HomeMy WebLinkAbout14-3617 ord117
ORDINANCE NO. 14-3617
AN ORDINANCE OF THE CITY OF PLAINVIEW, TEXAS,
APPROVING A SETTLEMENT AGREEMENT BETWEEN THE
ALLIANCE OF XCEL MUNICIPALITIES ("AXM") AND
SOUTHWESTERN PUBLIC SERVICE COMPANY ("SPS" OR
"COMPANY") REGARDING THE COMPANY'S STATEMENT OF
INTENT TO CHANGE ELECTRIC RATES IN ALL CITIES
EXERCISING ORIGINAL JURISDICTION; DECLARING EXISTING
RATES TO BE UNREASONABLE; ADOPTING TARIFFS THAT
REFLECT RATE ADJUSTMENTS CONSISTENT WITH THE
SETTLEMENT AGREEMENT AND FINDING THE RATES TO BE
SET BY THE ATTACHED TARIFFS TO BE JUST AND
REASONABLE; FINDING THE CITY'S RATE CASE EXPENSES
REASONABLE; DIRECTING SPS TO REIMBURSE THE CITY ITS
REASONABLE RATE CASE EXPENSES; DETERMINING THAT
THIS ORDINANCE WAS PASSED IN ACCORDANCE WITH THE
REQUIREMENTS OF THE TEXAS OPEN MEETING ACT;
DECLARING AN EFFECTIVE DATE; REPEALING ANY PRIOR
RESOLUTIONS INCONSISTENT WITH THIS ORDINANCE AND
REQUIRING DELIVERY OF THIS ORDINANCE TO THE
COMPANY AND LEGAL COUNSEL.
WHEREAS, the City of Plainview, Texas ("City") has exclusive original
jurisdiction as a regulatory authority over Southwestern Public Service Company
("SPS" or "Company") rates, operations, and services within the City; and
WHEREAS, the City is also an electric utility customer of SPS, and has an
interest in SPS's rates and charges; and
WHEREAS, SPS filed a Statement of Intent with the City on or about
January 7, 2014 to increase its annual revenue requirement by approximately
$81.5 million on a system -wide basis, which represents an increase in base
revenue of approximately 17.6%, and which included an increase in residential
base rates of approximately 18%; and
WHEREAS, the City took action to suspend the effective date and to
coordinate a response to SPS's filing with other similarly situated municipalities
(such participating cities are referred to herein as the Alliance of Xcel
Municipalities ("AXM")); and
WHEREAS, the City took action on or before February 11, 2014 to
suspend the effective date; and
WHEREAS, one of AXM's goals is to minimize rate -case expenses to the
extent reasonable, that otherwise would result from lengthy, contested rate -case
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proceedings before the Public Utility Commission of Texas ("PUCT") and through
the appellate process in the courts for the pending rate case; and
WHEREAS, AXM authorized its attorneys and experts to formulate and
review reasonable settlement positions to resolve SPS' pending request to
increase rates; and
WHEREAS, AXM's attorneys met numerous times with the Company to
negotiate a Settlement Agreement resolving the issues raised by the Company's
Statement of Intent filing; and
WHEREAS, after extensive review and analysis, AXM's attorneys and
experts found that SPS's initially proposed increase in revenue and its initially
proposed rates are unreasonable; and
WHEREAS, AXM's attorneys and experts have evaluated what a likely
outcome from a fully -litigated proceeding would be and are of the opinion that the
increase of approximately $37 million noted in the negotiated Settlement
Agreement compares favorably with a likely outcome from a fully -litigated
proceeding; and
WHEREAS, after extensive review and analysis, AXM's attorneys and
experts found that the significantly lower increase of approximately $37 million
instead of the $81.5 million increase initially proposed by SPS is reasonable; and
WHEREAS, as part of the Settlement Agreement, SPS's existing rates are
deemed interim as of June 1, 2014; and
WHEREAS, AXM's attorneys and experts and AXM's Steering Committee,
based on the advice of its attorneys and experts, recommend that AXM's
members approve the negotiated Settlement Agreement and attached tariffs; and
WHEREAS, under the Public Utility Regulatory Act, the City has a right to
reimbursement of its reasonable rate -case expenses and SPS has an obligation
to reimburse the City's reasonable rate -case expenses; and
WHEREAS, the attached tariffs implementing new rates are consistent
with the Settlement Agreement and are just, reasonable, and in the public
interest; and
WHEREAS, the Settlement Agreement as a whole is in the public interest;
NOW THEREFORE, the City Council of the City of Plainview, Texas
hereby ordains that:
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SECTION I.
The findings set out in the preamble are in all things approved and
incorporated herein as if fully set forth.
SECTION II.
That the City Council finds that the Settlement Agreement, which is
attached hereto "Attachment A" and incorporated herein, is in the public interest
and is hereby endorsed in all respects.
SECTION III.
That SPS's existing rates are deemed interim as of June 1, 2014, and are
found unreasonable upon the implementation of the rates set forth in the
Settlement Agreement.
SECTION IV.
That the revenue and resulting rates set forth in the Settlement Agreement
and schedule of rates and tariffs for electric service provided by SPS, which are
attached to the Settlement Agreement as "Exhibit B" appended to this Ordinance,
are just and reasonable, and are hereby adopted for service rendered on and
after June 1, 2014.
SECTION V.
That rates under the Settlement Agreement shall be effective for service
rendered on and after June 1, 2014.
SECTION VI.
That SPS shall seek the City's approval of any surcharge that may be
necessary to recover revenue foregone by SPS under rates pursuant to the
Settlement Agreement and its current rates from June 1, 2014 to the later of
October 30, 2014, or when final action is to approve the rates under the
Settlement Agreement.
SECTION VII.
That to the extent any resolution or ordinance previously adopted by the
Council is inconsistent with this Ordinance, it is hereby repealed.
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SECTION VIII.
That the meeting at which this Ordinance was approved was in all things
conducted in strict compliance with the Texas Open Meetings Act, Texas
Government Code, Chapter 551.
SECTION IX.
That if any one or more sections or clauses of this Ordinance is adjudged
to be unconstitutional or invalid, such judgment shall not affect, impair or
invalidate the remaining provision of this Ordinance and the remaining provisions
of the Ordinance shall be interpreted as if the offending section or clause never
existed.
SECTION X.
That this Ordinance shall become effective from and after its passage.
SECTION XI.
The City Secretary or other appropriate city official shall notify SPS of this
Ordinance by sending a copy of the Ordinance to James M. Bagley, Manager,
Regulatory Administration Xcel Energy Services Inc., P.O. Box 1261, Amarillo,
Texas 79105, and AXM shall be notified by sending a copy of this resolution to
Mr. Marcus Norris, City Attorney, City of Amarillo, Texas by fax to 806-378-3018.
PASSED AND APPROVED on first reading this 14th day of October, 2014.
PASSED AND APPROVED on second reading this 28th day of October, 2014.
ende I Dunlap, Mayor
ATT ST:
Belinda Hinojosa, City S: tary
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SPS RATE ORDINANCE
ATTACHMENT A
SPS 2014 Statement of Intent
Stipulation and Settlement
Agreement
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SOAH DOCKET NO. 473-14-1665
PUC DOCKET NO. 42004
APPLICATION OF SOUTHWESTERN
PUBLIC SERVICE COMPANY FOR
AUTHORITY TO CHANGE RATES
AND TO RECONCILE FUEL AND
PURCHASED POWER COSTS FOR
THE PERIOD JULY 1, 2012
THROUGH JUNE 30, 2013
§
§
§
§
§
BEFORE THE STATE OFFICE
OF
ADMINISTRATIVE HEARINGS
NON -UNANIMOUS STIPULATION
(Filename: Docket No. 42004 Stipulation.doc; Total Pages: 170)
Table of Contents
Unopposed Stipulation 3
Section I. Agreement as to Base Rate Increase 4
Section II. Interim Rates 5
Section M. Resolution of Accounting Issues and Future Commitments 5
Section IV. Transmission Cost Recovery Factor (TCRF) Baseline 7
Section V. Franchise Fees 7
Section VI. Prudence of Capital Additions 8
Section VII. Renewable Energy Credits 8
Section VIII. Refund of TUCO Charges 8
Section IX. Amortization of past Energy Efficiency Costs 9
Section X. Margin Sharing for Short -Term Wholesale Sales and
Electric Commodity Sales 9
Cost Allocation and Rate Design 9
Fuel Reconciliation 9
Information SPS Has Agreed to Provide in its Next Base Rate Case 11
Proposed Findings of Fact, Conclusions of Law, and Ordering Paragraphs12
Obligation to Support this Stipulation 12
Effect of Stipulation in this Proceeding 12
Effect of Stipulation in Other Regulatory Proceedings 13
Multiple Counterparts 14
Section XI.
Section XII.
Section XIII.
Section XIV.
Section XV.
Section XVI.
Section XVII.
Section XVIII.
Exhibit A
Exhibit B
Exhibit C-1
Exhibit C-2
Base Rate Increase and Proof of Revenue 27
Rate Tariffs 36
TCRF Baseline Costs 145
TCRF Cost Allocation 149
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Non -Unanimous Stipulation
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Exhibit D Revised Fuel Cost Recovery Factors
Exhibit E List of Rates
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SOAR DOCKET NO. 473-14-1665
PUC DOCKET NO. 42004
APPLICATION OF SOUTHWESTERN
PUBLIC SERVICE COMPANY FOR
AUTHORITY TO CHANGE RATES
AND TO RECONCILE FUEL AND
PURCHASED POWER COSTS FOR
FOR THE PERIOD JULY 1, 2012
THROUGH JUNE 30, 2013
§
§
§
BEFORE THE STATE OFFICE
OF
ADMINISTRATIVE HEARINGS
NON -UNANIMOUS STIPULATION
The Signatories to this Non -Unanimous Stipulation (Stipulation), which is dated as of
September 2, 2014, are:
• Staff of the Public Utility Commission of Texas (Commission);
• Southwestern Public Service Company (SPS);
• Texas Industrial Energy Consumers;
• State of Texas agencies and institutions of higher education;
• Alliance of Xcel Municipalities;
• Texas Cotton Ginners' Association;
• Occidental Permian Ltd.;
• Pioneer Natural Resources USA, Inc.;
• United States Department of Energy.
• Office of Public Utility Counsel;
• Wal-Mart Stores Texas, LLC and Sam's East, Inc.;
• Canadian River Municipal Water Authority;
• Carson County Gin, LLP; and
• Amarillo Recycling, Inc.
Golden Spread Electric Cooperative, Inc. and Sierra Club do not join this Stipulation but do not
oppose it. Intervenor Laurance Kriegel opposes the Stipulation.
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The parties who are joining this Stipulation shall be referred to individually either as a
Signatory or by the acronym assigned above, and collectively as the Signatories. The Signatories
submit this Stipulation to the Commission as representing a just and reasonable disposition of the
issues related to this docket consistent with the public interest. The Signatories request approval
of this Stipulation and entry of findings of fact and conclusions of law consistent with that
approval.
On January 7, 2014, in accordance with Sections 36.001-36.111 and 36.203 of the Public
Utility Regulatory Act, TEX. UTII,. CODE ANN. § 11.001 et seq. (Vernon 2007 & Supp. 2013)
(PURA), SPS filed its application with the Commission seeking authority to revise its base rates
and to reconcile its fuel and purchased power costs for the period from July 1, 2012 through June
30, 2013. SPS's application, as later modified by errata filings, requested: (1) that the
Commission authorize an increase in SPS's Texas retail jurisdictional base rate revenues of
approximately $76.9 million for service rendered on and after the date on which final rates are
set in this case;' and (2) that the Commission find SPS had under -recovered its fuel and
purchased power expense by $20.4 million (excluding interest) during the reconciliation period.
The Commission suspended the effective date of the requested increase for 150 days, and SPS
later extended the jurisdictional deadline by agreement.
By this Stipulation, the Signatories resolve all of the remaining issues among them
related to SPS's application, and agree as follows:
I. Agreement as to Base Rate Increase
SPS will institute an increase in base rate revenues of $37.0 million in its Texas retail
service area for service rendered on and after June 1, 2014. The increase by class and revenue
proof is reflected in Exhibit A to this Stipulation (Exhibit A). The rate tariffs for the increase are
provided in Exhibit B to this Stipulation (Exhibit B).
' SPS's original application sought an increase in Texas retail jurisdictional base rate revenues of
approximately $81.5 million.
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II. Interim Rates
(a) It is the Signatories' intention that the $37.0 million base rate increase set forth in
Section I of this Stipulation become effective for service rendered on and after
June 1, 2014. Therefore, the Signatories agree that SPS may implement an
interim base rate increase that reflects the $37.0 million increase for service
rendered on and after October 1, 2014 for if the Commission has not issued a
final order in this docket by that date. The tariffs provided in Exhibit B would
serve as the interim rates.
(b) lithe Commission's final order in this docket approves the $37.0 million base rate
increase set forth in Section I of this Stipulation, no true -up of interim rates that
became effective under Section II(a) of this Stipulation shall be necessary because
the interim rates will be identical to the final rates approved by the Commission.
(c) If the Commission does not approve this Stipulation, SPS shall institute a refund
or surcharge after the date on which the Commission's order in this docket
becomes final to refund the interim rates implemented under Section II(a) of this
Stipulation.
(d) For service rendered on and after June 1, 2014 through September 30, 2014, SPS
may implement a surcharge to recover the revenue it would have received during
that period if the tariffs provided in Exhibit B had been in effect during that
period.
III. Resolution of Accounting Issues and Future Commitments
The Signatories have reached the following specific agreements as a part of the overall
resolution of this proceeding:
(a) There will be no change in the SPS depreciation rates established in Application
of Southwestern Public Service Company for Authority to Change Rates and to
Reconcile Fuel and Purchased Power Costs for the Period January 1, 2010
Through June 30, 2012, Docket No. 40824.
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(b) The Signatories agree that SPS is allowed to present analysis of the lives and net
salvage values for capital assets using vintage group accounting in each future
depreciation study rather than in each future rate case, but the depreciation study
relied on in a base rate case must have been completed not more than two years
prior to the beginning of the test year in that rate case.
(c) Rate case expenses for this rate case and for Docket No. 40824 (SPS's last rate
case) are included in the base rate increase reflected in Section I of this
Stipulation and will be amortized over a three-year period, starting June 1, 2014.
The rate case expenses to be recovered through the amortization are the actual
rate case expenses from Docket No. 42004 whenever incurred plus $1,228,264 of
unamortized rate case expenses (the balance as of May 31, 2014) from Docket
No. 40824. If SPS files for rate relief before the end of the three-year
amortization period, it may include any unamortized rate case expense balances in
its request for relief.
(d) Recovery of deferred pension and OPEB tracker amounts of $6,690,007 are
included in the base rate increase reflected in Section I of this Stipulation and will
be amortized over a three-year period beginning on June 1, 2014. These amounts
consist of $3,468,975 deferred in 2013 and $196,032 deferred in 2014, plus
$3,025,000 of unamortized pension and OPEB amounts (the balance as of May
31, 2014) from Docket No. 40824 (Finding of Fact 19.b). If SPS files for rate
relief before the end of the three-year amortization period, it may include any
unamortized pension and OPEB balances in its request for relief.
(e) The amortization of the gain associated with SPS's sale of distribution assets to
Lubbock Power & Light is included in the base rate increase reflected in Section I
of this Stipulation and the unamortized balance as of May 31, 2014 of $3,484,607
will be amortized over a three-year period beginning on June 1, 2014. If SPS files
for rate relief before the end of the three-year amortization period, it shall include
any unamortized balance of the gain on sale in its request for relief.
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(f) Starting on June 1, 2014, the baseline for the pension and OPEB tracker
established in accordance with PURA § 36.065 is set at $9,338,000.
(g) For Allowance for Funds Used During Construction purposes only, the return on
equity will be 9.7 percent effective June 1, 2104. By agreeing to this term in this
Stipulation, the Signatories are not agreeing to a return on equity that will be
applied to Southwest Power Pool (SPP) revenue credits.
(h) For SPS's next base rate case, the Signatories agree not to oppose a request by
SPS to waive the requirement to file Schedule S of the Electric Utility Rate Filing
Package for Generating Utilities dated September 9, 1992.
(i) If SPS receives a refund associated with the Tri -County Electric Cooperative, Inc.
(Tri -County) proceeding, Federal Energy Regulatory Commission (FERC)
Docket No: ER12-959, SPS will provide a refund to its Texas retail customers
based on the Texas retail jurisdictional percentage applicable to transmission
charges during the period May 1, 2103 until the date the Tri -County stopped
charging the rates that are being refunded to SPS. This refund to Texas retail
customers will apply only to the portion of the refund from the FERC litigation
applicable to the period starting May 1, 2013 going forward.
IV. Transmission Cost Recovery Factor (TCRF) Baseline
Solely for purposes of any TCRF application that SPS files before the effective date of
new rates in SPS's next base rate case, the baseline costs for purposes of calculating SPS's
TCRF will be the amounts set forth in Exhibit C-1 to this Stipulation. The class allocation
factors to be used in setting the TCRF will be as set forth in Exhibit C-2 to this Stipulation. SPS
agrees that no baseline costs will be set in this case for a distribution cost recovery factor or a
purchased power capacity cost recovery factor.
V. Franchise Fees
The Signatories agree to retain the current method for collecting franchise fees. Under the
current method of collecting franchise fees, an overall franchise fee equivalent to approximately
two percent of gross revenues is included in base rates and paid by all customers inside and
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outside municipalities, except that customers who take service under SPS's Large General
Service — Transmission (LGS-T) tariff in the environs areas do not pay franchise fees. LGS-T
customers within the cities are responsible for paying all franchise fees allocated to the LGS-T
class. The actual franchise fee factor used to calculate the amount of franchise fees to be
included in base rates varies from city to city. Franchise fees in excess of the amount produced
by each city's baseline franchise fee factor are collected from only those customers located
within the municipality that authorized the additional franchise fee.
VI. Prudence of Capital Additions
The Signatories agree to the reasonableness and necessity of all SPS capital additions that
were placed into service during the period from January 1, 1978 through December 31, 2009 and
that are included in SPS's proposed Test Year rate base reflected in the Second Errata filed on
April 22, 2014.
VII. Renewable Energy Credits (RECs)
(a) The price of Texas -generated RECs will decrease from $2.55 to $1.10 effective
on June 1, 2014.
(b) REC sales margins for RECs with a vintage of July 1, 2013 and later will be
credited through eligible fuel expense.
(c) For the period the base rates set in this case are in effect, the Commission will
establish the value for Texas -generated bundled RECs, and the New Mexico
Public Regulation Commission will establish the value for New Mexico -
generated bundled RECs.
(d) For base rate purposes, REC expenses and revenues will continue to be direct
assigned to the New Mexico and Texas retail jurisdictions.
VIII. Refund of TUCO Charges
A regulatory liability associated with the refund of TUCO overcharges accrued through
May 31, 2014 of $592,689.93 plus interest of $35,455.32, for a total of $628,145.25, is included
in the base rate increase reflected in Section I of this Stipulation and will be amortized over a
fifteen -month period beginning on June 1, 2014.
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IX. Amortization of Past Energy Efficiency Costs
(a) Costs accrued under the energy efficiency tracker as of April 30, 2013 will
continue to be amortized as set forth in the Docket No. 40824 Final Order at page
8, Finding of Fact No. 24.a.
(b) Energy efficiency expenses accrued as of December 31, 2008 will continue to be
amortized as set forth in the Docket No. 35763 Final Order at page 8, Finding of
Fact No. 22.a.
X. Margin Sharing for Short -Term Wholesale Sales and Electric Commodity Sales
With regard to proprietary book / commodity trading margins, SPS will retain the first
$400,000 of margins (Texas retail), and then credit Texas jurisdictional fuel costs with 55% of
the remaining margins.
XL Cost Allocation and Rate Design
(a) The base rate revenue increases specified in Section I of this Stipulation will be
allocated and implemented through the rate design reflected in Exhibit A.
(b) The SPS rate tariffs as reflected in Exhibit B are reasonable and should be
approved.
XII. Fuel Reconciliation
(a) The Signatories agree to a black box settlement resolving all fuel reconciliation
issues concerning Texas retail rates relating to the fuel reconciliation period from
July 1, 2012 through June 30, 2013, as shown in the following table:
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Description
Amount
June 30, 2012, Over -Recovery Balance
(excluding interest)
$17,345,030.19
Fuel and Purchase Power Energy Cost: 7/12-6/13
($372,647,789.25)
Fuel Revenue Collected: 7/12-6/13
$348,717,367.75
Fuel Cost Refunded: 7/12-6/13
($17,233,896,12)
Gen. Book Net Sales Margins: 7/12-6/13
$2,674,538.60
Docket Nos. 40824, 38147 and 29801 Adjustments
$711,916.64
June 30, 2013 Under -Collected Balance (excluding
interest)
($20,400,503.62)
Stipulated Disallowance
$165,000
Total Agreed Under -Collected Fuel Balance as of June
30, 2013 (excluding interest)
($20,235,503.62)
Total Agreed Under -Recovery Balance of Interest
Expense as of June 30, 2013
($475,345.15)
(b) The Signatories agree that SPS's line loss study presented in this case is approved
and the resulting demand and energy loss factors are approved.
(c) The Signatories agree that the effective date of the new demand and energy loss
factors is July 1, 2012.
(d) SPS will complete an updated line loss study to capture the full effects of the SPP
Integrated Marketplace and all other relevant factors during a study period that
will end no Iater than December 31, 2016.
(e) The Signatories agree that revised fuel factors calculated using the energy loss
factors from SPS's line loss study, as reflected in Exhibit D to this Stipulation,
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should be approved, with the new fuel factors to become effective as of the start
of the first billing cycle in the first calendar month following the Commission's
issuance of its final Order in this docket. •
XIIL Information SPS Has Agreed to Provide in its Next Base Rate Case
Staff has requested that SPS provide the following information in the next SPS base rate
case:
1. A cost of service study with its costs assigned and allocated among SPS's
retail rates as listed in Exhibit E to this Stipulation (Exhibit E).
2. A Load study that corresponds to a cost of service study with the retail
rates as listed in Exhibit E. In addition, SPS will provide separate
information consistent with Schedules 0-1.1 through 0-1.4 and 0-1.7 for
the customers served under: (1) the Service Agreement Summary tariffs
SAS -4, SAS -8, SAS -12, and SAS -13; and (2) the QF Standby Service
Tariffs shown on Exhibit E.
3. In the cost of service study described above, for each line item in its filed
jurisdictional cost of service study that contains amounts that are allocated
among SPS's rates, provide one allocation basis to allocate the amounts in
that line item among SPS's rates.
4. Unit cost analysis by rate based upon the cost of service study described
above.
5. A revenue analysis showing the effect of moving rates to the cost
calculated by the study described above.
6. Sufficient data (billing determinants) to enable Staff to develop rates based
upon the revenue allocation provided under Item 5.
7. In its response to Item Nos. 1-6 above, SPS will include the following
statement:
SPS is providing this information solely to comply with the
Section XIII of the Stipulation in Commission Docket No. 42004,
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and—as agreed by all Signatories to the Stipulation in Docket No.
42004—the act of providing this information shall not be
interpreted as SPS's or any other Signatory's agreement that the
information SPS is providing will or will not result in cost -based
rates or in a movement toward cost -based rates.
SPS agrees to provide the information Staff has requested. SPS agrees to file a response to
Staff's information request on the day it files its Statement of Intent and Application for its next
base rate case with the Commission. SPS, however, will file the information separate from its
Statement of Intent and Application and supporting documents (rate filing package schedules and
pre -filed direct testimony), and all Signatories (including Staff) agree that the information SPS
will file is not part of SPS's Statement of Intent and Application and rate filing package
schedules. The Signatories (other than Staff) do not join in Staff's request for this information
and reserve all rights and positions they may have in the next SPS base rate case regarding issues
related to the information SPS will file in compliance with this Section of this Stipulation.
Further, a Signatory's agreement to this Stipulation shall in no way be interpreted as agreement
that the information SPS will provide results in cost -based rates or in movement toward cost -
based rates.
XIV. Proposed Findings of Fact, Conclusions of Law, and Ordering Paragraphs
The Signatories agree to request entry of the findings of fact, conclusions of law, and
ordering paragraphs shown on Exhibit F to this Stipulation.
XV. Obligation to Support this Stipulation
The Signatories agree that they will support this Stipulation before the Commission.
XVI. Effect of Stipulation in this Proceeding
There are no third -party beneficiaries of this Stipulation. The Signatories agree that this
Stipulation resolves issues only with respect to the Texas retail jurisdiction and shall not be
binding on or have any effect on proceedings in other jurisdictions. Signatories are not agreeing
to any methodology or theory that may support or underlie any of the dollar amounts, rates in
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tariffs, depreciation rates, dollar balances, or other monetary or numerical values set out in, or
attached to, this Stipulation.
This Stipulation has been drafted by all the Signatories and is the result of negotiation,
compromise, settlement, and accommodation. The Signatories agree that this settlement is in the
public interest. The Signatories agree that the terms and conditions herein are interdependent.
The various provisions of this Stipulation are not severable. None of the provisions of this
Stipulation shall become fully operative unless the Commission shall have entered a final order
approving this Stipulation. If the Commission issues a final order inconsistent with the terms of
this Stipulation, each Signatory has the right to withdraw from this Stipulation, to submit
testimony, and to obtain a hearing and advocate any position it deems appropriate with respect to
any issue in this Stipulation.
XVII. Effect of Stipulation in Other Regulatory Proceedings
This Stipulation is binding on each of the Signatories only for the purpose of settling the
issues as set forth herein in this jurisdiction only and for no other purposes. The matters resolved
herein are resolved on the basis of a compromise and settlement. Except to the extent that this
Stipulation expressly governs a Signatory's rights and obligations for future periods, this
Stipulation shall not be binding or precedential on a Signatory outside of this proceeding or a
proceeding to enforce the terms of this Stipulation. The Signatories recognize and agree that
Sections III, IV, V, VII(b) through (d), IX, X, and XIII of this Stipulation all include forward-
looking provisions and corresponding obligations. It is acknowledged that a Signatory's support
of the matters contained in this Stipulation may differ from the position taken or testimony
presented by it in other dockets or other jurisdictions. To the extent that there is a difference, a
Signatory does not waive its position in any of those other dockets or jurisdictions. Because this
is a stipulated resolution, no Signatory is under any obligation to take the same positions as set
out in this Stipulation in other dockets or jurisdictions, regardless of whether other dockets
present the same or a different set of circumstances, except as otherwise may be explicitly
provided by this Stipulation. Agreement by the Signatories to any provision in this Stipulation
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will not be used against any Signatory in any future proceeding with respect to different
positions that may be taken by that Signatory.
The provisions of this Stipulation are intended to relate to only the specific matters
referred to herein. By agreeing to this Stipulation, no Signatory waives any claim it may
otherwise have with respect to issues not expressly provided for herein. It is further understood
and agreed that this Stipulation represents a negotiated settlement of all issues in this proceeding.
This settlement represented b)' this Stipulation resolves the stated issues in the Texas retail
jurisdiction only, and this Stipulation does not resolve any claims, issues or proceedings pending
in or pertaining to other jurisdictions.
XVIII. Multiple Counterparts
Each copy of this Stipulation may not bear the signatures of all the Signatories but will be
deemed fully executed if all copies together bear the signatures of all Signatories.
Fully and duly authorized representatives of the Signatories have signed this Stipulation
as of the date first set forth above.
Commission Staff supports the stipulation with the exception of the Transmission Cost Recovery
Factor — Cost Allocation, as included in Exhibit C-2 to the Stipulation, to which Staff does not
oppose.
STAFF OF THE PUBLIC UTILITY COMMISSION OF TEXAS
ason aas
Attorneys of Record
SOUTHWESTERN PUBLIC SERVICE COMPANY
By:
Stephen Fogel
Ron H. Moss
Attorneys of Record
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 14
-014-
136
will not be used against any Signatory in any future . proceeding with respect to different
positions that may be taken by that Signatory.
The provisions of this Stipulation are intended to relate to only the specific matters
referred to herein. By agreeing to this Stipulation, no Signatory waives any claim it may
otherwise have with respect to issues not expressly provided for herein. It is further understood
and agreed that this Stipulation represents a negotiated settlement of all issues in this proceeding.
This settlement represented by this Stipulation resolves the stated issues in the Texas retail
jurisdiction only, and this Stipulation does not resolve any claims, issues or proceedings pending
in or pertaining to other jurisdictions.
XVIII. Multiple Counterparts
Each copy of this Stipulation may not bear the signatures of all the Signatories but will be
deemed fully executed if all copies together bear the signatures of all Signatories.
Fully and duly authorized representatives of the Signatories have signed this Stipulation
as of the date first set forth above.
STAFF OF THE PUBLIC UTILITY COMMISSION OF TEXAS
By:
Karen S. Hubbard
Jason Haas
Attorneys of Record
SOUTHWESTERN PUBLIC SERVICE COMPA
By:
Stephen ogel
Ron H. Moss
Attorneys of Record
TEXAS INDUSTRIAL ENERGY CONSUMERS
By:
Rex D. VanMiddlesworth
PUC Docket No. 42004
SOAR Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 14
-015-
will not be used against any Signatory in any future proceeding with respect to different
positions that may be taken by that Signatory.
The provisions of this Stipulation are intended to relate to only the specific matters
referred to herein. By agreeing to this Stipulation, no Signatory waives any claim it may
otherwise have with respect to issues not expressly provided for herein. It is further understood
and agreed that this Stipulation represents a negotiated settlement of all issues in this proceeding.
This settlement represented by this Stipulation resolves the stated issues in the Texas retail
jurisdiction only, and this Stipulation does not resolve any claims, issues or proceedings pending
in or pertaining to other jurisdictions.
XVIII. Multiple Counterparts
Each copy of this Stipulation may not bear the signatures of all the Signatories but will be
deemed fully executed if all copies together bear the signatures of all Signatories.
Fully and duly authorized representatives of the Signatories have signed this Stipulation
as of the date first set forth above.
STAFF OF THE PUBLIC UTILITY COMMISSION OF TEXAS
By:
Karen S. Hubbard
Jason Haas
Attorneys of Record
SOUTHWESTERN PUBLIC SERVICE COMPANY
By:
Stephen Fogel
Ron H. Moss
Attorneys of Record
TEXAS INDUSTRIAL ENERGY CONSUMERS
By i2A'_RA-w-7•-'zr---
Rex D. VanMiddlesworth
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 14
-016-
137
138
STATE OF TEXAS .AGENCIES AND INSF1TUTBS OF
HIGHS DUCATION
Susan M. Kelley
Attorney of Record
ALLIANCE OF XCEL MUNICIPALITIES
BY:
Alfred R Herrera.
Felipe Alamo III
Attorneys efRec ord
TEXAS COTTON DINNERS' ASSOCIATION
and CARSON COUNIY GIN, LLP
Zachary S. Brady
Attorney of Record
OCCIDENTAL PERMIAN LTD.
MikeStengiein
Adam Gray
Attorneys of Record -
PIONEER NATURAL RESOURCES USA, INC.
By:
lames Z. Brazell
Attorney of Record
PUC Docket No. 42004
SOAR Docket No. 473-14-1665
Noo-Unanimous Stipulation
Page IS
-017-
STATE OF TEXAS AGENCIES AND INSTITUTES OF
HIGHER EDUCATION
By:
Susan M. Kelley
Attorney of Record
ALLIAN OF XCEL MUNICIPALITIES
By: 4.0.‘„?/
Alfred R. Herrera
Felipe Alonso III
Attorneys of Record
TEXAS COTTON GINNERS' ASSOCIATION
and CARSON COUNTY GIN, LLP
By:
Zachary S. Brady
Attorney of Record
OCCIDENTAL PERMIAN LTD.
By:
Mike Stenglein
Adam Gray
Attorneys of Record
PIONEER NATURAL RESOURCES USA, INC.
By:
James Z. Brazell
Attorney of Record
139
PUC Docket No. 42004
SOAR Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 15
-018-
140
STATE OF TEXAS AGENCIES AND INSTITUTES OF
HIGHER EDUCATION
By:
Susan M. Kelley
Attorney of Record
ALLIANCE OF XCEL MUNICIPALITIES
By:
Alfred R. Herrera
Felipe Alonso III
Attorneys of Record
TEXAS COTTON GINNERS' ASSOCIATION
and CARSON COUNTY GIN, LLP
OCCIDENTAL PERMIAN LTD.
By:
Mike Stenglein
Adam Gray
Attorneys of Record
PIONEER NATURAL RESOURCES USA, INC.
By:
James Z. Brazell
Attorney of Record
PUC Docket No. 42004
SCAR Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 15
-019-
STATE OF TEXAS AGENCIES AND INSTITUTES OF
HIGHER EDUCATION
Bv:
Susan M. Kelley
Attorney of Record
ALLIANCE OF XCEL MUNICIPALITIES
By:
Alfred R. Herrera
Felipe Alonso III
Attorneys of Record
TEXAS COTTON GINNERS' ASSOCIATION
and CARSON COUNTY GIN, LLP
By:
Zachary S. Brady
Attorney of Record
OCCIDENTAL PERMIAN LTD.
By:
Mike Stenglein
Adam Gray
Attorneys of Record
PIONEER NATURAL RESOURCES USA, INC.
By:
James Z. Brazell
Attorney of Record
141
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 15
-020-
142
STATE OF TEXAS AGENCIES AND INSTITUTES OF
HIGHER EDUCATION
13y:
Susan M, Kelley
Attorney of Record
ALLIANCE OF XCEL MUNICIPALITIES
By:
Alfred R. Herrera .
Felipe Alonso II!I
Attorneys of Record
TEXAS COTTON DINNERS' ASSOCIATION
and CARSON COUNTY GIN, LLP
By:
Zachary S. Brady
Attorney of Record
OCCIDENTAL PERMIAN LTD.
By:
Mike Stenglein
Adam Gray
Attorneys of Record
PIONEER NAT44RojkL RESOURCES US -P .-'
Jaynes Z. Brazel!
Attorney of Record
PUC Docket No. 42004
SOAH .Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 15
-021-
143
THE UNITED STATES DEPARTMENT OF ENERGY
Steven A. Porter
Attorney of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Sara J. Ferris
Cassandra Quinn
Attorneys of Record
WAL-MART STORES TEXAS, LLC and SAM'S EAST, INC.
By:
Rick D. Chamberlain
Attorney of Record
CANADIAN RIVER MUNICIPAL WATER AUTHORITY
By:
R. Michael Anderson
Attorney of Record
AMARILLO RECYCLING, INC.
By:
Rick Russwurm
Attorney of Record
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 16
-022-
144
THE UNITED STATES DEPARTMENT OF ENERGY
By:
Steven A. Porter
Attorney of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Fem
Cass dra Qu nn
Attorneys of Record
WAL-MART STORES TEXAS, LLC and SAM'S EAST, INC.
By:
Rick D. Chamberlain_
Attorney of Record
CANADIAN RIVER MUNICIPAL WATER AUTHORITY
BY:
R. Michael Anderson
Attorney of Record
AMARILLO RECYCLING, INC.
By:
Rick Russwurm
Attorney of Record
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 16
-023-
THE UNITED STATES DEPARTMENT OF ENERGY
By:
Steven A. Porter
Attorney of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Sara J. Ferris
Cassandra Quinn
Attorneys of Record
WAL-MART STO
B
TEXAS, LLC and SAM'S EAST, INC.
Rick D. Chamberlain
Attorney of Record
-CANADIAN RIVER MUNICIPAL WATER AUTHORITY
By:
R. Michael Anderson
Attorney of Record
AMARILLO RECYCLING, INC.
By: -
Rick Russwurm
Attorney of Record
PUC Docket No. 42004
SOAH Docket No. 473-141665
Non -Unanimous Stipulation
Page 16
-024-
145
146
THE UNITED STATES DEPARTMENT OF ENERGY
By:
Steven A. Porter
Attorney of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Sara J. Ferris
Cassandra Quinn
Attorneys of Record
WAL-MART STORES TEXAS, LLC and SAM'S EAST, INC.
By:
Rick D. Chamberlain
Attorney of Record
CANADIAN RIVER MUNICIPAL TER AUTHORITY
By:
R. Michael Anderson
Attorney of Record
AMARILLO RECYCLING, INC.
By:
Rick Russwurm
Attorney of Record
PUC Docket No. 42004
SOAH Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 16
-025-
THE UNITED STATES DEPARTMENT OF ENERGY
By:
Steven A. Porter
Attorney of Record
OFFICE OF PUBLIC UTILITY COUNSEL
By:
Sara J. Ferris
Cassandra Quinn
Attorneys of Record"
WAL-MART STORES TEXAS, LLC and SAM'S EAST, INC.
By:
Rick D. Chamberlain
Attorney of Record
CANADIAN RIVER MUNICIPAL WATER AUTHORITY
By:
R. Michael Anderson
Attorney of Record
AMARIO/YCLING, INC.
By:
Rick Russwurm
Attorney of Record
PUC Docket No. 42004
SOAR Docket No. 473-14-1665
Non -Unanimous Stipulation
Page 16
-026-
147
148
EXHIBIT A
-027-
Soudeweetr.. FthLk Servkn C..ep.ry
Sensory of Rea Rate Reuses lacrosse
Docket No. 42994
Ted Year Ended Jose 342913
77e knew sodorgoolmoen ejrake w ink AWOL dote WI ...present. o6eeen ni on ndwn is o'reit aku'wl o no,pnoedene4l w wMr '3.7e elan t' urea used 7o Mir ase awl ie roe
pnowdmMklon how tndew Ow 39. '68d 'mk dna' In ,W1kaeet Gam raw ease or inflows SPSp weans,.
u..
N.,
3
9
10
12
13
14
3
Rea S.e.rry
Prong
Base Sete
Rooms
Reddeadd Smite
Rddend.l
R®dm4iel Spare Hering
7%91 Rendentlal Unite
Sorel Ge..rul Service
CaeaewN I aid I.ds.vi1 Service
Se>arYry General
Pitney Grum
Gr eOmer& Service. 196,n.iraion
69 IN
115 kV+
Lul Coo.ren[I.l earl I.destrk1 Service
M..lelp.l.69 $e9ooI Service
Smell Monioip.l mdSdml Swim
Grp Mnlcip.l Service
L.qe School Service
Teta 61aoldp.1 Ned SAW Sankt
Street and Aro. LI9kd.1 Smite
rowel*
Teal ANIS
S 116.500,072
S 47378.032
163,974104
S 12,943,393
100997,993
61.718097
17.211,792
S 81,371,392
S 261,399,273
S 901,268
S 6,569.143
S 1,781,217
S 16,239,391
S 7,783,771
462.164140
Teed
Nevem
8Lna9.
44 Inman
S 127,27%329
S
14176,257
9.2194
S 31 760500
S
4,342,468
9.25%
f 179,034129
0
15,158,725
9.231C
S 14.142,844
S
1,197,449
97376
S 109.714119
S
0,714127
1.60%
L 63,020,348
S
1,302,252
2.11%
S 11103.612
S
1,392191
9.2376
5 14891.246
0
7,526,854
92376
S 210,436,596
S
19,137,323
7.52%
S 992,282
S
84,013
9.23%
1 7,177153
$
607,710
9.2546
S '9393.556
S
812,269
97394
s 17,763,392
s
1503,994
9.23%
s 7,782,771
S-
0.00%
f 2.309
s
2,509
6 499,164,940
1
37,000,909
6,9794
-028-
149
150
Docket No, 42004
Southwestern Public Service Company
Pro Forme Base Rats Revenue
Docket No.42004
Test Year Faded hue 30, 2013
The listing and organization of rates an this &i114t does not ranusent an agreement on what Ls a "rate clad' and le not precedential an what "rate daces" wire used in this case and
6 not prece dentlal on how to define the terns 'mte"and "rate class' In SPS7 nut base rote case or in future SPS proceedings.
Line
No.
Proposed Rate
Residentlal Servke
Hillbg Datta
Bate Rate Revenue
at Proposed Base Rates
Rah Revenue -S
1 RTX Service Availability Charge 1,826,092.00 Bills S 7.60 / Month S 13,878399
2 Energy Charge - Summer 667,225,357 kWh S 0.076093 1 kWh 50,771,179
3 Energy Charge - Winter 952,958,493 kWh S 0.065718 / kWh 62,626,526
4 Total 1,620,183,849 kWh S 127,276,004
5 Tngct 127,276,329
6
Under Target 325
7 RSRTX Service Availability Charge 544,378.00 Bills S 7.60 / Month S 4,137,273
8 Energy Charge - Summer 253387,347 kWh S 0.076093 / kWh 19,273,394
9 EnergvCfarge- Winter 518,424,691 kWh S 0.054686 /kWh 28,350,573
10 Total 771,712,038 kWh $ 51,761,240
11 Target 51,760,500
12 Over Target (740)
13 Total Realdeatlal Service
14
15
Small Coi ie rclal Service
2,391,895,887 kWh
S 179,037,244
Target 179,036,829
Over Target 415
16 SCSTX Service Availability Charge 324,936.00 Bills $ 12.67 /Month S 4,116.939
17 Energy Charge -Summer 72,837,520 kWh S 0.055756 /kWh 4,061,129
18 Energy Charge - Winter 125,998,699 kWh S 0.047335 / kWh 3,964,148
19 Total 198,836,219 kWh
20 Total Small Commercial Service
21
22
198,836,219 kWh
S 14,142,216
$ 14,142,216
Target 14,142,844
Under Target 628
-029-
Docket No. 42004
5ecoadare Voltage
23 SGTX Service Availability Charge 190,474.00 Bills $ 26.76 / Month S 5,097,084
24 Demand Charge - Summer 2,365,626.59 kW -Mo S 15.95 1 kW -Mo 37,731,744
25 DanandCharge- Winter 4,151,328.72 kW -Mo 5 12.97 / kW -Mo 53,842,734
26 Energy Charge 2,258,136,129 kWh S 0.005651 /kWh 12,760,727
27 Power Factor Adjustment Charge 544,388 Kvar $ 0.54 / Kvar 293,970
28 Power Factor Adjustment Credit 25,637 Kvar 5 (0.54) /Kvar (13,844)
29 Toni 2,258,136,129 kWh $ 109,712,415
30 Total Secondary Voltage 2,258,136,129 kWh S 109,712,415
31 Target 109,714,119
32 Under Target 1,705
Primary Voltage
33 PGTX Smite Availability Charge 49,224.00 Bills $ 163.03 / Month S 8,024,989
34 Demand Charge - Summer 1,281,40028 kW -Mo S 13.13 1 kW -Mo 16,824,786
35 Demeod Charge- Winer 2,437,781.69 kW -Mo S 10.08 /kW -Mo 24,572,839
36 Energy Charge 2,084,971,921 kWh S 0.004631 / kWh 9,655,505
37 Powe Factor Adjustment Charge 647,390 Kvar S 0.51 / Kvar 330,169
38 Powe Factor Adjustment Credit • 97,621 Kvar S (0.51) /Kvar (49,787)
39 Total 2,084,971,921 kWh $ 59,358,501
40 Standby Service Availability Charge 120.00 Bills S 163.03 / Month S 19,564
41 Primary Ten & Dist Standby Capacity Fee - Summer 3,818.00 kW -Mo S 6.29 / kW -Mo 24,015
42 Tran & Dist Standby Capacity Fee - Winter 8,768.00 kW -Mo S 5.07 / kW -Mo 44,454
43 Gen Standby Cep Reservation Fee - Summer 3,818.00 kW -Mo S 1.57 1 kW -Mo 5,994
44 Gen Standby Cap Renovation Fee - Winter 8,768.00 kW -Mo 5 1.26 / kW -Mo 11,048
45 Usage Demand Charge - Summer 0.00 kW -Mo $ 13.13 I kW -Mo
46 Usage Demand Charge - Wester 0.00 kW -Mo 5 10.08 1 kW -Mo
47 Energy Charge 470,377 kWh $ 0.004631 / kWh 2,178
48 Total 470,377 kWh $ 107,253
49 SAS -4 First 3,500,000kWh/Month 42,000,000 kWh 5 0.025434 /kWh S 1,068,228
S0 All Additional Energy 99,370,253 kWh 5 0.019772 /kWh 1,964,749
51 Total 141,370,253 kWh S 3,032,977
52 SAS -8 Service Availability Charge 0.00 Bills $ 163.03 / Month $
53 Demand Charge - Summer 0.00 kW -Mo S 13.13 / kW -Mo
54 Demand Charge - Winter 0.00 kW -Mo S 10.08 / kW -Mo
55 Energy Charge 0.00 kWh S 0.004631 /kWh
56 Contract Rate -Energy Charge 33;875,116 kWh S 0.008432 /kWh 285,635
57 Total 33,875,116 kWh S 285,635
58 SAS -13 Service Availability Charge 12.00 Bilk 5 26.76 I Month $ 321
59 Demand Charge - Summer 6,042.65 kW -Mo S 15.95 / kW -Mo 96,380
60 Demand Charge -Winter 10,074.54 kW -Mo S 12.97 /kW -Mo 130,667
61 Energy Charge 1,294,769 kWh S 0.005651 /kWh 7,317
62 Power Fatter Adjustment Charge 0 Kvar $ 0.54 / Kvar
63 Power Factor Adjustment Credit 0 Kvar S (0.54) / Kvar
64 Total 1,294,769 kWh S 234,685
65 Total Printery Voltage
66
67
2,261,982,436 kWh
$ 63,019,051
Target $ 63,020,348
Under Target 1,297
-030-
151
152
Docket No. 42004
Sub -Transmission Voltage 69-115 kV
68 LGST[% Service Availability Charge 108.00 Bills 5 1,789.06 /Month S 193,218
69 Demand Charge - Summer 567,922.30 kW -Mo S 1046 1 kW -Mo 6,054,052
70 DemandClarge- Winter 1,061,124.70 kW -Mo $ 7.48 /kW -Mo 7,937,213
71 Energy Charge 1,101,550,734 kWh $ 0.003891 /kWh 4,286,134
72 Energy Charge, Imide City Limits 0 kWh S 0.006358 / kWh
73 Leu: REC Opt -Out 978,937,589 kWh $ (0.000288) / kWh (281,934)
74 Power Factor Atijuehnent Charge 274,077 Kum. S 0.55 / Kvar 150,742
75 Power Factor Adjustment Crdit 24,688 Kyr S (0.55) / Kver (13,578)
76 Total 1,101,550,734 kWh $ 18,325,847
77 Standby Service Availability Charge -Non Firm stand-by 12.00 Bills $ 1,789.06 / Month S 21,469
78 49-115 kV Tramminion Standby Capacity Fa - Sommer 39,667.00 kW -Mo $ 2.88 / kW -Mo 114,241
79 Trananloloo Standby Capacity Fee - Winter 80,333.00 kW -Mo S 2.35 / kW -Mo 188,783
80 Gen Standby Cap Reservation Fee - Sommer 39,667.00 kW -Ma 5 1.16 / kW -Mo 46,014
81 Gen Standby Cap Reservation Fee- Winter 80,333.00 kW -Mo $ 0.94 / kW -Mo 75,513
82 Usage Demand Charge - Summa 0.00 kW -Mo $ 10.66 / kW -Mo
83 Usage Deroand Purge - Winter 0.00 kW -Mo S 7.48 / kW -Mo
HI EnagyCharge 8,228,087 kWh S 0.003891 /kWh 32,015
85 Toll 8,228,087 kWh 5 478,035
86 Total Sob -Transmission Voltage 69. 115 kV 1,109,778.821 kWh S 18,803,882
87 Target S 18,803,882
88 Under Target 0
Backbone Traasmlaion Voltage 115+ kV
39 LGSTBTX Service Availability Charge 468.00 Bills S 1,77331 ( Month $ 829,909
90 Demand Charge - Summer 2,680,723.06 kW -Mo $ 10.57 / kW -Mo 28,333,243
91 Demand Charge - Whiter 5,255,988.27 kW -Mo $ 7.39 / kW -Mo 38,841.753
92 EnagyCharge 4,950,879,940 kWh $ 0.003870 /kWh 19,159,905
93 Energy Charge, Inside City Limits 167,990,427 kWh 5 0.006337 / kWh 1,064,555
94 Ices: RECOpt-Out 3,397,872,109 kWh S (0.000286)/kWh (971.791)
95 Power Factor ActuWnaHCharge 964.739 Kvar $ 0.55 / Kvar 530,606
96 Power Factor Adjustment Credit 664,685 Kvar S (0.55) / Kvar (365,577)
97 Total 5,118,870,367 kWh S 87,424,603
98 Standby Service Availability Charge -Non Firm stand-by 120.00 Bills 5 1,773.31 / Month 5 212,797
99 115+ kV Transmission Standby Capacity Fee- Stunner 89,217.33 kW -Mo S 2.85 / kW -Mo 254,269
100 Transmission Standby Capacity Fee - Winter 190,678.67 kW -Mo $ 232 / kW -Mo 442,375
101 Gan Standby Cap Reservation Fee - Summer 89,21733 kW -Mo 5 116 / kW -Mo 103,492
102 Gan Standby Cap Reservation Fa - Witmer 190,678.67 kW -Mo 5 0.94 1 kW -Mo 179,238
103 Usage Demand Charge - Snnmer 2,360.67 kW -Mo S 10.57 / kW -Mo 24,952
104 Usage Demand Charge - Winter 6,624.33 kW -Mo S 7.39 / kW -Mo 48,954
105 Energy Charge 53,635,474 kWh S 0.003870 /kWh 207,569
106 Total 53,635,474 kWh S 1,473,646
107 Total Backbone Transmission Voltage 115+ kV 5,172,505,841 kWh 5 88,898,249
S 88,898,246
108 Total (fiat 30+65+86+107) 11,001,239,447 kWh 5 280,433,591
t09 Target 280,436,596
110 Under Target 2,999
-031-
153
Docket No. 42004
$Dull Maalclaal and School %Mee
111 SMSTX Service Availability Charge 30,769.00 Bills 5 12.67 / Month S 389,843
112 Bunny Charge -Summer 4,692,326 kWh $ 0.045956 /kWh 215,641
113 EnergyCharge- Winter 10,152,115 kWh 5 0.038091 /kWh 386,704
114 Tolal 14,844,442 kWh S 992,188
115 Total Sma11 Mnateipal and School Service
116
117
Lame Modeipal and School Service
14,844,442 kWh
S 992,188
Target 992,282
Under Target (94)
118 LMSTX Service Availability Charge 13,339.00 Bills S 25.89 / Month S 345,347
119 Demand Charge - Summer 221.419.89 kW -Mo $ 11.60 / kW -Mo 2,568,471
120 Demand Charge .Winter 358,151.16 kW -Mo $ 9.14 /kW -Mo 3,273,502
121 Energy Charge 190,891,479 kWh S 0.005123 / kWh 977,937
122 Power Factor Adjustment Charge 33,573 Kvar S 0.55 /Kvar 18,465
123 Power Factor Adjustment Credit 14,742 Kvar 5 (0.55) /Kva+ (8,108)
124 Total 190,891,479 kWh S 7,175,614
125 Target $ 7,177,553
126 Under Target 1,939
127 LSSTX Service Availability Charge 9,286.00 Bills S 36.49 / Month S 338,846
128 Demand (targe - Summer 265,763.66 kW -Mo S 12.89 / kW -Mo 3,425,694
129 Dead Charge -Winter 469,384.52 kW -Mo S 10.19 / kW -Mo 4,783,028
130 Energy Charge 175,460,220 kWh S 0.005901 /kWh 1,035,391
131 Power Factor Adjustment Charge 19,492 Kvar 5 0.55 / Kvar 10,721
132 Power Facer Adjustment Credit 3,282 Kvar S (0.55) 1 Kvar (1,805)
133 Tolal 175,460,240 kWh S 9,591,875
134 Target 9,593,556
135 Under Target 1,682
136 Total Large Meaidpal asd School Service 366,351,719 kWh $ 16,767,489
137 Total (lines 115 + 136) 381,196,161 kWh S 17,759,677
138 Target 17,763,392
139 Under Target 3,713
-032-
154
Area Lithane Service
140 Plood Ltg. Light Charge
141 Energy Charge
142 Per Book - Base Rate Rave=
143 GaardLtg. Light Charge
144 Energy Charge
145 Per Book - Base Rete Revenue
146 SA -810 Light Charge
147 Energy Charge
148 Per Book - Base Rate Revenue
149 Total Area Lighting Saralee
Street Ltehtiea Service
150 SL Light Charge
151 Energy Charge
152 Per Book - Bear Rede Revenue
153 Total -Street Llghtiag Servka
Sian Uehtlue Service
154 SA -805 Minimum Charge
155 Energy Charge
156 Per Book - Baae Rate Revenue
157 Tota/ Sign Lighting Service
Docket No. 42004
51,084.00 Ltg-Mo varknu / Ug -Mo 5 1,425,244
12,314,868 kWh 50.000000 / kWh
12,314,868 kWh S 1,425,244
265,212-00 leg -Mo various / Ltg-Mo S 3,572,371
15,703,152 kWh 50.000000 /kWh
15,733,152 kWh 5 3,572,371
936.00 Ltg-Mo micas / Ltg-Mo $ 9,305
67,164 kWh 10.000000 /kWh
67,164 kWh 3 9,305
28,085,184 kWh 5 5,006,920
304,920.00 Ltg-Mo
29,113,200 kWh
29,113,200 kWb
29,113,200 kWh
various / Ltg-Mo S 2,772,288
10.000000 / kWh
S 2,772,288
S 2.772,288
0.00 Meters 50.00 / Meter 5
107,250 kWh 5 0.033220 /kWh $ 3,363
107,250 kWh 9 3,563
107,250 kWh
S 3,563
I58 Total (lines 149+153+157) 57,305,634 kWh S 7,782.771
Target 7,782,771
Over Target 0
159 Total Texas Ratak Bane Rate Revenue at Proposed Rates 13,831,637,129 kWh 5 494,155,504
Target S 499,164,940
tinder Target S (9,436)
-033-
111
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XceIEnergy�
$OUIHWI$U RP PUIIIC StitYief
ELECTRIC TARIFF
Section No. IS
Sheet No. I-1
Revision No. 39
Page 1 of 1
TABLE OF CONTENTS
SECTION TITLE SECTION SHEET
I Table of Contents I 1
II Description of Operations II 1
III Service Area List III 1
IV Rate Schedules IV 1-203
V Service Rules and Regulations V 1-31
T
X„.„,21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-037-
/6'
,[Energy°
JOUHSWE$TFRW PUrLMC SUYJCf
ELECTRIC TARIFF
159
Section No. II -S
Sheet No. II -1
Revision NoTS
Page 1 of 2
GENERAL DESCRIPTION OF OPERATIONS
Southwestern Public Service Company is an integrated, publicly -held, generation, transmission and
distribution company supplying retail and wholesale electric utility service in the counties and cities
shown on Section No. III of this tariff. The Company also serves retail and wholesale customers in the
State of New Mexico. The Generation and Transmission Map, Section No. II, Sheet No. II -1, page 2 of
2, details the primary power supply and location of the Company.
This tariff, including all Rules and Regulations, and all applicable rate schedules, is on file in the
Company's Amarillo and Austin offices, and copies are obtainable by any Customer without charge
upon request.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-038-
160
ra XcelEnerg►y�
$OUtNWISIIRN 10Uttie U IV CE
ELECTRIC TARIFF
Section No. III
Sheet No. III -1
Revision No?9
Page 1 of 1
LIST OF COUNTIES AND CITIES PROVIDED ELECTRIC UTILITY
SERVICES BY SOUTHWESTERN PUBLIC SERVICE COMPANY
COUNTY crrr s WITHIN COUNTY
Armstrong Claude
Bailey Muleshoe
Briscoe Silverton
Carson Groom, Panhandle, Skellytown, White Deer
Castro Dimrnitt, Hart
Cochran Morton, Whiteface
Crosby Crosbyton, Lorenzo, Rails
Dailam Dalhart
Dawson
Deaf Smith Hereford
Donley
Floyd Floydada, Lockney
Gaines Seminole, Seagraves
Garza Post
Gray Lefors, McLean, Pampa
Hale Abernathy, Hale Center, Petersburg, Plainview
Hansford Gruver, Spearman
Hartley Channing, Dalliart
Hemphill Canadian
Hockley Anton, Levelland, Ropesville
Hutchinson Borger, Fritch, Stinnett
Lamb Amherst, Earth, Littlefield, Olton, Springlake, Sudan
Lipscomb Booker, Darrouzett, Follett, Higgins
Lubbock Idalou, Lubbock, New Deal, Shallowator, Slaton, Wolfforth
Lynn Tahoka, Wilson
Moore Cactus, Dumas, Sunray
Ochiltree Perryton
Oldham Adrian, Vega '
Panner Bovine, Friona, Farwell
Potter Amarillo
Randall Amarillo, Canyon, Lake Tanglewood, Timbercreek,
Palisades
Roberts Miami
Sherman Stratford
Swisher Happy, Kress
Terry Meadow, Wellman
Wheeler Mobeetie, Wheeler
Yoakum Denver City
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS -039-
"0„,
XceelEnerg}-
SOUTHwlSFFBN PUBLIC SEBYICE
ELECTRIC TARIFF
161
Section No. IV
Sheet No. 1V-3
Revision No. 18
Page 1 of 2
RESIDENTIAL SERVICE
APPLICABLILITY: To residential Customers for electric service used for domestic purposes in private
residences and separately metered individual apartments, when all service is supplied at one point of
delivery and measured through one kilowatt-hour meter, where facilities of adequate capacity and suitable
voltage are adjacent to the premises to be served. Single phase motors that do not exceed 10 horsepower
individual capacity, may be served under this rate. A Residential Service with Electric Space Heating Tariff
is available for Customers who predominately use electric space heating.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $7.60 per month.
Energy Charge:
$0.076093 per kWh for all kWh used per month during each summer month
$0.065718 per kWh for all kWh used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
I
I
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kilowatt-hour of the above rate shall be
increased by the applicable fuel cost recovery factor per kilowatt-hour as provided in PLJCT Sheet IV -69.
This rate schedule is subject to other applicable rate adjustments.
AVERAGE MONTHLY PAYMENT: Upon request, any residential customer may be billed monthly on F
levelized payment plan. A Customer's monthly payment amount is calculated by obtaining the most recent
twelve months of actual consumption and dividing that amount by twelve, and applying Company's current
rates to the average kWh consumption. The account will be trued -up every twelve months. The true]
amount is equal to the difference between the total levelized payments during the previous twelve monthe
and the actual amount billed during the same period.
CHARACTER OF SERVICE: A -C; 60 hertz; single-phase 120/240 volts; where available on secondary,
three phase 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension policy.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-040-
162
Xcel Energy
9outHWESU*W rU9ttt S UVSCE
ELECTRIC TARIFF
Section No. TV
Sheet No. IV -3
Revision No. 18
Page 2 of 2
RESIDENTIAL SERVICE
TERMS OF PAYMENT: Net in 16 days after mailing date. If the sixteenth day falls on a holiday or weekend, the
due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is subjec
to the terms and conditions set forth in Company's Rules, Regulations, and Conditions of Service on filet
with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-041-
XcelEnergy'
SOftliiiM IN Ptlitit St'ttY4Ct
ELECTRIC TARIFF
163
Section No. IV
Sheet No. IV -18
Revision NtT 18
Page 1 of 2
SECONDARY GENERAL SERVICE
APPLICABILITY: To all commercial and industrial electric service supplied at secondary voltage at one
Point of Delivery and measured through one meter, where facilities of adequate capacity and suitable
voltage are adjacent to the premises to be served, in excess of 10 kW of demand.
Each year, Company will review the demand of all Customers receiving service under this tariff. If the
average of Customer's twelve monthly demands in the immediately preceding calendar year does not
exceed 10 kW, then Customer is not eligible to continue receiving service under this tariff.
Not applicable to standby, supplementary, resale or shared service, or service to oil and natural gas
production Customers.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $26.76 per month
Energy Charge: $0.005651 per kWh for all kWh used during the month
Demand Charge:
$15.95 per kW of demand used per month during each summer month
$12.97 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
I
I
I
I
DEMAND: Company will furnish, at Company's expense, the necessary metering equipment to measure the
Customer's kW demand for the 30 -minute period of greatest use during the month. In no month, shall
the billing demand be greater than the kW value determined by dividing the kWh sales for the billing
period by 80 hours.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with
demand exceeding 200 kW. Bills will be increased $0.54 for each kvar by which the reactive demand
exceeds 0.33 times the measured kW demand, and will be reduced $0.54 for each kvar by which the
reactive demand is less than 0.33 times the measured kW demand. R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-042-
164
0 &elEnerg►y-
SOUTHWESTERN PeWC SERV)CE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -18
Revision No. 18
Page 2 of 2
SECONDARY GENERAL SERVICE
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh shall be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate schedule is subject to
other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard secondary
voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. if the,
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in the Company's Rules, Regulations and Conditions of
Service on file with the Public Utility Commission of Texas. A Contract may be required by the
Company to be executed prior to extending service if Customer's load is expected to be greater than 200
kW. The contract term shall contain a minimum contract period with an automatic renewable provision
from year to year thereafter.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-043-
XceIEnerg
SOUVHWF$UIN ?USEIe SERVICE
ELECTRIC TARIFF
165
Section No. IV
Sheet No. IV -56
Revision No. k5
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Bishop Hills Property Owners, Amarillo, Texas.
RATE: Each 7,000 lumen mercury vapor post top light @ $8.29 per month.
AGREEMENT WITH: Amarillo College, Amarillo, Texas. •
RATE: Each 7,000 lumen wood pole overhead mercury vapor street light @ $8.29 per month.
Each 20,000 lumen steel pole underground mercury vapor street light (two lamps per pole) @ $24.81 per
month.
AGREEMENT WITH: Chase Bank, Amarillo, Texas.
RATE: Floodlighting of Chase Bank Building, $234.87 per month.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF ENERGY USE: 7,000 lumen lamp uses 68 kWh per month
20,000 lumen lamp uses 151 kWh per month
Floodlighting uses 6,909 kWh per month
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel
cost recovery factor per kWh as provided in PUCT Sheet IV -69.
Pursuant to the 2005 Energy Policy Act, mercury vapor lamp ballasts shall not be manufactured or
imported after January 1, 2008. When Company's inventory of mercury vapor ballasts and lamps is
exhausted, Customers will be given the option of having the lighting facilities removed, or replaced with
another type of lamp at the applicable rate for the replacement lamp.
„C„,0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-044-
166
X e1'Energy-
SODTHWE$URN Mite SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -58
Revision No. 15
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Cal Farley's Boys Ranch, Amarillo, Texas.
POINTS OF SERVICE: Northwest of Amarillo, Southwest of Gruver.
RATE: Each 7,000 lumen wood pole overhead mercury vapor (MV) light @ $8.29 per month.
Each 15,000 lumen wood pole overhead high pressure sodium (TIPS) light @ $10.12 per month.
Each 20,000 lumen wood pole overhead mercury vapor (MV) light @ $20.41 per month.
DETERMINATION OF ENERGY USE: 7,000 lumen MV lamp uses 68 kWh per month
15,000 lumen RPS lamp uses 56 kWh per month
20,000 lumen MV lamp uses 151 kWh per month
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel
cost recovery factor per kWh as provided in PUCT Sheet 1V-69.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
Pursuant to the 2005 Energy Policy Act, MV lamp ballasts shall not be manufactured or imported after
January 1, 2008. When the Company's inventory of MV ballasts and lamps is exhausted, customers will
be given the option of having the lighting facilities removed, or replaced with another type of light at the
applicable rate for the replacement light.
.‘„,21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-045-
XCeIEnertg
JOUIHWUVUt4 rUltVC MVO'
ELECTRIC TARIFF
167
Section No. IV
Sheet No. IV -61
Revision No. 12
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Canadian River Municipal Water Authority (CRMWA)
POINTS OF SERVICE: Pumping facilities related to CRMWA's transport and production of water to
CRMWA' s member cities from Lake Meredith and groundwater in Roberts County, Texas.
RATE: The base rate for firm and interruptible service to CRMWA is:
$0.025434 per kWh for the first 3,500,000 kWh used per month. I
$0.019772 per kWh for all additional energy used per month. I
INTERRUPTIBII.TTY: When a scheduled interruption is requested in any month by Company, CRMWA will
interrupt all load at Pump Station Nos. 1 — 4, in excess of two pumping units at each station, and will
also interrupt all load at Pump Station Nos. 21 and 22, in excess of one pumping unit at each station, and
will interrupt all load in the waterfield, including Booster Stations 31 and 32 and the wells associated
with these stations, with the exception of the wells feeding Pump Station No. 21 directly, or which can
be delivered to Pump Station No. 21 by gravity flow. Uninterrupted wells will not have a connected
load in excess of 2134 kW. Pump Station Nos. 5 and 6 are not subject to interruption. Normal
interruptions of load shall not exceed 60 hours in any month except in an extreme emergency. If a
scheduled interruption of load causes an inability of CRMWA to maintain sufficient water storage,
pumps may be restarted with two-hour notice to the Company. Energy served during this period will be
billed at the rate for the first energy block.
NOTICE OF INTERRUPTION: Company will give notice of need for interruption at least two hours before
the interruption is required.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel
cost recovery factor per kWh as provided in PUCT Sheet IV -69.
POWER FACTOR: Synchronous motors will be installed on each pumping unit in CRMWA's pumping plant
Nos. 1 — 4, and will be operated at Unity Power Factor. Customer agrees to maintain a power factor of
at least 0.95 on pumping units 21 and 22.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next workday.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-046-
168
Energy
SOUtx1EJytR$ 00111C JERY{CE
ELECTRIC TARIFF
Section No. IV
Shed No. IV -65
Revision No. 17
Page 1 of 2
GUARD LIGHTING SERVICE
APPLICABILITY: Under contract for night outdoor lighting service where facilities of adequate capacity and
suitable voltage are adjacent to the premises to be served. This tariff is closed to new Customers as of
September 1, 2000 in accordance with the Public Utility Commission of Texas Order in Docket No.
21190, and no additional lights will be installed for existing Customers. Ownership of existing Guard
Lights may be transferred to a new Customer if the property that the Guard Light serves is sold to the new
Customer and the new Customer agrees to the monthly charge for the applicable Guard Light.
Pursuant to the Federal Energy Policy Act of 2005, mercury vapor lamp ballasts shall not be
manufactured or imported after January 1, 2008. When Company's inventory of mercury vapor ballasts
and lamps is exhausted, Customers will be given the option of having the lighting facilities removed, or
replaced with another type of light at the rate for the replacement light.
TERRITORY: Texas service territory.
RATE: Each 15,000 lumen high pressure sodium (HPS), wood pole, overhead bracket type light @ $13.36 per
month.
Each 7,000 lumen mercury vapor (MV), wood pole, overhead bracket type light @ $13.77 per month.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If service is
billed on a residential bill, the late payment charge will not be imposed. If the sixteenth day falls on a
holiday or weekend, the due date will be the next work day.
DETERMINATION OF ENERGY USE: 15,000 lumen HPS lamp uses 56 kWh per month; 7,000 lumen MV
lamp uses 68 kWh per month.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel cost
recovery factor per kWh as provided in PUCT Sheet IV -69. However, Guard Light Service provided by
Company which is connected to a circuit previously metered by Company for other electric service shall
not have the above rate increased by the applicable fuel cost recovery factor.
CONDITIONS OF SERVICE: Company will construct, own, operate and maintain, on Customer's premises, the
required number of 15,000 lumen, 150 watt, HPS overhead lights, and/or the required number of 7,000
lumen, 175 watt, MV overhead lights, mounted on a metal bracket, photo -electrically controlled, installer
on Company's service pole, on a separate 30 foot pole, or on any suitable mounting device belonging to
the Customer, having a secondary line span not to exceed 150 feet in length. Lights will not be installed
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-047-
XcelEne
SOtTRWM RN POIIIC SEXYICE
ELECTRIC TARIFF
169
T
Section No. IV
Sheet No, IV -65
Revision No. 17
Page 2 of 2
GUARD LIGHTING SERVICE
on any mounting device which the Company deems, in its sole discretion, unsafe or unsuitable for this
purpose.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase; 120 or 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension policy.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in Company's Rules, Regulations, and Conditions of
Service on file with the Public Utility Commission of Texas.
X,„.0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-048-
170
XcelEnergy-
SO1T$WESTE1N tUltit StIYJCl
ELECTRIC TARIFF
Section No. W
Sheet No. IV -91
Revision No. 14 T
Page 1 of 4
MUNICIPAL AND STATE STREET LIGHTING SERVICE
APPLICABILITY: To Municipal and State of Texas Agency Customers for street lighting service where
facilities of adequate capacity and suitable voltage are adjacent to the point of service.
Pursuant to the Federal Energy Policy Act of 2005, mercury vapor (MV) lamp ballasts shall not be
manufactured or imported after January 1, 2008. When Company's inventory of MV ballasts and
lamps is exhausted, Customers will be given the option of having the lighting facilities removed, or
replaced with another type of light at the rate for the replacement light.
TERRITORY: Texas service territory.
RATE: The charge per lamp per month shall be in accordance with the following rates:
RESIDENTIAL AREAS
LAMP SIZE LAMP TYPE WOOD POLE • STEEL POLE
Lumen Overhead (2) Overhead Underground (1)
7,000 MV $ 5.72 $ 7.93 $ 9.02
15,000 BPS 10.88 10.88 10.88
COMMERCIAL AREAS AND TRAFFIC ARTERIES
LAMP SIZE LAMP TYPE WOOD POLE SPELL POLE
Lumen Overhead Overhead Underground (1)
20,000 MV 9.60 13.24 18.01
35,000 MV 13.33 16.86 21.88
50,000 MV 16.23 20.00 24.84
15,000 HPS 10.88 10.88 10.88
27,500 HPS 21.00 21.00 21.00
EXISTING FEEDER NEW STREET LIGHT CIRCUIT
CIRCUIT (50' POLES) (45'WOOD POLES OVERHEAD)
50,000 IMPS $ 23.14 $ 27.34
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-049-
Xef Energr
SOU?HWUUIN PUSLIC SERVICI
ELECTRIC TARIFF
171
Section No. IV
Sheet No. IV -91
Revision No. 14 T
Page 2 of 4
MUNICIPAL AND STATE STREET LIGHTING SERVICE
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added after 16 days if the sixteenth
day falls on a holiday or weekend, the due date will be the next work day.
STATE OWNED FREEWAY LIGHTING SYSTEM:
Available to all state-owned and city maintained street and highway lighting and incidental safety
lighting that is photocell controlled. The state-owned highway lighting rates do not include any
maintenance service by Company.
Lumen Lamp Type Underground
20,000 MV $6.84
27,500 HPS 4.84
50,000
HPS-400 watt 6.10
(1) Applicable to both bracket -type and post -top luminaires.
(2) Underground option is available where facilities of correct voltage are readily available and customer
agrees to pay a non-refundable contribution in aid of construction equal to the total cost of installation
in accordance with the standard line extension policy.
DETERMINATION OF ENERGY USE:
MERCURY VAPOR
7,000 lumen lamp uses 68 kWh per month
20,000 lumen lamp uses 151 kWh per month
35,000 lumen lamp uses 257 kWh per month
50,000 lumen lamp uses 363 kWh per month
100 watt lamp uses 42 kWh per month
1,000 watt lamp uses 363 kWh per month
HIGH PRESSURE SODIUM
15,000 lumen lamp uses 56 kWh per month
27,500 lumen lamp uses 97 kWh per month
50,000 lumen lamp uses 159 kWh per month
400 watt lamp uses 159 kWh per month
.X„,„00
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-050-
172
Xis�;nerg
SOUVHWE$7ERN ►URIC SERV/CE
ELECTRIC TARIFF
Section No. 1V
Sheet No. IV -91
Revision No. 14 T
Page 3 of 4
MUNICIPAL AND STATE STREET LIGHTING SERVICE
FUEL COST RECOVERY: The charge per kilowatt-hour of the above rate shall be increased by the
applicable fuel cost recovery factor per kilowatt-hour as provided in PUCT Sheet IV -69.
If any street light is permanently removed from service at the City's request, the City will pay to
Company, at the time of removal from service of such light, the original cost of the equipment
taken out of service, less depreciation of four percent per year. If any street light is removed from
service temporarily (at least two months) at the City's request, the monthly rate for the light during
temporary disconnection will be the base charge per lamp as stated above. Fuel cost recovery will
not be charged or credited on any temporarily disconnected street light.
CONDITIONS OF SERVICE: The foregoing rates include the furnishing by Company of the electric
energy necessary to operate the municipal street lighting system, the replacement of lamps, and the
normal maintenance of fixtures, wires, transformers and all other component parts of the street
lighting systems, as such replacements and maintenance become necessary. In the event
maintenance and/or lamp and glassware replacements become excessive due to vandalism or
similar causes, Company will notify the City and the City will exert whatever means are at its
disposal in the form of law enforcement agencies or other protective measures to eliminate
destruction of street lighting equipment. If such vandalism persists, Company reserves the right to
remove street lights.
Company will install, own, operate and maintain the municipal street lighting system. If, for any
reason, Company is unable to continue service of particular equipment, said equipment will, at the
City's option, be removed by Company or replaced by Company with currently available
equipment, and the City will pay the appropriate rate for new equipment.
Street light burning time will be from approximately one-half hour after sunset to approximately
one-half hour before sunrise.
STREET LIGHT OUTAGE REPAIR: SPS shall patrol all streetlights on a quarterly basis. SPS will
track street light outage information and report performance to any requesting city and/or state
agency within thirty (30) days after each quarterly patrol is completed. In addition, SPS will
implement a formal system to track street light outage performance and will track trouble reports
submitted by: (a) Customers; (b) employees; (c) municipalities; and (d) routine SPS patrols. SPS
shall use best efforts to repair all street light trouble orders, exclusive of freeway lights, within
seven calendar days. If a municipal street light, exclusive of freeway lights, is not repaired within
seven (7) calendar days after SPS receives notice of the specific streetlight trouble, SPS shall issue
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-051-
xcelEnergy-
saUTHWE$TURN PUittt SttYJtr
ELECTRIC TARIFF
173
Section No. IV
Sheet No. IV -91
Revision No. 14 T
Page 4 of 4
MUNICIPAL AND STATE STREET LIGHTING SERVICE
STREET LIGHT OUTAGE REPAIR: (cont.)
a credit to the Customer's bill equal to one month's charges for the respective street light. Further,
SPS shall issue an additional credit to the Customer equal to a month's charges for each such
streetlight for each additional seven (7) calendar -day delay in completing repairs for each affected
streetlight. Freeway lights shall be repaired in a reasonable amount of time taking into account
coordination with state transportation agencies and arranging traffic control for public safety while
SPS agents repair freeway lights. SPS shall prepare a written street light performance plan to
include periodic patrolling, advanced re-lamping, painting, and glassware cleaning, and shall
provide any city and/or state agency an annual streetlight -performance report showing the number
of streetlights for which SPS has issued credits, including identification of those streetlights for
which SPS issued multiple credits, and amounts of said credits. The streetlight -performance plan
shall be completed by December 1 of each year and the streetlight -performance report shall be
completed by the end of the First Quarter of the succeeding year to which the report applies.
Upon request, SPS shall also provide a detailed report to any requesting city and/or state agency
identifying the streetlights for which a trouble report was received, the date the trouble report was
received, the commitment date provided by SPS stating when the trouble would be repaired, and the
date the trouble was repaired. Notwithstanding the above conditions, both Customer and SPS
realize that storm outages and other items outside of the control of SPS may affect repair times for
street light outages. SPS shall not be required to provide credits to Customers for delayed repairs
caused by, or during, such events.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
RULES REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in the Company's Rules, Regulations, and Conditions
of Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-052-
174
XceIEnergy-
11011?HWF57Uk ru!!tc atrvicr
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -98
Revision No. V1
Page 1 of 5
MISCELLANEOUS SERVICE CHARGES
APPLICABILITY: The service charges listed below are applicable to all Customers served by Company, and
are in addition to any other charges made under Company's tariff for electric service.
TERRITORY: Texas service territory.
Name Charge
1. Returned Check Charge $ 16.00
2. After Hours Connection Charge
Inside City Limits
Outside City Limits
3. Field Collection Charge
4. Special Bill Form Charge
5. Account History Charge
6. Reconnect Charge:
Inside City Limits
Reconnect during business hours
Reconnect during non -business hours
Outside City Limits
Reconnect during business hours
Reconnect during non -business hours
7. Facilities Rental Charge
8. Restoration of Tampered
Service Charge
$ 87.00
$108.00
$ 10.00
$ 10.00
$ 20.00 or cost, whichever is greater.
$ 55.00
$ 87.00
$ 90.00
$ 108.00
2.00% per month applied to net
reproduction cost of facilities.
$200.00 during business hours
each occurrence or
$240.00 during non -business hours
each occurrence, plus expense for damages.
T
I
I
X„,„21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-053-
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SOUlHWWEsw iUtitC SMOG,
ELECTRIC TARIFF
175
Section No. IV
Sheet No. W-98
Revision No. 14
Page 2 of 5
MISCELLANEOUS SERVICE CHARGES
9. Temporary Service Charge At cost.
10. Meter Testing Charge At cost, not to exceed $81.00.
11. Load Control Equipment Charge At cost, see Articles IV and V of Electric
Demand Signal Agreement.
12. Miscellaneous Charges At cost.
13. Relocation of Facilities Charge Cost of relocation.
14. Non -Routine Charges At cost.
15. Pulse Metering Equipment
Installation and Replacement Charge
Installation Cost (One Output) $335
With Additional Output $485
Replacement:
Service Call
Up to 2 Components
All Components
plus
$205
$235
Components
Meter Pulse Initiator $120
Pulse Termination Box $ 10
Pulse Isolation Relay $120
16. Sale of Renewable Energy Credits At agreed-upon price
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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176
XceiEnergy"
SOUIJIWES?EIN PtHaft SEIV10E
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -98
Revision No. 14
Page 3 of 5
MISCELLANEOUS SERVICE CHARGES
DESCRIPTION:
1. Returned Check Charge is made when Customer's check has been dishonored by the maker's bank
and returned to Company.
2. After Hours Connection Charge is made when a new connection is requested by Customer to be
made outside of regular working hours.
3. Field Collection Charge is made when Company makes contact at Customer's premises for
collection of delinquent bill or deposits. Only one charge is made per month.
4. Special Bill Form Charge is made each time Company provides a manually prepared special bill
analysis.
5. Account History Charge is made each time Customer requests, and Company provides, a billing or
usage history or analysis for a premises, exceeding the most recent 36 months of service. The charges
for these services will equal Company's labor, material, overhead, and data processing expenses for
processing the request, or $20.00, whichever is greater.
6. Reconnect Charge is made when Customer requests' reconnection of electric service following
disconnection due to a delinquent account.
7. Facilities Rental Charge is made when Customer rents facilities owned and maintained by Company
(not applicable to substation facilities).
S. Restoration of Tampered Service Charge is applied to any Customer who has tampered with the
meter installed on Customer's premises, or by any other means prevented the total energy consumed by
Customer from being registered by the meter installed for such purposes.
9. Temporary Service Charge is made when Customer requests temporary services. In addition to the
cost of service rendered under the applicable rate, Customer will be charged the cost of installing and
removing the facilities required to provide temporary service, in excess of any salvage realized.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-055-
XcelEnetrjy-
SOUTNWiMIN Mitt SERVILE
ELECTRIC TARIFF
177
Section No, IV
Sheet No. IV -98
Revision No. 14
Page 4 of 5
MISCELLANEOUS SERVICE CHARGES
10. Meter Testing Charge is free for the first meter test. If Customer requests a meter test within four
years of Customer's last request for a meter test, Company may charge Customer an amount to recover
the cost of the test, not to exceed $81.00 for a residential Customer, if the meter is determined to be
functioning properly.
11. Load Control Equipment Charge is equal to cost of materials, labor, transportation, miscellaneous
expenses and all applicable overheads for the installation necessary to provide the required signals. In
certain cases, Customer may be charged for totalizing and/or recording equipment. Customer will also
be charged for operation and maintenance expenses in accordance with Articles IV and V of the Electric
Demand Signal Agreement.
12. Miscellaneous Charges are made for services performed at the request of Customer but not covered
specifically by a specific rate. Customer will be charged the reasonable costs incurred for performing
such services, including but not limited to, parts, labor and transportation.
13. Relocation of Facilities Charge is made when Customer requests the relocation of facilities for
Customer's benefit or convenience.
14. Non -Routine Charge is made for maintenance and replacement of street lighting facilities, other than
what is provided for by the street light tariff. These costs include labor, materials, transportation,
processing and special equipment. This includes, without limitation, costa for traffic control as required
by federal, state or local laws or regulations.
15. Pulse Metering Equipment Installation and Replacement Charge is made when Customer requests
access to pulse from the revenue meter, in accordance with the Agreement and Terms and Conditions for
Pulse Metering Equipment Installation. Replacement of existing pulse metering equipment is charged
according to type of equipment Customer requests be replaced.
16. Sale of Renewable Energy Credits ("RECs"). Company may transfer RECs, as defined at P.U.C.
SUBST. R. 25.173(c)(13)(14) and (15), to end-use Customers, as authorized by P.U.C. SUBST. R.
25.173(d) and 25.173(1)(2)(3) and (6), with consideration agreed-upon between the Company and the
purchaser. Amounts due the Company from sales of RECs may be added to
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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178
"0 XceIEnergy-
JOUT$WESVE1tr +UIUC $,IYICI
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -98
Revision No. 14
Page 5 of 5
MISCELLANEOUS SERVICE CHARGES
Sale of Renewable Energy Credits ("RECs") (cont.)
an end-use Customer's bill for electric service under another tariff, but do not alter the purchaser's
responsibilities under the conditions and rates for electric service provided through that tariff.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-057-
/0
Jl Energy°
souTNwssruN ssitvlct
ELECTRIC TARIFF
179
Section No. IV
Sheet No. IV -99
Revision No. 12
Page 1 of 1
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Orion Engineered Carbons (formerly Degussa; or J.M. Huber Corp.)
POINT OF SERVICE: Vicinity of Borger, Texas
RATE: The Contract rate of $0.008432 per kilowatt-hour (kWh) used per month.
I
If, during any billing month, the kWh output of Degussa's generating plant is less than Degussa's kWh
load, the applicable general service rate shall apply to that portion of demand and energy exceeding the
output, except during one month each calendar year which is mutually agreed upon by SPS and Degussa
wherein scheduled boiler inspection and maintenance is conducted. During that month, all kWh will be
billed at the above contract rate.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day,
FUEL COST RECOVERY: The net charge per kWh delivered under the above contract rate shall be increased
by the primary distribution fuel cost recovery factor provided in PUCT Sheet No. IV -69.
ORIGINAL CONTRACT PERIOD: January 1, 1989 — December 31, 1995.
ANNUAL MINIMUM CHARGE: The contract rate for an amount of kWh calculated by multiplying the
maximum kW demand of Orion's load experienced during the prior twelve months by 5,256 hours.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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180
XceI Energy~
sourrrwetrrsk rustts srxv?cr
ELECTRIC TARIFF
Section No. IV
Sheet No. 1V-108
Revision No. 10
Page 1 of 4
LARGE GENERAL SERVICE - TRANSMISSION
APPLICABILITY: Under contract to all commercial and industrial electric service supplied at transmission
level voltage at one Point of Delivery and measured through one meter, where facilities of adequate
capacity and suitable voltage of 69 kV or higher is adjacent to the premises to be served.
Not applicable to standby, supplementary, resale or shared service.
TERRITORY: Texas service territory.
OUTSIDE CITY LIMITS
SUB TRANSMISSION SERVICE OF 69 KV:
RATE: Service Availability Charge Per Month: $1,789.06 '
Energy Charge: $0.003891 per kWh for all kWh used during the month
Demand Charge: $10.66 per kW of demand used per month during each summer month
$ 7.48 per kW of demand used per month during each winter month
TRANSMISSION SERVICE OF 115 KV AND ABOVE:
RATE: Service Availability Charge Per Month: $1,773.31
Energy Charge: $0.003870 per kWh for all kWh used during the month
Demand Charge: $10.57 per kW of demand used per month during each summer month
$ 7.39 per kW of demand used per month during each winter month
I
INSIDE CITY LIMITS
T
SUB TRANSMISSION SERVICE OF 69 KV:
I
RATE: Service Availability Charge Per Month: $1,789.06
Energy Charge: $0.006358 per kWh for all kWh used during the month I
I
Demand Charge: $10.66 per kW of demand used per month during each summer month
$7.48 per kW of demand used per month during each winter month I
TRANSMISSION SERVICE OF 115 KV AND ABOVE: I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-059-
XcelEnergy.'
$OUVNWESTE!N PttIEtt SEEYICE
ELECTRIC TARIFF
181
Section No. IV
Sheet No. IV -108
Revision No. 10
Page 2 of 4
LARGE GENERAL SERVICE - TRANSMISSION
RATE: Service Availability Charge Per Month: $1,773.31
Energy Charge: $0.006337 per kWh for all kWh used during the month
Demand Charge: $10.57 per kW of demand used per month during each summer month
$ 7.39 per kW of demand used per month during each winter month
APPLICABLE TO BOTH INSIDE AND OUTSIDE CITY LIMITS
SUMMER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October — May.
OPTIONAL SERVICE: Customers receiving service under this rate may elect to receive interruptible service by
participating in the Interruptible Credit Option.
DETERMINATION OF DEMAND: The kW determined from Company's demand meter for the 30 -minute
period of Customer's greatest kW use during the month, but not less than 70 percent of the highest
demand established in the preceding eleven months.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with demand
exceeding 200 kW. Bills computed under the above rate will be increased $0.55 for each kvar by which
the reactive demand exceeds 0.33 times the measured kW demand, and will be reduced $0.55 for each
kvar by which the reactive demand is less than 0.33 times the measured kW demand
LOSS ADJUSTMENT: Meter readings used for billing shall be increased to include transformation 1osgpi
when a meter is installed on the secondary side of any voltage transformation under 69 kV made on
Customer's side of the point of service.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be increased
by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate schedule
is suhject to other applicable rate adjustments.
CHARACTER OF SERVICE: Three phase, 60 hertz, supplied to the entire premises at approximately 69 kV
or above.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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182
6,1 XceiEnergy-
$ourawrsteUN PU$rrr SUvica
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -108
Revision No. 10
Page 3 of 4
LARGE GENERAL SERVICE - TRANSMISSION
LINE EXTENSIONS: All cost of equipment, supplies, and labor related to the installation of facilities
necessary to make service available shall be paid by Customer in advance. No transformation will be
made by Company at the point of service unless agreed to by Company.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied pursuant to this schedule is
subject to the terms and conditions set forth in the Company's Rules, Regulations and Conditions of
Service on file with the Public Utility Commission of Texas and to the terms and conditions of any
special contract service between Company and Customer that are not in conflict herewith.
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA §39.904(m-
1) and Commission regulations promulgated thereunder, shall receive a credit of $0.000288 per kWh tc
their electric billings. Customers who receive REC credits under this tariff do not share in any REC costs
and shall not be eligible to receive revenue credits for sales of RECs by the Company.
115 kV Customers who provide written notice to the Commission pursuant to PURA §39.904(m-1) and
Commission regulations promulgated thereunder, shall receive a credit of $0.000286 per kWh to their
electric billings. Customers who receive REC credits'under this tariff do not share in any REC costs and
shall not be eligible to receive revenue credits for sales of RECs by Company.
SUBSTATION LEASE: Company reserves the option to lease substation facilities. If the substation facilities tc
be leased serve a single Customer, that Customer must lease 100% of the facilities. If the substation
facilities to be leased serve multiple Customers, Company will determine a percentage of the substatior
capacity to be leased to the lessee, but no less than 4000 KVA of substation capacity will be leased to a
single Customer. The monthly lease charge will be two percent of the net reproduction costs of the leasee
facilities, calculated as of the commencement of the lease, and shall be paid by Customer to Company
along with the monthly invoice for
SUBSTATION LEASE (cont): electric service. Company reserves the right to increase the monthly substation.
lease charge whenever Company spends more than $100,000 in repairs, replacements, or upgrades to the
leased substation facilities in any consecutive twelve month period during the term of the lease. The
minimum lease term shall be 120 months and shall continue month to month thereafter until the lease
agreement is terminated. The lease agreement may be terminated by Customer with at least six months
prior written notice to Company. If Customer terminates the lease without giving Company six months
tzs,0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-061-
Xcel Energy
SOUINWESUURN'Witte SERVICE
ELECTRIC TARIFF
183
Section No. IV
Sheet No. 1V-108
Revision No. 10
Page 4 of 4
LARGE GENERAL SERVICE - TRANSMISSION
prior written notice or (2) earlier than 120 months from the commencement of the lease, the following
termination penalty shall apply:
Customer shall pay a Iease termination penalty of the net present value, using a rate of 8.18 percent
applied to the sum calculated as follows:
1. If Customer has made 120 or more monthly lease payments, the sum shall be six times the monthly lease
payment.
2. If Customer has made less than 120 monthly lease payments, the sum will be 120, less the number of
monthly lease payments made (but no less than six), times the monthly lease payment.
st,
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-062-
184
X Energ►yy
SOUit1WEHHEJli PO$tfe SEIVJCE
ELECTRIC TARIFF
Section No. IV
Sheet No.111-109
Revision No. Tl
Page 1 of 2
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: WRB Refining L.P.
POINTS OF SERVICE: WRB Refining L.P. Refinery and Chemical
Complex near Borger, Texas.
APPLICABILITY: Transmission service at or above 69 kV.
RATE: Service Availability Charge Per Month: $1,789.06
Energy Charge:
$0.003891 per kWh for all kWh used during the month
Demand Charge:
$10.66 per kW of demand used per month during each summer month
$ 7.48 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months °Owe through September.
WINTER MONTHS: The billing months of October through May.
OPTIONAL SERVICE: Customers receiving service under this rate may elect to receive interruptible service
under the Interruptible Credt Option.
NOTE: All meter readings of service under this tariff at common voltage levels will be combined for billing
purposes.
I
I
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF DEMAND: The kW determined from the Company's demand meters for the 30 -
minute period of Customer's greatest kW use during the month, but not less than 70 percent of the
highest demand established in the preceding eleven months.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
S
-063-
"0„
Ene '
SOUTWW 3VEIN raretc $E1VsC
ELECTRIC TARIFF
185
Section No. IV
Sheet No. IV -109
Revision No. 1'l
Page 2 of 2
SERVICE AGREEMENT SUMMARY
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA §39.904(tt-
1) and Commission regulations promulgated thereunder, shall receive a credit of $0.000288 per kWh to
their electric billings. Customers who receive REC credits under this tariff do not share in any REC costs
and shall not be eligible to receive revenue credits for sales of RECs by the Company.
N
LOSS ADJUSTMENT: Meter readings used for billing shall be increased to include transformation losses
when metering is installed on the secondary side of any voltage transformation under 69 kV made on
Customer's side of the Point of Delivery.
LINE EXTENSIONS: All cost of equipment, supplies, and labor related to the installation cost of facilities
necessary to make service available shall be paid by the Customer in advance. No transformation will be
made by the Company at the point of service.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with demand
exceeding 200 kW. Bills computed under the above rate will be increased $0.55 for each kvar by which
the reactive demand exceeds 0.33 times the measured kW demand, and will be reduced $0.55 for each
kvar by which the reactive demand is less than 0.33 times the measured kW demand
R
CHARACTER OF SERVICE: A -C; 60 hertz; at one available standard transmission voltage for each point of
service.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel
cost recovery factor per kWh as provided in PUCT Sheet IV -69.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-064-
186
XceI Enetgy'
SOISlHWtSUIN'Utile $UYIdt
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -118
Revision No18
Page 1 of 3
FLOOD LIGHT SERVICE
APPLICABLILITY:
T
Under contract to all night outdoor flood light service, where facilities of adequate capacity and suitable
voltage are adjacent to the premises to be served. This tariff will be closed to new Customers as of
September 1, 2000 in accordance with the Public Utility Commission of Texas Order in Docket No.
21190, and no new lights will be installed. If this service is in effect at a property that is sold to a new
Customer, the new Customer may continue this service at that property if the new Customer agrees to
the rate then in effect for this service.
TERRITORY: Texas service territory.
RATE: The charge per month shall be the sum of A + B + C.
A. Charge per lamp, per month, for the first light on each 30 -foot wood pole with overhead service:
Lamp Wattage Metal Halide High Pressure Sodium
150 N/A $19.74
175 $19.86 N/A
250 $21.28 $21.38
400 $22.14 $22.61
1,000 $33.87 $34.27
B. Added charge per month for each additional lamp per pole:
Lamp Wattage Metal Halide High Pressure Sodium
150 N/A 57.11
175 57.20 N/A
250 8.22 8.30
400 8.90 9.29
1,000 18.60 18.90
C. Additional charge per month, per pole:
Added Charge Added Charge Added Charge
Pole Per Overhead Per Wood Pole • Added Charge Per Steel Pole
Helght Wood Pole Underground Per Steel Pole Underground
30' $ .00 $3.09 $ 5.15 5 8.25
35' 1.52 4.61 6.67 9.77
T
X„.0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-065-
/0„ )(eel
Energ a
SOUTNWESUEIN PLIIUC SE!UYICE
ELECTRIC TARIFF
187
Section No. IV
Sheet No. IV -118
Revision Noi8
Page 2 of 3
FLOOD LIGHT SERVICE
40' 3.25 6.35 8.42 11.51
45' 4.60 7.71 9.76 12.86
50' 6.09 9.19 N/A N/A
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
DETERMINATION OF ENERGY USE:
Lamp Metal Halide High Pressure Sodium
Wattaee Lumen kWh Lumen kWh
150 15,000 56
175 14,000 62 --
250 20,500 97 27,500 97
400 36,000 136 50,000 159
1,000 110,000 359 140,000 350
FUEL COST RECOVERY:
The above rate shall be increased by the applicable fuel cost recovery factor per kWh, provided in
PUCT Sheet No. IV -69. However, Flood Light Systems service provided by the Company which is
connected to a circuit previously metered by Company for other electric service, shall not have the
above rate increased by the applicable fuel cost recovery factor.
CONDTTIONS OF SERVICE: T
Company will construct, own, operate and maintain, on the Customer's premises, the required number
of photo -electrically controlled overhead flood lights of the type and size selected by Customer,
installed on Company's poles, and having a secondary line span less than 150 feet in length.
Company will not construct, own or maintain underground lines on Customer's premises. Construction
of underground lines will be to the specifications of Company, and will be arranged and paid for by the
Customer. Customer is responsible for any trenching and backfilling necessary for construction.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase; 120 or 240 volts.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-066-
188
"0, XCei &e ."
$OII1$WESUER1! Milt SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. N-118
Revision No. 8
Page 3 of 3
FLOOD LIGHT SERVICE
TERM OF CONTRACT: A period of not less than three years.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terns and conditions set forth in the Company's Rules, Regulations, and Conditions of
Service on file with the Public Utility Commission of Texas.
�a-
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-067-
XcelEnergy-
$OUTNWE$T$1N PUILIC SERVICE
ELECTRIC TARIFF
189
Section No. IV
Sheet No. 1V-150
Revision NoT7
Page 1 of 3
RESTRICTED OUTDOOR LIGHTING SERVICE
APPLICABILITY: Under contract for night outdoor lighting service where facilities of adequate capacity and
suitable voltage are available and service is being provided at the time of the Company's acquisition of
Texas New Mexico Power Company's property in Hansford, Ochiltree and Lipscomb Counties.
Pursuant to the 2005 Energy Policy Act, mercury vapor (MV) lamp ballasts shall not be manufactured
or imported after January 1, 2008. When the Company's inventory of mercury vapor ballasts and lamps
is exhausted, Customers will be given the option of having the lighting facilities removed, or replaced
with another type of light at the rate for the replacement light.
TERMS OF SERVICE: No new Customers will be added to this service; however, if this service is provided
to a privately -owned property and the property is sold to a new Customer, the new Customer has th
option to continue service under the existing rate if the new Customer agrees to the rate then in effec
for this service. Existing equipment will be replaced with standard Company equipment as wear
out and obsolescence occur, if the Customer agrees to continue service under the rate then in effect fo
standard Company equipment. T
TERRITORY: Areas in the counties of Hansford, Ochiltree; and Lipscomb previously served by Texas -New
Mexico Power Company.
GUARD LIGHTS:
RATE: Each 21,500 lumen, 400 watt, mercury vapor lamp for $16.69 per month.
Each 9,500 lumen, 100 watt, high pressure sodium (HPS) lamp for $12.75 per month.
Each 22,000 lumen, 200 watt, HPS lamp for $14.06 per month.
FLOOD LIGHTS:
RATE: Each 21,500 lumen, 400 watt, MV lamp for $16.69 per month.
Each 36,000 lumen, 400 watt, metal halide (MH) lamp for $22.14 per month.
Each 110,000 lumen, 1,000 watt, MH lamp for $33.87 per month.
Each 50,000 lumen, 400 watt, HPS lamp for $22.61 per month.
Company will own, operate and maintain on Customer's premises, the number of photo -electrically
controlled lamps requested by Customer, mounted on a metal bracket, installed on Company's service
pole, a separate 30 foot pole or on any suitable mounting device belonging to
T
RATE (Cont.):
,X,„0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-068-
190
JlEnergy-
SdUtRWfSftsfN t►UDttC StiVJCE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -150
Revision No. 7
Page 2 of 3
RESTRICTED OUTDOOR LIGHTING SERVICE
Customer, and having a secondary line span not to exceed.150 feet in length. Lights will not be
installed on any mounting device which, in the opinion of Company, is unsafe or unsuitable for this
purpose.
The charge per lamp, per month shall be in accordance with the following rates:
Lumen Lamp Wood Underground Ornamental
Lamp Type Pole Pole
Size
8,150 MV $11.95
9,500 HPS $10.70 $10.70 $10.70
22,000 HPS $11.70 $11.70
The aforementioned rates include furnishing, by Company, of the electric energy necessary to operate
the street lighting system, the replacement of lamps and normal maintenance of fixtures, wires,
transformers and other component parts of the street lighting system, as said replacements and
maintenance become necessary. In the event maintenance and/or lamp and glassware replacements
become excessive due to vandalism or similar causes, Company will notify the City, and the City will
implement whatever means at its disposal through law enforcement agencies or other protective
measures, to eliminate destruction of street lighting equipment. If said vandalism persists, Company
reserves the right to remove the street lights.
If any street light is permanently removed from service at the City's request, the City will pay
Company, at the time of removal from service of said light, the original cost of the equipment taken out
of service, less depreciation of four percent per year. If any street light is removed from service
temporarily (at least two months) at the City's request, the monthly rate for said light during such
temporary disconnection will be the base charge per lamp as stated above. Fuel cost recovery will not
be charged or credited on any temporarily disconnected street light.
Company will install, own, operate and maintain the street lighting system. If, for any reason,
Company is unable to continue service of particular equipment, said equipment, at the option of the
City, will be removed or replaced by Company with currently available equipment, and the City will
pay the appropriate rate for the new equipment.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-069-
`0,
XcelFnerCgy*
iOVTHWtS Eaw OUitiC SEIVtCt
ELECTRIC TARIFF
191
Section No. IV
Sheet No. IV -150
Revision NoT7
Page 3 of 3
RESTRICTED OUTDOOR LIGHTING SERVICE
,RATE (Cont.):
Street light burning time will be from approximately one-half hour after sunset to approximately one-
half hour before sunrise.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If service is
billed on a residential bill, the late payment charge will not be imposed. If the sixteenth day falls on a
holiday or weekend, the due date will be the following work day.
DETERMINATION OF ENERGY USE:
8,150 lumen, 175 watt,
21,500 lumen, 400 watt,
9,500 lumen, 100 watt,
22,000 lumen, 200 watt,
34,000 lumen, 400 watt,
110,000 lumen, 1,000 watt,
25,500 lumen, 250 watt,
50,000 lumen, 400 watt,
MV Lamp uses 68, kWh per month
MV lamp uses 151 kWh per month
HPS lamp uses 39 kWh per month
HPS lamp uses 75 kWh per month
MH lamp uses 136 kWh per month
MH lamp uses 359 kWh per month
HPS lamp uses 97 kWh per month
HPS lamp uses 159 kWh per month
FUEL COST RECOVERY: The charge per kWh of the aforementioned rate shall be increased by the
applicable fuel cost factor per kWh as provided in PUCT Sheet IV -69. However, Outdoor Lighting
Service provided by Company, which is connected to a circuit previously metered by Company for
other electric service, shall not have the above rate increased by the applicable fuel cost recovery factor.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase; 120 or 240 volts.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in Company's Rules, Regulations, and Conditions of
Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-070-
192
X Energyy
SOUTSWEsrt1M'UStit SU VICZ
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -1 59
Revision No:14
Page 1 of 24
DISTRIBUTED GENERATION INTERCONNECTION
AVAILABILITY: Company shall interconnect distributed generation as described in PUC Substantive Rules
§25.211, §25.212 and §25.213 pursuant to the tern of the Agreement for Interconnection and Parallel
Operation of Disrributed Generation, which is incorporated herein.
APPLICATION: A person seeking interconnection and parallel operation of distributed generation with the
Company must complete and submit the Application for Interconnection and Parallel Operation of
Distributed Generation with the Utility System, which is incorporated herein. Distributed generation
interconnections made under this tariff shall not be used to sell, transmit or distribute power or energy to
ultimate consuming facilities in the Company's certificated service area until the Company is authorized
by the Public Utility Commission of Texas to implement customer choice.
STANDBY OR SUPPLEMENTAL POWER TO A DISTRIBUTED GENERATOR OF
AGGREGATE GENERATING CAPACITY OF:
100 KW OR LESS
RATE: Same as tariff for applicable class of service.
TERMS OF PAYMENT: Same as tariff for applicable class of service. DEMAND:
Same as tariff for applicable class of service.
FUEL COST RECOVERY: Same as tariff for applicable class of service.
TAX ADJUSTMENT: Same as tariff for applicable class of service.
CHARACTER OF SERVICE: Same as tariff for applicable class of service. MINIMUM:
Same as tariff for applicable class of service.
LINE EXTENSIONS: The Company will make line extensions in accordance with its standard line extension
policy.
MoD
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-071-
XtelEnelg
SOUlHWE$TUN PUItle SE1VlCE
ELECTRIC TARIFF
•
193
Section No. IV
Sheet No. IV -159
Revision No:I
Page 2 of 24
DISTRIBUTED GENERATION INTERCONNECTION
STANDBY SERVICE TO A DISTRIBUTED GENERATOR OF
AGGREGATE GENERATING CAPACITY:
GREATER THAN 100 KW
BACKUP SERVICE: Backup service is capacity and energy supplied by the Company to replace the Customer's
generation during an unscheduled outage. The level of Standby Demand for Backup Service shall be
nominated in the Agreement for Interconnection and Parallel Operation of Distributed Generation with the
Utility System. If Customer receives Replacement Power for 100 or more hours in a month where a
scheduled outage was not planned in accordance with the Maintenance Service section below, then all
power and energy delivered through the Customer Meter shall be billed in accordance with the standard
applicable rate schedule, but the demand ratchet for future months under the standard applicable rates
schedule shall not apply. Also, the StandbyDemand Charge will not be assess d in that month.
MAINTENANCE SERVICE: Maintenance Service is capacity and energy supplied by the Company to replace the
Customer's self -generation during scheduled outages of the Customer's generation. Scheduled outages
shall be set at a time mutually agreeable by Customer and the Company, but exclusive of the months of
June, July, and August of every year. The scheduled outage shall be scheduled within only two billing
months per calendar year. Scheduled outages shall be agreed to in writing at least 30 days prior to the
beginning of thc month in which the scheduled outage is planned to take place. Customer shall be charged
by Company for Maintenance Service at the rate specified below. However the Supplemental Demand
established in a scheduled outage period shall not be used to determine future minimum Supplemental
Demands.
T
SUPPLEMENTAL SERVICE: Supplemental Service is capacity and energy supplied by the utility and
used by the Customer in addition to thc Customer's self -generation in order to meet the Customer's total
load requirement and shall be billed in accordance with the standard applicable rate schedule.
CUSTOMER METER DEMAND: The Customer Meter Demand shall be the kW determined from Company's
demand meter at the Customer Meter for the 30 -minute period of greatest use during the month.
MINIMUM GENERATION DEMAND: The Minimum Generation Demand shall be the kW determined at the
Distnbuted Generation Meter for the 30 -minute period of least total generation during the month.
REPLACEMENT DEMAND: The Replacement Demand shall be equal to the minimum of (a) the Customer
X..„21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-072-
194
Xeel Energ
soulowasre.w Fustic seUYICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 3 of 24
DISTRIBUTED GENERATION INTERCONNECTION
Meter Demand, (b) the Standby Demand, or (c) the remainder of the Distributed Generation Capability
minus the Minimum Generation Demand. The Generation Capability shall be set forth in the contract.
REPLACEMENT ENERGY: The Replacement Energy shall be equal to the energy metered at the Customer
Meter, but not more than the outage hours in a month times the Generation Capability.
STANDBY DEMAND: The Standby Demand shall be the demand nominated for Backup Service in the
Agreement for Interconnection and Parallel Operation of Distributed Generation with the Utility System.
SUPPLEMENTAL DEMAND: The Supplemental Demand shall be equal to the Customer Meter Demand
minus the Replacement Demand, but not less than the minimum demand set forth in the applicable tariff. If
the Customer Meter Demand minus the Replacement Demand is at a level below the applicable
minimum demand level, the billing Standby Demand shall be reduced in only that month by the amount
of demand below the applicable minimum demand level. If a Customer Charge is collected for
Supplemental Service, a separate Standby Customer Charge shall not be billed.
APPLICABLE TO GENERATING CAPACITY GREATER THAN 100 kW
MONTHLY RATE: The Customer shall be charged monthly for Distributed Generation Standby
Service at the following applicable rates:
T
Standby Customer Charge $26.76
Transmission & Distribution Standby Capacity Fee — Summer: $8.37 / kW Month
Transmission & Distribution Standby Capacity Fee — Winter: $6.82 / kW Month
Generation Standby Capacity Fee — Summer: 51.86 / kW Month
Generation Standby Capacity Fee — Winter: 51.50 / kW Month
Energy Charge: $0.005651 per kWh
MINIMUM CHARGE: The minimum charges in a month shall be the sum of the Standby Customer Charge and
the StandbyDemand Charge.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-073-
XatiEnergy-
JOUTIIVMMIN PURttC SURYICt
ELECTRIC TARIFF
195
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 4 of 24
DISTRIBUTED GENERATION INTERCONNECTION
PRIMARY SERVICE DISCOUNT: A discount of 3 percent of customer, standby demand, energy and power
factor adjustment will be allowed when distribution voltage level service is supplied at a line voltage of
12 kilovolts, or greater, and no transformation is made by the Company at the Customer's location.
FUEL COST RECOVERY: The charge per kilowatt-hour of the above rate shall be increased by the applicable
fuel cost reoovery per kilowatt-hour as provided in Tariff No. IV -69.
TAX ADJUSTMENT: (Applicable to sales inside corporate limits): Billings under this schedule may be
increased by an amount equal to the sum of the taxes payable under federal, state and local sales tax acts,
and of all additional taxes, fees, or charges, (exclusive of ad valorem, state and federal income taxes)
payable by the utility and levied or assessed by any governmental authority on the public utility
services rendered, or on the right or privilege of rendering the service, or on any object or event incidental to
the rendition of service.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for customers with demand
exceeding 200 kW. Bills computed under the above rate will be increased $0.54 for each kvar by which
the reactive demand exceeds 0.33 times the measured kW demand, and will be reduced $0.54 for each
kvar by which the reactive demand is less than 0.33 times the measured kW demand
TERMS OF PAYMENT: net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day
falls on a holiday or weekend, the due date will be the next workday.
CHARACTER OF SERVICE: Alternating current; 60hertz at approxirrately the contract wltage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-074-
196
XcOIEnergyM
SOUTHWESTERN PU$Ete SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No:FI
Page 5 of 24
DISTRIBUTED GENERATION INTERCONNECTION
INTERCONNECTION OF DISTRIBUTED GENERATION
TERMS AND CONDITIONS OF SERVICE: The terms and conditions under which interconnection of
distributed generation are to be provided are contained in Commission Substantive Rules §25.211,
§25.212 and §25.213, which are incorporated herein by reference, and in the Agreement for
Interconnection and Parallel Operation of Distributed Generation, which is incorporated herein. The rulesi
are subject to change from time to time as determined by the Commission, and such changes shall be
automatically applicable hereto based upon the effective date of any Commission order or rule
amendment.
STUDIES AND SERVICES: Pre -interconnection studies may be required and conducted by the Company. Other
services may be provided as requested by the customer and provided pursuant to negotiations and
agreement by the customer and the Company and may be subject to approval by the Commission.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-075-
0." XEner-gy-
ourNWtSTERN 011R1fC SERVICE
ELECTRIC TARIFF
197
Section No. IV
Sheet No. IV -159
Revision No:4
Page 6 of 24
DISTRIBUTED GENERATION INTERCONNECTION
PRE -INTERCONNECTION STUDY FEE SCHEDULE:
NON -EXPORTING
0 to 10 kW
Pre -Certified
Not on Network
$0
Not Pre -Certified
Not on Network
$196
Pre -Certified
On Network
$181*
Not Pre -Certified
On Network
$300
10+ to 500 kW
Pre -Certified
Not on Network
$166**
Not Pre -Certified
Not on Network
$286
Pre -Certified
On Network
$960*
Not Pre -Certified
On Network
$1,720
500+ to 2,000 kW
Pre -Certified
Not on Network
$468
Not Pre -Certified
Not on Network
$588
Pre -Certified
On Network
$2,550
Not Pre -Certified
On Network
$2,550
2,000+ kW
Pre -Certified
Not on Network
$785
Not Pre -Certified
Not on Network
$905
Pre -Certified
On Network
$3,000
Not Pre -Certified
On Network
$3,440
* No charge if 20 kW or less inverter is used
** No charge if generator supplies less than 15% of feeder load and less than 25% of feeder fault current
‘i,„d
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-076-
198
,ice% Energy*
SQUTHWF$YEIN ruikie $EIVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No14
Page 7 of 24
DISTRIBUTED GENERATION INTERCONNECTION
EXPORTING
0 to 10 kW
Pre -Certified
Not on Network
$0
Not Pre -Certified
Not on Network
$196
Pre -Certified
On Network
$181 *
Not Pre -Certified
On Network
$300
10+ to 500 kW
Pre -Certified
Not on Network
$166*
Not Pre -Certified
Not on Network
$286
Pre -Certified
On Network •
$1,290*
Not Pre -Certified
On Network
$1,720
500+ to 2,000 kW
Pre -Certified
Not on Network
$468
Not Pre -Certified
Not on Network
$588
Pm -Certified
On Network
$3,000
Not Pre -Certified
On Network
$3,125
2,000+ kW
Pre -Certified
Not on Network
$785
Not Pre -Certified
Not on Network
$905
Pre -Certified
On Network'
$3,320
Not Pre -Certified
On Network
$3,440
Prescribed Form for the Application for Interconnection and Parallel Operation of Distributed
Generation
** T
Customers seeking to interconnect distributed generation with the utility system will complete and file with
the company the following Application for Parallel Operation:
APPLICATION FOR INTERCONNECTION AND
PARALLEL OPERATION OF DISTRIBUTED GENERATION
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-077-
,1Energy�
SOUr$WESI%1N PUSLIC SERVICE
ELECTRIC TARIFF
199
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 8 of 24
DISTRIBUTED GENERATION INTERCONNECTION
Return Completed Application to:
Customer's Name:
Address:
Southwestern Public Service Company
Attention: ResourcePlanning Dept.
600 S. Tyler, Sulte 2900
Amarillo, TX 79101-2353
Contact Person:
Email Address:
T
Telephone Number:
Service Point Address:
Information Prepared and Submitted By:
(Name and Address)
Signature
The following information shall be supplied by the Customer or Customer's designated representative. All applicable
items must be accurately completed in order that the Customer's generating facilities may be effectively evaluated
by Southwestern Public Seawice Company for interconnection with the utility system.
GENERATOR
�a-
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-078-
200
XcetEnergyµ
$OUtHWESUURN P01tIC SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 9 of 24
DISTRIBUTED GENERATION INTERCONNECTION
Number of Units:
Manufacturer
Type (Synchronous, Induction, orInverter):
Fuel Source Type (Solar, Natural Gas, Wind, etc.):
Kilowatt Rating (95 F at location)
Kilovolt -Ampere Rating (95 F at location):
Power Factor:
Voltage Rating
Number of Phases:
Frequency.
Do you plan to export power: Yes / No
If Yes, maximum amount expected:
T
REGIONAL VICE PRESIDENT RATES AND
• REGULATORY AFFAIRS
-079-
XcelEnergy
SdttTNWE$7ERN .urttc SEUVICE
ELECTRIC TARIFF
201
Section No. IV
Sheet No. IV -159
Revision No.T4
Page 10 of 24
DISTRIBUTED GENERATION INTERCONNECTION
Pre -Certification Label or Type Number (e.g., UL -1741 Utility Interactive or IEEE 1547.1):
Expected Energzation and Startup Date:
Normal operation of interconnection: (examples: provide power to meet base load, demand management, standby,
back-up, other (please describe))
One -line diagram attached Yes
For systems not using pre -certified inverters (e.g., inverters certified to UL 1741 or IEEE 1547.1), does
Southwestern Public Service Company have the dynamic modeling values from the generator manufacturer?
Yes / No
If not, please explain:
(Note: For pre -certified equipment, the answer is Yes. Otherwise, applicant must provide the dynamic modeling
values if they are available.)
Layout sketch showing Iockable, "visible" disconnect device is attached:
Yes
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-080-
202
r'd Xcel Energy«
soutHwrsreaw rur€rc st,evict
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision NoT4
Page 11 of 24
SOUTHWESTERN PUBLIC SERVICE [CUSTOMER NAME]
COMPANY
BY:
PRINTED NAME:
TITLE:
BY:
PRINTED NAME:
1'IILE:
DATE: DATE:
the
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-081-
DISTRIBUTED GENERATION INTERCONNECTION
Authorized Release ofInformation List
By signing this Application in the space provided below, Customer authorims Southwestern Public Savice
Company to release Customer's proprietary information to the extent necessary to process this Applcation tt
following persons:
Name
Phone Number •
Email Address
Project Manager
Electrical Contractor
Consultant
Other
SOUTHWESTERN PUBLIC SERVICE [CUSTOMER NAME]
COMPANY
BY:
PRINTED NAME:
TITLE:
BY:
PRINTED NAME:
1'IILE:
DATE: DATE:
the
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-081-
10,
Energy-
SOUTNWESMN PU$LtC SERVICE
ELECTRIC TARIFF
203
Section No. IV
Sheet No. IV -159
Revision No:r4
Page 12 of 24
DISTRIBUTED GENERATION INTERCONNECTION
AGREEMENT FOR INTERCONNECTION AND PARALLEL OPERATION
OF DISTRIBUTED GENERATION
This Interconnection Agreement ("Agreement") is made and entered into this day of
, , by Southwestern Public Service Company ("Company"), and
("Customer"}, a
[specify whether corporation, and if so name state, municipal
corporation, cooperative corporation, or other], each hereinafter sometimes referred to individually as
"Party" or both referred to collectively as the "Parties." hi consideration of the mutual covenants set forth
herein, the Parties agree as follows:
1. Scope of Agreement -- This Agreement is applicable to conditions under which Company and
Customer agree that one or more generating facility or facilities of ten megawatts or less and related
interconnecting facilities to be interconnected at less than 60 kilovolts ("Facilities") may be interconnected to
Company's facilities, as described in Exhibit A.
2. Establishment of Point(s) of Interconnection Company and Customer agree to interconnect
Facilities at the locations specified in this Agreement, in accordance with Public Utility Commission of
Texas ("Commission") Substantive Rules 25.211, relating to Interconnection of Distributed Generation, and
25.212, relating to Technical requirements for Interconnection and Parallel Operation of On -Site Distributed
Generation (16 Texas Administrative Code §25.211 and §25.212) (the `Rules") or any successor rule
addressing distributed generation and as described in the attached Exhibit A (the "Point(s) of
Interconnection").
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-082-
204
Xcet Energym
$OUZNwrsrtttN ►mitt stlVICF
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No14
Page 13 of 24
DISTRIBUTED GENERATION INTERCONNECTION
3. Responsibilities of Company and Customer -- Customer shall, at its own cost and expense,
operate, maintain, repair, and inspect, and shall be fully responsible for, Facilities specified on Exhibit A.
Customer shall conduct operations of Facilities in compliance with all aspects of the Rules, and Company
shall conduct operations on its facilities in compliance with all aspects of the Rules, and as further described
and mutually agreed to in the applicable Facility Schedule. Maintenance of Facilities shall be performed in
accordance with the applicable manufacturer's recommended maintenance schedule. Customer agrees to
cause Facilities to be constructed in accordance with specifications equal to or greater than those provided by
the National Electrical Safety Code, approved by the American National Standards Institute, in effect at the
time of construction.
Each Party covenants and agrees to design, install, maintain, and operate, or cause the design, installation,
maintenance, and operation of, its facilities so as to reasonably minimize the likelihood of a disturbance,
originating in the facilities of one Party, affecting or impairing the facilities of the other Party, or other
facilities with which Company is interconnected.
Company shall notify Customer if there is evidence that operation of Facilities causes disruption or
deterioration of service to other utility customers or if the operation of Facilities causes damage to
Company's facilities or other facilities with which Company is interconnected. Company and Customer shall
work cooperatively and promptly to resolve the problem.
Customer shall notify Company of any emergency or hazardous condition or occurrence with Facilitied
which could affect safe operation of Company's facilities or other facilities with which Company is
interconnected.
Customer shall provide Company at least 14 days' written notice of a change in ownership or cessation of
operations of one or more Facilities.
4. Limitation of Liability and Indemnification
a. Notwithstanding any other provision in this Agreement, with respect to Company's provision of electric
service to Customer other than the interconnections service addressed by this Agreement, Company's
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-083-
Xce1Energy
SOUTHWESTERN 'Mit SEIY CE
ELECTRIC TARIFF
205
Section No. IV
Sheet No. IV -159
Revision No.T4
Page 14 of 24
DISTRIBUTED GENERATION INTERCONNECTION
liability to Customer shall be limited as set forth in Rule No. 6 of Company's Commission -approved
tariffs, which are incorporated herein by reference.
b. Neither Company nor Customer shall be liable to the other for damages for anything that is beyond
such Party's control, including an act of God, labor disturbance, act of a public enemy, war, insurrection,
riot, fire, storm or flood; explosion, breakage or accident to machinery or equipment, a curtailment, order,
or regulation or restriction imposed by governmental, military, or lawfully established civilian authorities,
or the making of necessary repairs upon the property or equipment of either party.
c. Notwithstanding Paragraph 4.b of this Agreement, Company shall assume all liability for and shall
indemnify Customer for any claims, losses, costs, and expenses of any kind or character to the extent that
they result from Company's negligence in connection with the design, construction, or operation of its
Facilities as described on Exhibit A; provided, however, that Company shall have no obligation to
indemnify Customer for claims brought by claimants who cannot recover directly from Company. Such
indemnity shall include, but is not limited to, financial responsibility for: (a) Customer's monetary losses;
(b) reasonable costs and expenses of defending an action or claim made by a third person; (c) damages
related to the death or injury of a third person; (d) damages to the property of Customer; (e) damages to
the property of a third person; Q) damages for the disruption of the business of a third person. In no event
shall Company be liable for consequential, special, incidental, or punitive damages, including, without
limitation, loss of profits, loss of revenue, or loss of production. The Company does not assume liability
for any costs for damages arising from the disruption of the business of Customer or for Customer's costs
and expenses of prosecuting or defending an action or claim against Company. This paragraph does not
create a liability on the part of Company to Customer or a third person, but requires indemnification
where such liability exists. The limitations of liability provided in this paragraph do not apply in cases of
gross negligence or intentional wrongdoing.
d Please check the appropriate box
O Private Entity
Notwithstanding Paragraph 4.b of this Agreement, Customer shall assume all liability for and shall
indemnify Company for any claims, losses, costs, and expenses of any kind or character to the extent that
they result from Customer's negligence in connection with the design, construction, or operation of
Facilities as described on Exhibit A; provided, however, that Customer shall have no obligation to
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-084-
206
Xl Energy
$OUt1tWEi1ERN'UItrc SERVICE
ELECTRIC TARIFF
T
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 15 of 24
DISTRIBUTED GENERATION INTERCONNECTION
indemnify Company for claims brought by claimants who cannot recover directly from Customer. Suc
indemnity shall include, but is not limited to, financial responsibility for: (a) Company's monetary losses,
(b) reasonable costs and expenses of defending an action or claim made by a third person; (c) damage
related to the death or injury of a third person; (d) damages to the property of Company; (e) damages
the property of a third person; (n damages for the disruption of the business of a third person. In no even
shall Customer be liable for consequential, specia4 incidental, or punitive damages, including, withou
limitation, loss of profits, loss of revenue, or loss of production. The Customer does not assume liabi i
for any costs for damages arising from the disruption of the business of Company or for Company's c
and expenses of prosecuting or defending an action or claim against Customer. This paragraph does no
create a liability on the part of Customer to Company or a third person, but requires indemnificatio
where such liability exists. The limitations of liability provided in this paragraph do not apply in cases o
gross negligence or intentional wrongdoing.
0 Federal Agency
Notwithstanding Paragraph 4.b of this Agreement, the liability, if any, of Customer relating to
Agreement, for injury or loss of property, or personal injury or death shall be governed exclusively by th
provisions of the Federal Tort Claims Act (28 U.S.C. §§ 1346, and 2671-2680). Subject to applicab
federal, state, and local laws, each Party's liability to the other for any loss, cost, claim, injury, liability, o
expense, including reasonable attorney's fees, relating to or arising from any act or omission in •
performance of this Agreement shall be limited to the amount of direct damages actually incurred, and
no event shall either Party be liable to the other for any indirect, special, consequential, or punitiv
damages.
e. Company and Customer shall each be responsible for the safe installation, maintenance, repair, an
condition of their respective facilities on their respective sides of the Points of Interconnection. Compan
does not assume any duty of inspecting Customer's Facilities.
f For the mutual protection of Customer and Company, only with Company prior authorization are th
connections between Company's service wires and Customer's service entrance conductors to b
energized
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-085-
Xcel Energyp
3OUTHWE$VEIt( ru$Lit ftIV CI
ELECTRIC TARIFF
207
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 16 of 24
DISTRIBUTED GENERATION INTERCONNECTION
5. Right of Access, Equipment Installation, Removal & Inspection -- Upon reasonable notice,
Company may send a qualified person to the premises of Customer at or immediately before the time
Facilities first produce energy to inspect the interconnection, and observe Facilities' commissioning
(including any testing), startup, and operation for a period of up to three days after initial startup of
Facilities.
Following the initial inspection process described above, at reasonable hours, and upon reasonable notice, or
at any time without notice in the event of an emergency or hazardous condition, Company shall have access
to Customer's premises for any reasonable purpose in connection with the performance of the obligations
imposed on it by this Agreement or if necessary to meet its legal obligation to provide service to its
customers.
6. Disconnection of Facilities — Customer retains the option to disconnect from Company's facilities.
Customer shall notify Company of its intent to disconnect by giving Company at least thirty days' written
notice. Such disconnection shall not be a termination of this Agreement unless Customer exercises rights
under Section 7.
Customer shall disconnect Facilities from Company's facilities upon the effective date of any termination
under Section 7.
Subject to Commission Rule, for routine maintenance and repairs of Company's facilities, Company shrill
provide Customer with seven business days' notice of service interruption.
Company shall have the right to suspend service in cases where continuance of service to Customer will
endanger persons or property. During the forced outage of Company's facilities serving Customer, Company
shall have the right to suspend service to effect immediate repairs of Company's facilities, but Company
shall use its best efforts to provide Customer with reasonable prior notice.
7. Effective Term and Termination Rights -- This Agreement becomes effective when executed by
both Parties and shall continue in effect until terminated. The Agreement may be terminated for the
following reasons: (a) Customer may terminate this Agreement at any time, by giving Company sixty days
written notice; (b) Company may terminate upon failure by Customer to generate energy from Facilities in
parallel with Company's facilities within twelve months after completion of the interconnection; (c) either
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-086-
208
L XcelEnergy-
SOURNWESTEEN PUBLIC SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 17 of 24
DISTRIBUTED GENERATION INTERCONNECTION
Party may terminate by giving the other Party at least sixty days' written notice that the other Party is in
default of any of the material terms and conditions of the Agreement, so long as the notice specifies the basis
for termination and there is reasonable opportunity to cure the default; or (d) Company may terminate by
giving Customer at least sixty days' written notice if possible in the event that there is a material change in
an applicable rule or statute that necessitates termination of this Agreement.
8. Governing Law and Regulatory Authority -- Please check the appropriate box.
0 Private Entity: This Agreement was executed in.the State of Texas and must in all respects be
governed by, interpreted, construed, and enforced in accordance with the laws thereof. This Agreement is
subject to, and the Parties' obligations hereunder include, operating in full compliance with all valid,
applicable federal, state, and local laws or ordinances, and all applicable rules, regulations, orders of, and
tariffs approved by, duly constituted regulatory authorities having jurisdiction.
0 Federal Agency: This Agreement was executed in the State of Texas and, to the extent not
inconsistent with all applicable federal law (including, but not limited to: (a) the Anti -Deficiency Acts, L1
USC §§1341, 1342 and 1501-1519; (b) the Tort Claims Act, 28 USC Chapter 171, §§2671-2680, and 281
CFR Part 14; and (c) the Contract Disputes ,Act of 1978, as amended, 41 USC §§601-613), must in all
respects be governed by, interpreted, construed, and enforced in accordance with the laws thereof. This
Agreement is subject to, and the Parties' obligations hereunder include, operating in full compliance with all
valid, applicable federal, state, and local laws or ordinances, and all applicable rules, regulations, orders of,
and tariffs approved by, duly constituted regulatory authorities having jurisdiction.
9. Amendment -- This Agreement may be amended only upon mutual agreement of the Parties, which
amendment will not be effective until reduced to writing and executed by the Parties.
10. Entirety of Agreement and Prior Agreements Superseded -- This Agreement, including the
attached Exhibit A and Facility Schedules, which are expressly made a part hereof for all purposes,
constitutes the entire agreement and understanding between the Parties with regard to the interconnection of
the facilities of the Parties at the Points of Interconnection expressly provided for in this Agreement. The
Parties are not bound by or liable for any statement, representation, promise, inducement, understanding, or
undertaking of any kind or nature (whether written or oral) with regard to the subject matter hereof not set
REGIONAL VICE PRESIDENT RATES AND
• REGULATORY AFFAIRS
-087-
/e),
Xcel Energy-
90UYNWE9fPIN PUbttt 3EAYICE
ELECTRIC TARIFF
209
Section No. IV
Sheet No. IV -159
Revision No. 4
Page 18 of 24
DISTRIBUTED GENERATION INTERCONNECTION
forth or provided for herein. This Agreement replaces all prior agreements and undertakings, oral or written
between the Parties with regard to the subject matter hereof, including without limitation
[specify any prior agreements being superseded],
and all such agreements and undertakings are agreed by the Parties to no longer be of any force or effect. It is
expressly acknowledged that the Parties may have other agreements covering other services not expressly
provided for herein, which agreements are unaffected by this Agreement.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-088-
210
L xce,Energr
SOUTNWESYU$ ,UIEft SSSVl6
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision No14
Page 19 of 24
DISTRIBUTED GENERATION INTERCONNECTION
11. Written Notices -- Written notices given under this Agreement are deemed to have been duly delivered
if hand delivered or sent by United States certified mail, return receipt requested, postage prepaid, to:
(a) If to Company:
(b) If to Customer:
The above -listed names, titles, and addresses of either Party may be changed by written notification to the
other, notwithstanding Section 10.
12. Invoicing and Payment -- Invoicing and payment terms for services associated with this agreement
shall be consistent with applicable Substantive Rules of the Commission.
13. No Third -Party Beneficiaries -- This Agreement is not intended to and does not create rights
remedies, or benefits of any character whatsoever in favor of any persons, corporations, associations, or
entities other than the Parties, and the obligations herein assumed are solely for the use and benefit of the
Parties, their successors in interest and, where permitted, their assigns.
14. No Waiver -- The failure of a Party to this Agreement to insist, on any occasion, upon strict
performance of any provision of this Agreement will not be considered to waive the obligations, rights, or
duties imposed upon the Parties.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-089-
XcelEnergy-
SOUtHWtdrfltM PUItIC SEIVICE
ELECTRIC TARIFF
211
Section No. IV
Sheet No. IV -159
Revision No.14
Page 20 of 24
DISTRIBUTED GENERATION INTERCONNECTION
15. Headings -- The descriptive headings of the various parts of this Agreement have been inserted for
convenience of reference only and are to be afforded no significance in the interpretation or construction of
this Agreement.
16. Multiple Counterparts -- This Agreement may be executed in two or more counterparts, each of
which is deemed an original but all constitute one and the same instrument.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-090-
212
XceiEnergr
JGU1$WrSTE1N turc►c SU'ICE
ELECTRIC TARIFF
Section No. W
Sheet No. IV -159
Revision No:I4
Page 21 of 24
DISTRIBUTED GENERATION INTERCONNECTION
IN WITNESS WHEREOF, the Parties have caused this Agreement to be signed by their respective duly
authorized representatives.
SOUTHWESTERN PUBLIC SERVICE [CUSTOMER NAME]
COMPANY
BY: BY:
PRINTED NAME: PRINTED NAME:
TITLE: TITLE:
DATE: DATE:
X1/4_„21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-091-
XCel &erg's
SOUVHWESlt1N PUitfC SERVICE
ELECTRIC TARIFF
213
Section No. IV
Sheet No. IV -159
Revision No:I4
Page 22 of 24
DISTRIBUTED GENERATION INTERCONNECTION
AGREEMENT FOR INTERCONNECTION AND PARALLEL OPERATION
OF DISTRIBUTED GENERATION
EXHIBIT A
LIST OF FACILITY SCHEDULES AND POINTS OF INTERCONNECTION
Facility Schedule No. Name of Point of Interconnection
[Insert Facility Schedule number and name for each Point of Interconnection]
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-092-
214
Ve/ XCel
Iour$WESYEkN Puatrc SUVicr
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -159
Revision NoTI
Page 23 of 24
DISTRIBUTED GENERATION INTERCONNECTION
FACILITY SCHEDULE NO.
[The following information is to be specified for each Point of Interconnection, if applicable.)
1. Customer Name:
2. Premises Owner Name:
3. Facility location:
4. Delivery voltage:
5. Metering (voltage, location, losses adjustment due to metering location, and other):
6. Normal Operation of Interconnection:
7. One line diagram attached (check one): Yes / No
If Yes, then the one -line drawing should show the most current drawing(s) available as of the signing of this
Schedule. Company and Customer agree drawings) may be updated to meet as -built or design changes that
occur during construction. Customer understands and agrees that any changes that substantially affect the
protective or functional requirements required by the Company will need to be reviewed and accepted by
Company.
8. Equipment to be furnished by Company:
(This section is intended to generally describe equipment to be furnished by Company to effectuate the
interconnection and may not be a complete list of necessary equipment.)
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-093-
XceIErierg `"
JOUTNWESiftttt IUSitt SERVICE
ELECTRIC TARIFF
215
Section No. IV
Sheet No. IV -159
Revision Nom
Page 24 of 24
DISTRIBUTED GENERATION INTERCONNECTION
9. Equipment to be furnished by Customer:
(This section is intended to describe equipment to be furnished by Customer to effectuate the interconnection
and may not be a complete list of necessary equipment.)
10. Cost Responsibility and Ownership and Control of Company Facilities:
Unless otherwise agreed or prescribed by applicable regulatory requirements or other law, any payments
received by Company from Customer will remain the property of Company. Company shall at all times have
title and complete ownership and control over facilities installed by Company.
11. Modifications to Customer Facilities.
Customer understands and agrees that, before making any modifications to its Facilities that substantially
affect the protective or interconnection parameters or requirements used in the interconnection process
(including in an Pre -interconnection Study performed by Company), Customer will both notify Company of,
and receive approval by Company for, such modifications. Customer further understands and agrees that, if
required pursuant to Commission Substantive Rule 25.211(m)(5), it will submit a new Application for
Interconnection and Parallel Operation request for the desired modifications.
12. Supplemental terms and conditions attached (check one): Yes / No
SOUTHWESTERN PUBLIC SERVICE [CUSTOMER NAME]
COMPANY
BY: BY:
1'I'1 LE: 111'LE:
DATE: DATE:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-094-
216
xce,Er,e,gy.
$OUTHWts!VIN rirrtIc stIY1rt
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -172
Revision No 16
Page 1 of 2
SMALL GENERAL SERVICE
APPLICABILITY: To commercial Customers for electric service used at secondary voltage and used for
commercial purposes when all service is supplied at one Point of Delivery, and measured through one
meter, where facilities of adequate capacity and suitable voltage are adjacent to the premises to be served,
not to exceed 10 kW of demand in any month. Single phase motors not to exceed 10 horsepower,
individual capacity, may be served under this rate.
Each year, Company will review the demand of all Customers receiving service under this tariff for
whom Company has installed the necessary equipment to measure Customer's kW demand. If the
average of Customer's twelve monthly demands in the immediately preceding calendar year exceeds 10
kW, then Customer is not eligible to continue receiving service under this tariff.
Not applicable to standby, supplementary, resale, or shared service, or service to oil and natural gas
production facilities.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $12.67 per month.
I
Energy Charge: $0.055756 per kWh for all kWh used per month during each summer month
$0.047335 per kWh for all kWh used per month during each winter month. I
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
DEMAND: If, over any four consecutive months, a Customer's average monthly usage exceeds 3,500 kWh
Company will furnish, at Company's expense, the necessary equipment to measure Customer's kV,
demand for the 30 -minute period of greatest use during the month.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be increased
by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate schedule
is suhject to other applicable rate adjustments.
AVERAGE MONTHLY PAYMENT: Upon request, any commercial Customer may be billed monthly based
on a levelized payment plan. A Customer's monthly payment amount is calculated by obtaining the most
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-095-
SOU1HWES1E1N POIEft MIYIGE
ELECTRIC TARIFF
217
Section No. IV
Sheet No. IV -172
Revision No.'6
Page 2 of 2
SMALL GENERAL SERVICE
recent twelve months of actual consumption and dividing that amount by twelve, and applying the
Company's current rates to the average kWh consumption. The account will be trued -up every twelve
months. The trued -up amount will be equal to the difference between the total of the prior twelve
months' levelized payments and the actual billings for the corresponding most recent twelve month
period.
CHARACTER OF SERVICE: A -C; 60 hertz; single phase 120/240 volts; or where available secondary, three
phase 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after sixteen days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in the Company's Rules, Regulations and Conditions of
Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
• REGULATORY AFFAIRS
-096-
218
XcelEnergr
saurxwr$rtta PUI&IC SERvttt
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -173
Revision No17
Page 1 of 2
PRIMARY GENERAL SERVICE
APPLICABILITY: To all commercial and industrial electric service supplied at a primary voltage of 2.4kV or
higher but less than 69 kV and at a single Point' of Delivery measured through approved electrical
metering determined by Company, where facilities of adequate capacity and suitable voltage are
adjacent to the premises to be served.
Not applicable to standby, supplementary, resale or shared service.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: S163.03 per month
Energy Charge: $0.004631 per kWh for all kWh used during the month
Demand Charge: $13.13 per kW of demand used per month during each summer month
F10.08 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
DETERMINATION OF DEMAND: The kW determined from Company's demand meter for the 30 -minute
period of Customer's greatest kW use during the month.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with
demand in excess of 200 kW. Bills computed under the above rate will be increased $0.51 for each kvaq
by which the reactive demand exceeds, numerically, 0.33 times the measured kW demand, and will be
reduced $0.51 for each kvar by which the reactive demand is less than, numerically, 0.33 times then
measured kW demand.
LOSS ADJUSTMENT: Meter readings used for billing shall be increased to include line and transformation
losses when Customer's load is metered at a secondary voltage.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUC] Sheet IV -69. This
rate schedule is subject to other applicable rate adjustments.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-097-
16' XcelEnergr
SOUIHWBS?IRN PUit:C SURVICE
ELECTRIC TARIFF
219
Section No. IV
Sheet No. IV -173
Revision NoT7
Page 2 of 2
PRIMARY GENERAL SERVICE
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase at Company's available primary voltage
that is 2.4 kV or higher but less than 69 W.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy, and no transformation will be made by Company at the Point of Delivery.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS 01? SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in the Company's Rules, Regulations, and Conditions of
Service on file with the Public Utility Commission of Texas. Company may require a Contract to be
executed prior to extending service if Customer's load is expected to be greater than 200 kW. The
contract term shall contain a minimum contract period with an automatic renewable provision from year
to year thereafter.
REGIONAL VICE PRESIDENT RATES AND
• REGULATORY AFFAIRS
-098-
220
XcelEnew
$oulNwesrt1+w Mite attYiCE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -174
Revision No.'16
Page 1 of 2
SMALL MUNICIPAL AND SCHOOL SERVICE
APPLICABILITY: To Municipal facilities and public and private schools for electric service used at
secondary voltage and used for municipal and school purposes when all service is supplied at one
point of delivery, and measured through one meter, where facilities of adequate capacity and
suitable voltage are adjacent to the premises to be served, not to exceed 10 kW of demand in any
month, Single phase motors not to exceed 10 horsepower, individual capacity, may be served
under this rate.
Each year, Company will review the demand of all Customers receiving service under this tariff
for whom Company has installed the necessary equipment to measure Customer's kW demand.
If the average of Customer's twelve monthly demands in the immediately preceding calendar
year exceeds 10 kW, then Customer is not eligible to continue receiving service under this tariff.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $12.67 per month.
Energy Charge:
$0,045956 per kWh for all kWh used per month during each summer month.
$0.038091 per kWh for all kWh used per month during each winter month.
SUMMER MONTHS: The billing months of ]une through September.
WINTER MONTHS: The billing months of October through May.
DEMAND: If, over any four consecutive months, a Customer's average monthly usage exceeds 3,500
kWh, Company will furnish, at Company's expense, the necessary equipment to measure
Customer's kW demand for the 30 -minute period of greatest use during the month.
I
I
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
/ x4eI Engrg y
sourawt$M1$ ruiitc $tRVICE
ELECTRIC TARIFF
221
Section No. IV
Sheet No. IV -174
Revision Noj6
Page 2 of 2
SMALL MUNICIPAL AND SCHOOL SERVICE
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be increased
by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate schedule
is subject to other applicable rate adjustments as in effect from time to time in this tariff.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard secondary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date: 5 percent added to bill after sixteen days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS, AND CONDITIONS OF SERVICE:
Service supplied under this schedule is subject to the terms and conditions set forth in Company's Rules
and Regulations on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-100-
222
Xc&Energy-
$OJtHWES7t1a mitre StIVICS
ELECTRIC TARIFF
Section No. IV
Sheet No. P14 75
Revision NoTI
Page 1 of 2
LARGE MUNICIPAL SERVICE
APPLICABILITY: To all municipal facilities supplied electric service at secondary voltage, at a single point
of delivery measured through one meter, where facilities of adequate capacity and suitable voltage are
adjacent to the premises to be served, exceeding 10 kW of demand in any month.
Each year, Company will review the demand of all Customers receiving service under this tariff. If the
average of Customer's twelve monthly demands in the immediately preceding calendar year does not
exceed 10 kW, then Customer is not eligible to continue receiving service under this tariff.
Not applicable to supplementary or shared service, or to service for which a specific rate schedule is
provided.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $25.89 per month
Energy Charge: $0.005123 per kWh for all kWh used during the month
Demand Charge: $11.60 per kW of demand used per month during each summer month
$9.14 per kW of demand used per month during each winter month I
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
DEMAND: Company will furnish, at its expense, the necessary metering equipment to measure Customer's
kW demand for the 30 -minute period of greatest use during the month. In no month shall the billing
demand be greater than the value in kW determined by dividing the kWh sales for the billing period by
80 hours.
I
I
I
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with
demand in excess of 200 kW. Bills computed under the above rate will be increased $0.55 for each kvar
by which the reactive demand exceeds 0.33 times (multiplied by) the measured kW demand, and will bei
reduced $0.55 for each kvar by which the reactive demand is less than 0.33 times (multiplied by) the
measured kW demand. R
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-101-
XCel Energy'
souVJ►WEa7E11161 Mitt $UVJCE
ELECTRIC TARIFF
223
Section No. IV
Sheet No. IV -175
Revision NoT7
Page 2 of 2
LARGE MUNICIPAL SERVICE
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This
rate schedule is subject to other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard secondary
voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in Company's Rules, Regulations and Conditions of
Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-102-
224
XcelEnengy*
souIHwtsrt1N rustic IEIV CE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -177
Revision No. 4
Page 1 of 12
T
INTERRUPTIBLE CREDIT OPTION
AVAILABILITY: Available as an optional, interruptible service for Customers who receive electric
service under Company's Large General Service Transmission rate schedules at voltages of 69
kV and above, when the total Contract Interruptible Load (CIL) for all existing Customers
taking service under this tariff is less than 85 MW, and the addition of the new Customer's CIL
does not cause the total CIL of all existing Customers to exceed 85 MW. Not available to
Customers who receive electric service under Conipany's standby service rate schedules.
APPLICABILITY:
Optional service under this tariff is applicable to a Customer under the following conditions:
(1) Customer's CIL to be used in calculating the Monthly Credit is 500 kilowatts (kW) or
greater; and
(2) Customer achieved an Interruptible Demand .of at least 500 kW during each of the most
recent four summer peak season months of June, July, August, and September; or,
Company estimates that Customer will achieve an Interruptible Demand of at least 500 kW
during each of the four summer peak season months of June, July, August, and September
in the coming season; and
(3) Customer and Company have executed an Interruptible Credit Option Agreement
(Agreement) that specifies the Contract Firm Demand, Number of Interruptible Hours, the
Service Options elected by Customer, as described under CUSTOMER SPECIFIED
TERMS AND CONDITIONS in this tariff; and Customer specific data necessary for
Company to calculate Customer's Monthly Credit Rate (MCR).
TARIFF TERMINATION AND CHANGE:
This tariff and the Agreement shall be deemed to be modified to conform to any changes or
revisions approved by the Public Utility Commission of Texas, as of the date of the
effectiveness of such change, including cancellation or termination of this option. Changes in
the Customer's MCR will take effect in the billing month following the effective date of a
change in this tariff. Company reserves the right to request approval by the Public Utility
Commission of Texas for changes to or termination of this tariff at any time.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-103-
0 &elEnergr
sourotwtsrEiN Pue&IC $ERYlCI
ELECTRIC TARIFF
225
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 2 of 12
INTERRUPTIBLE CREDIT OPTION
TERM OF AGREEMENT, SERVICE PERIODS, AND TERMINATION OF AGREEMENT BY
CUSTOMER:
Service Periods under this tariff normally will begin on January 1 and continue for one calendar
year. Customer may enter into an Agreement at any time during the calendar year, however, if
Customer enters into the Agreement after March 1 of any year, the first Service Period under
this tariff will begin at the start of the following calendar year. If Customer enters into the
Agreement prior to March 1 of any year, the first Service Period will begin on the first day of
the following month and will consist of the remainder of that calendar year. Customer's
Number of Interruptible Hours (Ha) for the first Service Period will be reduced to a level that is
reasonably representative of the Number of interruptible Hours remaining for that calendar
year, determined at the discretion of the Company.
At any time during the first Service Period under this rate schedule, Customer may opt to
cancel the Agreement by returning all Monthly Credits paid by Company up until the date of
cancellation. No additional payment will be assessed. Economic buy -through payments made
by Customer and Economic buy -through penalty charges shall not be refunded by Company.
Capacity Interruption penalties shall be refunded. '
Any Customer who otherwise terminates the Agreement prior to the end of its term shall be
required to pay the Company, as a penalty, an amount equal to the product of one hundred and
ten percent (110%) times Customer's CIL, times Customer's MCR for each of the remaining
months of the unexpired contract term. In addition, Customer shall reimburse the Company for
the direct cost incurred by the Company for equipment (including its installation cost, less
salvage value) to measure Customer's Interruptible Demand and to interrupt Customer.
OBLIGATION TO INTERRUPT:
A Customer taking service under this tariff is required to reduce its load to the level of the
Contract Firm Demand specified in the Agreement when Company schedules an interruption
pursuant to the terms and conditions specified herein. Company shall have the right to interrupt
Customer's available interruptible load for the total Number of Interruptible Hours (Ha)
specified in the Agreement.
T
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-104-
226
J IEnergy
$0UI1NWE3tERN Mt+EiIC SESVJCI
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 3 of 12
INTERRUPTIBLE CREDIT OPTION
CUSTOMER SPECIFIED TERMS, CONDITIONS, AND SERVICE OPTIONS :
Contract Finn Demand - the Contract Firm Demand shall be specified by Customer in the
Agreement. The Contract Firm Demand of an existing Customs taking service under this tariff
may not be changed unless approved by Company.
Number of Interruptible Hours (Ha) — the Number of Interruptible Hours (Ha) shall be
specified by Customer in the Agreement. The options are: 40 hours, 80 hours, or 160 hours
annually
Four (4) Hour Minimum / Waiver of Four (4) Hour Minimum - an interruption shall be a
minimum of four (4) hours in duration. In the Agreement, however, Customer may elect to
waive the 4 hour minimum, in which case, the interruption may be less than 4 hours in duration.
The duration of any interruption shall not be less than one hour.
One Hour Notice / No Notice Option - Company shall provide notice a minimum of one hour
prior to the start of the interruption. In the Agreement, however, Customer may allow
Company to interrupt Customer's load without providing prior notice of the interruption.
ECONOMIC INTERRUPTION:
Company shall have the right to call an Economic Interruption for one or more Customers once
per day when Company determines, in its sole discretion, that calling an interruption will lower
its overall system costs when compared to what the overall system cost would be in the absence
of the interruption. The duration of any Economic Interruption shall not be less than four
hours, unless Customer has opted to waive the four-hour minimum and, in such case, the
duration shall not be less than one hour. Company will provide notice at least one hour prior to
an Economic Interruption.
BUY -THROUGH - ECONOMIC INTERRUPTION:
Once Company has called an Economic Interruption, Company will provide Customer, via the
contact methods identified on the Contact Information Sheet of the Agreement, with the
estimated buy -through price for each hour of the interruption period. Such notice shall advise
Customer of Company's best estimate of the buy -through price. Customers must notify
Company forty-five (45) minutes prior to the start of an Economic Interruption if they elect to
buy -through all or a portion of their available interruptible load by logging into the ICO Web
Site at the address provided in the Agreement and indicating their buy -through request for each
hour of the Economic Interruption period The ICO Web Site shall advise Customer of
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-105-
1l Energy~
soutxWESrEON PUltte SERVICE
ELECTRIC TARIFF
227
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 4 of 12
INTERRUPTIBLE CREDIT OPTION
BUY -THROUGH - ECONOMIC INTERRUPTION: (cont.)
Company's best estimate of the buy -through price for each hour of the Economic Interruption
period.
The buy -through price shall be calculated by taking the weighted average cost, as determined
by the Company's Cost Calculator or its successor, plus three mils per kWh, for the block of
electricity used to serve Customer(s) who elected to buy -through. For purposes of this
calculation, Company shall assume that the block of electricity used is the highest cost block of
electricity consumed in each buy -through hour.
If Customer elects to buy -through the Economic Interruption, it must continue to buy -through
all hours of the interruption period unless Company provides notice to Customer of an updated
buy -through price for any hour of the interruption that exceeds the original estimated buy -
through price for the hour in question, whereupon Customer that elected initially to buy -
through the Economic Interruption will have 15 minutes after being provided notice of the
updated estimated price to advise the Company that such Customer desires to be interrupted at
the start of the next hour. Once Customer chooses to interrupt, Customer will be interrupted for
the remainder of the interruption period, as determined by the Company.
If Company chooses to extend an Economic Interruption from the original notification, all ICO
Customers affected by the Economic Interruption will be provided notice of the opportunity to
buy -through or interrupt for the duration of the Economic Interruption extension period.
Economic Interruption extensions may be less than four hours in duration.
Customer may provide advance election to buy -though up to a specified price. Such election
shall be made no later than the last business day prior to the first day of the month to which the
election will apply, and shall be delivered to Customer's service representative by electronic
mail as provided in Customer's Agreement. Any Customer with a standing buy -though order
shall have the option, up to 45 minutes before the start of an event, to advise Company that it
desires to be interrupted. Further, in the event that the buy -though price exceeds the Customer -
specified price, Customer may nevertheless elect to buy though the interruption by providing
the Company with the required notice within 45 minutes.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-106-
228
"0., . a Energ r
$OU11HWPSUIN PUSLIC SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 5 of 12
INTERRUPTIBLE CREDIT OPTION
CAPACITY INTERRUPTION:
Company shall have the right to call a Capacity Interruption for one or more Customers at any
time when Company believes, in its sole discretion, that generation or transmission capacity is
not sufficiently available to serve its firm Load obligations, other than obligations to make intra-
day energy sales. Capacity Interruptions will typically be called when the Company forecasts
or, on shorter notice, has presently scheduled all available energy resources that are not held
back for other contingency or reserve purposes, to be online generating to serve obligation
loads. The Capacity Interruption may be activated to enable the Company to maintain
Operating Reserves, consisting of spinning and non -spinning reserves, ensuring adequate
capability above firm system demand to provide for such things as regulation, load forecasting
error, equipment forced outages and local area protection. A Capacity Interruption may be
called to relieve transmission facility overloads, relieve transmission under voltage conditions,
prevent system instability, relieve a system under frequency condition, shed load if SPS is
directed to shed Ioad by the Southwest Power Pool (or subsequent regional reliability
organization) Reliability Coordinator, and respond to other transmission system emergencies.
The duration of any Capacity Interruption shall not be less than four hours, unless Customer has
opted to waive the four-hour minimum duration and, in such case, the duration shall not be less
than one hour. In addition, a single interruption of less than four hours is permitted for any
Customer, if the Customer has less than four hours remaining of its Number of Interruptible
Hours.
CONTINGENCY INTERRUPTION: Company shall have the right to call a Contingency
Interruption for one or more Customers receiving service under the No Notice Option at any
time when the Company believes, in its sole discretion, that interruption is necessary for the
Company to be able to meet its Disturbance Control Standard (DCS) criteria. Contingency
Interruptions will typically be called by the Company following the unexpected failure or
outage of a system component, such as a generator, transmission line or other element.
Interruptible loads that are qualified as Contingency Reserve may be deployed by the Company
to meet current or future North American Electric Reliability Corporation (NERC) and other
Regional Reliability Organization contingency or reliability standards. The current standard is
the DCS, which sets the time limit following a disturbance within which a Balancing Authority
(BA) must return its Area Control Error (ACE) to within a specified range. In other words, a
Contingency Interruption will be activated to help restore resources and load balance after an
unexpected resource outage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-107-
XcelEnerg r
SOUTHWESTERN PirsttC SERVICE
ELECTRIC TARIFF
229
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 6 of 12
INTERRUPTIBLE CREDIT OPTION
The duration of any Contingency Interruption shall not be less than four hours, unless Customer
has opted to waive the four-hour minimum duration and, in such case, the duration shall not be
less than one hour. In addition, a single interruption of less than four hours is permitted if
Customer has less than four hours of interruption available to use the remaining hours.
FAILURE TO INTERRUPT
Economic Interruption - In the event that Customer fails to interrupt during an Economic
Interruption, Customer will be deemed by the Company to have failed to interrupt for all
demand that Customer was obligated to interrupt, but did not. The failure -to -interrupt charge
shall be equal to the highest incremental price for power during the Economic Interruption plus
three mils per kWh, as determined by the Company after the fact, including market costs, unit
start-up costs, spinning reserve costs and reserve penalty costs, if any. The charge will only
apply to the portion of the load Customer fails to interrupt.
Capacity or Contingency Interruption - In the event Customer is directed to interrupt and
fails to comply during a Capacity or Contingency Interruption, Customer shall pay the
Company fifty percent (50%) of Customer's expected annual credit rate times the maximum 30
minute demand recorded during the event for all demand that Customer was obligated to
interrupt, but did not. The penalty will apply only to the portion of the load that Customer fails
to interrupt. After Customer fails to interrupt twice, the Company shall have the option to
cancel the Agreement. If the Agreement is cancelled by the Company, Customer shall not be
eligible for service under this tariff for a minimum of one year, and Customer will not be liable
for the payment of 110% times the Customer's CIL, times Customer's MCR for each of the
remaining months of the unexpired contract term, as previously specified under term of
agreement, service periods, and termination of agreement by customer. For determining
compliance during a Capacity or Contingency Interruption, the first and last fifteen -minute
interval of each event shall not be considered. If Customer's violation is less than 60 minutes
in duration, not including the first and last control period intervals, then Customer's penalty
shall be: (1) be reduced by 75% if the violation is 15 minutes or shorter; (2) reduced by 50% if
the violation is 16 to 30 minutes in duration; and (3) reduced by 25% if the violation is 31 to 59
minutes in duration. This provision does not apply to Economic Interruptions.
If Customer is a No Notice Option Customer and Company controls Customer's load through
the operation of a Company installed, operated, and owned disconnect switch, in the event that
Custorner violates a Capacity or Contingency Interruption, Customer shall not be penalized
unless evidence of tampering or bypassing the direct load control of Company is shown.
T
T
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-108-
230
XcelErtergr
,OUTNWElrERN POSIIC SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 7 of 12
INTERRUPTIBLE CREDIT OPTION
Capacity or Contingency Interruption (cont.) -In the event that Company issues a Capacity
or Contingency Interruption during a time in which the Customer's phone line is not working,
the above described penalties shall apply if Customer fails to comply with the interruption.
BILLING AND MONTHLY CREDIT:
A Customer electing to take service under this tariff shall be billed on a calendar month basis,
such that the first day of each month shall be the beginning and the last day of each month shall
be the end of the monthly billing period. Company shall apply a Monthly Credit to Customer's
monthly bill, pursuant to the terms and conditions specified herein.
The Customer's Monthly Credit shall be calculated by multiplying the applicable Monthly
Credit Rate (MCR), as shown on the following table, by the lesser of the Customer's CIL, or
the actual Interruptible Demand, during the billing month. The applicable MCR is determined
by how the Customer is connected to the grid, the Number of Interruptible Hours (Ha) selected
by the Customer in the Agreement, and the season of the year.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-109-
XceIEnergy
�
$OUT$WUVE1N PUItIC MIMMI,
ELECTRIC TARIFF
231
Section No. IV
Sheet No. IV -177
Revision No. 4
Page 8 of 12
INTERRUPTIBLE CREDIT OPTION
Monthly Credit Rate (MCR)
Contract Interruptible Load (CIL) - Customer's CIL is the median of Customer's maximum
daily thirty (30) minute integrated kW demands occurring between the hours of 12:00 noon and
8:00 p.m. Monday through Friday, excluding federal holidays, during the period June 1 through
September 30 of the prior year, less the Contract Finn Demand, if any. If Customer has no
history in the prior year or Customer anticipates that its CIL for the upcoming year will exceed
the prior year's CIL by one hundred (100) kW or more, at Customer's request, Company may,
in its sole discretion, estimate the CIL. In extraordinary circumstances, Company may
calculate CIL using load data from the year prior to the year normally used to calculate the CIL,
if Customer has shown that, due to extraordinary circumstances, the load data that would
normally be used to calculate its CIL is less representative of what Customer's load is likely to
.‘„,21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-110-
ONE HOUR NOTICE OPTION
NO NOTICE OPTION
Ha
GRID CONNECTION
WINTER PER
kW MONTH
CREDIT
SUMMER PER
kW MONTH
CREDIT
WINTER
PER kW
MONTH
CREDIT
SUMMER PER kW
MONTH CREDIT
40
SUB-
TRANSMISSION
$1.58
52.25
51.84
$2.62
BACKBONE
TRANSMISSION
51.57
$2.23
$1.83
$2.59
80
SUB -
TRANSMISSION
$2.63
$3.74
$3.06
$4.34
BACKBONE..
TRANSMISSION
$2,61
, $3.70
$3.03
84.30
160
SUB -
TRANSMISSION
$4.03
$5.73
$4.68
$6.65
BACKBONE
TRANSMISSION
$3.99
$5.67
84.64
56.58
Contract Interruptible Load (CIL) - Customer's CIL is the median of Customer's maximum
daily thirty (30) minute integrated kW demands occurring between the hours of 12:00 noon and
8:00 p.m. Monday through Friday, excluding federal holidays, during the period June 1 through
September 30 of the prior year, less the Contract Finn Demand, if any. If Customer has no
history in the prior year or Customer anticipates that its CIL for the upcoming year will exceed
the prior year's CIL by one hundred (100) kW or more, at Customer's request, Company may,
in its sole discretion, estimate the CIL. In extraordinary circumstances, Company may
calculate CIL using load data from the year prior to the year normally used to calculate the CIL,
if Customer has shown that, due to extraordinary circumstances, the load data that would
normally be used to calculate its CIL is less representative of what Customer's load is likely to
.‘„,21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-110-
232
XcelEnetyy-
SOUTHWESTEIM'UOtrt stitVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. 1V-177
Revision No. 4 T
Page 9 of 12
INTERRUPTIBLE CREDIT OPTION
Contract Interruptible Load (CIL) (cont.) —
be in the upcoming year. For existing Customers, Company shall calculate Customer's CIL to
be used in the upcoming year by December 31" of the current year. If the Company determines
that Customer's CIL to be used in the upcoming year is less than 500 kW, then the Agreement
shall teuninate at the end of the current year. If the Company determines that the combined
CIL of all existing Customers to be used in the upcoming year exceeds 85MW, then those
existing Customers whose CIL is greater than the prior year's CIL may be required to reduce
their CIL (by increasing their Contract Finn Demand) proportionally, so that total CIL does not
exceed 85MW.
Interruptible Demand —Customer's Interruptible Demand is the maximum thirty (30) minute
integrated kW demand, determined by meter measurement, that is used during the month, less
the Contract Finn Demand, if any, but not less than zero. Interruptible Demand is measured
between the hours of 12:00 noon to 8:00 p.m. Monday through Friday, excluding federal
holidays.
Application of Monthly Credit - the Monthly Credit shall be applied to Customer's monthly
bill beginning in January if the Agreement was executed prior to that January. If the
Agreement is executed between January 1 and May 1, to be effective in that year, the Monthly
Credit will begin in the month following the month in which service begins. If the Agreement
is executed after May 1, the Monthly Credit will begin in January of the following year. In the
event that Customer's CIL is estimated, the Monthly Credit applicable to the estimated CIL will
be applied to Customer's December bill, after the CIL calculation is completed for that year.
For Customers with no history, the entire accumulated Monthly Credit will be credited to the
December bill. For Customers with history, but who estimate an increase, accumulated credits
attributable to the estimated increase in the CIL will be credited to the December bill and
credits attributable to the actual CIL will be credited monthly.
PHONE LINE REQUIREMENTS:.
Customer is responsible for the cost of installing and maintaining a properly working
communication path between Customer and Company The communication path must be
dedicated. Options for the communication path include, but are not limited to, a dedicated
analog phone line to the meter location. The communication path must be installed and
working before Customer may begin taking service under this rate schedule.
X..„00
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-111-
XcelEnergy-
cOUTNWISTION tttfirt SitY1C1
ELECTRIC TARIFF
233
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 10 of 12
INTERRUPTIBLE CREDIT OPTION
PHONE LINE REQUIREMENTS (Cont.):
In the event that the Company issues a Capacity or Contingency interruption during a time in
which Customer's phone line is not working, the penalties detailed in the section of this tariff
titled FAILURE TO INTERRUPT — Capacity and Contingency Interruptions, shall apply if
Customer fails to comply with the interruption.
COMMUNICATION AND PHYSICAL CONTROL REQUIREMENTS FOR NO NOTICE
OPTION CUSTOMERS:
A No Notice Option Customer must install and maintain a Company specified dedicated phone
line to the meter location. In addition a No Notice Option Customer must also pay for the
communication charges associated with the Company specified communication equipment
installed in the Remote Terminal Unit (RTU) used to receive and transmit interruption signals
and Heal time usage information.
A No Notice Option Customer shall either:
(i) utilize its own Energy Management System (EMS) automated intelligent equipment to
reduce load down to the Contract Firm Demand level when requested by Company.
Customer will pay for the cost of an RTU that will receive the interruption and restore
signals via phone or cellular communication. The RTU shall be designed, purchased,
installed, and tested by Company or Company contractor at Customer's expense.
Customer must demonstrate that its automated intelligent device or equipment will
receive Company's signal and automatically act upon that signal to remove load down
to the Contract Finn Demand level within a time period to be specified in the
Agreement. A $1,000 non-refundable contribution is required to perform the
engineering and design work required to determine the costs associated with
purchasing and installing the RTU;
or
utilize a Company owned and operated switch to remove Customer's entire load
during a Capacity or Contingency Interruption. Use of a Company switch requires
that Customer have no Contract Firm Demand. Customer must pay for the cost of
Company-owned switch and an RTU that will receive the interruption and restore
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-112-
234
XcelEnergy-
soutHwtsrmt 'taw sesv+ct
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 11 of 12
INTERRUPTIBLE CREDIT OPTION
COMMUNICATION AND PHYSICAL CONTROL REQUIREMENTS FOR NO NOTICE
OPTION CUSTOMERS (cont.): signals via phone or cellular communication, and lock
Customer's load out during a Capacity or Contingency Interruption. The RTU shall be
designed, purchased, installed, and tested by Company at Customer's expense. A $1,000 non-
refundable contribution is required to perform the engineering and design work needed to
determine the costs associated with providing Company physical control over Customer's load.
A minimum of six (6) months is required to design, order, install and test the required
equipment to give the Company control over Customer's load. During a Capacity or
Contingency Interruption, the Company shall lock out Customer's load to prevent Customer
from terminating the interruption before release. This option is not available if Customer
receives secondary service from the Company.
A No Notice Option Customer shall submit to equipment testing at least once per year at
Company's discretion, provided no other Capacity or Contingency events occurred in the past
12 months that could be used to verify the correct operation of the disconnect equipment and
RTU. Equipment testing may last less than the four-hour duration and may not count toward
Customer's Number of Interruptible Hours.
TAMPERING:
If Company determines that its load management or load control equipment on Customer's
premises has been rendered ineffective due to tampering by use of mechanical, electrical, or
other devices or actions, then Company may terminate Customer's Agreement, or remove
Customer from the No Notice Option and place Customer on the One Hour Notice Option rate
for a minimum one-year period. The Customer's credits will be adjusted accordingly. In
addition, Customer may be billed for all expenses involved with the removal, replacement or
repair of the load management equipment or load control equipment and any charges resulting
from the investigation of the device tampering. Customer shall also pay 50% of the expected
annual credit rate, times the maximum 30 minute demand recorded during the interruption
event for all demand Customer was obligated to interrupt, but did not. The penalty will apply
only to the portion of the load that Customer fails to interrupt. A Customer that is removed
from the program is only eligible to participate again at the discretion of Company. Company
will verify installation has been corrected before Customer is permitted to participate in the
program again.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-113-
X Energy-
$OUIR vttrt1N PU1ttt =EIVICI
ELECTRIC TARIFF
235
Section No. IV
Sheet No. IV -177
Revision No. 4 T
Page 12 of 12
INTERRUPTIBLE CREDIT OPTION
LIMITATION OF LIABILITY:
Customers who elect to take service under this tariff agree to indemnify and save harniless
Company from all claims or losses of any sort due to death or injury to person or property
resulting from interruption of electric service under this tariff or from the operation of the
intemiption signal and switching equipment.
X,vc->40
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-114-
236
Fr
SOU1KWEITE1111 ►YItIC SURYiCE
ELECTRIC TARIFF
Section No. IV
Sheet No. 1V-179
Revision No:16
Page 1 of 4
PRIMARY STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at a primary voltage of 2.4 kV or higher but
less than 69 kV and supplied at one Point of Delivery, for which Company's service is used as standby,
backup or maintenance service. Applies to Customers who operate any electric generating equipment
in parallel with Company's electric system which normally serves all or a portion of the Customer's
electrical load requirements; who requires Standby Capacity from the Company; and who desire use of
the Company's electrical service for temporary backup or maintenance power and energy. Not
applicable to power generated for resale.
AVAILABILITY: Service hereunder is available only to Customers who have executed an Electric Service
Agreement with the Company that specifies Customer's Contract Standby Capacity and Total Load
requirements. All power service supplied by Company to Customer in excess of the contract Standby
Capacity shall be provided by Company nnder the Primary General Service ("PG") tariff. Standby
service provided for Customer generation hereunder is not available under the Company's Interruptible
Credit Option ("ICO") tariff. Customers receiving service under this tariff shall be billed on a calendars
month basis, such that the first day of each month shall be the beginning and the last day of each month
shall be the end of the monthly billing period.
RATE: Service Availability Charge:
Transmission & Distribution Standby Capacity Fee — Summer
Transmission & Distribution Standby Capacity Fee — Winter:
Generation Standby Capacity Fee — Summer
Generation Standby Capacity Fee Winter:
Energy Charge: for all kWh used during the month
EXCESS USAGE
If Customer Usage Hours exceed 99 Usage Hours, the above charges
shall not apply and the charges will be as follows:
$163.03 per month
$6,29 / kW Month
$5.07 / kW Month
$1.57 / kW Month
$1.26 / kW Month
$0.004631 per kWh
Service Availability Charge: $163.03 per month
Usage Demand Charge - Summer:
Usage Demand Charge Winter:
$13.13/kW Month
$10.08 / kW Month
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-115-
XceI Energy
sourHWEsreitm PUBLIC SERVICE
237
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -179
Revision No16
Page 2 of 4
PRIMARY STANDBY SERVICE
Energy Charge: for all kWh used during the month $0.004631 per kWh I
SUMMER MONTHS: The billing months of June - September.
WINTER MONTHS: The billing months of October — May.
DEFINITIONS:
CONTRACT STANDBY CAPACITY: The level of Contract Standby Capacity in kilowatts the CompanyT
reserves in its transmission and distribution systems and its generation for the Customer as set forth in
the Electric Standby Service Agreement. Contract Standby Capacity is limited to and is the lesser of
• the Customer's Total Load,
the Customer's generation capacity, or
an amount agreed to by the Company and the Customer.
CUSTOMER'S TOTAL LOAD: Represents the maximum historical level of electrical demand at th
Customer's service location on or after January 1 °`, 2012, and shall be determined by mete
measurement of the total capacity requirements of Customer, regardless of whether such capacity i
supplied by Company, Customer's own generation equipment, or a combination of both. Customer'
Total Load shall carry forward from year-to-year until Customer's maximum demand exceeds previo
Total Load. In the month following the month in which larger total was metered, the larger value woul
then become the Customer's Total Load.
T
STANDBY SERVICE: Standby Service shall be the service provided by Company under this Primary
Standby Service tariff. T
USAGE HOURS: Each hour in a calendar month during which a 30 -minute interval of Customer generation is
less than the lower of Customer Usage or 60% of Contract Standby Capacity, excluding energy used
during Qualified Scheduled Maintenance Periods, is considered a Usage Hour. If the number of Usage
Hours in a month is 100 or more hours, Customer shall pay according to the provisions of Excess Usage
for Standby Service.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
238
�►.:.� Ene }!""
SOUTHWE$1IIM Ptlitte SURYttt
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -179
Revision No16
Page 3 of 4
PRIMARY STANDBY SERVICE
CONTRACT PERIOD: All contracts under this schedule shall be for a minimum period of one year and one-
year periods thereafter until terminated, where service•is no longer required, on 30 days notice. Greater
minimum periods may be required by contract in situations involving large or unusual loads.
METER INSTALLATION: Company shall install, own, operate, and maintain the metering to measure the
electric power and energy supplied to Customer to allow for proper billing of the separate PG Service
and Standby Service demands and grace period identified above. In particular, Company will install a
meter that measures the flow of power and energy from Customer's own generating facility (generation
metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company may
determine that it is more practical or economical to use generation metering installed and owned by
Customer, rather than Company-owned metering equipment. If Company, at its sole discretion, makes
such a determination, then Customer -owned generation metering may be used for the billing purposes,
so long as such metering equipment meets Company's standards for quality and accuracy.
If through the course of Company's evaluation of the metering requirements for the generation
meter(s), Company determines, at its sole discretion, that it is impracticable, uneconomical or
unnecessary to install metering on Customer's generator(s), Company shall determine the billing for the
provision of the Standby Service tariff on an un -metered and calculated basis. This determination can
only be made if the only electrical load located at Customer's site is station power equipment as defined
by the Federal Energy Regulatory Commission.
Regardless of Company's ultimate determination of the requirement (or lack thereof) for installation of
the generation metering, a meter will always be required at the point of interconnection between'.
Company and Customer and such meter will measure both delivered and received capacity and energy.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE: Qualifying Scheduled Maintenance Periods must occur within the winter months as
defined above. Customer must provide Company with 30 days written notice of scheduled maintenance
prior to the beginning of the maintenance period. The duration of qualifying scheduled maintenance
periods may not exceed a total of six weeks in any 12 -month period.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE W1TH STANDBY SCHEDULED
MAINTENANCE (cont.):
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-117-
XCelEnergy-
SODUYHWESi'UN PUlttt SEEYICE
ELECTRIC TARIFF
239
Section No. IV
Sheet No, IV -179
Revision No. 6
Page 4 of 4
PRIMARY STANDBY SERVICE
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods shall
result in the energy used during unapproved maintenance outages being applied against the Usage
Hours energy limit.
DEFINITION OF SUPPLEMENTAL DEMAND: If Customer's Total Load is in excess of the Contract
Standby Demand, the Supplemental Demand (kW) • is equal to Customer's Total Load minus the
Contract Standby Capacity. Supplemental Demand and energy will be billed on the applicable PG
tariff.
FUEL COST RECOVERY: The charge per kWh of the above rate shall be increased by the applicable fuel
cost recovery per kWh as provided in PUCT Sheet No. IV -69.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE: A -C 60 hertz, single or three phase at Company's available primary voltage.
‘i„„21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-118-
240
V„, Xcel Energyw
sou?Nwesre,RN PUItte SE*VICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -180
Revision No16
Page 1 of 4
SECONDARY STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at secondary voltage supplied at one Point of
Delivery, for which Company's service is used as standby backup or maintenance service. Applies to
Customers who operate any electric generating equipment in parallel with Company's electric system
which normally serves all or a portion of Customer's electrical load requirements; who requires
Standby Capacity from Company; and who desire use of Company's electrical service for temporary
backup or maintenance power and energy. Not applicable to power generated for resale.
AVAILABILITY:
Service hereunder is available only to Customers who have executed an Electric Service Agreement
with Company that specifies Customer's Contract Standby Capacity and Total Load requirements. All
power service supplied by Company to the Customer in excess of the contract Standby Capacity shall
be provided by Company under the Secondary General Service ("SG") tariff. Service hereunder is not
available under Company's Interruptible Credit Option ("ICO") tariff. Customers receiving service
under this tariff shall be billed on a calendar month basis, such that the first day of each month shall be
the beginning and the last day of each month shall be the end of the monthly billing period.
RATE: Service Availability Charge:
Transmission & Distribution Standby Capacity Fee — Summer:
Transmission & Distribution Standby Capacity Fee — Winter:
Generation Standby Capacity Fee — Summer.
Generation Standby Capacity Fee — Winter.
Energy Charge:
EXCESS USAGE
If Customer Usage Hours exceed 99 Usage Hours, the above
charges shall not apply and the charges will be as follows:
Service Availability Charge:
Usage Demand Charge - Summer:
Usage Demand Charge - Winter:
Energy Charge: for all kWh used during the month
$26.76 per month
$8.37 / kW Month
$6.82 / kW Month
$1.86 / kW Month
$1.50 / kW Month
50.005651 per kWh
$26.76 per month
$15.94 / kW Month
$12.96 / kW Month
$0.005651 per kWh
1
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-119-
/0_,•
XcelEnergy"
aovtwwrsrUrrt Ponta tU#YICI
ELECTRIC TARIFF
241
Section No. IV
Sheet No. W-180
Revision No. 6
Page 2 of 4
SECONDARY STANDBY SERVICE
SUMMER MONTHS: The billing months of June — September.
WINTER MONTHS: The billing months of October — May.
DEFINITIONS:
CONTRACT STANDBY CAPACITY:
The level of Contract Standby Capacity in kilowatts the Company reserves in its transmission and
distribution systems and its generation for the Customer as set forth in the Electric Standby Service
Agreement. The Contract Standby Capacity is limited to and is the lesser of:
• the Customer's Total Load,
• the Customer's generation capacity, or
• an amount agreed to by the Company and the Customer.
CUSTOMER'S TOTAL LOAD:
Represents the maximum historical level of electrical.demand at the Customer's service location on or
after January 1°`, 2012, and shall be determined by meter measurement as the total capacity
requirements of Customer, regardless of whether such capacity is supplied by Company, Customer's
own generation equipment, or a combination of both. Customer's Total Load shall carry forward from
year-to-year until Customer's maximum demand exceeds previous Total Load. In the month following
the month in which larger total was metered, the larger value would then become the Customer's Total
Load.
T
STANDBY SERVICE:
Standby Service shall be the service provided by Company under this Secondary Standby Service tariff.
USAGE HOURS:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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242
xceIEne
SOU?Hwt$IUM ,U,tlt EIRY►Ct
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -180
Revision No. 6
Page 3 of 4
SECONDARY STANDBY SERVICE
Each hour in a calendar month during which a 30 -minute interval of Customer generation is less than
the lower of Customer usage or 60% of Contract Standby Capacity, excluding energy used during
Qualified Scheduled Maintenance Periods, is considered a Usage Hour. If the number of
Usage Hours in a month is 100 or more hours, Customer shall pay according to the provisions of Excess
Usage for Standby Service.
CONTRACT PERIOD: All contracts under this schedule shall be for a minimum period of one year and one-
year periods thereafter until terminated, where service is no longer required, on 30 days notice. Greater
minimum periods may be required by contract in situations involving large or unusual loads.
METER INSTALLATION: Company shall install, own, operate, and maintain the metering to measure the
electric power and energy supplied to Customer to allow for proper billing of the separate SG Service
and Standby Service demands and grace period identified above. In particular, Company will install a
meta that measures the flow of power and energy from Customer's own generating facility (generation
metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company may
determine that it is more practical or economical to use generation metering installed and owned by
Customer, rather than Company-owned metering equipment. If Company, at its sole discretion, makes
such a determination, then Customer -owned generation metering may be used for the billing purposes,
so long as such metering equipment meets Company's standards for quality and accuracy.
If through the course of Company's evaluation of the metering requirements for the generation
meter(s), Company determines, at its sole discretion, that it is impracticable, uneconomical or
unnecessary to install metering on Customer's generator(s), Company shall determine the billing for they
provision of the Standby Service tariff on an un -metered and calculated basis. This determination can
only be made if the only electrical load located at Customer's site is station power equipment as defined
by the Federal Energy Regulatory Commission.
METER INSTALLATION:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-121-
X Energy-
SOUTNWESIUN PUIt1C SERYSCE
ELECTRIC TARIFF
243
Section No. IV
Sheet No. IV -180
Revision No. 6
Page 4 of 4
SECONDARY STANDBY SERVICE
Regardless of Company's ultimate determination of the requirement (or lack thereof) for installation of
the generation metering, a meter will always be required at the point of interconnection between
Company and Customer and such meter will measure both delivered and received capacity and energy.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE:
Qualifying Scheduled Maintenance Periods must occur within the winter months as defined above.
Customer must provide Company with 30 days written notice of scheduled maintenance prior to the
beginning of the maintenance period. The duration of qualifying scheduled maintenance periods may
not exceed a total of six weeks in any 12 -month period.
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods shall
result in the energy used during unapproved maintenance outages being applied against the Usage
Hours energy limit.
DEFINITION OF SUPPLEMENTAL DEMAND:
If Customer's Total Load is in excess of the Contract Standby Demand, the Supplemental Demand
(kW) is equal to Customer's Total Load minus the Contract Standby Capacity. Supplemental Demand
and energy will be billed on the applicable SG tariff.
FUEL COST RECOVERY:
The charge per kWh of the above rate shall be increased by the applicable fuel cost recovery per kWh
as provided in PUCT Sheet No. IV -69.
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day falls on a
holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE:
Alternating current; 60 hertz; single or three phase, at one available standard secondary voltage.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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/0, l Energy*
aanrswESMN PUIatc s!IVSCE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -181
Revision Nom
Page 1 of 5
TRANSMISSION STANDBY SERVICE
APPLICABILITY: Under contract for electric service provided at a transmission voltage supplied at one
Point of Delivery, for which Company's service is used as standby, backup or maintenance service.
Applies to Customers who operate any electric generating equipment in parallel with Company's
electric system which normally serves all or a portion of Customer's electrical load requirements; who
requires Standby Capacity from Company; and who desire use of Company's electrical service for
temporary backup or maintenance power and energy. Not applicable to power generated for resale.
AVMLABILITY: Service hereunder is available only to Customers who have executed an Electric Service
Agreement with Company that specifies Customer's Contract Standby Capacity and Total Load
requirements. All power service supplied by Company to Customer in excess of the Contract Standby
Capacity shall be provided by Company under the Large General Service Transmission ("LGS-T')
tariff. Service under Company's Interruptible Credit Option (ICO) tariff is not available to Customers
taking service under this Transmission Standby Service tariff. Customers receiving service under this
tariff shall be billed on a calendar month basis, such that the first day of each month shall be the
beginning and the last day of each month shall be the end of the monthly billing period.
SUB TRANSMISSION STANDBY SERVICE - 69 KV:
RATE: Service Availability Charge Per Month: $1,789.06
• Transmission Standby Capacity Fee - Summer: $2.88 / kW Month
Transmission Standby Capacity Fee - Winter: $2.35 / kW Month
Generation Standby Capacity Fee - Summer: $1.16 / kW Month
Generation Standby Capacity Fee - Winter: 50.94 / kW Month
Energy Charge: for all kWh used during the month: 50.003891 per kWh
TRANSMISSION STANDBY SERVICE -115 KV AND ABOVE:
RATE: Service Availability Charge Per Month: $1,773.31
Transmission Standby Capacity Fee- Summer: $2.85 / kW Month
Transmission Standby Capacity Fee- Winter: $2.32 / kW Month
Generation Standby Capacity Fee - Summa: 51.16 / kW Month
Generation Standby Capacity Fee - Winter: $0.94 / kW Month
Energy Charge: for all kWh used during the month: $0.003870 per kWh
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-123-
I
Xcel Energy~
5OUTHWUVf*N 'USW SUYICt
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -181
Revision No. 6
Page 2 of 5
TRANSMISSION STANDBY SERVICE
EXCESS USAGE — 69 kV
If Customer Usage Hours exceed 99 Usage Hours, the above charges shall not apply and the charges
will be as follows:
Service Availability Charge Per Month: $1,789.06
Demand Charge - Summer. $10.66 / kW Month
Demand Charge - Winter. $ 7.48 / kW Month
Energy Charge: for all kWh used during the month $0.003891 per kWh
EXCESS USAGE —115 kV AND ABOVE
If Customer Usage Hours exceed 99 Usage Hours, the above charges shall not apply and the charges
will be as follows:
Service Availability Charge Per Month: $1,773.31
Demand Charge - Summer: $10.57 / kW Month
Demand Charge - Winter. $ 7.39 / kW Month
Energy Charge: for all kWh used during the month $0.003870 per kWh
SUMMER MONTHS: The billing months of June — September.
T
WINTER MONTHS: The billing months of October - May.
T
DEFINITIONS:
X1/4„,.0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-124-
T
245
246
XCelEnergr
sourHwasrfRW ►UItlt SEIVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -181
Revision No. 6
Page 3 of 5
TRANSMISSION STANDBY SERVICE
CONTRACT STANDBY CAPACITY:
The level of Contract Standby Capacity in kilowatts the Company reserves in its transmission and
distribution systems and its generation for the Customer as set forth in the Electric Standby Service
Agreement. Contract Standby Capacity is limited to and is the lesser of:
• the Customer's Total Load,
• the Customer's generation capacity, or
• an amount agreed to by the Company and the Customer.
Customer's Total Load represents the maximum historical level of electrical demand at the Customer's
service location on or after January 1 ", 2012, and shall be determined by meter measurement of the to
capacity requirements of Customer, regardless of whether such capacity is supplied by Company
Customer's own generation equipment, or a combination of both. Customer's Total Load shall
forward from year-to-year until Customer's maximum demand exceeds previous Total Load. In th
month following the month in which larger total was metered, the larger value would then become th
Customer's Total Load.
STANDBY SERVICE:
Standby Service shall be the service provided by Company under this Transmission Standby Service
tariff.
USAGE HOURS:
Each hour in a calendar month during which a 30 -minute interval of Customer generation is less than
the lower of Customer usage or 60% of Contract Standby Capacity, excluding energy used during
Qualified Scheduled Maintenance Periods, is considered a Usage Hour. If the number of Usage Hours
in a month is 100 or more hours, Customer billing will be based upon the provisions of Excess Usage/.
for Standby Service.
CONTRACT PERIOD:
All contracts under this schedule shall be for a minimum period of one year and one-year periods
thereafter until terminated, where service is no longer required, on 30 days notice. Greater minimum
periods may be required by contract in situations involving large or unusual loads.
METER INSTALLATION:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-125-
Energy"
sourswEsrexa Pnseic seRVtCE
ELECTRIC TARIFF
247
Section No. IV
Sheet No. IV -181
Revision No. 6
Page 4 of 5
TRANSMISSION STANDBY SERVICE
Company shall install, own, operate, and maintain the metering to measure the electric power and
energy supplied to Customer to allow for proper billing of the separate LGS-T Service and Standby
Service demands and energy identified above. In particular, Company will install a meter that measures
the flow of power and energy from Customer's own generating facility (generation metering).
As a result of the electrical or physical configuration of Customer's generation facility, Company may
determine that it is more practical or economical to use generation metering installed and owned by
Customer, rather than Company-owned metering equipment. If Company, at its sole discretion, makes
such a determination, then Customer -owned generation metering may be used for the billing purposes,
so long as such metering equipment meets Company's standards for quality and accuracy. If through
the course of Company's evaluation of the metering requirements for the generation meter(s), Company
determines, at Customer's generator(s), Company shall determine the billing for the provision of the
Standby Service tariff on an un -metered and calculated basis This determination can only be made if
the only electrical load located at Customer's site is station power equipment as defined by the Federal
Energy Regulatory Commission.
Regardless of Company's ultimate determination of the requirement (or lack thereof) for installation of
the generation metering, a meter will always be required at the point of interconnection between
Company and Customer and such meter will measure both delivered and received capacity and energy.
ADDITIONAL TERMS AND CONDITIONS OF SERVICE WITH STANDBY SCHEDULED
MAINTENANCE:
Qualifying Scheduled Maintenance Periods must occur within the winter months as defined above.
Customer must provide Company with 30 days written notice of scheduled maintenance prior to the
beginning of the maintenance period. The duration of qualifying scheduled maintenance periods mayr
not exceed a total of six weeks in any 12 -month period.
Any non-compliance with all terms and conditions for qualifying scheduled maintenance periods shall
result in the energy used during unapproved maintenance outages being applied against the Usage
Hours energy limit.
DEFINITION OF SUPPLEMENTAL DEMAND:
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
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Energy-
SGUr8WESUEHk PU$tlt SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -181
Revision No, 6
Page 5 of 5
TRANSMISSION STANDBY SERVICE
If Customer's Total Load is in excess of the Contract Standby Demand, the Supplemental Demand
(kW) is equal to the Customer's Total Load minus the Contract Standby Capacity. Supplemental
Demand and energy will be billed on the applicable LGS-T tariff.
FUEL COST RECOVERY:
The charge per kWh of the above rate shall be increased by the applicable fuel cost recovery factor per
kWh as provided in PUCT Sheet No. IV -69. This rate schedule is subject to other applicable rate
adjustments.
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day falls on a
holiday or weekend, the due date will be the next work day.
CHARACTER OF SERVICE:
Alternating current; 60 hertz; at approximately the contract voltage of 69 kV or larger.
REC CREDIT: 69 kV Customers who provide written notice to the Commission pursuant to PURA Section
39.904(m-1) and Commission's regulations promulgated there under, shall receive a credit of
$0.000288 per kWh to their billings under this tariff. Customers who receive REC credits under this
tariff do not share in any REC costs, and shall not be eligible to receive any revenue credits from sales
of RECs by the Company.
115 kV Customers who provide written notice to the Commission pursuant to PURA Section 39.904(m-
1) and Commission's regulations promulgated there under, shall receive a credit of $0.000286 per kWh
to their billings under this tariff. Customers who receive REC credits under this tariff do not share in
any REC costs, and shall not be eligible to receive any revenue credits from sales of RECs by the
Company.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-127-
'6 )(eel Energ
SOUINWt*TEIN tingle SERVICE
ELECTRIC TARIFF
249
Section No. IV
Sheet No. IV -182
Revision NoT7
Page 1 of 2
LARGE SCHOOL SERVICE
APPLICABILITY: To all public and private schools supplied electric service at secondary voltage measured
through one meter and at one Point of Delivery, where facilities of adequate capacity and suitable
voltage are adjacent to the premises to be served, exceeding 10 kW of demand in any month.
Each year, Company will review the demand of all Customers receiving service under this tariff. If the
average of Customer's twelve monthly demands in the immediately preceding calendar year does not
exceed 10 kW, then Customer is not eligible to continue receiving service under this tariff.
Not applicable to standby, supplementary, or shared service, or to service for which a specific rate
schedule is provided.
TERRITORY: Texas service territory.
RATE: Service Availability Charge: $36.49 per month
Energy Charge: $0.005901 per kWh for all kWh used during the month
Demand Charge:
$12.89 per kW of demand used per month during each summer month
$ 10.19 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
I
DEMAND: Company will furnish, at its expense, the necessary metering equipment to measure Customer's
kW demand for the 30 -minute period of greatest use during the month. In no month, shall the billingf
demand be greater than the value in kW determined by dividing the kWh sales for the billing period by
80 hours.
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with
demand exceeding 200 kW. Bills computed under the above rate will be increased $0.55 for each kvar
by which the reactive demand exceeds 0.33 times (multiplied by) the measured kW demand,
I
POWER FACTOR ADJUSTMENT (cont.):
R
,‘„J
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-128-
250
/0, Xefil Energy*
•OV7NWe$►flN rv:ett $EUYItr
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -182
Revision No. 7
Page 2 of 2
LARGE SCHOOL SERVICE
and will be reduced $0.55 for each kvar by which the reactive demand is less than 0.33 times
(multiplied by) the measured kW demand.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be increased
by the applicable fuel cost recovery factor per kWh hour as provided in PUCT Sheet IV -69. This rate
schedule is subject to other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; single or three phase, at one available standard secondary
voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the teens and conditions set forth in Company's Rules, Regulations and Conditions of
Service on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-129-
XCel
SOI:HWUY UN PUBLIC Sflyitt
ELECTRIC TARIFF
251
Section No. IV
Sheet No. 1V-183
Revision No16
Page 1 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
T
AVAILABILITY: This Schedule is available under contract to Customers whose total demand is normally
served by Customer's generation of at least 1,000 kW during June, July, August, and September, and
whose facilities are equipped with appropriate telemetering and control equipment to permit Customer to
comply with, or Company to implement, curtailment requests. Service under this rate is available when
taken in conjunction with service under the applicable large general service rate schedules and riders, or
with firm standby service under the Transmission Qualifying Facility Standby Service rate schedule.
APPLICABILITY:
Under contract for electric service to a Qualifying Facility ("QF") provided at a transmission voltage for
which Company's service is used as non-firm standby backup or non-firm maintenance service supplied
at one Point of Delivery.
RATE:
SUB TRANSMISSION SERVICE OF 69 KV:
Service Availability Charge Per Month: The following charge will apply if non-firm standby service is
provided on a stand-alone basis: $1,789.06
Delivery Charges:
Transmission System Standby Capacity Fee -Summer: $ 2.88 per 4CP kW
Transmission System Standby Capacity Fee -Winter: $ 2.35 per 4CP kW
Generation System Standby Capacity Fee- Summer: $ 0.93 per kW of Nominated Standby
Capacity T
Generation System Standby Capacity Fee- Winter: $ 0.75 per kW of Nominated Standby
Capacity
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-130-
252
Xcel Ene gy'"
SOUTHWESTERN RUSTIC SERVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -183
Revision No. 6
Page 2 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
TRANSMISSION SERVICE OF 115 KV AND ABOVE:
Service Availability Charge Per Month: The following charge will apply if non-firm standby service is
provided on a stand-alone basis: $1,773.31
Delivery Charges:
Transmission System Standby Capacity Fee -Summer: $2.85 per 4CP kW
Transmission System Standby Capacity Fee -Winter: $2.32 per 4CP kW
Generation System Standby Capacity Fee- Summer: $0.93 per kW of Nominated Standby
Capacity
Generation System Standby Capacity Fee- Winter: $0.75 per kW of Nominated Standby
Capacity
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
Usage Rates:
Demand Charge:
There will be no additional demand charge for use of Standby Service except for
Non -Compliant use as defined herein. In this case, Standby Service Demand
Charges shall be as defined in the Non -Compliance Payment paragraph of this
tariff.
Energy Charge:
All Standby Replacement Energy provided by Company during non -interrupt
periods shall be billed at the Hourly Clearing Price of the applicable regional wholesale
energy market. Additionally, an Energy Margin of five percent (5%) of
I
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-131-
.' #Energ
souriwtstrRM POlttc SERVICE
ELECTRIC TARIFF
253
Section No. IV
Sheet No. IV -183
Revision No. 6
Page 3 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
Energy Charge (cont.):
the Hourly Clearing Price, no less than $0.003870 per kWh, shall be added to the charge
for all Standby Replacement Energy provided by Company.
BACKUP SERVICE:
Backup Service is capacity and energy supplied by Company to replace Customer's generation during
an unscheduled outage. The maximum required level of Backup Demand (the "Standby Capacity')
shall be nominated annually in writing at least 30 days before the beginning of the calendar year.
MAINTENANCE SERVICE:
Maintenance Service is capacity and energy supplied by Company to replace Customer's self -generation
during scheduled outages of Customer's generation. Scheduled outages shall be set at a time mutually
agreeable by Customer and Company, excluding June, July, and August. The scheduled outage(s) shall
be scheduled in two billing months per calendar year.. Scheduled outages shall be agreed to in writing at
least 30 days prior to the beginning of the month in which the scheduled outage is planned to take place.
SUPPLEMENTAL GENERATION SERVICE:
Supplemental Generation Service is capacity and energy supplied by Company and used by Customer in
place of Customer's self -generation whenever Customer's self -generation is not operating at the full level
of the nominated Standby Capacity. This Supplemental Generation Service usage shall be billed Standby
Replacement Demand and Standby Replacement Energy as described below.
SUPPLEMENTAL LOAD SERVICE:
Supplemental Load Service is capacity and energy supplied by Company to Customer for load
requirements above the nominated Standby Capacity for Customer's self -generation, in order to meet
Customer's total load requirement. This Supplemental Load Service usage shall be billed in accordance
with the standard applicable rate schedule.
DEFINITION OF CUSTOMER METER DEMAND:
Customer Meter Demand shall be the demand in kW determined from Company's demand meter at the
Customer Meter for the 30 minute period of greatest use during the month.
DEFINITION OF 4CP DEMAND:
The 4CP Demand applicable under the Delivery Charges shall be the average of the Standby
X.,„„0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-132-
254
XcelEnergy
$OUVHWESI`9R# il!ltlt SttVICE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -183
Revision No. 6
Page 4 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
Replacement Demand at the time of Company's system peak demand in June, July, August and
September of the previous calendar year. Retail Non -Firm Standby Customers without previous history
on which to base their 4CP Demand will be billed based on an estimate of the 4CP Demand.
DEFINITION OF MINIMUM GENERATION PRODUCTION:
The Minimum Generation Production shall be the generation output in kW determined at the QF
Generation Meter for the 30 -minute period of least total generation output during the month.
DEFINITION OF STANDBY REPLACEMENT DEMAND:
The Standby Replacement Demand shall be equal to the minimum of (a) Customer Meter Demand, (b)
the Standby Capacity (Backup Demand), or (c) the nominated Standby Capacity minus the Minimum
Generation Production.
DEFINITION OF STANDBY REPLACEMENT ENERGY:
The Standby Replacement Energy shall be equal to the energy metered at the Customer Meter less the
energy supplied to Customer's Supplemental Load Service, but not more than the outage hours in a
month times (multiplied by) the nominated Standby Capacity.
DEFINITION OF SUPPLEMENTAL LOAD DEMAND:
The Supplemental Load Demand shall be equal to Customer Meter Demand minus the Standby
Replacement Demand, but no less than the minimum demand set forth in the applicable tariff.
MINIMUM CHARGE:
The minimum charges in a month shall be the sum of the Service Availability Billing Charge, Service'
Availability Charge per Meter if applicable, and the Delivery Charges.
POWER FACTOR ADJUSTMENT:
Bills computed under the above rate will be increased $0.55 for each kvar by which the reactivJ
demand exceeds 0.33 times (multiplied by) the measured kW demand, and will be reduced $0.55 fob
each kvar by which the reactive demand is less than 0.33 times (multiplied by) the measured kW
demand.
TERMS OF PAYMENT:
Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the sixteenth day falls on a
holiday or weekend, the due date will be the next work day.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-133-
61" iEnergr
$OVVkWES1'RSN PUI(JC SESYICE
ELECTRIC TARIFF
255
Section No. IV
Sheet No. IV -183
Revision No. 6
Page 5 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
CHARACTER OF SERVICE:
Alternating current; 60 hertz; at approximately the contract voltage.
GENERAL CONDITIONS:
Customer understands that failure to interrupt this Non -Firm Standby Service when requested threatens
the reliability of service to other customers. Company will attempt to provide as much prior notice as
possible prior to interruptions. Interruptions may be made at any time, in the judgment of Company,
when demand for electricity exceeds or is likely to exceed Company's available electric, supply for any
reason including, but not limited to, breakdown of generating units, transmission equipment or other
critical facilities; short or
long-term shortages of fuel or generation, transmission, and other facilities; and requirement or orders
of governmental agencies.
CONDITIONS OF SERVICE:
Customer is required to install, own, operate and maintain necessary monitoring devices and interruption-
control equipment including protective devices, at Customer's point of delivery, as reasonably specified
by Company. In addition, Company shall install interruption -control equipment on the Company's side of
the point of delivery as it reasonably determines is necessary to interrupt the interruptible load. All
interruption -control equipment shall be under the exclusive control of Company, and the installation and
maintenance of such facilities shall be at the expense of Customer. Interruption -control equipment
consists of, but is not limited to, under -frequency relays, switchgear, remote control and communicatioils
equipment including a communications path, timers, trip counters, and/or other devices as specified by
Company. Remote control and communications equipment includes equipment necessary to provide
instantaneous load information to Company's designated system operating centers. Operation of the
equipment will remain under the control of Company and Company reserves the right to inspect and test
all interruption -control equipment and review Customers' maintenance records. Customer will make
commercially reasonable efforts to notify the Company of the timing and anticipated duration of planned
outages.
NON-COMPLIANCE PAYMENT:
When Company requests a reduction of any part or all of Customer's Standby load, Customer must
comply with such request within the specified time period. If, at any time, Customer fails in whole or in
part to maintain the requested load reduction, Customer shall pay the following charges:
1. During interrupt periods called under Company's Interruptible Rate Rider, Customer
shall pay Company's identifiable additional cost for capacity and 150% of the Hourly
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-134-
256
Energy-
SOU?NWESTEIN PUitle SMILE
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -183
Revision No. 6
Page 6 of 6
TRANSMISSION QUALIFYING FACILITY
NON-FIRM STANDBY SERVICE
Clearing Price of the applicable regional wholesale energy market for energy for any
Standby Replacement Demand and Energy used by Customer, plus any charges or
penalties imposed by any governing entity that result from Customer's non-
compliance. In the absence of identifiable additional capacity cost, Customer shall pay
150% of the firm demand charge in accordance with the Transmission Qualifying
Facility Standby Service rate schedule for the amount of demand not interrupted during
the billing month.
2. If Customer fails to comply twice in any twelve month period, Customer shall pay the
same charges as just described, except that the demand charge shall be an amount equal
to the normal firm demand charge in accordance with the Transmission Qualifying
Facility Standby Service rate schedule for the amount of demand not interrupted during
the billing month, multiplied by a factor of twelve. Additionally, a second non-
compliance event during a Capacity Control interrupt period in any twelve month
period shall result in the Customer being removed from the Non -Firm Standby Service
tariff and Customer shall not be eligible to return to this tariff for one year.
X„,21
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-135-
X En -
SDUrMWISrERN PUBLIC SERYfCE
ELECTRIC TARIFF
257
Section No. IV
Sheet No. IV -184
Revision NoT6
Page 1 of 2
RESIDENTIAL SERVICE WITH ELECTRIC SPACE HEATING
APPLICABILITY: To residential Customers for electric service who predominately use electric space heating
in private residences for domestic purposes, and separately metered individual apartments, when all
service is supplied at one Point of Delivery and measured through one kWh meter, and facilities of
adequate capacity and suitable voltage are adjacent to the premises to be served. Single-phase motors
not to exceed 10 horsepower, individual capacity, may be served under this rate. Electric space heating
includes permanently installed space heating equipment in regular use, including heat pumps and
electric resistance heating, excluding bathroom heaters.
TERRITORY: Texas service territory.
RATE: Service Availability Charge Per Month: $7.60 per month.
Energy Charge: 0.076093 per kWh for all kWh used per month during each summer month
0.054686 per kWh for all kWh used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
WINTER MONTHS: The billing months of October through May.
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh of the above rate shall be
increased by the applicable fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This
rate schedule is subject to other applicable rate adjustments.
AVERAGE MONTHLY PAYMENT: Upon request, a residential Customer may be billed monthly on a
levelized payment plan. A Customer's monthly payment amount is calculated by obtaining the most
recent twelve months of actual consumption, dividing that amount by twelve, and applying Company's
current rates to the average kWh consumption. The account will be trued -up every twelve months. The
true -up amount will be the difference between the total prior twelve months' levelized payments and
the actual billings for the corresponding twelve month period.
CHARACTER OF SERVICE: A -C; 60 hertz; secondary voltage; single-phase 120/240 volts; where available,
three phase 240 volts.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension
policy.
I
1
X,4)
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-136-
258
1/0" Energy""
SOU RWUsrMe •u$LIC sett/CE
ELECTRIC TARIFF
Section No. 1V
Sheet No. IV -184
Revision No76
Page 2 of 2
RESIDENTIAL SERVICE WITH ELECTRIC SPACE HEATING
TERMS OF PAYMENT:
Net in 16 days after mailing date. If the sixteenth day falls on a holiday or weekend, the due date will
be the next work day.
RULES REGULATIONS AND CONDITIONS OF SERVICE:
Service supplied under this schedule is subject to the terms and conditions set forth in Company's
Rules, Regulations, and Conditions of Service on file with the Public Utility Commission of Texas. In
addition, Customer will provide Company with a signed affidavit indicating Customer is eligible for
service under this tariff.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-137-
id
&elEnergy-
SOUINVIEMIN PU$tIC SUIYSCF
ELECTRIC TARIFF
259
Section No. IV
Sheet No. IV -188
Revision No. 2
Page 1 of 2
RESIDENTIAL CONTROLLED AIR CONDITIONING
RIDER
AVAILABILITY:
Available to Residential Service customers with Company controlled central air conditioning
(including heat pumps).
Not available to customers that have an air conditioning system that significantly exceeds
summer cooling requirements, as determined by Company. Availability is restricted to air
conditioning units on which Company owned equipment can be installed, and that are located
within the operating range of Company's radio control transmitters.
This Rider shall be deemed to be modified to conform to any changes or revisions approved by
the Public Utility Commission of Texas, including the rate schedule's termination, as of the
date of the effectiveness of such change. Company reserves the right to request approval by the
Public Utility Commission of Texas for changes to, or termination of, this Rider at any time.
Upon termination of this Rider, the Agreement shall terminate.
CREDIT:
An Annual Credit of $50 per controlled air conditioner shall be applied to the customer's
October bill.
TERMS AND CONDITIONS OF SERVICE:
1. The duration and frequency of interruptions will be determined by the Company.
Customer air conditioners normally will be cycled on a schedule designed to achieve a
50 percent reduction in the building air conditioning requirements during a load
management period. Load management periods may occur at any time during the year;
however, they normally will occur on high demand days during summer months or
when, in Company's opinion, interruption will assist in meeting Company's peak
demand and system economic dispatch requirements, or the reliability of the
Company's system may be at risk. Interruptions normally will not occur during the
observation day of the following holidays: New Year's Day, Good Friday, Memorial
Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day. The
interruptions as described above may occur up to a maximum of 300 hours per calendar
year.
i
T
�d-
REGIONAL VICE PRESIDENT, REGULATORY
ADMINISTRATION
-138-
260
"0, . Energy '
SOUfNWESTUN POI tre $ERY1CF
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -188
Revision No. 2
Page 2 of 2
RESIDENTIAL CONTROLLED AIR CONDITIONING
RIDER
2. Customer must agree to Company load control for no less than one year.
3. If Company determines that its load management equipment on the customer's
premises has been rendered ineffective due to tampering by use of mechanical,
electrical, or other devices or actions, then Company may discontinue customer's
participation in the program. Company may bill customer for all expenses involved
with the removal, replacement or repair of the load management equipment and any
charges resulting from investigation of the device tampering. Company may re -bill all
prior load management credits received by customer to the date the tampering appears
to have first occurred or the previous twelve months, whichever is longer. A customer
removed from the program is only eligible to participate again at Company's discretion.
Company will verify installation has been corrected before the customer is permitted to
participate in the program.
MUTATION OF LIABILITY:
Customers who elect to take service under this Rider agree to indemnify and save harmless
Company from all claims or losses of any sort due to death or injury to person or property
resulting flout interruption of electric service, or from the operation of the interruption signal
and switching equipment.
REGIONAL VICE PRESIDENT, REGULATORY
ADMINISTRATION
-139-
/0,
XcelEnergy'
sourNWe$tERN PU$tSC $URvJCR
ELECTRIC TARIFF
261
Section No. IV
Sheet No. 1V-189
Revision No. 3 T
Page 1 of 2
COMMERCIAL AND INDUSTRIAL CONTROLLED AIR CONDITIONING RIDER
AVAILABILITY:
Available to non-residential Customers taking service under the Small General Service or
General Service tariffs. Availability is restricted to Customers with Company controlled
central air conditioning. Not available to Customers that have an air conditioning system that
significantly exceeds summer cooling requirements, as determined by Company. Availability
is restricted to single and/or dual stage air conditioning units of five tons or more cooling
capacity, on which Company owned equipment can be installed, and that is located within the
operating range of Company's radio control transmitters.
This Rider shall be deemed to be modified to conform to any changes or revisions approved by T
the Public Utility Commission of Texas, including the Rider's termination, as of the date of the
effectiveness of such change. Company reserves the right to request approval by the Public
Utility Commission of Texas for changes to, or termination of, this Rider at any time. T
CREDIT: An Annual Credit of $20 per ton shall be applied to Customer's October bill.
TERMS AND CONDITIONS OF SERVICE:
1. The duration and frequency of interruptions will be determined by Company. T
Customer's single and dual stage air conditioners normally will be cycled on a schedule
designed to achieve a 50 percent reduction in the building air conditioning
requirements during a load management period. Load management periods may occur
at any time during the year, however, normally load management periods will occur on T
high demand days during summer months or when, in Company's opinion, interruption
will assist in meeting Company's peak demand and system economic dispatch
requirements, or the reliability of Company's system may be at risk. Air conditioning
interruptions normally will not occur during the observation day of the following
holidays: New Year's Day, Good Friday, Memorial Day, Independence Day, Labor
Day, Thanksgiving Day, and Christmas Day. The interruptions described above may
occur up to a maximum of 300 hours per calendar year.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-140-
262
XCel Ererg y-
SOUtHIVESIE1lN PUILIC SEwv1Ct
ELECTRIC TARIFF
Section No. IV
Sheet No. IV -189
Revision No. 3 T
Page 2 of 2
COMMERCIAL AND INDUSTRIAL CONTROLLED AIR CONDITIONING RIDER
TERMS AND CONDITIONS OF SERVICE (Cont.):
2. Company will normally control every eligible air conditioning unit at Customer's
building. Subject to Company approval, Customers may exclude individual eligible air
conditioning units from Company control where those units serve either a sufficiently
isolated area within a building or a separate building.
3. Customer must agree to Company load control for no less than one year.
4, If Company determines that its load management equipment on Customer's premises
has been rendered ineffective due to tampering by use of mechanical, electrical, or
other devices or actions, then Company may discontinue Customer's participation in
the program. Company may bili Customer for all expenses involved with the removal,
replacement or repair of the load management equipment and any charges resulting
from the investigation of the device tampering. Company may rebill all prior load
management credits received by Customer to the date the tampering appears to have
first occurred, or the previous twelve months, whichever is longer. A Customer that is
removed from the program is only eligible to participate again at Company's
discretion, Company will verify installation has been corrected before Customer is
permitted to participate in the program.
LIMITATION OF LIABILITY:
Customers who elect to take service under this Rider shall agree to indemnify and save
harmless Company from all claims or losses of any sort due to death or injury to person or
property resulting from interruption of electric service, or from the operation of the interruption
signal and switching equipment.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-141-
Po/ Xeld
$G4 HHWIIU1N PVIIUUC s$1YICL
ELECTRIC TARIFF
263
Section No. IV
Sheet No. IV -199
Revision No32
Page 1 of 2
SERVICE AGREEMENT SUMMARY
AGREEMENT WITH: Amarillo Recycling Company
POINT OF SERVICE: Amarillo Recycling Company at Unit Shredder in Amarillo, Texas
APPLICABILITY: Customer agrees to operate its car crushing operations during off-peak hours. Peak hours
are defined as 12 p.m. to 8 p.m. weekdays during the summer months of June through September.
If Customer's demand exceeds 300 kW during peak hours, this service agreement will be suspended,
and Customer will be billed under the applicable Primary General Service rate, which does not permit
Rule of 80 demand billing discussed under the DEMAND section below, for the remaining Summed
Months of the calendar year.
N
RATE: Service Availability Charge: $26.76 per month
Energy Charge: $0.005651 per kWh for all kWh used during the month
Demand Charge:
$15.95 per kW of demand used per month during each summer month
$12.97 per kW of demand used per month during each winter month
SUMMER MONTHS: The billing months of June through September.
I
WINTER MONTHS: The billing months of October through May.
DEMAND: Company will furnish, at Company's expense, the necessary metering equipment to measure the
customer's kW demand for the 30 -minute period of greatest use during the month. In no month in
which Customer controls load to a maximum of 300 kW during peak hours, discussed in the
APPLICABILITY section above, shall the billing demand be greater than the kW value determined b)l
dividing the kWh sales for the billing period by 80 hours. N
POWER FACTOR ADJUSTMENT: Company may install power factor metering for Customers with
demand exceeding 200 kW. Bilis will be increased $0.54 for each kvar by which the reactive demand
exceeds 0.33 times the measured kW demand, and will be reduced $0.54 for each kvar by which th4
reactive demand is less than 0.33 times the measured kW demand. R
X.J
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-142-
264
Xl Enerrgy-
SOUTHWISMN rU,L1C sUUVIsa
ELECTRIC TARIFF
Section No. IV
Sheet No. 1V-199
Revision lam. 2
Page 2 of 2
SERVICE AGREEMENT SUMMARY
FUEL COST RECOVERY AND ADJUSTMENTS: The charge per kWh shall be increased by the applicable
fuel cost recovery factor per kWh as provided in PUCT Sheet IV -69. This rate schedule is subject to
other applicable rate adjustments.
CHARACTER OF SERVICE: A -C; 60 hertz; three phase, at one available standard primary voltage.
LINE EXTENSIONS: Company will make line extensions in accordance with its standard line extension policy.
TERMS OF PAYMENT: Net in 16 days after mailing date; 5 percent added to bill after 16 days. If the
sixteenth day falls on a holiday or weekend, the due date will be the next work day.
RULES, REGULATIONS AND CONDITIONS OF SERVICE: Service supplied under this schedule is
subject to the terms and conditions set forth in Company's Rules, Regulations and Conditions of Service
on file with the Public Utility Commission of Texas.
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-143-
)1celEnergy-
SOUTOWESTIIIN tUJLSC $!NICE
ELECTRIC TARIFF
265
Section No. W
Sheet No. IV -203
Original
Page 1 of I
N
DISCOUNT FOR VETERANS SEVERELY BURNED IN COMBAT
APPLICABILITY: To any Residential customer who suffered a burn injury in combat as a
member of the United States military. Burn injury, as it pertains to this tariff, is as
defined in SB 981, 83`4 Legislative Regular Session, Bill Payment Assistance Program
for Veterans Severely Burned in Combat. This rate is available only as a rate discount to
Residential customers in conjunction with a Customer's applicable standard Residential
rate schedule currently in effect.
TERRITORY: Texas service territory.
MONTHLY BASE RATE DISCOUNT: A discount of 20% will be applied to all charges
during the months of June, July, August, and September applicable to a veteran taking
electrical service under a standard Residential rate schedule currently in effect.
TERMS AND CONDITIONS: Company's Rules and Regulations apply to service under this
schedule.
N
X„..0
REGIONAL VICE PRESIDENT RATES AND
REGULATORY AFFAIRS
-144-
266
EXHIBIT C-1
Southwestern Public Service Company
Transmission Cost Recovery Factor - Baseline
Line
No.
Description
TCRF
Baseline
1 Invested Capital
2 Total Transmission Gross Plant in Service 612,7I6,224
3 Accumulated Depreciation (145,112,927)
4 Accumulated Deferred Income Taxes (105,673,432)
5
6 Net Plant in Service 361,929,865
7
8 Total Transmission Invested Capital 361.929 865
9
10 Authorized Rate of Return on Invested Capital 8.06%
11
12 Return on Invested Capital 29,171,547
13
14 Depreciation Expense 14,925,331
I5
16 Property Tax 4,785,749
17
18 Income Tax Expense
19 Earnings 29,171,547
2.0 Weighted Cost of Debt 2.83%
21 Synchronized Interest 10,242,615
22 Pet mane it and Flow -Through Differences 289,931
23 Federal Taxable Income 19,218,863
24 Federal Tax Rate 35.00%
25 Federal Income Tax Expense 6,726,602
26 Impact of Production Tax Deduction 0
27 Subtotal Income Tax Expense 6,726,602
28 Income Tax Gross Up Factor 1.538462
29 Income Tax Expense 10,348,619
30
31 Revenue Credits (23,498,694)
32
33 Total Investment Related Costs - "revreqt" 35,732,552
34
-146-
267
268
35 Approved Transmission Charges
36
37 RTO Administrative Fees
38 SPP Schedule la - 561,4 2,178,657
39 SPP Schedule la - 561.8 - Total SPS 1,575,187
40 RETAIL -TRAM Allocaha 73.48%
41 SPP Schedule la- 561,8 -Texas Jurisdiction 1,157,412
42
43 Total RTO Administrative Fees 3,336,069
44
45 Wholesale Transmission Charges
46 Schedule 9 Tri County
47 Schedule 11
48 Schedule 12
49 Non -RTO Wholesale Transmission
50 Total Wholesale Transmission Charges
51
52 Total Approved Transmission Charges - "ATC"
53
54 Total TCR' Baseline Costs
1,274,061
36,153,544
1,054,096
4,326,850
42,808,551
46,144,620
81,877,171
Allocators Texas Jurisdiction
1 Transmission Demand
2 12CP-TRAN
3
4 Production Demand
45.74%
5 12CP-PROD 49.61%
6
7 Retail Transmission Demand
8 RETAIL-TRAN
9
10 Transmission Plant in Service
1I PIS-TRAN
12
13 Net Plant in Service
14 PIS -NET 53.65%
15
16 Direct Assigned
17 TX 100.00%
18 NM 0.00%
19 WETS 0.00%
20
21
73.48%
46.54%
-147-
22
23
24 Transmission System (Functional)
25 TRAN
26
27 Transmission Radial Lines (Functional)
28 TRAM RL
29
30 Transmission Interconnection (Functional)
31 TRAN IN
32
33 Plant in Service Transmission (Functional)
34 PLTSVGTRAN
35
36 Plant in Service Net (Functional)
37 PLTSVC-N
Transmission Transmission Radial
Interconnection System Lines
0.000% 100.000% 0.000%
0.000% 0.000% 100.000%
100.000% 0.000% 0.000%
2.040% 90.665% 7.296%
0.645% 28.672% 2.307%
-148-
269
270
EXHIBIT C-2
-149-
Southwestern Public Service Company
Transmission Cost Recovery Factor - Cost Allocation
Line
No. Rate ALLOC
1
2 Residential Service 40.972%
3
4 Small General Service 3.237%
5
6 Secondary General Service 21559%
7
8 Primary General Service 3.520%
9
10 Large General Service - Transmission:
11 69 kV 4.303%
12 115 kV+ 20.344%
13
14 Small Municipal and School Service 0.227%
15
16 Large Municipal Service 1.643%
17
18 Large School Service 2.195%
19
20 Street and Area Lighting 0.000%
21
22 Total 100.000%
-150-
271
272
EXHIBIT D
"0" Xeek
t Energy"
sOUTKWEtt1IN +mitt stavItt
ELECTRIC TARIFF
273
Section No. IV
Sheet No. IV -69
Revision No. 42
Page 1 of 1
FUEL COST RECOVERY FACTOR
Application of fuel cost recovery factors are as follows:
SECONDARY DISTRIBUTION FUEL COST RECOVERY FACTOR:
The Secondary Distribution fuel cost recovery factor to be billed is 3.4414¢ per kilowatt-hour for the
months of June -September and 3.2663¢ per kilowatt-hour for the months of October -May and shall
apply when service is metered at less than approximately 2.4 kV.
PRIMARY DISTRIBUTION FUEL COST RECOVERY FACTOR:
The Primary Distribution fuel cost recovery factor to be billed is 3.3771¢ per kilowatt-hour for the
months of June -September and 3.2052¢ per kilowatt-hour for the months of October- May and shall
apply when service is metered at greater than or equal to approximately 2.4 kV and less than
approximately 69 kV.
SUB -TRANSMISSION FUEL COST RECOVERY FACTOR:
The Sub -transmission fuel cost recovery factor to be billed is 3.1732¢ per kilowatt-hour for the months
of June -September and 3.0117¢ per kilowatt-hour for the months of October -May and shall apply when
service is metered at greater than or equal to approximately 69 kV and leas than approximately 115 kV
or loss compensated meters are used to include losses to the sub -transmission.
BACKBONE -TRANSMISSION FUEL COST RECOVERY FACTOR:
The Backbone transmission fuel cost recovery factor to be billed is 3.1494¢ per kilowatt-hour for the
months of June -September and 2.9891¢ per kilowatt-hour for the months of October -May and shall
apply when service is metered at greater than or equal to approximately 115 kV or loss compensated
meters are used to include losses to the backbone transmission.
Evan D. Evans
REGIONAL VICE PRESIDENT, RATES AND
REGULATORY AFFAIRS
-152-
274
EXHIBIT E
-153-
Page 1 of 2
Rates
Attachment 1
• Residential Service
• Residential Space Heating Service
• Small General Service
• Secondary General Service
• Primary General Service
• Large General Service Transmission 69 to 115 kV
• Large General Service Backbone Transmission 115 kV+
• Small Municipal and School Service
• Large Municipal Service
• Large School Service
• Guard Lighting and Flood Lighting Service
• Municipal and State Street Lighting Service
Service Agreement Summary Tariffs
• Service Agreement Summary 4 (SAS -4) — commercial and
industrial customer served at primary voltage
• Service Agreement Summary 8 (SAS -8) — commercial and
industrial customer served at primary voltage
• Service Agreement Summary 12 (SAS -12) — commercial and
industrial customer served at transmission voltage
• Service Agreement Summary 13 (SAS -13) — commercial and
industrial customer served at primary voltage
• Service Agreement — Lighting: WRB Refining L.P., Bishop Hills
Property Owners, Chase Bank, Texas State Park Board (Palo Duro
Canyon)
• Service Agreement — Lighting: Cal Farley's Boys Ranch
• Service Agreement — Highway Sign Lighting
-154-
275
276
Standby Service Tariffs
• Secondary QF Standby Service
• Primary QF Standby Service
• Transmission QF Standby Service 69 to 115 kV
• Backbone Transmission QF Standby Service 115 kV+
Page2of2
-155-