
1W
OR
KP
AP
ER
KJB
-5C
, PA
GE
4 O
F 5
2N
AT
UR
AL
GA
S IN
VE
NT
OR
Y3
Oct
-15
No
v-1
5D
ec-
15
Jan
-16
Fe
b-1
6M
ar-
16
Ap
r-1
6M
ay-
16
Jun
-16
Jul-1
6A
ug
-16
Se
p-1
6T
otal
4T
rans
co S
-2 O
pen
ing
Bal
ance
140,
008
140,
206
140,
206
104,
188
55,4
9411
,989
127
17,8
8738
,007
63,9
5191
,077
118,
205
5S
tora
ge
Inje
ctio
ns T
rans
co S
-219
80
00
00
17,7
6020
,120
25,9
4427
,126
27,1
2821
,762
140,
038
6 7T
rans
co S
-2 In
vent
ory
Sub
Tot
al D
t14
0,20
614
0,20
614
0,20
610
4,18
855
,494
11,9
8917
,887
38,0
0763
,951
91,0
7711
8,20
513
9,96
78
Net
Sto
rag
e W
ithdr
awal
s T
rans
co S
-20
036
,018
48,6
9443
,505
11,8
620
00
00
7714
0,15
69 10
Tra
nsco
S-2
Inve
ntor
y B
alan
ce14
0,20
614
0,20
610
4,18
855
,494
11,9
8912
717
,887
38,0
0763
,951
91,0
7711
8,20
513
9,89
011 12
Tra
nsco
S-2
Inve
ntor
y C
ost O
pen
Bal
ance
$328
,645
$329
,048
$329
,048
$244
,441
$130
,059
$27,
866
$1$3
2,26
7$7
3,00
2$1
29,8
01$1
92,8
39$2
57,8
4513 14
Tra
nsco
S-2
Sto
rag
e In
ject
ions
Cos
t$4
02$0
$0$0
$0$0
$32,
266
$40,
735
$56,
799
$63,
038
$65,
006
$52,
876
$311
,122
15 16T
rans
co S
-2 In
vent
ory
Cos
t Sub
Tot
al$3
29,0
48$3
29,0
48$3
29,0
48$2
44,4
41$1
30,0
59$2
7,86
6$3
2,26
7$7
3,00
2$1
29,8
01$1
92,8
39$2
57,8
45$3
10,7
2117
Tot
al T
rans
co S
-2 S
tora
ge
With
draw
al C
ost
$0$0
$84,
606
$114
,382
$102
,193
$27,
865
$0$0
$0$0
$0$1
68$3
29,2
1518 19
Tot
al T
rans
S-2
Inve
ntor
y C
ost B
al$3
29,0
48$3
29,0
48$2
44,4
41$1
30,0
59$2
7,86
6$1
$32,
267
$73,
002
$129
,801
$192
,839
$257
,845
$310
,553
20 21T
rans
co S
-2 In
vent
ory
Cos
t Rat
e$2
.346
9$2
.346
9$2
.346
2$2
.343
7$2
.324
3$0
.007
2$1
.803
9$1
.920
8$2
.029
7$2
.117
3$2
.181
3$2
.220
022 23
Col
FS
S O
pen
ing
Bal
ance
1,85
0,63
12,
004,
374
1,74
6,48
11,
489,
664
1,36
1,08
975
8,26
439
8,05
060
1,84
788
2,13
81,
162,
429
1,44
2,72
01,
723,
011
24S
tora
ge
Inje
ctio
ns C
olum
bia
FS
S &
(M
EP
)29
9,00
259
,758
220,
446
333,
801
182,
341
121,
382
476,
010
280,
291
280,
291
280,
291
280,
291
273,
794
3,0
87,6
9825 26
Col
FS
S In
vent
ory
Sub
Tot
al D
t2,
149,
633
2,06
4,13
21,
966,
927
1,82
3,46
51,
543,
430
879,
646
874,
060
882,
138
1,16
2,42
91,
442,
720
1,72
3,01
11,
996,
805
27N
et S
tora
ge
With
draw
al C
ol F
SS
& (
ME
P)
145,
259
317,
651
477,
263
462,
376
785,
166
481,
596
272,
213
00
00
02,
941,
524
28 29C
ol F
SS
& (
ME
P)
Inve
ntor
y B
alan
ce2,
004,
374
1,74
6,48
11,
489,
664
1,36
1,08
975
8,26
439
8,05
060
1,84
788
2,13
81,
162,
429
1,44
2,72
01,
723,
011
1,99
6,80
530 31
Col
FS
S &
(M
EP
) In
vent
ory
Cos
t Op
en B
alan
ce$3
,720
,906
$3,9
88,3
14$3
,457
,075
$2,9
95,5
20$2
,938
,028
$1,7
94,0
82$8
11,6
20$1
,015
,854
$1,5
92,2
88$2
,215
,631
$2,8
77,2
86$3
,559
,545
32 33C
ol F
SS
Sto
rag
e In
ject
ions
Cos
t$5
56,5
75$1
01,1
09$4
83,6
64$8
72,8
55$5
52,0
92$1
58,3
91$6
64,4
10$5
76,4
34$6
23,3
43$6
61,6
55$6
82,2
59$6
75,7
64$6
,608
,550
34 35C
ol F
SS
Inve
ntor
y C
ost S
ub T
otal
$4,2
77,4
81$4
,089
,423
$3,9
40,7
39$3
,868
,375
$3,4
90,1
19$1
,952
,473
$1,4
76,0
30$1
,592
,288
$2,2
15,6
31$2
,877
,286
$3,5
59,5
45$4
,235
,309
36T
otal
Col
FS
S S
tora
ge
With
draw
al C
ost
$289
,167
$632
,348
$945
,219
$930
,347
$1,6
96,0
37$1
,140
,853
$460
,176
$0$0
$0$0
$0$6
,094
,147
37 38T
otal
Col
FS
S &
(M
EP
) In
vent
ory
Cos
t Bal
$3,9
88,3
14$3
,457
,075
$2,9
95,5
20$2
,938
,028
$1,7
94,0
82$8
11,6
20$1
,015
,854
$1,5
92,2
88$2
,215
,631
$2,8
77,2
86$3
,559
,545
$4,2
35,3
0939 40
Col
FS
S &
(M
EP
) In
vent
ory
Cos
t Rat
e$1
.989
8$1
.979
5$2
.010
9$2
.158
6$2
.366
0$2
.039
0$1
.687
9$1
.805
0$1
.906
0$1
.994
3$2
.065
9$2
.121
041 42
Tot
al B
egin
ning
Inve
ntor
y D
t6,
576,
516
7,02
9,21
2
6,21
7,16
4
5,
196,
086
3,71
4,90
6
1,79
8,21
7
815,
821
1,61
3,37
6
2,66
5,86
4
3,73
7,52
4
4,76
1,36
6
5,74
4,13
7
43 44T
otal
End
ing
Inve
ntor
y D
t7,
029,
212
6,21
7,16
4
5,19
6,08
6
3,
714,
906
1,79
8,21
7
815,
821
1,61
3,37
6
2,66
5,86
4
3,73
7,52
4
4,76
1,36
6
5,74
4,13
7
6,69
0,88
5
45 46T
otal
Beg
inni
ng In
vent
ory
Cos
t$1
2,85
1,84
1$1
3,59
1,68
0$1
2,00
6,00
8$1
0,16
6,54
1$7
,629
,046
$3,9
63,5
40$1
,785
,475
$2,7
41,2
00$4
,895
,444
$7,2
58,2
04$9
,657
,995
$12,
035,
387
47 48T
otal
End
ing
Inve
ntor
y C
ost
$13,
591,
680
$12,
006,
008
$10,
166,
541
$7,6
29,0
46$3
,963
,540
$1,7
85,4
75$2
,741
,200
$4,8
95,4
44$7
,258
,204
$9,6
57,9
95$1
2,03
5,38
7$1
4,35
8,88
2
2015-2016 WORKPAPER KJB-5C PAGE 4 of 5
1W
OR
KP
AP
ER
KJB
-5C
, PA
GE
5 O
F 5
2N
AT
UR
AL
GA
S IN
VE
NT
OR
Y -
WIT
HD
RA
WA
LS
3O
ct-1
5N
ov-
15
De
c-1
5Ja
n-1
6F
eb
-16
Ma
r-1
6A
pr-
16
Ma
y-1
6Ju
n-1
6Ju
l-16
Au
g-1
6S
ep
-16
Tot
al4
Net
Sto
rag
e W
ithdr
awal
s T
rans
co G
SS
28,3
7063
,549
194,
117
344,
511
540,
180
172,
898
112,
390
50,0
000
00
01,
506,
015
5 6G
SS
Inve
ntor
y C
ost R
ate
$2.0
752
$2.0
592
$2.0
753
$2.0
979
$2.1
224
$2.0
479
$1.6
842
$1.8
485
$1.9
838
$2.0
763
$2.1
443
$2.2
020
7 8T
otal
GS
S S
tora
ge
With
draw
al C
ost
$59,
271
$132
,767
$402
,191
$720
,407
$1,1
45,9
92$3
76,7
10$1
93,9
18$9
2,42
7$0
$0$0
$0$3
,123
,682
9 10N
et S
tora
ge
With
draw
als
Tra
nsco
ES
S0
41,9
9115
,635
713
,965
182
20,5
1515
,000
22,0
0020
,000
20,0
0031
,140
200,
435
11 12E
SS
Inve
ntor
y C
ost R
ate
$3.0
673
$2.9
988
$2.8
797
$2.8
720
$2.8
720
$2.7
874
$2.6
911
$2.6
578
$2.6
144
$2.5
840
$2.5
681
$2.5
478
13 14T
otal
ES
S S
tora
ge
With
draw
al C
ost
$0$1
28,7
99$4
6,66
0$2
0$4
0,10
7$5
23$5
5,20
8$3
9,86
7$5
7,51
7$5
1,68
0$5
1,36
2$7
9,33
6$5
51,0
7915 16
Net
Sto
rag
e W
ithdr
awal
s T
rans
co L
SS
026
5,01
526
4,66
633
6,95
021
9,60
913
7,76
00
00
00
01,
224,
000
17 18LS
S In
vent
ory
Cos
t Rat
e$1
.756
6$1
.738
2$1
.736
2$1
.732
7$1
.720
9$1
.682
9-$
0.00
04$1
.304
8$1
.694
3$1
.869
4$1
.977
2$2
.056
519 20
Tot
al L
SS
Sto
rag
e W
ithdr
awal
Cos
t$0
$462
,584
$461
,975
$588
,146
$383
,349
$240
,460
$0$0
$0$0
$0$0
$2,1
36,5
1421 22
Net
Sto
rag
e W
ithdr
awal
Tra
nsco
SS
20
256,
468
403,
126
465,
915
365,
780
273,
386
00
00
00
1,76
4,67
523 24
SS
2 In
vent
ory
Cos
t Rat
e$1
.789
2$1
.778
1$1
.777
8$1
.777
0$1
.774
6$1
.767
4-$
0.01
03$1
.320
2$1
.709
3$1
.869
0$1
.981
5$2
.059
325 26
Tot
al S
S 2
Sto
rag
e W
ithdr
awal
Cos
t$0
$456
,539
$717
,605
$829
,422
$651
,125
$486
,682
$0$0
$0$0
$0$0
$3,1
41,3
7227 28
Net
Sto
rag
e D
omin
ion
GS
S
00
019
9,54
714
9,70
173
,752
00
00
00
423,
000
29 30D
omin
ion
GS
S
Inve
ntor
y C
ost R
ate
$1.7
208
$1.7
208
$1.7
208
$1.7
208
$1.7
209
$1.7
210
-$0.
3252
$1.4
298
$1.7
058
$1.8
475
$1.9
609
$2.0
463
31 32T
otal
Dom
inio
n G
SS
Sto
rag
e W
ithdr
awal
Cos
t$0
$0$0
$343
,380
$257
,605
$126
,905
$0$0
$0$0
$0$0
$727
,891
33 34N
et S
tora
ge
With
draw
als
Tra
nsco
S-2
00
36,0
1848
,694
43,5
0511
,862
00
00
077
140,
156
35 36T
rans
co S
-2 In
vent
ory
Cos
t Rat
e$2
.347
3$2
.346
9$2
.346
9$2
.346
2$2
.343
7$2
.324
3$0
.007
2$1
.803
9$1
.920
8$2
.029
7$2
.117
3$2
.181
337 38
Tot
al T
rans
co S
-2 S
tora
ge
With
draw
al C
ost
$0$0
$84,
606
$114
,382
$102
,193
$27,
865
$0$0
$0$0
$0$1
68$3
29,2
1539 40
Net
Sto
rag
e W
ithdr
awal
Col
FS
S &
(M
EP
)14
5,25
931
7,65
147
7,26
346
2,37
678
5,16
648
1,59
627
2,21
30
00
00
2,94
1,52
441 42
Col
FS
S &
(M
EP
) In
vent
ory
Cos
t Rat
e$1
.989
9$1
.981
2$2
.003
5$2
.121
4$2
.261
3$2
.219
6$1
.688
7$1
.805
0$1
.906
0$1
.994
3$2
.065
9$2
.121
043 44
Tot
al C
ol F
SS
Sto
rag
e W
ithdr
awal
Cos
t$2
89,1
67$6
32,3
48$9
45,2
19$9
30,3
47$1
,696
,037
$1,1
40,8
53$4
60,1
76$0
$0$0
$0$0
$6,0
94,1
4745 46
Tot
al S
tora
ge
With
draw
als
Dt
173,
629
944,
674
1,39
0,82
51,
858,
000
2,11
7,90
61,
151,
436
405,
118
65,0
0022
,000
20,0
0020
,000
31,2
178,
199,
805
47 48T
otal
Sto
rag
e W
ithdr
awal
s C
ost
$348
,438
$1,8
13,0
36$2
,658
,255
$3,5
26,1
05$4
,276
,410
$2,3
99,9
98$7
09,3
02$1
32,2
94$5
7,51
7$5
1,68
0$5
1,36
2$7
9,50
4$1
6,10
3,90
0 2015-2016 WORKPAPER KJB-5C PAGE 5 of 5
1W
OR
KP
AP
ER
KJB
-5D
2L
NG
INV
EN
TO
RY
3O
ct-1
5N
ov-
15
De
c-1
5Ja
n-1
6F
eb
-16
Ma
r-1
6A
pr-
16
Ma
y-1
6Ju
n-1
6Ju
l-16
Au
g-1
6S
ep
-16
Tot
al4
Net
Sto
rag
e In
ject
ions
Com
pan
y LN
G36
,675
34
,969
43
,055
32,4
18
50
,515
-
00
00
00
197,
632
5LN
G R
ate
$5.0
057
$5.2
111
$5.4
130
$5.6
067
$5.3
930
$0.0
000
$0.0
000
$0.0
000
$0.0
000
$0.0
000
$0.0
000
$0.0
000
6 7T
otal
LN
G S
tora
ge
Inje
ctio
n C
ost
$226
,179
$258
,236
$341
,535
$305
,654
$521
,293
$9,5
92$0
$0$0
$0$0
$0$1
,662
,489
8 9 10LN
G O
pen
ing
Bal
ance
Inve
ntor
y31
4,88
034
2,83
536
9,76
539
1,99
629
8,00
931
1,51
130
4,10
529
8,38
628
8,88
627
9,38
626
9,88
626
0,38
611
Net
Sto
rag
e In
ject
ions
Com
pan
y LN
G36
,675
34,9
6943
,055
32,4
1850
,515
00
00
00
019
7,63
212 13
LNG
Inve
ntor
y S
ub T
otal
351,
555
377,
804
412,
820
424,
414
348,
524
311,
511
304,
105
298,
386
288,
886
279,
386
269,
886
260,
386
14N
et S
tora
ge
With
draw
als
Com
pan
y LN
G8,
720
8,03
920
,824
126,
405
37,0
137,
406
5,71
99,
500
9,50
09,
500
9,50
09,
500
261,
626
15 16LN
G In
vent
ory
Bal
ance
342,
835
369,
765
391,
996
298,
009
311,
511
304,
105
298,
386
288,
886
279,
386
269,
886
260,
386
250,
886
17 18LN
G In
vent
ory
Cos
t Op
en B
alan
ce$3
,705
,625
$3,8
34,2
79$4
,005
,434
$4,1
27,6
93$3
,112
,945
$3,2
48,2
85$3
,180
,422
$3,1
20,6
11$3
,021
,257
$2,9
21,9
03$2
,822
,549
$2,7
23,1
9619 20
LNG
Inje
ctio
n C
ost
$226
,179
$258
,236
$341
,535
$305
,654
$521
,293
$9,5
92$0
$0$0
$0$0
$0$1
,662
,489
21 22T
otal
LN
G In
vent
ory
Cos
t Sub
Tot
al$3
,931
,804
$4,0
92,5
15$4
,346
,968
$4,4
33,3
47$3
,634
,238
$3,2
57,8
76$3
,180
,422
$3,1
20,6
11$3
,021
,257
$2,9
21,9
03$2
,822
,549
$2,7
23,1
9623
Tot
al L
NG
Sto
rag
e W
ithdr
awal
Cos
t$9
7,52
5$8
7,08
1$2
19,2
75$1
,320
,402
$385
,953
$77,
454
$59,
811
$99,
354
$99,
354
$99,
354
$99,
354
$99,
354
$2,7
44,2
7224 25
Tot
al L
NG
Inve
ntor
y C
ost
$3,8
34,2
79$4
,005
,434
$4,1
27,6
93$3
,112
,945
$3,2
48,2
85$3
,180
,422
$3,1
20,6
11$3
,021
,257
$2,9
21,9
03$2
,822
,549
$2,7
23,1
96$2
,623
,842
26 27E
ndin
g L
NG
Inve
ntor
y C
ost R
ate
$11.
1840
$10.
8324
$10.
5299
$10.
4458
$10.
4275
$10.
4583
$10.
4583
$10.
4583
$10.
4583
$10.
4583
$10.
4583
$10.
4583
28 29N
et S
tora
ge
With
draw
als
Com
pan
y LN
G8,
720
8,03
920
,824
126,
405
37,0
137,
406
5,71
99,
500
9,50
09,
500
9,50
09,
500
261,
626
30 31LN
G In
vent
ory
Cos
t Rat
e$1
1.18
40$1
0.83
24$1
0.52
99$1
0.44
58$1
0.42
75$1
0.45
83$1
0.45
83$1
0.45
83$1
0.45
83$1
0.45
83$1
0.45
83$1
0.45
8332 33
Tot
al L
NG
Sto
rag
e W
ithdr
awal
Cos
t$9
7,52
5$8
7,08
1$2
19,2
75$1
,320
,402
$385
,953
$77,
454
$59,
811
$99,
354
$99,
354
$99,
354
$99,
354
$99,
354
$2,7
44,2
72 2015-2016 WORKPAPER KJB-5D
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
220
15 -
201
6 B
GS
SC
3M
onth
ly In
terr
uptib
le/O
ff-S
yste
m/C
apac
ity R
elea
se C
redi
t4 5
Oct
-15
No
v-1
5D
ec-
15
Jan
-16
Fe
b-1
6M
ar-
16
Ap
r-1
6M
ay-
16
Jun
-16
Jul-1
6A
ug
-16
Se
p-1
6T
otal
6 7P
re-T
ax In
terr
uptib
le M
arg
ins
$36,
099
$34,
129
$38,
295
$52,
375
$32,
900
$54,
316
$9,9
10$2
4,50
0$2
0,97
8$1
5,49
2$1
2,09
3$1
6,18
1$3
47,2
688 9
Pre
-Tax
Off
-Sys
tem
Sal
es a
nd C
apac
ity R
elea
se$2
,140
,994
$4,1
29,3
57$3
,872
,304
$4,0
26,8
60$3
,516
,435
$3,6
64,3
94$1
,717
,411
$1,4
25,2
75$1
,415
,971
$1,4
25,2
75$1
,425
,275
$1,4
15,9
71$3
0,17
5,52
110 11
Pre
-tax
Mar
gin
s S
ubje
ct to
Rev
enue
12 S
hari
ng %
$2,1
77,0
92$4
,163
,486
$3,9
10,5
99$4
,079
,234
$3,5
49,3
35$3
,718
,709
$1,7
27,3
22$1
,449
,775
$1,4
36,9
49$1
,440
,767
$1,4
37,3
68$1
,432
,152
$30,
522,
789
13 14 15R
even
ue S
hari
ng %
85%
85%
85%
85%
85%
85%
85%
85%
85%
85%
85%
85%
16 17 18In
terr
uptib
le/O
ff-S
yste
m S
ales
/Cap
acity
Rel
ease
Cre
dit
$1,8
50,5
28$3
,538
,963
$3,3
24,0
09$3
,467
,349
$3,0
16,9
35$3
,160
,903
$1,4
68,2
24$1
,232
,309
$1,2
21,4
07$1
,224
,652
$1,2
21,7
63$1
,217
,329
$25,
944,
370 2015-2016 WORKPAPER
KJB-6
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
22
01
5 -
20
16
BG
SS
C3
Inte
rru
pti
ble
Inc
om
e S
tate
me
nt
4 5O
ct-1
5N
ov-
15
De
c-1
5Ja
n-1
6F
eb
-16
Ma
r-1
6A
pr-
16
Ma
y-1
6Ju
n-1
6Ju
l-1
6A
ug
-16
Se
p-1
6T
ota
l6
Vo
lum
es
7IG
S0
00
00
1,9
27
02
50
00
00
2,1
77
8IT
S1
01
,18
01
20
,16
31
19
,62
01
54
,35
61
00
,52
31
19
,73
54
0,3
40
73
,87
27
0,0
04
51
,69
54
0,3
55
53
,99
51
,04
5,8
39
9 10
To
tal V
olu
me
s1
01
,18
01
20
,16
31
19
,62
01
54
,35
61
00
,52
31
21
,66
24
0,3
40
74
,12
27
0,0
04
51
,69
54
0,3
55
53
,99
51
,04
8,0
16
11
12
Re
ven
ue
s1
3IG
S$
0$
0$
0$
0$
0$
17
,26
1$
0$
3,0
72
$0
$0
$0
$0
$2
0,3
34
14
ITS
$3
6,3
01
$3
4,3
50
$3
8,5
25
$5
2,6
78
$3
3,0
95
$3
9,8
80
$9
,97
0$
22
,45
7$
21
,28
1$
15
,71
5$
12
,26
8$
16
,41
5$
33
2,9
36
15
16
To
tal R
eve
nu
e$
36
,30
1$
34
,35
0$
38
,52
5$
52
,67
8$
33
,09
5$
57
,14
1$
9,9
70
$2
5,5
30
$2
1,2
81
$1
5,7
15
$1
2,2
68
$1
6,4
15
$3
53
,27
01
71
8C
ost
Of
Ga
s In
terr
Sa
les
19
IGS
$0
$0
$0
$0
$0
$2
,55
3$
0$
50
3$
0$
0$
0$
0$
3,0
56
20
ITS
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
$0
21
22
To
tal C
ost
Of
Ga
s In
terr
Sa
les
$0
$0
$0
$0
$0
$2
,55
3$
0$
50
3$
0$
0$
0$
0$
3,0
56
23
24
NJ
Sa
les
Ta
x, T
EF
A &
PU
A2
5IG
S$
0$
0$
0$
0$
0$
39
$0
$2
07
$0
$0
$0
$0
$2
47
26
ITS
$2
03
$2
22
$2
30
$3
03
$1
95
$2
33
$5
9$
32
0$
30
3$
22
4$
17
5$
23
4$
2,7
00
27
28
To
tal R
eve
nu
e T
axe
s$
20
3$
22
2$
23
0$
30
3$
19
5$
27
2$
59
$5
27
$3
03
$2
24
$1
75
$2
34
$2
,94
62
93
0P
re-T
ax
Ma
rgin
$3
6,0
99
$3
4,1
29
$3
8,2
95
$5
2,3
75
$3
2,9
00
$5
4,3
16
$9
,91
0$
24
,50
0$
20
,97
8$
15
,49
2$
12
,09
3$
16
,18
1$
34
7,2
68 2015-2016 WORKPAPER
KJB-6A PAGE 1 of 3
1S
OU
TH
JE
RS
EY
GA
S C
OM
PA
NY
22
01
5 -
20
16
BG
SS
C3
Off
-Sys
tem
Sa
les
& C
ap
ac
ity
Re
lea
se
Inc
om
e S
tate
me
nt
4 5 6 7O
ct-1
5N
ov-1
5D
ec-1
5Ja
n-16
Feb
-16
Mar
-16
Apr
-16
May
-16
Jun-
16Ju
l-16
Aug
-16
Sep
-16
8V
olu
me
s (D
T)
1,3
35
,99
5
2,2
67
,96
3
2,3
47
,04
2
1,2
03
,89
6
1
,78
5,1
49
2
,06
0,9
92
1
,06
0,1
21
4
65
,00
0
4
50
,00
0
4
65
,00
0
4
65
,00
0
4
50
,00
0
9
Sa
les
Ra
te p
er
DT
$2
.30
42
$2
.40
17
$2
.30
80
$3
.54
61
$2
.89
14
$1
.96
88
$2
.55
75
$3
.13
04
$3
.33
13
$3
.42
64
$3
.49
84
$3
.56
63
10
11
Off
-Sys
tem
Sa
les
Re
ven
ue
$3
,07
8,4
57
$5
,44
6,9
30
$5
,41
6,9
58
$4
,26
9,0
92
$5
,16
1,5
49
$4
,05
7,5
97
$2
,71
1,2
65
$1
,45
5,6
36
$1
,49
9,0
85
$1
,59
3,2
76
$1
,62
6,7
56
$1
,60
4,8
35
12
13
Ca
pa
city
Re
lea
se R
eve
nu
e$
1,1
59
,51
6$
1,9
64
,66
7$
2,0
53
,03
7$
2,1
05
,92
7$
1,8
18
,64
2$
1,8
89
,97
3$
48
8,2
30
$8
91
,26
9$
88
3,4
86
$8
91
,26
9$
89
1,2
69
$8
83
,48
61
41
5T
ota
l Re
ven
ue
$4
,23
7,9
73
$7
,41
1,5
97
$7
,46
9,9
95
$6
,37
5,0
19
$6
,98
0,1
92
$5
,94
7,5
70
$3
,19
9,4
94
$2
,34
6,9
05
$2
,38
2,5
71
$2
,48
4,5
45
$2
,51
8,0
25
$2
,48
8,3
21
16
17
18
19
Vo
lum
es
(DT
)1
,33
5,9
95
2
,26
7,9
63
2
,34
7,0
42
1
,20
3,8
96
1,7
85
,14
9
2,0
60
,99
2
1,0
60
,12
1
46
5,0
00
45
0,0
00
46
5,0
00
46
5,0
00
45
0,0
00
20
CO
G R
ate
pe
r D
T$
1.5
69
6$
1.4
47
2$
1.5
32
9$
1.9
50
5$
1.9
40
3$
1.1
07
8$
1.3
98
0$
1.9
82
0$
2.1
48
0$
2.2
78
0$
2.3
50
0$
2.3
83
02
12
2T
ota
l Co
st o
f G
as
$2
,09
6,9
80
$3
,28
2,2
40
$3
,59
7,6
92
$2
,34
8,1
59
$3
,46
3,7
57
$2
,28
3,1
76
$1
,48
2,0
83
$9
21
,63
0$
96
6,6
00
$1
,05
9,2
70
$1
,09
2,7
50
$1
,07
2,3
50
23
24
25
Pre
tax
Ma
rgin
$2
,14
0,9
94
$4
,12
9,3
57
$3
,87
2,3
04
$4
,02
6,8
60
$3
,51
6,4
35
$3
,66
4,3
94
$1
,71
7,4
11
$1
,42
5,2
75
$1
,41
5,9
71
$1
,42
5,2
75
$1
,42
5,2
75
$1
,41
5,9
71 2015-2016 WORKPAPER
KJB-6A PAGE 2 of 3
1W
OR
KP
AP
ER
KJB
-6A
Pa
ge
3 o
f 3
2IN
TE
RR
UP
TIB
LE
RA
TE
S3 4 5
Oct
-15
Nov
-15
Dec
-15
Jan-
16F
eb-1
6M
ar-1
6A
pr-1
6M
ay-1
6Ju
n-16
Jul-
16A
ug-1
6S
ep-1
66
Sa
les
Ra
te P
er
Dt
7
IGS
$1
2.9
20
4$
12
.33
20
$1
2.5
23
4$
12
.70
83
$1
2.5
04
9$
11
.97
41
$1
2.1
87
3$
12
.28
95
$1
2.4
70
1$
12
.61
15
$1
2.6
89
8$
12
.72
57
8
ITS
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
$0
.30
40
9 10
CO
G R
ate
Pe
r D
t in
cl.
Un
acc
ou
nte
d$
2.5
98
6$
2.0
49
9$
2.2
28
4$
2.4
00
8$
2.2
11
2$
1.7
16
2$
1.9
15
0$
2.0
10
3$
2.1
78
7$
2.3
10
6$
2.3
83
6$
2.4
17
11
11
2R
ate
De
riva
tion
:1
3IG
SC
ost
of
Ga
s/D
t$
2.5
98
6$
2.0
49
9$
2.2
28
4$
2.4
00
8$
2.2
11
2$
1.7
16
2$
1.9
15
0$
2.0
10
3$
2.1
78
7$
2.3
10
6$
2.3
83
6$
2.4
17
11
4/T
he
rm F
act
or
10
10
10
10
10
10
10
10
10
10
10
10
15
16
Co
st o
f G
as/
Th
$0
.25
99
$0
.20
50
$0
.22
28
$0
.24
01
$0
.22
11
$0
.17
16
$0
.19
15
$0
.20
10
$0
.21
79
$0
.23
11
$0
.23
84
$0
.24
17
17
Pro
ject
ed
NIB
T/T
h$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
0$
0.9
45
01
81
9R
ate
Be
fore
Re
ven
ue
T$
1.2
04
9$
1.1
50
0$
1.1
67
8$
1.1
85
1$
1.1
66
1$
1.1
16
6$
1.1
36
5$
1.1
46
0$
1.1
62
9$
1.1
76
1$
1.1
83
4$
1.1
86
72
02
1P
UA
$0
.00
27
$0
.00
25
$0
.00
26
$0
.00
26
$0
.00
26
$0
.00
25
$0
.00
25
$0
.00
25
$0
.00
26
$0
.00
26
$0
.00
26
$0
.00
26
22
SU
T$
0.0
84
5$
0.0
80
7$
0.0
81
9$
0.0
83
1$
0.0
81
8$
0.0
78
3$
0.0
79
7$
0.0
80
4$
0.0
81
6$
0.0
82
5$
0.0
83
0$
0.0
83
32
32
4R
ate
/Th
$1
.29
20
$1
.23
32
$1
.25
23
$1
.27
08
$1
.25
05
$1
.19
74
$1
.21
87
$1
.22
90
$1
.24
70
$1
.26
12
$1
.26
90
$1
.27
26
25
Th
erm
Fa
cto
r1
01
01
01
01
01
01
01
01
01
01
01
02
627
Rat
e/D
t$
12
.92
04
$1
2.3
32
0$
12
.52
34
$1
2.7
08
3$
12
.50
49
$1
1.9
74
1$
12
.18
73
$1
2.2
89
5$
12
.47
01
$1
2.6
11
5$
12
.68
98
$1
2.7
25
72
82
93
03
1
ITS
Ra
te/T
he
rm$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
4$
0.0
30
43
2X
Th
erm
Fa
cto
r1
01
01
01
01
01
01
01
01
01
01
01
03
334
Rat
e/D
t$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
0$
0.3
04
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1 2 3 4 5O
ct-1
5N
ov-1
5D
ec-1
5Ja
n-16
Feb
-16
Mar
-16
Apr
-16
May
-16
Jun-
16Ju
l-16
Aug
-16
Sep
-16
Tot
al6 7
Util
ity S
endo
ut1,
070,
153
2,49
2,38
44,
205,
186
5,16
0,49
04,
456,
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3,54
0,93
11,
790,
293
934,
709
596,
646
584,
863
605,
990
604,
755
26,0
43,0
858
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Mon
thly
BG
SS
198,
498
343,
852
507,
174
659,
811
857,
547
391,
728
264,
797
69,2
2413
8,85
315
7,19
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2,59
449
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3,83
1,23
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ly B
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77
78
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3,04
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1,88
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1,88
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874,
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00
00
00
00
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00
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299,
097
2,86
1,60
94,
717,
442
5,84
5,67
05,
356,
847
3,98
8,46
42,
110,
895
1,08
5,10
294
8,55
487
3,94
793
0,48
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0,81
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15 16N
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17 18T
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25,9
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27,1
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112,
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0,57
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7,61
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3,51
122
7,43
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rans
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25,4
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30,2
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22,8
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20,6
3022
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9,07
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Tra
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182,
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Dom
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81,0
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36,6
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00
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5,39
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128
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1,62
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S C
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r F
uel 1
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00
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sor
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00
00
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11,9
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11,9
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11,6
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esso
r F
uel 0
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00
00
00
042
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142
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141
12,
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33T
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esso
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uel 0
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00
00
00
013
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717
517
514
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734
Dom
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pres
sor
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l 1.9
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00
00
00
1,28
71,
107
1,15
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807
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uel 2
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35,
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36 37T
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3,00
016
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2,80
240
9,23
825
1,73
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9,04
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231,
917
1,18
8,08
51,
162,
625
1,11
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071,
508
1,04
5,36
88,
886,
021
38 39T
otal
Req
uire
men
ts1,
962,
097
3,02
9,20
45,
130,
244
6,25
4,90
85,
608,
579
4,15
7,50
43,
342,
812
2,27
3,18
72,
111,
180
1,98
7,05
82,
001,
988
1,77
6,18
639
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y
2015-2016 WORKPAPER TWR-1 PAGE 1 of 2
1 2 3 4 5O
ct-1
5N
ov-1
5D
ec-1
5Ja
n-16
Feb
-16
Mar
-16
Apr
-16
May
-16
Jun-
16Ju
l-16
Aug
-16
Sep
-16
Tot
al6 7
Net
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With
draw
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8 9T
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036
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48,6
9443
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11,8
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00
00
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0,15
610
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nsco
SS
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2)0
256,
468
403,
126
465,
915
365,
780
273,
386
00
00
00
1,76
4,67
511
Tra
nsco
ES
S0
41,9
9115
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713
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182
20,5
1515
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20,0
0031
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200,
435
12T
rans
co G
SS
28,3
7063
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194,
117
344,
511
540,
180
172,
898
112,
390
50,0
000
00
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015
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co L
NG
(LG
A)
00
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00
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264,
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336,
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219,
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00
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Col
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a F
SS
145,
259
317,
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477,
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166
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00
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025 26
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urch
ases
- C
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177,
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240
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2015-2016 WORKPAPER TWR-1 PAGE 2 of 2
1 2 3 4 5O
ct-1
5N
ov-1
5D
ec-1
5Ja
n-16
Feb
-16
Mar
-16
Apr
-16
May
-16
Jun-
16Ju
l-16
Aug
-16
Sep
-16
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2015-2016 WORKPAPER TWR-2 PAGE 1 of 2
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2015-2016 WORKPAPER TWR-2 PAGE 2 of 2
PREPARED DIRECT TESTIMONY 1 OF 2
BRUCE S. GROSSMAN 3 PROGRAM MANAGER, RESIDENTIAL ENERGY EFFICIENCY 4
SOUTH JERSEY GAS COMPANY 5 JUNE 2016 6
7 8
9 I. INTRODUCTION 10
My name is Bruce S. Grossman, and my business address is One South Jersey Plaza, Route 11
54, Folsom, New Jersey. I am the Program Manager, Residential Energy Efficiency for the 12
Energy Efficiency Education and Consulting (“EEECO”) Department for South Jersey Gas 13
(“South Jersey” or the “Company”). In this position, I plan, direct and oversee the 14
activities of the Conservation Department, and manage the residential activities of the 15
Company’s EEECO Department. I also represent the Company in civic and regulatory 16
forums related to conservation and energy efficiency. My responsibilities also include the 17
development, implementation, and management of customer directed energy efficiency 18
programs. In total, I have been with the Company for over 37 years, serving the Company 19
in various managerial positions. Prior to serving the Company in my current role, I was the 20
Manager of Energy Programs for nine years. 21
I have been responsible for the Company’s residential, commercial and industrial retail 22
sales, and facilitated negotiations for natural gas contracts with some of the Company’s 23
largest customers. Since March of 2001, I have represented South Jersey as one of seven 24
utility managers who work with the administrator of the New Jersey Clean Energy Program 25
™, within the New Jersey Board of Public Utilities (“Board” or “BPU”) Office of Clean 26
Energy. In that capacity, I was the Senior Utility Sponsor for the Commercial/Industrial 27
Construction Program, otherwise known as the SmartStart Buildings Program ®, the 28
2
Convener of the Combined Heat and Power Program and the Utility Sponsor for the Home 1
Performance with Energy Star Program. 2
I previously represented South Jersey on all of the New Jersey Clean Energy Efficiency 3
working groups and chaired the Commercial/Industrial Subcommittee of the New Jersey 4
Clean Energy Council. 5
I currently serve as a member on the Energy Efficiency committee of the Clean Energy 6
Council, serve on various committees with the Consortium for Energy Efficiency, and I 7
also serve on the American Gas Association (AGA) Sustainable Growth Committee. For 8
the past several years, I have served as the Senior Utility Sponsor for the Comfort Partners, 9
Low Income Working Group, which manages the Comfort Partners Low Income Program, 10
administered by the BPU Office of Clean Energy. In 2012, I was asked to serve on the 11
Sustainable Growth Committee of the American Gas Association. I earned a Bachelor of 12
Arts degree in Honors Political Science from Rutgers University, Camden College of Arts 13
and Sciences, and a Master’s Degree in Public Policy from the Rutgers School of Public 14
Policy, Camden, NJ. 15
II. PURPOSE OF TESTIMONY 16
The purpose of my testimony is to provide information about the conservation oriented 17
initiatives that South Jersey has launched since the Conservation Incentive Program 18
(“CIP”) was originally approved by the Board on October 12, 2006 in BPU Docket No. 19
GR0512019, as further extended on January 20, 2010 and again on May 21, 2014. I will 20
also provide actual cost information for each of these programs. 21
22
23
3
III. BACKGROUND 1
The CIP has enabled South Jersey to share the common goal of energy efficiency with its 2
customers and local, State and national level policy-makers. For several years, the 3
Company has been in a position to manage and develop energy conservation programs 4
collaboratively with the BPU and other utilities. The Board's approval of the CIP has 5
aligned the Company's interests with those of its customers, as the program has eliminated 6
the Company’s financial disincentive to promote methods and opportunities for customers 7
to reduce their natural gas consumption and their bills. 8
The Board’s approval of the CIP, and other significant efforts such as the initiation of the 9
New Jersey Clean Energy Program, have recast public policy concerning the efficient use 10
of natural gas and its effect on the environment. The CIP and the promotion of energy 11
efficiency have become an integral part of our Company's culture. For example, the focus 12
of South Jersey's residential and commercial and industrial (“C&I”) sales force has shifted 13
from increasing customer natural gas consumption, to promoting specific customer-focused 14
programs that encourage conservation and energy efficiency. 15
Moreover, in September of 2009, the Company redefined its approach to the marketplace 16
by restructuring its Sales Department. The department is now known as the Energy 17
Efficiency Education and Consulting Department. The new management structure 18
embedded the implementation of energy efficiency programming into our sales and 19
marketing efforts. Company representatives in this department are referred to as 20
consultants, and have been exposed to various energy efficiency training seminars and 21
courses. Customers are not only educated about the benefits of natural gas service, but they 22
are also educated about energy efficiency. In fact, the residential and commercial subsets of 23
4
the EEECO department each have an energy efficiency implementation focus and a 1
consultative focus. The former concentrates on programming, such as the energy efficiency 2
installation offers that are available from the State of New Jersey and from the Company. 3
The latter concentrates on educating customers on energy efficiency as they become part of 4
the South Jersey network. 5
Through this restructuring, South Jersey has tied together the themes of energy efficiency, 6
comfort and savings. We will continue to promote the efficient use of natural gas through 7
the use of better technology, energy education, and sensible energy consumption patterns 8
through targeted presentations, and through partnerships with public entities and nonprofit 9
organizations, to promote energy efficiency program outreach to a variety of audiences. 10
Finally, strategic energy efficiency communication is fully integrated into South Jersey’s 11
CIP. A communications strategy focusing on the CIP and its benefits to customers and 12
shareholders is not viewed as a separate program, but rather a corporate initiative. It 13
remains our goal to educate political leaders, corporate executives, business leaders, and 14
building managers about the facts associated with the CIP and to bring to light the vast 15
array of energy programs, policies, and practices necessary to achieve sustainable energy 16
efficiency in the market place. 17
18
IV. REVIEW OF CURRENT PROGRAMS 19
Attached to my testimony as Exhibit BSG-1 is the Company’s thirty-sixth (36th) CIP 20
quarterly report, which was filed with the Board on November 5, 2015. The information 21
contained in Exhibit BSG-1 illustrates the Company’s energy efficiency and conservation 22
related accomplishments during the eighth year of the CIP, which encompassed the time 23
5
period of October 2014 to September 2015. I have also attached as Exhibit BSG-2 the 1
Company’s thirty- eight (38th) CIP quarterly report, which was filed with the Board on May 2
2, 2016. The information contained in Exhibit BSG-2 summarizes the Company’s energy 3
efficiency and conservation related accomplishments during the first half of the current CIP 4
year, which encompasses the time period October 2015 to March 2016. This CIP quarterly 5
report illustrates how CIP programming has evolved into initiatives that promote energy 6
efficiency with a sense of urgency towards educating policy makers, energy program 7
designers, and trade ally contractors on the critical relationships between building science 8
and the installation of high efficiency heating and water heating equipment. Exhibit BSG-2 9
provides details of each program implemented in the tenth (10th) year of the CIP and 10
contains program-specific material used to promote those programs. The following 11
discussion provides a summary and status of the programs that continue to resonate with 12
our customers. 13
Local on the 8’s 14
This program was originally launched in January 2007 and continues to be a successful 15
method of promoting energy efficiency and conservation to our customers. In 2014, 16
South Jersey again utilized the exposure of the Weather Channel and placed messages 17
on the “ribbon” during the “Local Weather On the 8’s Message” from January 2015 18
through April 2015. The use of cable television enables companies to target messages 19
to specific regions and a diverse demographic within a market area. The viewers, who 20
watched the weather forecast and alerts every eight minutes, also saw South Jersey's 21
message to exercise energy efficiency practices. This messaging effort was aired 22
during some of the most challenging weather days experienced in several years. 23
6
Messages directed customers to visit the New Jersey Office of Clean Energy website 1
and the South Jersey Gas website to learn more about home audits, statewide programs, 2
and equipment rebates. During the winter of 2016, this program was phased out. The 3
primary reason is that advances in mobile devices have made viewing weather events 4
part of the low cost smartphone and tablet platform. The Company would rather direct 5
funds used for this initiative for other means that could have more impact on the 6
customer to save energy. More detail regarding this change will be discussed in 7
upcoming reports. 8
Outreach 9
Our market is represented by various chambers of commerce, trade associations, and 10
other public and private organizations that support economic enterprise and promote 11
public welfare. To promote energy efficiency programming entities, South Jersey 12
established an outreach program to communicate to local and state institutional 13
constituents, and created supportive relationships with trade ally organizations. The 14
purpose of this outreach is to illustrate how better energy practices will lead to lower 15
operating costs, and ultimately, savings for ratepayers and taxpayers. 16
For example, the Company continued its work to support a call center designed to 17
enhance our approach to better communicate with our customers, and answer questions 18
related to energy efficiency. This call center is part of a much larger campaign known 19
as “Keep it Simple,” and is an extension of the previous “Simple is Beautiful” 20
campaign. The concept is to clearly show customers that upgrading to energy efficiency 21
neither painful nor complicated, and can be done simply and seamlessly by leveraging 22
the resources available to our collective customers. The collective goal is to engage our 23
7
customers, and to provide them with a dedicated virtual call center, which began 1
operations on August 20, 2015 that can now assist in providing our callers with 2
information about the program that is the best fit for them. Over the first quarter of 3
2016, the call center experienced increased monthly activity in terms of minutes of 4
utilization. Specifically, in January 2016 there were 402.28 minutes, in February there 5
were 259.32 minutes, and in March there were 536.72 minutes. We encourage our 6
customers and trade allies to view the offerings found on this newly created very 7
informative website; www.sjgsimple.com, or to call 856-678-5860. Moreover, in the 8
month of April 2016, the Company enhanced its website further with the “Be South 9
Jersey Smart” campaign. The Company continues its efforts to leverage its partnership 10
approach with the NJ Clean Energy Program, in order to offer customers the most 11
energy value available to them. 12
The Company has also continued its involvement with the American Gas Association 13
(AGA), and with the Consortium for Energy Efficiency in an effort to engage with 14
various energy efficiency organizations, as well as its involvement with the 15
Environment Protection Agency (EPA) to find common ground whereby energy 16
efficiency gains can be gleaned according to best practices and market acceptance. An 17
example of this is our sponsorship toward the “National Awareness of Energy Star ® 18
for 2015”, Analysis of CEE Energy Star Household Awareness Survey (Please see 19
letter of acknowledgement attached to my testimony as Exhibit BSG – 3). 20
The Company promoted our theme of energy efficiency by emphasizing the importance 21
of crafting messages that are meaningful to the customer. It has become evident that 22
consumers desire more than energy efficiency and want a benefit that satisfies their 23
8
value proposition. For many residential customers, that benefit is comfort at an 1
affordable price. The Company is also making efforts to evolve from a broadcast 2
media platform, which may have limited reach to our customers, to a more direct and 3
modern approach. For an example, please see a SJG energy efficiency message at: 4
https://www.youtube.com/watch?v=oFaeE87mCVs 5
The Company continues to reach out to municipal and other civic and efficiency 6
minded constituents by participating in a variety of programs both inside and outside 7
our service territory. For example, the Company has been represented at community 8
and national industry functions. On October 20 – 21, SJG participated as a Platinum 9
Sponsor, for the Affordable Comfort Institute Conference in Cherry Hill, NJ, and also 10
participated as one of the presenters. On November 4 – 5, 2015, the Company was 11
represented in a Sustainable Growth Committee Conference with the AGA in 12
Alexandria, VA. The purpose of the conference was to discuss the implications of the 13
impending federal Department of Energy rules concerning the implementation of the 14
new furnace and boiler standards, as well as updates on the Clean Power Plan as a 15
compliance option for states. 16
During the fourth quarter of 2016, the Company continued to embark upon a targeted 17
campaign, designed to serve local strategic communities. These efforts included various 18
public outreach events, including Sound Off for South Jersey (Atlantic City); AC 19
Chamber of Commerce Business Showcase (Somers Point); Atlantic Builders 20
Convention (Wildwood); and the Atlantic County Plumbers Association (Somers 21
Point). Since the inception of the CIP, South Jersey has participated in numerous events 22
with various groups and organizations, and makes Company representatives available 23
9
to offer formal presentations regarding energy efficiency programs to any group upon 1
request. 2
Additionally, SJG utilized their social media to promote available financing and rebates 3
with spots running on Comcast starting in September and running through February 4
2016. 5
6
Aclara (Nexus) Dashboard Program 7
On March 8, 2008, the Company launched the Nexus (now known as Aclara) Prism 8
Dashboard System. The Prism System was an electronic platform that interfaced with 9
South Jersey’s billing system and provided customers meaningful information to help 10
them understand, compare, and manage their natural gas bills. Most importantly, it was 11
designed to motivate customers to implement conservation measures in order to reduce 12
their consumption and energy costs. The program offered our customers a better 13
understanding of what drove their energy bills. It also leveraged the web self - service 14
feature to promote conservation and energy efficiency by illustrating how the customer 15
could save money through improved energy behaviors and by installing energy saving 16
devices and technologies. South Jersey promoted the dashboard program through our 17
website and through direct “on bill” messaging. The promotional tag line for this 18
program was “Take Control of Your Gas Bill”. Unfortunately, after many years of 19
engagement with Aclara, and its predecessor, Nexus, SJG determined that there are 20
other opportunities that could better serve our customers’ capabilities to be more energy 21
conscious and in February 2016 SJG decided to discontinue operations with Aclara. 22
10
Though South Jersey’s and Aclara’ s IT teams worked toward making the site more 1
user friendly, customer participation for this website has dropped off significantly. 2
Therefore, after many years of engagement with this Aclara, and its predecessor, 3
Nexus, SJG has determined that there are other opportunities that could better serve our 4
customer’s capabilities to be more energy conscious, and discontinued operations with 5
Aclara on February 29, 2016. 6
Sustainable Jersey Program 7
In 2013, the Company began taking a more global view of sustainability and energy 8
efficiency messaging. To foster that effort, the Company engaged with Sustainable 9
Jersey and made a substantial contribution to foster their efforts to create a “South 10
Jersey Hub.” Sustainable Jersey provides financial resources and support for 11
sustainability programs and encourages participation in clean energy and energy 12
efficiency programs. With South Jersey’s contribution, Sustainable Jersey has been 13
able to make significant inroads to foster initiatives throughout Southern New Jersey. 14
In March of 2016, the Company again provided $150,000 to help fund the new 15
Sustainable Jersey for Schools Program. Sustainable Jersey for Schools is a voluntary 16
certification program for New Jersey public schools that provides tools, training and 17
financial incentives to support and reward schools as they pursue sustainability 18
programs such as energy efficiency, renewable energy and climate mitigation. 19
20
V. REVIEW OF CURRENT CIP YEAR PROGRAM EXPENSES 21
Quarterly expenses incurred for each of South Jersey's CIP programs are summarized in 22
Exhibits BSG-1 and BSG-2, attached to this testimony. During the first half of the CIP 23
11
year, which encompasses the time period October 2015 to March 2016, South Jersey 1
invested $214,719 in these programs. With the Company’s involvement in Sustainable 2
Jersey, increased targeted and cost effective media promotions, and concentrated outreach 3
within the communities we serve and the industries that support and foster an energy 4
efficiency economy, South Jersey projects that it will spend approximately $500,000 by the 5
conclusion of the CIP year on September 30, 2016. 6
7
VI. CONCLUSION 8
This testimony has provided an overview of the programs in effect during the 2014 -2015 9
CIP year, as well as insights into the 2015-2016 CIP year programs and their related 10
expenditures. All of South Jersey’s CIP programs are designed to complement current 11
energy policies articulated by the Board and the State of New Jersey and are intended to 12
motivate customers to use energy wisely and reduce their costs. 13
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BSG-3
SOUTH JERSEY GAS COMPANY
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY
I. INTRODUCTION 1
Q. Please state your name, affiliation and business address. 2
A. My name is Daniel P. Yardley. I am Principal, Yardley & Associates and my 3
business address is 2409 Providence Hills Drive, Matthews, NC 28105. 4
Q. On whose behalf are you testifying? 5
A. I am testifying on behalf of South Jersey Gas Company (“South Jersey Gas” or 6
the “Company”). 7
Q. Please summarize your professional and educational background. 8
A. I have been employed as a consultant to the natural gas industry for over twenty-9
five years. During this period, I have directed or participated in numerous 10
consulting assignments. A number of these assignments involved the 11
development of gas distribution company cost allocation, pricing, service 12
unbundling, revenue decoupling and other tariff analyses. In addition to this 13
work, I have performed interstate pipeline cost of service, rate design and service 14
unbundling analyses; gas supply planning analyses; and financial evaluation 15
analyses. I received a Bachelor of Science Degree in Electrical Engineering from 16
the Massachusetts Institute of Technology in 1988. 17
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 2 OF 12
Q. Have you previously testified before the New Jersey Board of Public 1
Utilities? 2
A. Yes. I testified before the New Jersey Board of Public Utilities (the “Board”) on 3
behalf of South Jersey Gas, Elizabethtown Gas Company and New Jersey Natural 4
Gas Company (“NJNG”) in a number of different proceedings. I sponsored 5
testimony in 2005 that supported the Company’s petition to implement an 6
innovative rate design that promoted customer conservation and energy 7
efficiency, which led to the development of the Company’s Conservation 8
Incentive Program (“CIP”), and in 2013 that supported continuation of the CIP. I 9
have also testified or sponsored pre-filed testimony in proceedings before a 10
number of other State utility regulatory commissions, the Federal Energy 11
Regulatory Commission and the National Energy Board of Canada on matters 12
pertaining to cost of service, cost allocation, rate design, revenue decoupling and 13
upstream capacity planning. 14
Q. What is the purpose of your testimony in this proceeding? 15
A. The purpose of my testimony is to describe South Jersey Gas’ CIP and present the 16
derivation of the associated tariff charges resulting from the operation of the 17
program for the annual period ending September 30, 2016. 18
Q. Are you sponsoring any exhibits that accompany your prepared direct 19
testimony? 20
A. Yes. I am sponsoring the following exhibits, each of which will be explained 21
later in my testimony: 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 3 OF 12
Exhibit No. DPY-1: Actual CIP Results for 2014-15 1
Exhibit No. DPY-2: Comparison of 2015-16 Customer Usage to 2 Baseline 3
Exhibit No. DPY-3: Calculation of Large Customer Adjustment 4
Exhibit No. DPY-4: Determination of Weather-Related Component of 5 CIP 6
Exhibit No. DPY-5: Application of BGSS Savings Eligibility Test 7
Exhibit No. DPY-6: Prior Period CIP Over / Under Recovery 8
Exhibit No. DPY-7: Derivation of CIP Charge / Credit Effective October 9 1, 2016 10
Exhibit No. DPY-8: Proposed Tariff Sheets 11
II. DESCRIPTION OF THE CIP 12
Q. How was the Company’s CIP developed? 13
A. Following a period of relatively low and stable prices throughout the 1990s, 14
natural gas commodity prices experienced increased volatility and higher market 15
clearing prices in the ensuing years as the growing demand for natural gas to fire 16
electric generation contributed to a significant tightening of the supply-demand 17
balance. Prices continued to rise following major hurricanes that damaged Gulf 18
Coast production in the summer of 2005. South Jersey Gas together with NJNG 19
developed and proposed an innovative program late in 2005 that would allow 20
them to aggressively promote energy efficiency and conservation by customers. 21
A necessary component of the proposal was the implementation of a tariff 22
mechanism that eliminated the link between throughput and margin recoveries. 23
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 4 OF 12
South Jersey Gas and NJNG, together with Board Staff and the New Jersey 1
Department of the Public Advocate, Division of Rate Counsel (“Rate Counsel”) 2
worked diligently to agree on the terms of a pilot program. The CIP was agreed 3
to by these parties pursuant to the CIP Stipulation, which was approved by the 4
Board for implementation on October 1, 2006. In January 2010, the Board 5
extended the CIP for an additional three-to-four year period. In May of 2014, the 6
Board approved continuation of the CIP with limited modifications as agreed to 7
by the Company, NJNG, Board Staff and Rate Counsel (“2014 CIP Stipulation”). 8
Q. How does the CIP promote energy efficiency and conservation? 9
A. The CIP is comprised of customer-oriented conservation programs and an 10
innovative tariff mechanism that normalizes South Jersey Gas’ margin recoveries 11
for the impact of conservation and other changes in customer use. The CIP tariff 12
more appropriately aligns South Jersey Gas’ interests with those of its customers 13
as any customer savings from conservation do not contribute negatively to the 14
Company’s financial performance. Elimination of the disincentives to pursue 15
customer conservation has enabled South Jersey Gas to implement new initiatives 16
that capitalize on various channels for promoting conservation by its customers. 17
Q. Is the CIP consistent with the current public policy direction in New Jersey? 18
A. Yes. The CIP promotes cost-effective energy choices by consumers by equipping 19
them with greater information concerning their consumption patterns. To the 20
extent South Jersey Gas customers participate in programs to install or upgrade 21
existing equipment with high efficiency alternatives, the New Jersey economy 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 5 OF 12
and the environment benefit. The CIP contributes to economic benefits through 1
the local jobs supported by the contractor activity and the lower cost of energy use 2
to customers. The CIP also contributes to environmental benefits as higher 3
efficiency equipment leads to reductions in greenhouse gas emissions. These 4
benefits are consistent with New Jersey energy policy objectives. 5
Q. Please summarize the important features of the CIP Tariff. 6
A. Details of the CIP mechanism are set forth as Rider M of South Jersey Gas’ tariff. 7
Rider M is applicable to all residential and general service customers. The CIP 8
tariff establishes a baseline monthly usage for four different groups of South 9
Jersey Gas customers: (i) residential non-heating, (ii) residential heating, (iii) 10
general service, and (iv) general service – large volume. Additionally, Rider M 11
sets forth the calculation method for establishing the charge or credit for each 12
applicable class based on a comparison of actual usage to the baseline usage and 13
on class-specific margin factors. Rider M also reflects features that potentially 14
limit the Company’s recoveries in a given year. These include limitations upon 15
the recovery of the margin impact of non-weather related changes in use, and a 16
requirement that total recoveries not contribute to the Company earning in excess 17
of 9.75% return on equity. 18
Q. Please describe the recovery limitations applicable to the non-weather 19
related CIP amount. 20
A. The CIP incorporates a recovery limitation specifically applicable to changes in 21
average consumption that are not attributable to weather. This is referred to as the 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 6 OF 12
non-weather component of the CIP amount and is determined by subtracting the 1
weather component from the total CIP amount. The non-weather component is 2
subject to a recovery limitation determined through the application of a two-3
pronged test. The first prong of the recovery test limits recoveries for any amounts 4
whereby BGSS savings are less than 75% of the non-weather component. The 5
second prong of the recovery test limits recoveries for any amounts whereby 6.5% 6
of variable margin revenues are less than the non-weather component. The 7
amount of the non-weather component that does not pass both of these recovery 8
limits is deferred to the subsequent year and is included in the non-weather 9
component subject to the two-pronged test at that time. 10
Q. Please explain the source of BGSS savings that are relied upon for the BGSS 11
savings test. 12
A. BGSS savings result from gas supply contract restructurings, avoided costs or 13
other purchasing practices that benefit customers by lowering BGSS costs. The 14
2014 CIP Stipulation specifies the categories of BGSS savings as well as an initial 15
level of verified BGSS savings. In the current filing, the Company is supporting 16
total BGSS savings of $8.6 million as further described in the testimony of 17
Timothy Rundall. The $8.6 million of BGSS savings includes $2.2 million of 18
permanent capacity release savings, $6.1 million of additional capacity release 19
savings and $0.3 million of avoided cost BGSS savings. 20
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 7 OF 12
Q. What steps are necessary to calculate the annual CIP charge or credit? 1
A. The calculation of the Rider M adjustment is performed for each of the four 2
customer groups subject to the clause, resulting in a single credit or charge 3
applicable to all customers within each grouping. The calculation begins by 4
dividing the actual customers for each month into the actual booked volumes to 5
establish an actual average use per customer. An adjustment to the number of 6
general service and general service large volume customers is made to reflect any 7
large customers that have been added to the system. 8
Next, the monthly average use per customer value is compared to the baseline 9
usage per customer for the corresponding customer group. This difference 10
represents the average usage impact for all customers in the class for the month. 11
In order to determine the total volume impact for the class, the monthly 12
differences are multiplied by the corresponding actual number of customers. 13
The margin impact is simply the usage impact multiplied by the margin revenue 14
factor for the customer group set forth in Rider M. The charge or credit for the 15
group is the total margin adjustment divided by the forecasted sales for the 16
recovery period. Since the charge or credit is derived based on projected 17
throughput, any over or under-recovery from the prior recovery period is included 18
in the calculation of the charge or credit for the current period. 19
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 8 OF 12
III. CONSERVATION INCENTIVE PROGRAM RESULTS FOR 2014-15 1
Q. What time period is covered under this CIP filing? 2
A. This filing addresses the annual period beginning October 1, 2015 through 3
September 30, 2016. The schedules supporting this filing are based on seven 4
months of actual data and five months of projected data for the period. The 5
resulting charge or credit, including any over or under recovery for the prior 6
period, is applied to customer bills beginning on October 1, 2016. The timing of 7
the CIP rate adjustments was agreed to in order to synchronize them with the 8
review and implementation of South Jersey Gas’ annual BGSS filing. 9
Q. Have you prepared a summary of results for the prior year of the CIP 10
program covering the twelve month period ending September 30, 2015? 11
A. Yes. Now that the annual period covered by the previous year of the CIP is 12
complete, actual results for this time period can be calculated. Exhibit No. DPY-1 13
provides the actual results for the year ending September 30, 2015 for each of the 14
four groups, which reflect a combined total of $18.0 million margin revenue 15
above the benchmark level, including the both weather and non-weather impacts. 16
Q. Please provide a comparison of customer usage to the benchmark for the 17
annual period beginning October 1, 2015. 18
A. Actual average use per customer for October 2015 through April 2016 and 19
projections through September 2016 are provided for each of the customer groups 20
covered by the CIP tariff in Exhibit No. DPY-2. Exhibit No. DPY-2 also 21
provides a comparison of the actual values shown in column (d) to the baseline 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 9 OF 12
values set forth in Rider M and shown in column (e). The margin impact of the 1
difference in average use per customer is calculated by multiplying the change in 2
average use per customer times the actual number of customers times the margin 3
revenue factor. The margin revenue factor for each customer group is also set 4
forth in Rider M. The monthly benchmark use per customer and margin revenue 5
factors reflect the Company’s currently-effective base rates. The total impact of 6
changes in average use per customer for the period results in a margin reduction 7
of $27.7 million below the benchmark level. 8
Q. Does the comparison reflected in Exhibit No. DPY-2 reflect the large 9
customer adjustment as provided for in Rider M? 10
A. Yes. The actual number of customers for the general service and general service 11
large volume customer groups shown in column (c) of Exhibit No. DPY-2 reflects 12
an adjustment for large customer additions to South Jersey Gas’ system. As 13
specified in Rider M, an adjustment is made for any incremental general service 14
customer that exceeds 1,200 cubic feet per hour of connected load and any 15
general service large volume customer that exceeds 50,000 cubic feet per hour of 16
connected load. The incremental load for these customers is converted into an 17
equivalent number of additional customers to be included in the Rider M 18
calculations going forward. This removes any potential disincentive to 19
connecting beneficial, large customer loads. The level of the monthly large 20
customer adjustment applicable for the period October 1, 2015 through September 21
30, 2016 is provided as Exhibit No. DPY-3. 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 10 OF 12
Q. Have you performed the dual pronged eligibility test applicable to the non-1
weather component of the CIP for the current year? 2
A. Yes. I determined the weather related component of the CIP by calculating the 3
margin impact of weather consistent with the terms of South Jersey Gas’ 4
Temperature Adjustment Clause. The calculation of the weather related 5
component for each customer group is provided in Exhibit No. DPY-4. The total 6
weather related component, which equals $21.9 million of revenue deficiency, is 7
subtracted from the total CIP additional revenue deficiency of $27.7 million to 8
establish the non-weather related component for the current period, which is a 9
revenue deficiency of $5.8 million. The modified BGSS Savings test and the 10
variable margin revenue test are shown on Exhibit No. DPY-5. Since the $5.8 11
million passes both of these two prongs of the CIP non-weather eligibility test, it 12
is recoverable in rates beginning October 1, 2016. 13
Q. Please provide the derivation of the CIP charge or credit to be effective 14
October 1, 2016. 15
A. The total amount of the CIP that is refunded to customers through Rider M is the 16
combination of the weather and non-weather related margin impacts, or $27.7 17
million. Recovery of this amount would not result in the Company exceeding the 18
ROE limitation set forth in Rider M. The weather and non-weather related CIP 19
amounts are collected through customer group-specific charges based on 20
projected throughput for the annual period beginning October 1, 2016. The 21
throughput forecast is the same as that proposed to be utilized to establish the 22
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 11 OF 12
BGSS price effective October 1, 2016. In addition to the CIP amount for the 1
current year, the calculated charges also include the net over-collection of the CIP 2
for the recovery period ending September 30, 2015 of $3.3 million, which is 3
shown in Exhibit No. DPY-6. 4
The derivation of the resulting CIP charges is set forth in Exhibit No. DPY-7. 5
This exhibit also shows the application of state taxes and assessments in order to 6
establish rates billed to customers. 7
Q. Are you sponsoring revised tariff sheets that implement these charges? 8
A. Yes. Exhibit No. DPY-8 provides proposed tariff sheets that reflect the CIP 9
charges to be effective October 1, 2016. 10
Q. Given that the CIP charge or credit is based in part on projected data, how 11
will these projections be trued up in the future? 12
A. The actual CIP recoveries or credits to customers will be trued up in future filings. 13
The first element of the true-up will reflect any adjustment to the recoverable 14
amount based on actual data for the period May 1, 2016 through September 30, 15
2016, which represents the final five months of the current year of the CIP. The 16
second element of the true-up relates to differences between actual and projected 17
throughput for the annual period beginning October 1, 2016, which is the period 18
over which the CIP charge or credit is collected. The true-up of these elements 19
for actual experience will be reflected in the docket addressing the Company’s 20
CIP filing to be made on or before June 1, 2016. 21
PREPARED DIRECT TESTIMONY OF DANIEL P. YARDLEY PAGE 12 OF 12
Q. Does this conclude your prepared direct testimony? 1
A. Yes, it does. 2
Exhibit No. DPY-1Page 1 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Comparison of 2014-15 Customer Usage to Baseline
Margin MarginLine Total Class Number of Average Baseline Difference Revenue Excess /No. Month Throughput Customers Use / Cust. Use / Cust. Per Cust. Factor (Deficiency)
(a) (b) (c) (d) = (b) / (c) (e) (f) = (d) - (e) (g) (h) = (f) * (c) * (g)
1 Group 1: RSG Non-Heating2 Actual Year-to-Date3 October '14 145,711 12,455 11.7 13.6 (1.9) 0.498637$ (11,496)$ 4 November '14 190,969 12,376 15.4 13.8 1.7 0.498637$ 10,371$ 5 December '14 298,835 12,275 24.3 20.7 3.6 0.498637$ 22,310$ 6 January '15 369,957 12,213 30.3 23.5 6.8 0.498637$ 41,363$ 7 February '15 450,978 12,204 37.0 23.3 13.7 0.498637$ 83,085$ 8 March '15 448,148 12,225 36.7 27.7 9.0 0.498637$ 54,608$ 9 April '15 258,065 12,249 21.1 19.7 1.4 0.498637$ 8,357$
10 May '15 133,859 12,257 10.9 14.0 (3.1) 0.498637$ (18,818)$ 11 June '15 141,114 12,271 11.5 11.4 0.1 0.498637$ 611$ 12 July '15 125,809 12,275 10.2 11.5 (1.3) 0.498637$ (7,656)$ 13 August '15 105,482 12,275 8.6 11.2 (2.6) 0.498637$ (15,955)$ 14 September '15 120,879 12,252 9.9 10.0 (0.1) 0.498637$ (818)$
15
16 227.6 200.317181920 21 Total Group 1 Margin Excess / (Deficiency) 165,962$
22
232425 Group 2: RSG Heating26 Actual Year-to-Date27 October '14 8,967,409 326,841 27.4 34.1 (6.6) 0.498637$ (1,077,817)$ 28 November '14 28,274,538 327,574 86.3 76.8 9.5 0.498637$ 1,557,446$ 29 December '14 41,230,499 329,875 125.0 126.4 (1.4) 0.498637$ (235,506)$ 30 January '15 56,804,811 330,456 171.9 157.0 14.9 0.498637$ 2,454,899$ 31 February '15 58,487,945 330,586 176.9 135.3 41.6 0.498637$ 6,861,075$ 32 March '15 46,246,697 331,819 139.4 104.3 35.1 0.498637$ 5,803,125$ 33 April '15 15,825,236 332,436 47.6 51.9 (4.3) 0.498637$ (712,150)$ 34 May '15 6,696,506 332,494 20.1 29.6 (9.5) 0.498637$ (1,568,371)$ 35 June '15 4,946,224 332,845 14.9 15.6 (0.7) 0.498637$ (122,743)$ 36 July '15 4,250,994 332,655 12.8 14.7 (1.9) 0.498637$ (318,646)$ 37 August '15 6,785,382 332,776 20.4 13.3 7.1 0.498637$ 1,176,515$ 38 September '15 5,007,048 332,864 15.0 16.8 (1.8) 0.498637$ (291,736)$
3940 857.7 775.84142434445 Total Group 2 Margin Excess / (Deficiency) 13,526,091$
Exhibit No. DPY-1Page 2 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Comparison of 2014-15 Customer Usage to Baseline
2011-12 Actual per Books Margin MarginLine Total Class Number of Average Baseline Difference Revenue Excess /No. Month Throughput Customers Use / Cust. Use / Cust. Per Cust. Factor (Deficiency)
(a) (b) (c) (d) = (b) / (c) (e) (f) = (d) - (e) (g) (h) = (f) * (c) * (g)
1 Group 3: GSG2 Actual Year-to-Date3 October '14 4,438,384 23,976 185.1 218.6 (33.5) 0.398903$ (320,227)$ 4 November '14 9,984,212 24,294 411.0 445.8 (34.8) 0.398903$ (337,493)$ 5 December '14 11,758,814 24,560 478.8 613.3 (134.5) 0.398903$ (1,317,615)$ 6 January '15 20,165,885 24,679 817.1 645.9 171.2 0.398903$ 1,685,652$ 7 February '15 23,657,780 24,716 957.2 622.2 335.0 0.398903$ 3,302,711$ 8 March '15 12,958,780 24,829 521.9 512.4 9.5 0.398903$ 94,301$ 9 April '15 5,155,549 24,891 207.1 261.6 (54.5) 0.398903$ (540,887)$
10 May '15 3,484,849 24,812 140.5 160.2 (19.7) 0.398903$ (195,476)$ 11 June '15 3,438,265 24,728 139.0 118.4 20.6 0.398903$ 203,628$ 12 July '15 3,500,780 24,715 141.6 104.0 37.6 0.398903$ 371,147$ 13 August '15 4,826,130 24,696 195.4 130.5 64.9 0.398903$ 639,562$ 14 September '15 2,483,351 24,710 100.5 122.4 (21.9) 0.398903$ (215,868)$ 1516 4,295.3 3,955.31718192021 Total Group 3 Margin Excess / (Deficiency) 3,369,435$
22
232425 Group 4: GSG Large Volume26 Actual Year-to-Date27 October '14 1,864,002 169 11,029.6 10,817.7 211.9 0.216751$ 7,762$ 28 November '14 3,402,179 172 19,780.1 17,479.9 2,300.2 0.216751$ 85,755$ 29 December '14 3,810,845 173 22,028.0 25,743.1 (3,715.1) 0.216751$ (139,308)$ 30 January '15 6,593,339 173 38,111.8 29,051.9 9,059.9 0.216751$ 339,727$ 31 February '15 5,729,292 172 33,309.8 24,583.0 8,726.8 0.216751$ 325,347$ 32 March '15 4,206,696 173 24,316.2 21,049.1 3,267.1 0.216751$ 122,508$ 33 April '15 2,237,575 175 12,786.1 14,872.7 (2,086.6) 0.216751$ (79,146)$ 34 May '15 1,027,489 174 5,905.1 10,250.2 (4,345.1) 0.216751$ (163,874)$ 35 June '15 1,342,013 174 7,712.7 7,627.9 84.8 0.216751$ 3,199$ 36 July '15 1,217,638 174 6,997.9 6,817.7 180.2 0.216751$ 6,797$ 37 August '15 2,832,611 175 16,186.3 5,906.0 10,280.3 0.216751$ 389,948$ 38 September '15 1,333,390 175 7,619.4 5,283.1 2,336.3 0.216751$ 88,618$ 39
40 205,783.1 179,482.3 41424344 45 Total Group 4 Margin Excess / (Deficiency) 987,333$
464748 Total Groups 1 through 4 18,048,821$
Exhibit No. DPY-2Page 1 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Comparison of 2015-16 Customer Usage to Baseline
Margin MarginLine Total Class Number of Average Baseline Difference Revenue Excess /No. Month Throughput Customers Use / Cust. Use / Cust. Per Cust. Factor (Deficiency)
(a) (b) (c) (d) = (b) / (c) (e) (f) = (d) - (e) (g) (h) = (f) * (c) * (g)
1 Group 1: RSG Non-Heating2 Actual3 October '15 118,947 12,199 9.8 13.6 (3.8) 0.509012$ (23,903)$ 4 November '15 200,390 12,166 16.5 13.7 2.8 0.509012$ 17,162$ 5 December '15 268,574 12,100 22.2 20.7 1.5 0.509012$ 9,215$ 6 January '16 299,699 12,113 24.7 23.5 1.2 0.509012$ 7,657$ 7 February '16 383,520 12,078 31.8 23.3 8.5 0.509012$ 51,971$ 8 March '16 288,020 12,088 23.8 27.7 (3.9) 0.509012$ (23,831)$ 9 April '16 154,317 12,077 12.8 19.7 (6.9) 0.509012$ (42,553)$
1011 Projected12 May '16 157,517 12,306 12.8 14.0 (1.2) 0.509012$ (7,517)$ 13 June '16 135,938 12,358 11.0 11.4 (0.4) 0.509012$ (2,516)$ 14 July '16 137,196 12,360 11.1 11.5 (0.4) 0.509012$ (2,517)$ 15 August '16 140,767 12,348 11.4 11.2 0.2 0.509012$ 1,257$ 16 September '16 141,519 12,306 11.5 10.0 1.5 0.509012$ 9,396$ 171819
20 199.3 200.32122232425 Total Group 1 Margin Excess / (Deficiency) (6,179)$
262728293031323334 353637
383940 Group 2: RSG Heating41 Actual42 October '15 11,322,875 333,546 33.9 34.1 (0.2) 0.509012$ (25,982)$ 43 November '15 19,833,415 334,779 59.2 76.8 (17.6) 0.509012$ (2,991,775)$ 44 December '15 23,833,867 335,988 70.9 126.4 (55.5) 0.509012$ (9,485,447)$ 45 January '16 52,266,682 337,096 155.0 157.0 (2.0) 0.509012$ (334,619)$ 46 February '16 42,289,202 337,825 125.2 135.3 (10.1) 0.509012$ (1,740,068)$ 47 March '16 25,939,573 338,296 76.7 104.3 (27.6) 0.509012$ (4,756,564)$ 48 April '16 18,003,532 338,248 53.2 51.9 1.3 0.509012$ 228,272$ 4950 Projected51 May '16 8,275,831 337,789 24.5 29.6 (5.1) 0.509012$ (876,887)$ 52 June '16 5,068,230 337,882 15.0 15.6 (0.6) 0.509012$ (103,192)$ 53 July '16 4,795,752 337,729 14.2 14.7 (0.5) 0.509012$ (85,954)$ 54 August '16 4,764,390 337,900 14.1 13.3 0.8 0.509012$ 137,596$ 55 September '16 5,509,645 338,015 16.3 16.8 (0.5) 0.509012$ (86,027)$ 565758
59 658.4 775.86061626364 Total Group 2 Margin Excess / (Deficiency) (20,120,647)$
Exhibit No. DPY-2Page 2 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Comparison of 2015-16 Customer Usage to Baseline
LineNo.
Margin MarginTotal Class Number of Average Baseline Difference Revenue Excess /
Month Throughput Customers Use / Cust. Use / Cust. Per Cust. Factor (Deficiency)(a) (b) (c) (d) = (b) / (c) (e) (f) = (d) - (e) (g) (h) = (f) * (c) * (g)
12 Group 3: GSG3 Actual4 October '15 5,026,294 24,877 202.0 218.6 (16.6) 0.406684$ (167,480)$ 5 November '15 7,084,165 24,945 284.0 445.8 (161.8) 0.406684$ (1,641,505)$ 6 December '15 7,556,901 25,112 300.9 613.3 (312.4) 0.406684$ (3,190,147)$ 7 January '16 16,078,015 25,320 635.0 645.9 (10.9) 0.406684$ (112,315)$ 8 February '16 14,442,599 25,377 569.1 622.2 (53.1) 0.406684$ (547,791)$ 9 March '16 9,059,092 25,404 356.6 512.4 (155.8) 0.406684$ (1,609,622)$
10 April '16 7,466,769 25,399 294.0 261.6 32.4 0.406684$ 334,453$ 1112 Projected13 May '16 3,441,160 24,734 139.1 160.2 (21.1) 0.406684$ (211,975)$ 14 June '16 3,411,366 24,581 138.8 118.4 20.4 0.406684$ 203,739$ 15 July '16 3,465,885 24,466 141.7 104.0 37.7 0.406684$ 374,727$ 16 August '16 3,101,184 24,414 127.0 130.5 (3.5) 0.406684$ (34,504)$ 17 September '16 3,024,655 24,432 123.8 122.4 1.4 0.406684$ 13,900$ 18192021 3,312.1 3,955.3
2223242526 Total Group 3 Margin Excess / (Deficiency) (6,588,520)$
2728293031323334353637 Group 4: GSG Large Volume38 Actual39 October '15 1,624,774 175 9,284.4 10,817.7 (1,533.3) 0.221371$ (59,399)$ 40 November '15 1,334,951 174 7,672.1 17,479.9 (9,807.8) 0.221371$ (377,781)$ 41 December '15 2,320,060 174 13,333.7 25,743.1 (12,409.4) 0.221371$ (477,993)$ 42 January '16 4,688,616 176 26,639.9 29,051.9 (2,412.0) 0.221371$ (93,976)$ 43 February '16 4,622,126 175 26,412.1 24,583.0 1,829.1 0.221371$ 70,861$ 44 March '16 2,891,210 175 16,521.2 21,049.1 (4,527.9) 0.221371$ (175,411)$ 45 April '16 3,682,963 176 20,925.9 14,872.7 6,053.2 0.221371$ 235,842$ 4647 Projected48 May '16 1,224,836 178 6,881.1 10,250.2 (3,369.1) 0.221371$ (132,756)$ 49 June '16 1,344,665 178 7,554.3 7,627.9 (73.6) 0.221371$ (2,900)$ 50 July '16 1,228,236 178 6,900.2 6,817.7 82.5 0.221371$ 3,251$ 51 August '16 1,049,613 178 5,896.7 5,906.0 (9.3) 0.221371$ (366)$ 52 September '16 945,661 178 5,312.7 5,283.1 29.6 0.221371$ 1,166$ 53545556 153,334.4 179,482.3 57
58596061 Total Group 4 Margin Excess / (Deficiency) (1,009,462)$
626364 Total Groups 1 through 4 (27,724,808)$
Exhibit No. DPY-3Page 1 of 1
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
GSG and GSG-LV Large Customer Adjustment
Cumulative
Line Customers Above 1,200 CFH Equivalent GSG Customers Monthly Large Customer
No. Month Count CFH Avg. CFH Customers Adjustment Adjustment
(a) (b) (c) (d) (e) = (c) / (d) (f) = (e) - (b) (g)
1 Group 3: GSG2 Starting Point 322
3
4 Actual
5 October '15 6 42,184 600 70 64 386
6 November '15 3 8,433 600 14 11 397
7 December '15 6 19,757 600 33 27 424
8 January '16 2 2,531 600 4 2 426
9 February '16 9 28,988 600 48 39 465
10 March '16 4 30,456 600 51 47 512
11 April '16 6 32,538 600 54 48 560
12
13 Projected
14 May '16 600 0 0 560
15 June '16 600 0 0 560
16 July '16 600 0 0 560
17 August '16 600 0 0 560
18 September '16 600 0 0 560
19
20
21
22
23
24
25
26 Group 4: GSG Large Volume
27 Starting Point 0
28
29 Actual
30 October '15 0 0 25,000 0 0 0
31 November '15 0 0 25,000 0 0 0
32 December '15 0 0 25,000 0 0 0
33 January '16 0 0 25,000 0 0 0
34 February '16 0 0 25,000 0 0 0
35 March '16 0 0 25,000 0 0 036 April '16 0 0 25,000 0 0 0
37
38 Projected
39 May '16 25,000 0 0 0
40 June '16 25,000 0 0 0
41 July '16 25,000 0 0 0
42 August '16 25,000 0 0 0
43 September '16 25,000 0 0 0
Exhibit No. DPY-4Page 1 of 5
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Determination of Weather-Related Component of CIP
Line Actual Actual Actual Actual Actual Actual Actual ForecastNo. Month October '15 November '15 December '15 January '16 February '16 March '16 April '16 May '16 Total
(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)
1 Group 2: RSG Heating2 480.11 RSG Heat Sales34 Therms 10,280,490 18,092,635 21,736,602 47,900,639 38,850,320 23,752,549 16,503,408 7,613,375 184,730,018 56 Customers 305,325 306,577 307,928 309,609 310,559 311,257 311,380 310,7507 Base Load / Customer 12.90 12.90 12.90 12.90 12.90 12.90 12.90 12.90
8 Total Baseload 3,938,693 3,954,843 3,972,271 3,993,956 4,006,211 4,015,215 4,016,802 4,008,675 31,906,666 9
10 Heat Load 6,341,797 14,137,792 17,764,331 43,906,683 34,844,109 19,737,334 12,486,606 3,604,700 152,823,352 1112 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 13 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
14 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 1516 Actual Heat Use per Degree Day 40,472.00 40,472.00 40,472.00 40,472.00 40,472.00 40,472.00 40,472.00 40,472.00 40,472.00 1718 Weather Impact - Therms (647,552) (5,989,856) (16,593,520) (121,416) (2,347,376) (7,284,960) 1,376,048 - (31,608,632) 1920 Margin Revenue Factor 0.509012$ 2122 Weather Impact - Dollars (16,089,173)$ 23
242526 490.21 RSG Heat Transp2728 Therms 1,042,383 1,740,780 2,097,265 4,366,043 3,438,882 2,187,024 1,500,124 662,456 17,034,956 2930 Customers 28,221 28,202 28,060 27,487 27,266 27,039 26,868 27,03931 Base Load / Customer 13.00 13.00 13.00 13.00 13.00 13.00 13.00 13.00
32 Total Baseload 366,873 366,626 364,780 357,331 354,458 351,507 349,284 351,507 2,862,366 33
34 Heat Load 675,510 1,374,154 1,732,485 4,008,712 3,084,424 1,835,517 1,150,840 310,949 14,172,590 3536 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 37 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
38 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 3940 Actual Heat Use per Degree Day 3,753.00 3,753.00 3,753.00 3,753.00 3,753.00 3,753.00 3,753.00 3,753.00 3,753.00 4142 Weather Impact - Therms (60,048) (555,444) (1,538,730) (11,259) (217,674) (675,540) 127,602 - (2,931,093) 4344 Margin Revenue Factor 0.509012$ 4546 Weather Impact - Dollars (1,491,962)$ 47
48
49 Group 2: RSG Heating Summary50 480.11 RSG Heat Sales (16,089,173)$ 51 490.21 RSG Heat Transp (1,491,962)$
52 Total (17,581,135)$
Exhibit No. DPY-4Page 2 of 5
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Determination of Weather-Related Component of CIP
Line Actual Actual Actual Actual Actual Actual Actual ForecastNo. Month October '15 November '15 December '15 January '16 February '16 March '16 April '16 May '16 Total
(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)
1 Group 3: GSG2 481.31 GSG Com Heat Sales34 Therms 2,201,470 3,253,787 3,322,857 7,427,829 7,344,969 4,405,823 3,343,980 2,263,410 33,564,124 56 Customers 16,854 16,891 17,020 17,112 17,093 17,022 16,911 16,766 7 Base Load / Customer 83.40 83.40 83.40 83.40 83.40 83.40 83.40 83.40
8 Total Baseload 1,405,624 1,408,709 1,419,468 1,427,141 1,425,556 1,419,635 1,410,377 1,398,284 11,314,795 9
10 Heat Load 795,846 1,845,077 1,903,389 6,000,688 5,919,413 2,986,188 1,933,603 865,126 22,249,330 1112 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 13 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
14 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 1516 Actual Heat Use per Degree Day 5,892.00 5,892.00 5,892.00 5,892.00 5,892.00 5,892.00 5,892.00 5,892.00 5,892.00 1718 Weather Impact - Therms (94,272) (872,016) (2,415,720) (17,676) (341,736) (1,060,560) 200,328 - (4,601,652) 1920 Margin Revenue Factor 0.406684$ 2122 Weather Impact - Dollars (1,871,418)$ 23
242526 481.32 GSG Ind Heat Sales2728 Therms 65,044 145,642 129,595 465,985 454,803 219,796 116,126 81,141 1,678,133 2930 Customers 272 272 270 267 268 267 267 267 31 Base Load / Customer 117.20 117.20 117.20 117.20 117.20 117.20 117.20 117.20
32 Total Baseload 31,878 31,878 31,644 31,292 31,410 31,292 31,292 31,292 251,980 33
34 Heat Load 33,166 113,764 97,951 434,693 423,394 188,504 84,834 49,849 1,426,153 3536 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 37 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
38 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 3940 Actual Heat Use per Degree Day 378.00 378.00 378.00 378.00 378.00 378.00 378.00 378.00 378.00 4142 Weather Impact - Therms (6,048) (55,944) (154,980) (1,134) (21,924) (68,040) 12,852 - (295,218) 4344 Margin Revenue Factor 0.406684$ 4546 Weather Impact - Dollars (120,060)$
Exhibit No. DPY-4Page 3 of 5
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Determination of Weather-Related Component of CIP
Line Actual Actual Actual Actual Actual Actual Actual ForecastNo. Month October '15 November '15 December '15 January '16 February '16 March '16 April '16 May '16 Total
(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)
1 Group 3: GSG (continued)2 489.831 GSG Com Heat Transp34 Therms 2,430,620 3,249,144 3,652,016 7,557,865 5,914,494 3,959,319 3,621,216 767,340 31,152,014 56 Customers 5,407 5,453 5,493 5,587 5,633 5,684 5,724 5,684 7 Base Load / Customer 238.80 238.80 238.80 238.80 238.80 238.80 238.80 238.80
8 Total Baseload 1,291,192 1,302,176 1,311,728 1,334,176 1,345,160 1,357,339 1,366,891 1,357,339 10,666,002 9
10 Heat Load 1,139,428 1,946,968 2,340,288 6,223,690 4,569,333 2,601,980 2,254,325 (589,999) 20,486,012 1112 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 13 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
14 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 1516 Actual Heat Use per Degree Day 5,425.00 5,425.00 5,425.00 5,425.00 5,425.00 5,425.00 5,425.00 5,425.00 5,425.00 1718 Weather Impact - Therms (86,800) (802,900) (2,224,250) (16,275) (314,650) (976,500) 184,450 - (4,236,925) 1920 Margin Revenue Factor 0.406684$ 2122 Weather Impact - Dollars (1,723,090)$ 23242526 489.832 GSG Ind Heat Transp2728 Therms 48,251 60,923 97,712 163,526 225,990 84,921 104,732 26,135 812,190 2930 Customers 83 84 83 87 86 86 86 86 31 Base Load / Customer 525.90 525.90 525.90 525.90 525.90 525.90 525.90 525.90
32 Total Baseload 43,650 44,176 43,650 45,753 45,227 45,227 45,227 45,227 358,138 33
34 Heat Load 4,601 16,747 54,063 117,772 180,763 39,694 59,504 (19,092) 454,052 3536 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 37 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
38 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 3940 Actual Heat Use per Degree Day 120.00 4142 Weather Impact - Therms (93,720) 4344 Margin Revenue Factor 0.406684$ 4546 Weather Impact - Dollars (38,114)$ 47
4849 Group 3: GSG Summary50 481.31 GSG Com Heat Sales (1,871,418)$ 51 481.32 GSG Ind Heat Sales (120,060)$ 52 489.831 GSG Com Heat Transp (1,723,090)$ 53 489.832 GSG Ind Heat Transp (38,114)$
54 Total (3,752,683)$
Exhibit No. DPY-4Page 4 of 5
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Determination of Weather-Related Component of CIP
Line Actual Actual Actual Actual Actual Actual Actual ForecastNo. Month October '15 November '15 December '15 January '16 February '16 March '16 April '16 May '16 Total
(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)
1 Group 4: GSG Large Volume2 481.630 GSG-LV Com Heat Sales34 Therms 159,964 291,825 356,934 682,770 452,878 447,886 461,318 185,790 3,039,365 56 Customers 38 38 36 25 25 27 27 27 7 Base Load / Customer 2,009.00 2,009.00 2,009.00 2,009.00 2,009.00 2,009.00 2,009.00 2,009.00
8 Total Baseload 76,342 76,342 72,324 50,225 50,225 54,243 54,243 54,243 488,187 9
10 Heat Load 83,622 215,483 284,610 632,545 402,653 393,643 407,075 131,547 2,551,178 1112 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 13 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
14 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 1516 Actual Heat Use per Degree Day 676.00 1718 Weather Impact - Therms (527,956) 1920 Margin Revenue Factor 0.221371$ 2122 Weather Impact - Dollars (116,874)$ 23
242526 481.640 GSG-LV Ind Heat Sales27 28 Therms 382,758 (1,200,854) 12,507 8,539 51,421 5,007 233,217 20,643 (486,761) 2930 Customers 3 3 3 3 3 3 3 3 31 Base Load / Customer 7,529.50 7,529.50 7,529.50 7,529.50 7,529.50 7,529.50 7,529.50 7,529.50
32 Total Baseload 22,589 22,589 22,589 22,589 22,589 22,589 22,589 22,589 180,708 33
34 Heat Load 360,170 (1,223,442) (10,081) (14,049) 28,832 (17,582) 210,629 (1,945) (667,469) 3536 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 37 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
38 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 3940 Actual Heat Use per Degree Day (177.00) 4142 Weather Impact - Therms 138,237 4344 Margin Revenue Factor 0.221371$ 4546 Weather Impact - Dollars 30,602$ 47
48
Exhibit No. DPY-4Page 5 of 5
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Determination of Weather-Related Component of CIP
Line Actual Actual Actual Actual Actual Actual Actual ForecastNo. Month October '15 November '15 December '15 January '16 February '16 March '16 April '16 May '16 Total
(a) (b) (c) (d) (e) (f) (g) (h) (i) (j)
1 Group 4: GSG Large Volume (continued)23 489.867 GSG-LV Com Heat Transp45 Therms 976,072 2,105,504 1,831,491 3,817,102 3,929,430 2,296,343 2,852,674 922,067 18,730,683 67 Customers 123 122 124 137 136 134 135 134 8 Base Load / Customer 8,249.40 8,249.40 8,249.40 8,249.40 8,249.40 8,249.40 8,249.40 8,249.40
9 Total Baseload 1,014,676 1,006,427 1,022,926 1,130,168 1,121,918 1,105,420 1,113,669 1,105,420 8,620,623 10
11 Heat Load (38,605) 1,099,077 808,565 2,686,935 2,807,512 1,190,923 1,739,005 (183,352) 10,110,060 1213 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 14 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
15 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 1617 Actual Heat Use per Degree Day 2,677.00 1819 Weather Impact - Therms (2,090,737) 2021 Margin Revenue Factor 0.221371$ 2223 Weather Impact - Dollars (462,829)$ 24252627 489.868 GSG-LV Ind Heat Transp2829 Therms 71,300 74,483 61,696 119,411 82,501 68,841 75,961 41,287 595,480 3031 Customers 6 6 6 6 6 6 6 6 32 Base Load / Customer 11,198 11,198 11,198 11,198 11,198 11,198 11,198 11,198
33 Total Baseload 67,186 67,186 67,186 67,186 67,186 67,186 67,186 67,186 537,485 34
35 Heat Load 4,114 7,298 (5,489) 52,226 15,315 1,655 8,775 (25,899) 57,995 3637 Actual Degree Days 245 383 419 959 767 482 384 137 3,776 38 Normal Degree Days 261 531 829 962 825 662 350 137 4,557
39 Difference (16) (148) (410) (3) (58) (180) 34 - (781) 4041 Actual Heat Use per Degree Day 15.00 4243 Weather Impact - Therms (11,715) 4445 Margin Revenue Factor 0.221371$ 4647 Weather Impact - Dollars (2,593)$ 48495051 Group 4: GSG Large Volume Summary52 481.630 GSG-LV Com Heat Sales (116,874)$ 53 481.640 GSG-LV Ind Heat Sales 30,602$ 54 489.867 GSG-LV Com Heat Transp (462,829)$ 55 489.868 GSG-LV Ind Heat Transp (2,593)$
56 (551,694)$
Exhibit No. DPY-5Page 1 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
BGSS Savings TestLine
No. Description Amount(a) (b)
1 Step 1: Determine Weather and Non-Weather CIP Impacts2 Weather Non-Weather Total3 CIP Group 1 -$ (6,179)$ (6,179)$ 4 CIP Group 2 (17,581,135)$ (2,539,512)$ (20,120,647)$ 5 CIP Group 3 (3,752,683)$ (2,835,837)$ (6,588,520)$ 6 CIP Group 4 (551,694)$ (457,768)$ (1,009,462)$
7 (21,885,512)$ (5,839,297)$ (27,724,808)$ 89
101112131415 Step 2: Apply Modified BGSS Savings Test1617
18 A. Non-weather Impact Subject to Modified BGSS Savings Test19 Non-Weather Deficiency 5,839,297$ 20 75% Factor 75%21 Subtotal 4,379,473$ 2223 Prior Year Carry-Forward (Modified BGSS Savings Test) -$ 2425 Non-weather Impact Subject to Test 4,379,473$ 262728 B. BGSS Savings29 Permanent Capacity Savings 2,243,369$ 30 Additional Capacity BGSS Savings 6,124,527$ 31 Avoided Cost BGSS Savings 260,288$
32 Total BGSS Savings 8,628,184$ 333435 C. Results36 Non-Weather Impacts Passing Test (current accrual) 5,839,297$ 37 Non-Weather Impacts Passing Test (prior year carry-forward) -$ 38 Non-Weather Impacts Exceeding Test (1)$
Margin Excess/(Deficiency)
Exhibit No. DPY-5Page 2 of 2
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
BGSS Savings TestLine
No.
1 Step 3: Apply Variable Margin Revenue Test234 A. Non-weather Impact Subject to Variable Margin Revenue Test5 Non-Weather Impact 5,839,297$ 67 Prior Year Carry-Forward (Variable Margin Revenue Test) -$ 89 Non-weather Impact Subject to Test 5,839,297$
101112 B. Variable Margin Revenues13 Variable Margin Revenues 181,697,880$ 14 6.5% Factor 6.5%
15 Total Fixed Recovery Cap 11,810,362$ 161718 C. Results19 Non-Weather Impacts Passing Test (current accrual) 5,839,297$ 20 Non-Weather Impacts Passing Test (prior year carry-forward) -$ 21 Non-Weather Impacts Exceeding Test -$ 222324 Notes:25 (1) Variable margin revenues equal to the actual number of customers multiplied by the Benchmark UPC26 and multiplied by the margin revenue factor.27282930 Step 4: Determine Recoverable Non-Weather CIP Impacts31
3233 A. Current Year Accrual Recoverable Non-Weather Impacts34 Amount Passing Modified BGSS Savings Test 5,839,297$ 3536 Amount Passing Variable Margin Revenue Test 5,839,297$ 3738 Recoverable Amount 5,839,297$ 394041 B. Previous Carry-Forward Recoverable Amounts42 Amount Passing Modified BGSS Savings Test -$ 4344 Amount Passing Variable Margin Revenue Test -$ 45 Deduction for any amount also included in above -$
46 -$ 4748 Total Non-Weather Recoverable CIP Amount 5,839,297$
Exhibit No. DPY-6Page 1 of 1
South Jersey Gas Company2016-17 Conservation Incentive Program Filing
Calculation of Over/(Under) Recovered CIP Balance
Line Group 1 Group 2 Group 3 Group 4No. Category RSG Non-Heating RSG Heating GSG GSG-LV Total
(a) (b) (c) (d) (e)(f) =
(b) + (c) + (d) + (e)
1 Actual and Projected Recoveries23 Actual4 October '15 (10,196)$ (291,451)$ (61,935)$ (8,626)$ (372,208)$ 5 November '15 (14,364)$ (682,271)$ (147,535)$ (47,225)$ (891,395)$ 6 December '15 (20,612)$ (1,253,118)$ (227,152)$ (55,893)$ (1,556,774)$ 7 January '16 (27,281)$ (1,842,568)$ (336,854)$ (89,142)$ (2,295,845)$ 8 February '16 (33,569)$ (2,452,857)$ (434,009)$ (98,953)$ (3,019,389)$ 9 March '16 (28,745)$ (2,035,557)$ (370,699)$ (86,049)$ (2,521,050)$
10 April '16 (22,187)$ (1,289,533)$ (271,631)$ (91,869)$ (1,675,220)$ 1112 Projected13 May '16 (16,668)$ (783,699)$ (157,642)$ (46,608)$ (1,004,617)$ 14 June '16 (12,529)$ (446,975)$ (90,261)$ (30,854)$ (580,618)$ 15 July '16 (10,061)$ (305,630)$ (104,749)$ (37,173)$ (457,613)$ 16 August '16 (10,715)$ (290,661)$ (123,127)$ (39,721)$ (464,224)$ 17 September '16 (11,760)$ (313,700)$ (133,338)$ (37,078)$ (495,876)$ 1819202122 Total Recoveries (218,687)$ (11,988,019)$ (2,458,933)$ (669,190)$ (15,334,828)$ 2324 Prior Period Adjustment -$ -$ -$ -$ -$ 25262728 29 Recoverable CIP Amounts
30 Final from 2014-2015 CIP Year (159,836)$ (13,609,329)$ (3,725,077)$ (1,121,537)$ (18,615,779)$ 31
32 Total Recoverable CIP (159,836)$ (13,609,329)$ (3,725,077)$ (1,121,537)$ (18,615,779)$ 33343536 Over / (Under) Recovery (58,851)$ 1,621,310$ 1,266,144$ 452,347$ 3,280,951$
Exhibit No. DPY-7Page 1 of 2
South Jersey Gas Company2015-16 Conservation Incentive Program Filing
Derivation of CIP Charge / Credit
Margin 2016-17 TotalLine Excess / Throughput Charge / Charge /No. Description (Deficiency) Therms (Credit) Taxes (Credit)
(a) (b) (c) (d) = (-b) / (c) (e) (f) = (d) + (e)
1 Group 1: RSG Non-Heating23 Weather-Related -$ 4 Non Weather-Related (6,179)$ 5 Total CIP (6,179)$ 67 Prior Year Amounts8 Prior Year Carry-Over -$ 9 Prior Year Over/(Under) Recovery (58,851)$ 10 Total CIP Including Prior Year (65,030)$ 11 Net Charge/(Credit) 2,618,862 0.024831$ 12 Public Utilities Assessment 0.000055$ 13 NJ State Sales Tax 0.001742$ 14 Total Including Taxes and Assessments 0.026628$ 15161718 Group 2: RSG Heating1920 Weather-Related (17,581,135)$ 21 Non Weather-Related (2,539,512)$ 22 Total CIP (20,120,647)$ 2324 Prior Year Amounts25 Prior Year Carry-Over -$ 26 Prior Year Over/(Under) Recovery 1,621,310$ 27 Total CIP Including Prior Year (18,499,337)$ 28 Net Charge/(Credit) 271,707,394 0.068086$ 29 Public Utilities Assessment 0.000150$ 30 NJ State Sales Tax 0.004777$ 31 Total Including Taxes and Assessments 0.073013$
Exhibit No. DPY-7Page 2 of 2
South Jersey Gas Company2015-16 Conservation Incentive Program Filing
Derivation of CIP Charge / Credit
Margin 2016-17 TotalLine Excess / Throughput Charge / Charge /No. Description (Deficiency) Therms (Credit) Taxes (Credit)
(a) (b) (c) (d) = (-b) / (c) (e) (f) = (d) + (e)
1 Group 3: GSG 23 Weather-Related (3,752,683)$ 4 Non Weather-Related (2,835,837)$ 5 Total CIP (6,588,520)$ 67 Prior Year Amounts8 Prior Year Carry-Over -$ 9 Prior Year Over/(Under) Recovery 1,266,144$ 10 Total CIP Including Prior Year (5,322,376)$ 11 Net Charge/(Credit) 97,844,886 0.054396$ 12 Public Utilities Assessment 0.000120$ 13 NJ State Sales Tax 0.003816$ 14 Total Including Taxes and Assessments 0.058332$ 15161718 Group 4: GSG Large Volume1920 Weather-Related (551,694)$ 21 Non Weather-Related (457,768)$ 22 Total CIP (1,009,462)$ 2324 Prior Year Amounts25 Prior Year Carry-Over -$ 26 Prior Year Over/(Under) Recovery 452,347$ 27 Total CIP Including Prior Year (557,115)$ 28 Net Charge/(Credit) 33,797,599 0.016484$ 29 Public Utilities Assessment 0.000036$ 30 NJ State Sales Tax 0.001156$ 31 Total Including Taxes and Assessments 0.017676$
SOUTH JERSEY GAS COMPANY Second Revised Sheet No. 104
B.P.U.N.J. No. 11 - GAS Superseding First Revised Sheet No. 104
Issued____________________ Effective with service rendered by South Jersey Gas Company, on and after ________________ J. DuBois, President
Filed pursuant to Order in Docket No. _____________of the Board of Public Utilities, State of New Jersey, dated _________________
CONSERVATION INCENTIVE PROGRAM (Continued)
mechanism. The Deficiency or Excess shall be calculated each month by multiplying the result obtained from
subtracting the Baseline Usage per Customer from the Actual Usage per Customer by the actual number of customers, and then multiplying the resulting therms by the Margin Revenue Factor.
(d) Recovery of any Deficiency in accordance with Paragraph (c), above, associated with non-weather related
changes in customer usage will be limited to the level of BGSS savings achieved as provided for in the 2006 Order of the Board of Public Utilities in Docket No. GR05121019. The value of the weather-related changes in customer usage shall be calculated in accordance with Rider F to this tariff.
(e) Except as limited by Paragraph (d), above, the amount to be surcharged or credited to the Customer Class Group
shall equal the aggregate Deficiency or Excess for all months during the Annual Period determined in accordance with the provisions herein, divided by the FAU for the Customer Class Group.
(f) The currently effective CIP Factor by Customer Class Group are as follows:
Group I: RSG
Non-Heating
Group II: RSG
Heating
Group III:
GSG
Group IV: GSG-LV
CIP Factors Per Therm ($0.02483193
226) ($0.0680865
4969) ($0.0543962
9561) ($0.01648423
768)
Applicable Revenue Tax Factor CIP Factors Per Therm
1.0022
($0.024886934
31)
1.0022
($0.0682365509
0)
1.0022
($0.05451629626)
1.0022
($0.01652023820)
Applicable NJ Sales Tax Factor 1.07 1.07 1.07 1.07
CIP Factors Per Therm with NJ Sales Tax
($0.02662899971)
($0.07301358946)
($0.05833231700)
($0.01767625487)
(g) The CIP shall not operate to cause the Company to earn in excess of its allowed rate of return on common equity
of 9.75% for any twelve month period ending September 30; any revenue which is not recovered will not be deferred. For purposes of this paragraph (f), the Company's rate of return on common equity shall be calculated by dividing the Company's net income for such annual period by the Company's average 13 month common equity balance for such annual period, all data as reflected in the Company's monthly reports to the Board of Public Utilities. The Company's net income shall be calculated by subtracting from total net income the Company’s share of margins from: (1) Interruptible Sales; (2) Interruptible Transportation; (3) On-System Capacity Release; (4) Off-System Sales and Capacity Release; (5) the Storage Incentive Mechanism, (6) the Energy Efficiency Tracker, (7) the Accelerated Infrastructure Replacement Program and (8) the Storm Hardening and Reliability Program..
(h) As used in this Rider “M”, the following terms shall have the meanings ascribed to them herein:
Exhibit No. DPY-8 Page 1 of 17
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Exhibit No. DPY-8 Page 2 of 17
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Exhibit No. DPY-8 Page 3 of 17
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Exhibit No. DPY-8 Page 4 of 17
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70
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71
Exhibit No. DPY-8 Page 5 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
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Pag
e 5
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15
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Exhibit No. DPY-8 Page 6 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
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Ap
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nd
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TR
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Exhibit No. DPY-8 Page 7 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
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of
Ra
te C
om
po
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Ap
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Exhibit No. DPY-8 Page 8 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
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of
Ra
te C
om
po
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00
.00
00
00
0.0
00
80
00
.01
26
00
Lim
ite
d F
irm
Cu
sto
me
r C
ha
rge
10
0.0
00
00
07
.00
00
00
10
7.0
00
00
0
De
live
ry C
ha
rge
:C
-1 F
T V
OL
UM
ET
RIC
CH
AR
GE
:
C-1
CO
ST
OF
SE
RV
ICE
0.0
94
60
00
.00
66
00
0.1
01
20
0
SB
C:
C
LE
P
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
R
AC
0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9
US
F0
.01
01
00
0.0
00
00
00
.00
07
00
0.0
10
80
0T
ota
l SB
C0
.03
17
60
0.0
00
04
80
.00
22
19
0.0
34
02
7
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.09
46
0.0
00
00
00
.03
85
69
0.0
00
06
30
.00
92
97
0.1
42
52
9
BS
-1 A
LL
TH
ER
MS
0.0
11
80
00
.00
00
00
0.0
00
80
00
.01
26
00
BS
-1 (
Op
t O
ut
Pro
visi
on
) A
LL
TH
ER
MS
0.0
02
50
00
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00
00
0.0
00
20
00
.00
27
00
BU
Y-O
UT
PR
ICE
RA
TE
SE
T M
ON
TH
LY
Exhibit No. DPY-8 Page 9 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
__
__
__
__
__
__
__
__
_
Pag
e 9
OT
HE
RB
AS
E R
AT
EB
GS
SR
IDE
RS
PU
AN
J S
AL
ES
TA
XT
AR
IFF
RA
TE
EL
EC
TR
IC G
EN
ER
AT
ION
SE
RV
ICE
(E
GS
)C
om
me
rcia
l/In
du
str
ial
Cu
sto
me
r C
ha
rge
25
.00
00
00
1.7
50
00
02
6.7
50
00
0
D-1
DE
MA
ND
6.5
00
00
00
.45
50
00
6.9
55
00
0
Ba
sic
Ga
s S
up
ply
Se
rvic
e (
BG
SS
):R
AT
E S
ET
MO
NT
HL
Y
De
live
ry C
ha
rge
- W
inte
r S
ea
so
n (
No
v -
Ma
r)C
OS
T O
F S
ER
VIC
E0
.11
56
38
0.0
08
09
50
.12
37
33
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
S &
FT
S)
0.1
15
63
80
.04
71
00
0.0
38
56
90
.00
01
63
0.0
14
09
20
.21
55
62
.
De
live
ry C
ha
rge
- S
um
me
r S
ea
so
n (
Ap
r -
Oc
t)
CO
ST
OF
SE
RV
ICE
0.0
85
63
80
.00
59
95
0.0
91
63
3
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
S &
FT
S)
0.0
85
63
80
.04
71
00
0.0
38
56
90
.00
01
63
0.0
11
99
20
.18
34
62
Exhibit No. DPY-8 Page 10 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
__
__
__
__
__
__
__
__
_
Pag
e 10
OT
HE
RB
AS
E R
AT
EB
GS
SR
IDE
RS
PU
AN
J S
AL
ES
TA
XT
AR
IFF
RA
TE
EL
EC
TR
IC G
EN
ER
AT
ION
SE
RV
ICE
(E
GS
)R
es
ide
nti
al
Cu
sto
me
r C
ha
rge
9.0
00
00
00
.63
00
00
9.6
30
00
0
Ba
sic
Ga
s S
up
ply
Se
rvic
e (
BG
SS
):0
.49
35
07
0.0
01
08
60
.03
46
21
0.5
29
21
4
De
live
ry C
ha
rge
CO
ST
OF
SE
RV
ICE
0.1
22
10
00
.00
86
00
0.1
30
70
0
S
BC
:
CL
EP
0
.01
18
79
0.0
00
02
60
.00
08
33
0.0
12
73
8
RA
C
0.0
09
78
10
.00
00
22
0.0
00
68
60
.01
04
89
U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
To
tal S
BC
0.0
31
76
00
.00
00
48
0.0
02
21
90
.03
40
27
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
Ba
lan
cin
g C
ha
rge
BS
C"J
" B
S-1
0.0
47
10
00
.00
01
00
0.0
03
30
00
.05
05
00
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E (
FS
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FT
S)
0.1
22
10
00
.04
71
00
0.0
38
56
90
.00
01
63
0.0
14
59
70
.22
25
29
Exhibit No. DPY-8 Page 11 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
__
__
__
__
__
__
__
__
_
Pag
e 11
OT
HE
RE
LE
CT
RIC
GE
NE
RA
TIO
N S
ER
VIC
E-L
V (
EG
S-L
V)
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Fir
mC
us
tom
er
Ch
arg
e1
80
.00
00
00
12
.60
00
00
19
2.6
00
00
0
D-1
DE
MA
ND
(R
ate
is
ne
go
tia
ted
. S
ho
wn
he
re i
s t
he
be
nc
hm
ark
ra
te.)
19
.43
54
41
1.3
60
48
12
0.7
95
92
2
D-2
DE
MA
ND
BG
SS
(ap
pli
ca
ble
to
Sa
les
Cu
sto
me
rs O
nly
)1
4.5
30
36
20
.03
19
67
1.0
19
36
31
5.5
81
69
2
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-2
BG
SS
RA
TE
SE
T M
ON
TH
LY
BS
C "
I" C
AS
H O
UT
CH
AR
GE
(C
RE
DIT
)R
AT
E S
ET
MO
NT
HL
YB
S-1
AL
L T
HE
RM
S0
.01
18
00
0.0
00
00
00
.00
08
00
0.0
12
60
0B
S-1
(O
pt
Ou
t P
rovi
sio
n)
AL
L T
HE
RM
S0
.00
25
00
0.0
00
00
00
.00
02
00
0.0
02
70
0
Lim
ite
d F
irm
D-2
DE
MA
ND
BG
SS
(ap
pli
ca
ble
to
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les
Cu
sto
me
rs O
nly
)7
.71
43
59
0.0
16
97
20
.54
11
93
8.2
72
52
4
C-1
CL
EP
0.0
11
87
90
.00
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26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-3
All
Th
erm
s (R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
chm
ark
ra
te.)
0.1
62
90
00
.01
14
00
0.1
74
30
0
C-2
BG
SS
RA
TE
SE
T M
ON
TH
LY
BS
C "
I" C
AS
H O
UT
CH
AR
GE
(C
RE
DIT
)R
AT
E S
ET
MO
NT
HL
YB
S-1
AL
L T
HE
RM
S0
.01
18
00
0.0
00
00
00
.00
08
00
0.0
12
60
0B
S-1
(O
pt
Ou
t P
rovi
sio
n)
AL
L T
HE
RM
S0
.00
25
00
0.0
00
00
00
.00
02
00
0.0
02
70
0
Exhibit No. DPY-8 Page 12 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
__
__
__
__
__
__
__
__
_
Pag
e 12
FIR
M E
LE
CT
RIC
SA
LE
S (
FE
S)
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Win
ter
D-1
DE
MA
ND
(R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
chm
ark
ra
te.)
2.8
97
20
00
.20
28
00
3.1
00
00
0
D-2
DE
MA
ND
BG
SS
(ap
plic
ab
le t
o S
ale
s C
ust
om
ers
On
ly)
7.7
14
35
90
.01
69
72
0.5
41
19
38
.27
25
24
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-3
All
Th
erm
s (R
ate
is n
eg
otia
ted
. S
ho
wn
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e b
en
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ark
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te.)
0.1
62
90
00
.01
14
00
0.1
74
30
0
C-4
Esc
ala
tor
Ra
te (
To
be
de
term
ine
d a
s p
resc
rib
ed
in t
he
Co
mp
an
y's
Ta
riff
)R
AT
E S
ET
MO
NT
HL
YC
-2 B
GS
S/C
OG
CR
AT
E S
ET
MO
NT
HL
YB
SC
"I"
CA
SH
OU
T C
HA
RG
E (
CR
ED
IT)
RA
TE
SE
T M
ON
TH
LY
Su
mm
er
D-1
DE
MA
ND
(R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
chm
ark
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te.)
2.8
97
20
00
.20
28
00
3.1
00
00
0
D-2
DE
MA
ND
BG
SS
(ap
plic
ab
le t
o S
ale
s C
ust
om
ers
On
ly)
7.7
14
35
90
.01
69
72
0.5
41
19
38
.27
25
24
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.03
85
69
0.0
00
06
30
.00
26
97
0.0
41
32
9
C-3
All
Th
erm
s (R
ate
is n
eg
otia
ted
. S
ho
wn
he
re is
th
e b
en
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ark
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te.)
0.1
62
90
00
.01
14
00
0.1
74
30
0
C-4
Esc
ala
tor
Ra
te (
To
be
de
term
ine
d a
s p
resc
rib
ed
in t
he
Co
mp
an
y's
Ta
riff
)R
AT
E S
ET
MO
NT
HL
YC
-2 B
GS
S/C
OG
CR
AT
E S
ET
MO
NT
HL
YB
SC
"I"
CA
SH
OU
T C
HA
RG
E (
CR
ED
IT)
RA
TE
SE
T M
ON
TH
LY
Exhibit No. DPY-8 Page 13 of 17
SO
UT
H J
ER
SE
Y G
AS
CO
MP
AN
YS
ch
ed
ule
of
Ra
te C
om
po
ne
nts
Ap
pe
nd
ix A
- _
__
__
__
__
__
__
__
__
_
NA
TU
RA
L G
AS
VE
HIC
LE
(N
GV
)P
age
13
BA
SE
RA
TE
BG
SS
RID
ER
SP
UA
NJ
SA
LE
S T
AX
TA
RIF
F R
AT
E
Co
mp
an
y O
pe
rate
d F
ue
lin
g S
tati
on
s
C-1
CL
EP
0.0
11
87
90
.00
00
26
0.0
00
83
30
.01
27
38
C-1
RA
C0
.00
97
81
0.0
00
02
20
.00
06
86
0.0
10
48
9C
-1 U
SF
0.0
10
10
00
.00
00
00
0.0
00
70
00
.01
08
00
E
ET
0.0
06
80
90
.00
00
15
0.0
00
47
80
.00
73
02
To
tal
C-1
VO
LU
ME
TR
IC C
HA
RG
E0
.00
00
00
0.0
38
56
90
.00
00
63
0.0
02
69
70
.04
13
29
Dis
trib
utio
n C
ha
rge
:0
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02
52
0.0
00
30
00
.00
98
00
0.1
50
35
2
Co
mp
ress
ion
Ch
arg
e0
.54
27
69
0.0
01
19
40
.03
80
77
0.5
82
04
0
Ba
sic
Ga
s S
up
ply
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Exhibit No. DPY-8 Page 14 of 17
SO
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Exhibit No. DPY-8 Page 15 of 17
SO
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7
Exhibit No. DPY-8 Page 16 of 17
SOUTH JERSEY GAS COMPANYSchedule of Rate Components
Appendix A - __________________
Page 16
Heat Residential Rate Schedule:
RSG FSS RSG-FTS Difference
BGSS 0.529214 0.000000 0.529214Cost of Service 0.544643 0.544643 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000CIP 0.073013 0.073013 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 1.237689 0.708475 0.529214
NonHeat Residential Rate Schedule:
RSG FSS RSG-FTS Difference
BGSS 0.529214 0.000000 0.529214CIP 0.026628 0.026628 0.000000Cost of Service 0.544643 0.544643 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 1.191304 0.662090 0.529214
GSG
(Under 5,000 therms annually)
GSG FSS GSG-FTS Difference
BGSS 0.529214 0.000000 0.529214CIP 0.058332 0.058332 0.000000Cost of Service 0.435152 0.435152 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 1.113517 0.584303 0.529214
GSG
(5,000 therms annually or greater)
GSG FSS GSG-FTS Difference
BGSS 0.336048 0.000000 0.336048CIP 0.058332 0.058332 0.000000Cost of Service 0.435152 0.435152 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.920351 0.584303 0.336048
GSG-LV
Prior to 7/15/97
GSG-LV FSS GSG-LV-FTS Difference
BGSS 0.336048 0.000000 0.336048CIP 0.017676 0.017676 0.000000Cost of Service 0.236867 0.236867 0.000000CLEP 0.012738 0.012738 0.000000RAC 0.010489 0.010489 0.000000TAC 0.000000 0.000000 0.000000USF 0.010800 0.010800 0.000000TIC (0.001010) (0.001010) 0.000000EET 0.007302 0.007302 0.000000BSC "J" BS-1 0.050500 0.050500 0.000000
Price to Compare 0.681410 0.345362 0.336048
Exhibit No. DPY-8 Page 17 of 17
