TXX-4998, Forwards Response to Reg Guide 9.3 Re Antitrust OL Review
| ML20209D053 | |
| Person / Time | |
|---|---|
| Site: | Comanche Peak  |
| Issue date: | 09/02/1986 |
| From: | Counsil W TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC) |
| To: | Funches J Office of Nuclear Reactor Regulation |
| References | |
| CON-#190-9849, RTR-REGGD-09.003, RTR-REGGD-9.003 A, TX-4998, TXX-4998, NUDOCS 8609090176 | |
| Download: ML20209D053 (51) | |
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Log # TXX-4998 File #
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10020 10047 clo TEXAS UTILITIES GENERATING COMPANY MKYW AY TOWER. 400 N(>RTH OLIVE STREET. L.H. 81. DALLAS. TEXAS 78301 September 2, 1986 EO*E&?2?.7&K Mr. Jesse L. Funches, Director Planning and Program Analysis Staff Office Of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D.C.
20555
SUBJECT:
COMANCHE PEAK STEAM ELECTRIC STATION (CPSES) UNITS 1 AND 2 DOCKET NOS. 50-445A AND 50-446A ANTITRUST OPERATING LICENSE REVIEW RESPONSE TO REGULATORY GUIDE 9.3 REF:
1.
Jesse L. Funches letter to William G. Counsil dated May 19, 1986.
2.
W.G. Counsil letter to Jesse L. Funches dated July 11, 1986.
Dear Mr. Funches:
Enclosed is Texas Utilities Electric Company's (TVEC) response to Regulatory Guide 9.3, which updates TUEC's changed activity since the September 15, 1980 antitrust settlement, as requested in reference 1.
~
This response is not intended to replace our original submittal.
It provides additional information on TUEC's changed activity since September 15, 1980, and is for both the Unit 1 and Unit 2 dockets.
Per the Regulatory Guide, five copies of our response are provided in the enclosure.
The minority owners (Brazos Electric Power Cooperative, Inc., Texas Municipal Power Agency, and Tex-La Electric Cooperative of Texas) have informed us that they will file their responses directly with the NRC.
If there are any further questions, please contact Mr. G. S. Keeley at (214) 979-8831.
Very truly yours,
&fL,
W. G. Counsil d
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Enclosure (original + 5 copies)
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UNITED STATES OF AMERICA NUCLEAR REGULATORY COMMISSION In the Matter of
)
)
TEXAS UTILITIES GENERATING COMPANY
)
Docket Nos. 50-445 a division of TEXAS UTILITIES ELECTRIC COMPANY
)
50-446
)
(Comanche Peak Steam Electric Station, Units 1 and 2)
)
INFORMATION FOR ANTITRUST REVIEW OF OPERATING LICENSE APPLICATION Set forth below is information to update the original response to Regulatory Guide 9.3 for consideration by the NRC Regulator:r Staff in connection with its antitrust review of operating license applications for nuclear power plants.
The responses follow the numbering of the Regulatory Guide.
The terms Texas Utilities Electric Company (TUEC) and Company are used in the responses to refer to the Applicant even though activities referenced which occurred prior to January 1,
1984 were undertaken by either Texas Power & Light Company (TP&L) or Texas Electric Service Company (TESCO).
These latter two companies along with Dallas Power & Light Company (DP&L) and portions of Texas Utilities Generating Company (TUGCO) and Texas Utilities Services Inc.
(TUSI) were merged on January 1,
1984 l
to form TUEC.
i i
September 2, 1986 l
I i
l l
I l
3 COMANCHE PEAK' OPERATING LICENSE 5NTITRUST REVIEW--REGULATORY GUIDE 9.3 B.l.a Anticipated excess or shortage in generating capacity resources not expected at the construction permit stage.
Reasons for the excess or shortage along with data on how the excess will be allocated, distributed, or otherwise utilized or how the shortage
-will be obtained.
The Company does not anticipate either excess or shortage of capacity.
TUEC has stated that Comanche Peak Unit 1 will not be ready for commercial operation prior to peak load in the summer of 1988 and that it is making
-other arrangements to obtain additional power supplies for such time.
B.l.b.
New power pools or coordinating groups. or changes in structure, activities,
- policies, practices, or membership of power pools or coordinating groups in which the licensee was, is, or will be a participant.-
There have been no such new power pools or coordinating groups since September 15, 1980.
At that time TUEC was a member of the Texas Interconnected System (TIS) and the Electric Reliability Council of Texas (ERCOT).
On September 4,
1981, the activities of TIS were consolidated with ERCOT activities and TIS ceased to function.
There were no i
[
material changes in policies and practices as a
result i
of the consolidation.
ERCGT membership by type of system i
is shown below on September 15, 1980, and at June 13, 1986:
1 l
1 i
g..
j Type of System Sept.-15, 1980 June 13, 1986 Municipal 26 20 Cooperative 49 48 Investor-Owned 8
6 State Agency 1
1 84 75 The number-of investor-owned systems decreased from.
8 to 6 on January 1,
1984, with the merger of DP&L, TESCO and TP&L into TUEC.
B.l.c.
Changes in transmission with respect to (1) the-nuclear plant, (2) interconnections, or (3) connections to wholesale customers.
(1)
No changes have been made in planned. transmission with respect to Comanche Peak with the exception of scheduling changes made in response to changed plant operating dates and in response to local conditions.
The conductor for the second circuit on the existing Comanche Peak-Benbrook 345 kv line will be installed prior to Comanche Peak Unit 2 operation.
The Comanche Peak-Comanche Switch 345 kv line,- originally scheduled to be completed after j
both Comanche Peak units were in service, will be completed i
in the fall of 1986.
Completion of this line, which will be jointly owned by TUEC and Brazos Electric Power 4
Cooperative, Inc.
(BEPC),
will support service quality for customers of both systems in the Stephenville-Brownwood area.
I i
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v-2 (2)
There have been no changes in transmission with respect to interconnections, other than additional interconnections to systems with which TUEC already maintained interconnections.
(3)
There have been no changes in transmission with respect to connections to wholesale customers, other than the addition of points of delivery to existing wholesale customers from the transmission system.
B.l.d.
Changes in the ownership or contractual allocation of the output of the nuclear facility.
Reasons and basis for such changes should be included.
Changes in undivided ownership shares and contractual allocation of output under the Joint Ownership Agreement are as follows:
Status of Change of Change of Change of Party 9/15/80 12/9/80 5/26/82 1/1/84 Dallas Power & Light 18 1/3%
18 1/3%
18 1/3%
0 Company Texas Power & Light 35 5/6%
31 1/2%
33 2/3%
0 Company Texas Electric Service 35 5/6%
35 5/6%
35 5/6%
0 Company Texas Utilities 0
0 0
87 5/6%
Electric Company Texas Municipal Power 6.2%
6.2%
6.2%
6.2%
Agency i
Brazos Electric Power 3.8%
3.8%
3.8%
3.8%
Cooperative Tex-La Electric Cooper-0 4 1/3%
2 1/6%
2 1/6%
ative of Texas The May 26, 1982, t'ransfer of a 2 1/6 percent ownership interest by Tex-La Electric Cooperative of Texa s, - Inc.
(Tex-La) to TP&L was occasioned by the inability of Tex-La to obtain permanent financing for its full prior purchase
't
' of a 4 1/3 percent interest and by TP&L's willingness to repurchase the 2 1/6 percent interest.
The rights and obligations of all the owners of Comanche Peak under the Joint Ownership Agreement are in litigation in suits pending before the 14th Judicial District Court of Dallas County, Texas, the 98th Judicial District Court of Travis County, Texas and the 345th Judicial District Court of Travis County, Texas.
4 B.l.e.
Changes in design, provisions, or conditions of rate schedules and reason for such changes.
Rate increases or decreases are not necessary.
The following responses are based on the understanding that the information requested pertains to wholesale rate schedules.
Prior to January 1,
- 1984, general rate change j
applications were separately filed by DP&L, TESCO and TP&L.
Only TP&L and TESCO served wholesale customers.
Following the formation of
- TUEC, all rate change applications have been filed by TUEC on a composite basis as required by the Public Utility Commission of Texas (PUC).
TESCO Rate Changes Prior to Merger There have been two rate changes subsequent to the 1980 filing of data for the Antitrust Review.
In October,
- 1980, the PUC approved new wholesale rates for TESCO customers.
Prior to this change TESCO had a single wholesale rate consisting of the traditional
- customer, demand and energy components, including a high-voltage credit, a 60 4
-.v
,e
_~-
't a
. minute demand period and provisions for use of conjunctive billing demand for customers with multiple points of delivery.
The new rates were of_the same general structure;
- however, three separate rates were established, one for each basic wholesale customer
- type, i.'e.,
cooperatives, investor-owned utilities and municipalities.
The only change in the basic rate structure was elimination of the conjunctive billing procedure.
New wholesale rates were again approved in December, 1983.
The primary change in basic format was the reduction of the 60 minute demand interval to 15 minutes consistent with the 15 minute interval applied to all other demand rates.
TP&L Rate Changes Prior-to Merger The basic format of TP&L wholesale rates was unchanged by rates that became effective in August,
- 1981, and in July, 1982.
The rate structures then in effect consisted of one rate for public utilities and municipalities and a second rate for cooperatives.
Both rates had traditional
- customer, demand and energy components, including a
30 minute demand interval, a credit for 'high-voltage service and provisions for conjunctive billing demand for customers with multiple points of delivery.
The cooperative rate had summer-winter differentials.
't~
> TUEC Rate Changes In November,
- 1984, the PUC approved a new wholesale rate for TUEC which continues in effect.
This single rate for. all wholesale customers utilizes the TESCO structure including the 15 minute demand interval.
The single rate replaced the three separate rates in effect at TESCO and the two separate rates in effect at TP&L.
All changes = in design, provisions or conditions of rate schedules have been approved by the PUC after adjudicatory hearings following the filing of applications for general rate increases by TUEC.
B.l.f.
List.of all (1) new whole' sale customers, (2) transfers' from one rate schedule to
- another, including copies of schedules-not previously furnished,
-(3) changes in licensee's service area, and (4) licensee's acquisitions or mergers.
(1)
There have been no new wholesale customers; however, points of delivery to existing wholesale customers have occasionally been added or deleted.
(2)
There have been no transfers from one schedule to another except where multiple rates were condensed to one
- rate, or one rate was expanded to multiple rates.
Copies of wholesale rate schedules not previously furnished are attached.
(3)
There have been no changes in TUEC's service area except:
- t
' (a.)
In 1981, the PUC certified TUEC to serve a new structure for an existing customer in an area certified to the City of Weatherford.
(b.)
In
- 1982, the PUC made minor corrections to-the service area boundary between TUEC and Tri-County Electric Cooperative, Inc.
in Denton County.
(c.)
In
- 1983, corrections were made in the boundary between TUEC and Pedernales Electric Cooperative, Inc. in Bell County.
(d.)
In
- 1985, the PUC established singly certificated service. areas for the City of Garland which did not materially change the area being served by TUEC.
(e.)
In 1986, TUEC sold its facilities in the City of Seymour to the City.
(4)
There have been no acquisitions or mergers other than the merger of DP&L, TESCO and TP&L into TUEC as earlier described.
i B.1.g List of those generating capacity additions committed for operation after the nuclear
- facility, including ownership rights or power output allocations.
Following is a
list of future generating
- capacity, other than the Comanche Peak nuclear facilities, certified by the PUC and announced by TUEC:
't s
' Year Unit (s)
TUEC OWNERSHIP,MW Fuel 1988 Combustion Turbines 190 Gas / Oil 1990 Combustion Turbines 770 Gas / Oil 1991 Twin Oak 1 750 Lignite 1992 Twin Oak 2 750 Lignite 1993 Forest Grove 1 750 Lignite 1994 Martin Lake 4 750 Lignite B.l.h Summary of requests or indications of interest by other electric power wholesale or retail distributors, and licensee's
- response, for any type of electric service or cooperative venture or study.
The following relates activities for the period September 19,
- 1980, to the present with respect to North Texas Entities.
The responses are presented under the following headings:
Municipalities, Cooperatives and Power
- Agencies, Investor-Owned and other Utilities, and Communication Related to DC Asynchronous Connections.
In addition to tha specific responses set forth below, verbal indications of interest may have been received from time to time from others;
- however, the Company has not declined to address the issues or to provide service or to enter into cooperative ventures or studies with any such entities.
These responses do not include discussions and agreements with others resulting from the normal process of business operations and communications.
's"
, Municipalities Bowie In March,
- 1986, the mayor of th'e City of Bowie, a
total requirements wholesale customer of
- TUEC, contacted the Company regarding power supply alternatives.
Included in the alternatives proposed were joint construction of generation and wholesale purchases from other suppliers as well as TUEC.
In addition to the above alternatives, the City had previously been exploring and continues to
' evaluate purchase of TUEC's substation in order to qualify for high voltage service credit.
TUEC has provided cost estimates and other information to support the City's evaluation and decision process.
Discussions are ongoing.
Bridgeport w
In 1983, the City of Bridgaport, a total requirements wholesale customer of TUEC, entered into discussion with the Company regarding sale of City electric facilities to TUEC.
TUEC supplied information and studies requested by the City and offered to supply further information if desired.
No further inquiries have been received to date.
Brownsville In August, 1986, TUEC 'and the Public Utilities Board of the City of Brownsville reached agreement whereby TUEC will provide wheeling service for the output from the City's ownership in the Oklaunion Steam Electric Station.
l l
's o Denton On September 29,
- 1980, TUEC declined an invitation from the mayor of Denton to submit a proposal for purchase of the Denton Municipal Electric System.
The City was and continues to be served principally under a long term power purchase contract with Texas Municipal Power Agency (TMPA).
Electra In
- 1983, the City of
- Electra, which is partially served by TUEC at retail and partly by the City from a wholesale source, inquired as to the willingness of TUEC to supply wholesale power requirements beginning in 1988.
The Company indicated that it was not seeking new loads because of the excessive incremental costs associated with adding new capacity, and that if new capacity were added for such purpose, all such costs would have to be recovered in any arrangement with the City in order to avoid increasing costs to existing TUEC customers.
TUEC subsquently supplied information in response to the request and in response to the City's inquiry regarding the possible sale by TUEC to the city of its facilities or purchase by TUEC of City facilities.
Information furnished has satisfied all requests to date.
Granbury By letter of February 25, 1983, the mayor of Granbury made inquiry concerning possible TUEC interest in purchasing
'e
, and operating the power distribution system of the City of-
- Granbury, presently served from BEPC.
TUEC representatives provided information needed to support the City's evaluation.
No further inquiries have been received.
Greenville The City of Greenville, a member of TMPA, appointed a
committee of-business leaders to ~ evaluate power and electric service options for the City.
A TUEC representative inet with the commission-in 1984 at its request to answer inquiries and to offer any information the City might require in.
its evaluation.
No further information has been requested.
Seymour In 1986, TUEC sold its faciliti'es in the City of Seymour to the City.
The sale was the result of the City's exploration of several options to achieve a single source of power supply - for its citizens.
Prior to the sale part of the City was served at retail by TUEC with the remainder served at retail from City-owned distribution facilities served from the BEPC system.
Vernon By notice dated November-13,
- 1983, proposals were solicited from those parties interested in purchasing the electric plant / distribution system of the City of Vernon.
Response was required by December 1,
1983.
TUEC elected not to respond.
I
_nv,-
w--,
-v-M
Weatherford The City of Weatherford, served by BEPC, has made inquiries of TUEC's interest in supplying wholesale electric service.
As an alternate, the City also inquired as to the possibility of joint participation in future generating unit construction.
With regard to wholesale supply, the Company indicated that it was not seeking new loads because of the excessive incremental costs associated with adding new capacity, and that if new capacity were added for such purpose, all such costs would have to be recovered in any arrangement with the City in order to avoid increasing costs to existing TUEC customers.
TUEC supplied cost information relative to wholesale supply.
With respect to prospects for future joint generating unit construction, the Company provided Weatherford representatives relevant cost information needed by the City to evaluate the economics of participating in a future power plant.-
In August, 1983, the City indicated it had no further interest in participating in a future power plant.
'Whitesboro In 1981, the City of Whitesboro expressed a desire to explore selling or leasing its municipally owned system.
The City provides retail service from a BEPC supply.
A TUEC representative met with city representatives, supplied preliminary information and offered any other information the City might need for its evaluation.
No further information has been requested to date.
l'
, Cooperatives and Power Agencies Brazos Electric Power Cooperative, Inc.
(1)
During the years 1980-1983, the Company analyzed a
proposed joint venture with BEPC to construct the 800 MW Village Bend Pumped Storage Facility.
This facility was scheduled. to become operational in the 1990 time-frame.
In 1983, the-determination was made that the project was not the least cost alternative for TUEC.
(2)
In the first half of 1981, a cooperative joint study was undertaken by TUEC and BEPC relative to joint ownership of TUEC's planned Monument Draw coal plant-Subsequent to the time joint study was undertaken, load growth uncertainties caused the project to be delayed beyond the time of interest to BEPC.
(3)
By letter of June 16,
- 1986, BEPC expressed concern that paragraph 20 of the Joint Ownership Agreement for Comanche Peak Steam Electric Station' restricted its ability to transmit power and eneqy in interstate commerce.
The Company has assured BEPC in writing that no such limitation exists and has specifically waived any contractual provisions inconsistent with License Conditions for Comanche Peak.
Cap Rock Electric Cooperative, Inc.
In 1980, the Company was contacted by representatives of Cap Rock, a wholesale customer of TUEC, for the purpose of exploring options of purchased power compared to jointly
{
owned generating facilities.
Cost information was furnished
~,,
t 8 Cap Rock representatives to aid in their comparative evaluations.
Cap Rock elected not to explore joint ownership of generation.
Midwest Electric Cooperative, Inc.
In 1984, Midwest Electric Cooperative, Inc., a wholesale customer of TUEC, elected to transfer a small portion of its load to Southwestern Public Service Company (SPS).
This action relieved load on a
TUEC source and thus eliminated a requirement for Midwest to make a contribution in aid of construction to upgrade TUEC facilities.
The company provided necessary support services to effect the transfer.
Rayburn Country Electric Cooperative, Inc.
(1)
In October, 1984, TUEC entered into a Scheduling Agent Agreement with Tex-La and Rayburn Country whereby TUEC will deliver energy and capacity purchased by Tex-La and Rayburn Country from the Southwestern Power Administration (SWPA).
TUEC provides the transmission system to link the generation from the hydroelectric units at Denison Dam (Lake Texoma) to the cooperatives' loads.
As Scheduling
- Agent, TUEC will seek to optimize electrical output from the facilities consistent with reservoir operations.
The Scheduling Agent Agreement is pursuant to the Power Sales Contract between SWPA and the cooperatives who are federally designated preference customers for the hydroelectric power.
e
, Subsequent to October, 1984, BEPC instituted litigation against SWPA in the United States District Court for the Western District of Texas, Waco Division, claiming, among other
- things, an interest in the power being allocated and sold to Tex-La and Rayburn Country from Denison and Whitney Dams.
Tex-La, Rayburn Country and TUEC intervened in that suit.
The suit was-dismissed by the court pursuant to defendant's motion for summary judgement and is now on appeal.
(2)
From time to time over the' past several
- years, discussions of alternate supply options have taken place between TUEC and Rayburn Country.
Rayburn Country is currently an all requirements wholesale customer of TUEC except for the SWPA power.
In recent months discussions have become more active.
TUEC understands that it is Rayburn Country's desire to obtain a
" master agreement",
under which it will explore and evaluate supply options.
These options would include power purchase from suppliers other than TUEC as well as ownership of generating capacity.
A draft of an agreement, which TUEC believes conforms to Rayburn Country's
" master agreement"
- concept, i.e.,
one that could serve as the
" umbrella" under which specific agreements could be negotiated in a consistent
- fashion, will be furnished to Rayburn Country in the near future.
(3)
By letter of July 16, 1986, Rayburn Country notified the Company of its intent to transfer approxima'tely one
. megawatt of demand from TUEC supply to Southwestern Electric Power Company (SWEPCO).
TUEC will make the necessary billing corrections and will provide other support necessary to effect the transfer.
Rio Grande Electric Cooperative, Inc.
In
- 1984, Rio Grande Cooperative, served by El Paso
- Electric, inquired as to the interest and capability of TUEC to serve approximately 20 MW of demand.
TU2C determined that because of limitations in both bulk supply and transmission facilities such service would impair service quality to existing customers and for this reason declined participation.
Texas Municipal Power Agency In
- April, 1985, TMPA inquired as to TUEC interest in supplying it power under long term purchase agreements or through participation in joint generating facility construction.
TMPA's expressed interest was for capacity needed by it in the early to mid-1990's.
The Company responded that its current resource plan did not include units to supply the needs expressed by TMPA, noting that TUEC's plans were to supplement its own capacity with firm power purchases to coincide as closely as possible to estimated load growth.
No further inquiries have been received from TMPA.
Tex-La Electric Cooperative of Texas (1)
In 1974, the company and Aluminum Company of America (Alcoa) entered into agreement to jointly construct and
. own Twin Oak Steam Electric Station.
The agreement provided for right of first refusal to either party should the other elect to sell its ownership share.
In 1983, the company agreed to purchase Alcoa's interest in the Twin Oak plant, then under construction in accordance with provision of the agreement.
In conjunction with the purchase, the Company sought to sell a portion of its ownership to a third party for a period of seven years.
At the end of this period, the Company had the option to repurchase the capacity.
Prior to completion of the Alcoa purchase by TUEC, Tex-La approached Alcoa to explore the possibility of purchasing an interest in the Twin Oak capacity which Alcoa had offered to TUEC under agreement provisions.
TUEC had need for the future capacity from the plant which would be lost in the event of a permanent sale to others.
It therefore exercised its rights under the agreement with Alcoa and purchased the Alcoa share of Twin Oak pursuant to an amendment to its Certificate of Convenience and Necessity granted by the PUC.
(2)
In October, 1984, TUEC entered into a Scheduling Agent Agreement to deliver SWPA power to Tex-La and Rayburn Country as described above under Rayburn Country Electric Cooperative, Inc.
(3)
In
- April, 1985, Tex-La requested consideration in joint purchasing of cogenerated energy.
In verbal discussion, TUEC held that there were no benefits to its customers from jointly contracting for cogenerated energy
. but-that it would support through the necessary agreements delivery to Tex-La of any cogenerated energy purchased by it, subject to conditions that all costs to TUEC be recovered and that quality of service to TUEC customers not be impaired.
i (4)
In March, 1986, Tex-La requested the Company to serve as scheduling agent for its purchase of economy energy pursuant to an agreement between itself and Houston Lighting Power Company (HL&P).
Extensive negotiations and discussions have taken place and Tex-La now is evaluating a draft of a scheduling agency agreement.
(5)
By letter dated May 20,
- 1986, Tex-La asserted its right to jointly own a portion of the 960 MW of proposed combustion turbine capacity for which the Company had been granted a Certificate of Convenience and Necessity by the PUC.
Tex-La cited a May 6,
1980, letter of intent as the basis for its claim.
Tex-La's claimed entitlement to interest in generating capacity which TUEC plans to install in the future is now in litigation in suits pending before the 14th Judicial District Court of Dallas County, Texas and 98th Judicial District Court of TraOis County, Texas.
(6)
In
- 1986, Tex-La elected to permanently transfer a
portion of its load to points of delivery outside of TUEC, in this
- case, to SWEPCO.
Tex-La plans further such transactions in the future with expected aggregate load to be approximately 40 MW.
The Company has and will provide
-f a
_19_
necessary billing and operational support services to effect these changes.
Investor-Owned and Other Utilities Central Power & Light Company - West Texas Utilities Company In August, 1986, Central Power & Light and West Texas Utilities made inquiries of TUEC's interest in near term capacity and energy purchases from surplus ERCOT sources.
Specific data are being developed by these companies to serve as the basis for further discussion.
El Paso Electric Company In 1982, El Paso Electric Company planning personnel met with TUEC representatives to discuss long range i
possibilities for mutual cooperation.
Southwestern Public Service Company In 1985, Southwestern Public Service Company proposed the sale of capacity and energy to TUEC.
The proposed sale would be accomplished by connecting certain SPS generators to the TUEC system through transmission links to be constructed as a part of the sale transaction.
TUEC will continue to evaluate _this proposal in view of a resource plan
- review, currently being
- updated, and other supply alternatives.
Texas-New Mexico Power Company l
(1)
In 1981, Texas-New Mexico Power Company (TNP) expressed interest in exploring joint ownership in TUEC's planned Monument Draw coal plant.
TUEC furnished information needed for TNP analysis of such joint ownership.
TNP elected not to pursue the venture.
=.
- o e
(2)
In-1986, TUEC agreed in principle to provide needed i
-interconnections and wheeling services related to TNP's proposed Robertson County fluidized-bed power plant scheduled
=!.
for 1990 operation,, subject to PUC approval.
Discussions are or. going.
{
(3)
In 1986, TUEC'and TNP entered into a 20 year electric r
service agreement.
This " master agreement" is the " umbrella" under which specific agree;nent.s related to electric service can be negotiated-in a consistent fashion, i
. General During the.early 1980's, the Company participated j
with other utilities in studies and discussions relative to the providing of electric service for the proposed electrification of the MK&T Railroad ~ between Ft.
Worth i-s and Houston.
Utility coordination for this project was performed by the Lower Colorado River Authority.
The involved parties were willing to provide electrification service under appropriate conditions;
- however, overall the project proved aneconomical.
Communications Related to DC Asynchronous Connections The Federal Energy Regulatory Comniission (FERC) issued l
an
" Order Requiring Interconnection and-Wheeling, and i
i Approving Settlement" in Docket Nos.
EL 79-8 and E-9558, l
on October 28,
- 1981, as corrected by the Errata Notice 1
1 t
i
i s,s u e d N o v e m b e r 5,
1981, and its Order issued. January 29, 1932, requiring the construction of two high voltage direct current interconnections between ERCOT and the Southwest Power Pool.
To provide transmission service to, from and over the HVDC. interconnections, the operating companies which constituted TUEC, the Central and South West (CSW) operating companies and HL&P were ordered by the FERC to file tariffs that would comply with the above order.
On June 6,
1986, a ' Contested Offer of Settlement in Docket ER 82-545-000 et al concerning tariffs filed by CSW, HL&P and TUEC for transmission service to, from and over the HVDC interconnections was certified to the FERC..
The offer of settlement was contested only by the City of Brownsville.
Subsequently, Brownsville agreed with TUEC to withdraw its opposition to the Offer of Settlement in FERC Docket ER 82-545-000 et al and support approval of the now uncontested Offer of Settlement.
In a letter of April 23, 1986, CSW, on behalf of itself and HL&P, informed TUEC of their intent to propose an alternate location of the Southeast DC Interconnection ordered by the FERC in Docket EL 79-8.
The proposed East Tie would conform to all provisions of the original settlement agreement and orders in EL 79-8.
The letter solicited TUEC cooperation and offered responses to relevant TUEC questions.
Subsequently, CSW and HL&P filed an
. application in Docket EL 79-8 to construct the East DC Tie in lieu of the South DC Tie.
TUEC intervened in that proceeding and is presently discussing with CSW and HL&P the impact of the proposed East Tie on TUEC's system.
As a result of the CSW and HL&P application, TUEC has received inquiries from various entities in North Texas as well as the FERC staff with respect to the ownership and operation of the East Tie, the possible impact on TUEC's
- system, etc. Various meetings have been held, principally under the superv'ision of the FERC staff, to evaluate the impact of the proposed changes.
In June,
- 1986, CSW inquired as to the interest of TUEC in ownership of capacity that would be provided by a proposed expansion of the capability of the North DC 1
Tie.
TUEC will not at this time participate in-the expansion of the North Tie.
l
. B.2.
Licensees whose construction permits include conditions pertaining to antitrust aspects should list and discuss those actions or policies which have been implemented in accordance with such conditions.
The Company believes its practices are consistent with l
the License Conditions for Comanche Peak.
The following relates actions and/or policies in terms of License Conditions for Comanche Peak Units 1 and 2,
as set forth in Section 3.D of the Construction Permit.
3.D.(2)(a)
The Company afforded full opportunity i
to participate in the Comanche Peak Steam Electric Station l
and Joint Ownership Agreements were executed with
- BEPC, TMPA and Tex-La.
3.D.(2)(b)
- The Company supported the merger of TIS into ERCOT and has supported membership for all eligible entities.
The Company participates in periodic joint studies at the ERCOT level.
Included are studies necessary to support meeting ERCOT planning and operating criteria as determined by the Engineering and Operating Subcommittees of the ERCOT Technical Advisory Committee.
Additionally, the Company has provided studies and planning results to any entity requesting such information to evaluate power supply options (See B.1.h).
3.D.(2)(c)(d)(e)(f)
The Company's operations with respect to reserve requirements, the exchange of maintenance schedules and emergency service conforms to the ERCOT operating guidelines.
Such guidelines are consistent with all License Conditions.
P o
. l 3.D.(2)(g)(h)
The Company has established
. interconnections with others
.to achieve-mutual benefits and has not refused to interconnect with anyone.
3.D.(2)(i)
The Company participates in
" bulletin board" economy energy transactions within ERCOT and was a
participant in prior
" brokerage" transactions both as purchaser and seiler.
The Company has entered into wheeling agreements to permit power transfer across its system for the benefit of others and has executed agreements-with other
. utilities to have power wheeled from cogenerators and others.
These wheeling agreements are undertaken under: PUC approved tariffs or mutually agreed rates as permitted by the PUC.
Additionally, the company has filed temporary and permanent tariffs with FERC for wheeling energy to, from and over the North DC tie as ordered by FERC in Docket' EL 79-8 and carries out transactions under these tariffs in a non-discriminatory manner.
Further, the Company delivers SWPA power as scheduling agent to Rayburn Country and Tex-La and is negotiating a scheduling agent agreement to deliver economy energy to Tex-La from HL&P (See B.l.h).
~
3.D.(2)(j)(a)(b) - The Company plans bulk transmission supply in accordance with ERCOT guidelines and has not refused to plan or provide other transmission arrangements consistent with ERCOT and PUC guidelines under the criteria set forth in this section of the License Conditions.
, 3.D.(2)(k)
The Company has entered into numerous discussions where sale by the Company of bulk power to North Texas Entities with less than 200 MW of capacity was under consideration and has not refused to sell power to any such entity (See.B.l.h).
3.D.(2)(1)(a)(b)(c)(d)
- The Company is in compliance with all requirements.
3.D.(2)(m)
- The practice of the Company is to amend any contract language which may be inconsistent with paragraph 3.D.(2)(1)(a) and (b),
or, to waive any obligation under such contractual provision.
3.D.(2)(n) - Not applicable.
3.D.(2)(o)
The Company is in compliance with obligations related to FERC Docket EL79-8.
3.D.(2)(p)
The Company is in compliance with the requirements of this paragraph.
,ww-9 e e e s
~
WH0LESALE RATES l
l
Section No.
Sheet No.
lil-D 6
TARIFF TEXAS UTILITIES FOR ELECTRIC 00MPANY November 13. 1984 ELECTRIC SERVICE
(
Revision Page Original 1 of 2 Section Title Tariff Name Applicable RATE WP OTHER WHOLESALE POWER APPLICATION Applicable to electric service provided to pubile utilities, municipalltles, and to rural electric distribution cooperatives for resale to ultimate consumers in the State of Texas. Service at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, supplementary, maintenance, or shared service.
TYPE OF SERVICE Three phase, 60 hertz, at the most available primary distribution or transmission voltage. Where service of the quantitv and type required by Customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its belnq fur-r i sh ed, if Customer takes service at transmission voltage, Company may at its option meter serv-Ice on the secondary side of Customer's transformers and adjust for transformer losses in accordance with Company's Tariff for Electric Service.
MONTHLY RATE k
Customer Charge: $240.00 per point of delivery Demand Charge: $ 6.33 per kW of demand
$1.00 per kW for each current month kW In excess of the contract kW Energy Charge:
0.52F per kWh all kWh fransmission Service Credit: $1.35 per kW of demand when service Is provided at 69,000 volts or higher.
Fuel Cost Plus an amount for fuel cost calculated in accordance with Rider FC.
Payment: Bills are due when rendered and are past due if not paid within 16 days thereaf ter.
Bills are increased 35 If not paid within 20 days af ter being rendered.
DEMAND DETERMINATION Demend for calculation of the monthly bill is the largest of:
- 1) the highest 15-minute kW recorded during the current month;
- 2) 805 of the on-peat kW;
- 3) 505 of the contract kW;
- 4) 50$ of the highest 15-minute kW recorded at the point of delivery In the 12 month period ended with the current month.
\\
Section No.
Sheet No.
lil-D 6
TW FF TEXAS UTILITIES Effective Date ELECTRIC (XWANY November 13, 1984 ELECTRIC SERVICE l
Revis ion Page Original 2 of 2 Section Title Tariff Nome Applicable RATE W OTHER
- Y WHOLESALE POWER I
DEFINITIONS On-peak kW is the highest 15-minute kW recorded during the billing months of June through September in the 12 month period ended with the current month. For a Customer contracting fcr new service, on-peak kW ls the oJrrent month kW until Customer establishes such demand through on-peak use, unless, in Company's sole judgment, suf ficient data exists for Company to estimate on-peak kW until Customer establishes on-peak history through actual use.
Contract kW ls the maximum kW specified in the Agreement for Electric Service.
Current month kW is the highest 15-minute kW recorded during current month.
AGREEMENT An Agreement for Electric Service with a term of not less then three years is required.
NOTICE
(
Service hereunder is subject to the orders of regulatory bodles having jurisdletion and to the Company's Tarif f for Electric Service.
I i
GCCTIEN N S, SNEET NO.
TARIFF III 52 TEXAS
" " ' * * * ^"
FOR EE.ECTRIC SERVICE December 28, H83
(
sannsr ELECTRIC SERVICE
,, E.,,, o M
.A.E spesii Fifth 1
2 o,
LLCTION TITLE TARIFF M AME A PPLIC A B LE Rate Schedules Rate W1 Entire System Resale (Cooperatives)
APPLICATION To electric service provided to rural electric cooperatives for resale to ultimate consumers in the State of Texas. Service at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF SERVICE Three phase, 60 hertz, and at 138 kv, or, at company's option, at 69 kv, or at the most available primary distribution voltage. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished. If customer takes service at transmission voltage, company may at its option meter service on the secondary side of customer's
,i transformers and adjust for transformer losses in accordance with company's tariff for electric service.
NET MONTHLY BILL Rate: $250.00 per point of delivery
$6.00 per kw of demand
$1.00 per kw for each current month kw in excess of the contract kw 0.544 per kwh all kwh Transmission Service Credit: $0.81 per kw of demand when service is provided at 69,000 volts or 138,000 volts.
Fuel Cost: Plus fuel cost in accordance with Rider F.
Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 3% if not paid within 20 days after being rendered.
SECTION NO.
SNE27 No.
TARIFF III s?
uni pon E n CTiv OAT =
ELECTRIC SERVICE
(
IINMII ELECTRIC SERVICE
"- - k=*
'S, 1083 navaslON PAGE SPe:
Fifth 9
o' 9
kCT80M TITLE TARIFF M AME APP LIC AIB LE Rate Schedules Rate W1 Entire System Resale (Cooperatives)
DEMAND DETERMINATION Current month kw is the highest 15-minute kw recorded during the current month.
On-cesk kw is the highest 15-minute kw recorded during t1e billing months of June through October in the 12 months ended with the current month. Company may esti-mate the on-peak kw for new custcmers and customers adding load when acceptable data exists until customer establishes en-peak history through actual use.
Contract kw is the maximum electrical load specified in the agreement for electric service.
Annual kw is the highest 15-minute kw recorded at the premises during the 12 months ended with the current month.
Kw of demand for calculation of the net monthly bill is:
{
1.
Current month kv.
2.
But not less than the largest of --
a.
75% of the on-peak kv.
b.
50% of the contract kw.
c.
50% of the annual kw.
AGREEMENT An agreement for electric service with a term of not less than three years is I
required.
NOTICE This established rate is subject to any change authorized by law and to the j
provisions of company's tariff for electric service.
1
G'CTI*,M MD.
CH3ET M 9.
TARIFF III 53 IEId8 LFFECTIVE DATE pg ELECTRIC SERVICE December 28, 1983 k
- Mar ELECTRIC SERVICE woe s e, Fifth 1
2 o,
SECT 80M TITLE TAREFF M AME A PP L4C A S LE Rate Schedules Rate W2 Entire System Ressle (TNP)
APPLICATION To electric service provided to Texas-New Mexico Power Company for resale to ultimate consumers in the State of Texas. Service at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF EERVICE Three phase, 60 hertz, and at 138 kv, or, at company's option, at 69 kv, or at the most available primary distribution voltage. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished. If customer takes service at transmission voltage, company may at its option meter service on the secondary side of customer's transforrers and adjust for transformer losses in accordance with company's tariff for electric service.
NET MCETHLY BILL Rate: $250.00 per point of delivery
$6.89 per kw of demand
$1.00 per kw for each current month kw in excess of the contract kw 0.544 per kwh all kwh Transmission Service Credit: $0.81 per kw of demand when service is provided at 69,000 volts or 138,000 volts.
Fuel Cost: Plus fuel cost in accordance with Rider F.
Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 3% if not paid within 20 days after being rendered.
SECTI2M NB.
CH'*CT NO.
TARIFF III 53 risss FOR
""'"'** ^
ELECTRIC SERVICE ELECTRIC SERVICE December 28. Ioat
- WAff nEvlsioM raoK Fifth 2 ** 2 kCTION TITLg T ARIFF M AME A PP LIC A S LE Rate Schedules Rate W2 Entire System Resale (TNP)
DEMAND DETERMINATION Current month kw is the highest 15-minute kw recorded during the current month.
On-oesk kw is the highest 15-minute kw recorded during the billing months of June through October in the 12 months ended with the current month. Company may esti-mate the on-peak kw for new customers and customers adding load when acceptable data exists until customer establishes on-peak history through actual use.
Contract kw is the maximum electrical load specified in the agreement for electric service.
Annual kw is the highest 15-minute kw recorded at the premises during the 12 months ended with the current month.
Kw of demand for calculation of the net monthly bill is:
i 1.
Current month kw.
2.
But not less than the largest of --
a.
75% of the on-peak kv.
b.
50% of the contract kv.
l c.
50% of the annual kw.
I AGREEMENT l
l An agreement for electric service with a term of not less than three years is required.
NOTICE l
l This established rate is subject to any change authcrized by law and to the provisions of company's tariff for electric service.
(
SECTl!N NB.
CH337 N 3.
TARIFF III 54
((Ed8 EFFECTIVE D ATE ELECTRIC SERV, gar ELECTRIC SERVICE
-December 28. 1983 REVISION PAGE Fifth 1 or 2 LCTION TITLE T ARIFF N AME A PP L8 C A S LE Rate Schedules Rate W3 Entire System Resale (B&G)
APPLICATION To electric service provided to cities of Bowie and Goldsmith for resale to ultimate consumers in the State of Texas. Service at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF SERVICE Three phase, 60 hertz, and at 138 kv, or, at company's option, at 69 kv, or at the most available primary distribution voltage. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished. If customer takes service at transmission voltage, company may at its option meter service on the secondary side of customer's transformers and adjust for transformer losses in accordance with company's tariff for electric service.
NET MONDILY BILL Rate: $250.00 per point of delivery
$8.06 per kw of demand
$1.00 per kw for each current month kw in excess of the contract kw 0.544 per kwh all kwh i
Transmission Service Credit: $0.81 per kw of demand when service is provided at 69,000 volts or 138,000 volts.
l Fuel Cost: Plus fuel cost in accordance with Rider F.
Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 3% if not paid within 20 days after being rendered.
l l
l C
SECTIEN M D.
CH3*T M 9.
TARIFF III 54
((Ed8 EFFECTIVE DATE pg ELECTRIC SERVICE December 28. 1983
(
- N#Afy ELECTRIC SERVICE SF...
Fifth 2
2 SECTION TITLE TAMIFF M AME APP LIC A B LE Rate Schedules Rate W3 Entire System Resale (B&G)
DEMAND DETERMINATION Current month kw is the highest 15-minute kw recorded during the current month.
On-oeak kw is the highest 15-minute kw recorded 'during the billing months of June through October in the 12 months ended with the current month. Company may esti-mate the on-peak kw for new customers and customers adding load when acceptable data exists until customer establishes on-peak history through actual use.
Contreet kw is the maximum electrical load specified in the agreement for electric service.
Annusi kw is the highest 15-minute kw recorded at the premises during the 12 months ended with the current month.
Kw of demand for calculation of the net monthly bill is:
I 1.
Curren't month kw.
2.
But not less than the largest of --
a.
75% of the on-peak kv.
b.
50% of the contract kw.
c.
50% of the annual kv.
AGREEMENT An agreement for electric service with a term of not less than three years is required.
NOTICE This established rate is subject to any change authorized by law and to the provisions of company's tariff for electric service.
(
. Ens:= m3
.M 2:na.
hy,,,,,
52 TARIFF
,,,,c
- TFEA, FOR october 14, 1980 ELECTRIC SERV,Ig,,
ELECTRIC SERVICE t
Fourth 1
3 4EGYlOM T4TLE TARIFF MAME A PPL8 C A B LE Rate Schedules Rate W1 Outside City Limits of Resale (Cooperatives)
Entire System APPLICATION To electric service provided to rural electric cooperatives for resale to ultimate consumers in the State of Texas. Service at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF SERVICE Single or three phase, 60 hertz, and at any one of company's standard primary voltages. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished.
If customer takes service at transmission voltage, company may at its option meter service on the secondary side of customer's transformers and adjust for k
transformer losses in accordance with company's service regulations.
NET MONTHLY BILL Rate: $195.00 per point of delivery
$5.89 per kw of demand
$1.00 per kw for each current month maximum kw in excess of the maximum electrical load specified in the j
agreement for electric service l
0.37c per kwh all kwh Transmission Service Credit: 20c per kw of demand when service is provided at 69,000 volts or 138,000 volts.
Fuel Cost: Plus fuel cost in accordance with Rider F.
l Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 37, if not paid within 20 days af ter being rendered.
(
l l
e SEITION 2C.
SM207 M B.
EFFECT VE DATE
(
d[
RI SERVg),
I 0ctober 14, 1980 ELECTRIC SERVICE Fourth 2
3
.o 0,
SECT 80M TITLE TARIFF MAME A PPLIC A S LE Rate Schedules Rate W1 Outside City Limits of Resale (Cooperatives)
Entire System DEMAND The current month maxim e kw, providc.d, however, that for customers having not less than one full month of on-peak kw history the kw thus determined may not exceed the se of the maximum on peak kw plus 30% of the amount by which the current month maximum kw exceeds the maximum on-peak kw; but not less than 80% of the maximtzn on-peak kw; nor, during the initial 12 months of service following connection of the point of delivery, less than 50% of the contract kw.
Current month maximum kw is the kw recorded during the 60-minute period of maximum use during the current month.
Maximum on-peak kw is the highest kw recorded at the premises during the billing months of June, July, August, September or October in the 12 months ending with the current month.
4 Contract kw is the greater of (a) the maximum electrical load specified in the agreement for electric service, or (b) the kw recorded at the premises during the 60-minute period of maximum use at any time during the 12 months ending with the current month.
TIME OF DAY OPTION At customer's option and af ter completion of necessary contractual ar-rangements and after installation of necessary metering equipment, the maximum on-peak kw as used above will be based upon the highest kw recorded during com-pany's peak hours. Peak hours are defined as the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> between 10 as and 10 pm each week day (Monday through Friday) excluding July 4 and labor Day dur-ing the billing months of June through October. An additional monthly charge of $30.00 is made when customer selects the time of day option.
For customers having no maximum on-peak kw history, company will estimate the maximtsn on-pe ak kw to be used as a billing factor and include such estimate in the agreement for electric service.
AGREEMEhT An agreement for electric service with a term of not less than three years is required.
S811T0003 MO.
"M 21T M D.
EPPE TIVE DATE
's YLECTRIC7SERVIEE
[,*,
ELECTRI SERVICE esEner Fourth 3,
3 SPeein SECTION TITLE TAR 6PP MAME APPLIC A S LE Rate Schedules Rate W1 Outside City Limits of Resale (Cooperatives)
Entire System NOTICE This established rate is subject to any change authorized by law, appli-cable charges in Rate H (Miscellaneous Service Qtarges), and to the provisions of company's service regulations.
(
?
.. :,. m c.
.2,...
I 53 TARIFF
,,,,,,f,1,,,,,
I d
,,,,,,$,ther14,1980 t,
g SERVICE ELECTRI SERVICE 80m!HY Fourth 1,
3
.ECTION 78764 TARIFF MAME APPb4 C ASLE Rate Schedules Rate W2 Outside City Limits of Resale (CPS)
Entire System APPLICATION To alectric service provided to Community Public Service Company for resale to ultimate consumers in the State of Texas. Service at each point of delivery is me.tered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF SERVICE Single or three phase, 60 hertz, and at any one of company's standard primary voltages. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished.
If customer takes service at transmission voltage, company may at its option g
meter service on the secondary side of customer's trensformers and adjust for transformer losses in accordance with company's service regulations.
NET MONTHLY BILL Rate: $195.00 per point of delivery
$6.47 per kw of demand
$1.00 per kw for each current month maximun kw in excess i
of the maximum electrical load specified in the agreement for electric service 0.37c per kwh all kwh i
Transmission Service Credit: 20c per kw of demand when service is provided at 69,000 volts or 138,000 volts.
Fuel Cost Plus fuel cost in accordance with Rider F.
i l
Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 3% if not paid within 20 days after being rendered.
(
SE3T80N Q@.
" M 3" ? M D.
III 53 TARIFF
,,,,c,,,,
TEXAa FOR October 14, 1980 ELECTRIC SERVIg###I E
ELECTRIC SERVICE Fourth 2
3 SPeets OF SFCTION TITLE T ARIFF M Atet APS L8 CABLE Rate Schedules Rate W2 Outside City Limits of Fesale (CPS)
Entire System I
DEMAND The current month maxistaa kw, provided, however, that for customers having not less than one full month of on-peak kw history the kw thus determined may not exceed the sum of the n;aximum on peak kw plus 30% of the amount by which the current month maximum kw exceeds the maximum on-peak kw; but not less than 80% of the maximum on-peak kw; nor, during the initial 12 months of service following connection of the point of delivery, less than 50% of the contract kw.
Current month maximum kw is the kw recorded during the 60-minute period of maximum use during the current month.
Maximum on-peak kw is the highest kw recorded at the premises during the billing months of June, July, Angust. September or October in the 12 months ending with the current month.
i Contract kw is the greater of (a) the maxistan electrical load specified in the agreement for electric service, or (b) the kw recorded at the premises during the 60-minute period of maximum use at any time during the 12 months ending with the current month.
TIME OF DAY OPTION At customer's option and after completion of necessary contractual ar-rangemer.ts and after installation of necessary metering equipment, the maximum l
on-peak kw as used above will be based upon the highest kw recorded during com-i pany's peak hours. Peak hours are defined as the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> between 10 am and I
10 pm each week day (Monday through Friday) excluding July 4 and Labor Day dur-ing the billing months of June through October. An additional monthly charge of $30.00 is made when customer selects the time of day option.
For customers having no maxistan on peak kw history, company will estimate the maximtun on-pe ak i
kw to be used as a billing factor and include such estimate in the agreement for electric service.
AGREEMENT An agreement for electric service with a term of not 1< ass than three years is required.
\\
{
e SE3780M MO.
iM3*T M S.
III 53 TARIFF TuAs FOR October 14, 1980 t.
ELECTRIC SERVI"E ELECTRIC SERVICE se1nur Fourth 3,, 3 S.S.,,
SEC780M TITLE TARIFF M AME A PPblC A B LE Rate Schedules Rate W2 Outside City Limits of Resale (CPS)
Entire System NOTICE This established rate is subject to any change authorized by law, appli-cable charges in Rate M (Miscellaneous Service Qiarges), and to the provisions of company's service regulations.
(
l I
l l
l l
l
- s2 tion me.
.=::t co.
III 54 TARIFF TEJAs FOR October 14, 1980 ELECTRIC SERVIPE ELECTRIC SERVICE scher Fourth 1,,
3
.P....
.tCTION TITLE TARIFF MAME A PP LIC A 3 65 Rate Schedules Rate W3 Outside City Limits of Resale (B & G)
Entire System APPLICATION To electric service provided to cities of Bowie and Goldsmith for resale to ultimate consumers in the State of Texas. Servica at each point of delivery is metered and billed separately.
Not applicable to temporary, standby, or shared service.
TYPE OF SERVICE Single or three phase, 60 hertz, and at any one of company's standard primary voltages. Where service of the quantity and type required by customer is not already available at the location to be served, additional charges and contract arrangements may be required prior to its being furnished.
If customer tskes service at transmission voltage, company may at its option 4
meter service on the secondary side of customer's transformers and adjust for transformer losses in accordance with company's service regulations.
NET MONTHLY BILL Rate:
$195.00 per point of delivery
$7.05 per kw of demand
$1.00 per kw for each current month maximum kw in excess l
of the maximum electrical load specified in the l
agreetnent for electric service 0.37c per kwh all kwh Transmission Service Credit: 20c per kw of demand when service is provided at 69,000 volts or 138,000 volts.
Fuel Cost: Plus fuel cost in accordance with Rider F.
Payment: Bills are due when rendered and are past due if not paid within 15 days thereafter. Bills are increased 3% if not paid within 20 days after being rendered.
(
e 521?sO 3 n3.
IM3CT8;S.
III 54 TARIFF
~
FOR October 14, 1980 FEEAs
_ SERVIgFAff ELECTRIC E
ELECTRIC SERVICE Fourth 2
3 spee,e or SECTION TITb8 TARlPP MAME APPLIC A 368 Rate Schedules Rate W3 Outside City Limits of Resale (B & G)
Entire System DDiAND The current month maximum kw, provided, however, that for customers having not less than one full month of on peak kw history the kw thus determined may not exceed the sum of the maximum on-peak kw plus 30% of the amount by which the current month maximum kw exceeds the maximum on-peak kw; but not less than 80% of the maximum on-peak kw; nor, during the initial 12 months of service following connection of the point of delivery, less than 50% of the contract kw.
Current month maximum kw is the kw recorded during the 60-minute period of asximum use during the current month.
Maximum on peak kw is the highest kw recorded at the premises during the billing months of June, July, August, September or October in the 12 months ending with the current month.
Contract kw is the greater of (a) the maximum electrical load specified in y
the agreement for electric service, or (b) the kw recorded at the premises during the 60-minute period of maximum use at any time during the 12 months ending with the current month, i
TIME OF DAY OPTION 1
At customer's option and after completion of nec'essary contrc:tual ar-rangements and after installation of necessary metering equipment, the maximum on peak kw as used above will be based upon the highest kw recorded during com-pany's peak hours. Peak hours are defined as the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> between 10 an and 10 pm each week day (Monday through Friday) excluding July 4 and Labor Day dur-ing the billing months of June through October. An additional monthly charge of $30.00 is made when customer selecta tha time of day option.
For customers having no maximum on-peak kw history, company will estimate the maximum on peak kw to be used as a billing factor sud include such estimate in the agreement for electric service.
ACREDiENT An agreement for electric service with a term of not less than three years is required.
l l
l l
e "0379G?3 MO.
CH337M3 III 54 TARIFF
'b ECTRIC7SERVgE
- er 14, 1980 ELECTRI SERVICE p,,,
Fourth 3,, 3 LECTION TITLE TAR 6FF MAME A PPLIC A S LE Rate Schedules Itate W3 Outside City Limits of Resale (B & G)
Entire System NOTICE This established rate is subject to any change authorized by law, appli-cable charges in Rate M (Miscellaneous Service Charges), and to the provisions of company's service regulations.
r l
l ('
ITEM:
WHOLESALE POWER TO RURAL Section No.
Ill-E ELECTRIC DISTRIBUTION COOPERATIVES SCHEDULE REA Sheet No-3
(-
July 1,1982 Effective Date APPLICABLE:
Revision Fifth ALL AREAS p.g, 1
of 1
AVAILABILITY Available in the territory in which the Company operates to Rural Electric Distribution Cooperatives for resale at retail.
MONTHLY RATE Billing Months of May-October Billing Months of November-April
$335.00 per Point of Delivery
$335.00 per Point of Delivery 8.99 per kw of Billing Demand, plus 5.36 per kw of Billing Demand, plus 0.43c per kwh 0.43C per kwh Transmission Service Credit If Customer takes service at a point of delivery at any available standard voltage of g
69,000 volts or higher, a credit equal to $1.10 per Kw of Demand will be allowed on that portion of the Billing Demand attributable to such point of delivery.
Plus a charge per Kwh of energy taken for fuel cost calculated in accordance with Schedule FCF.
The maximum demand shall be the average number of kilowatts supplied dur:ng the 30-minute period of maximum use at each point of delivery, except as to distribution cooperatives having multiple points of delivery whose maximum demand shall be the highest sum of such 30-minute maximum demands for the month at each point of delivery to such Cooperative; provided, that if at any point of delivery of Company to Cooperative hereunder, the power factor should be less than 85 percent lagging during said 30-411nute period of maximum use, the maximum demand for such point of delivery shall be the average number of kilowatts supplied during such period multiplied by 85 percent and divided by the actual power factor in percent during such priod.
The billing demand shall be the maximum demand so determined, provided that in no event shall such billing demand be less than 65% of the highest maximum demand similarly determined during the billing months of June, July, August, September, or October in the 12 months ending with the current month.
h TEXAS POWER & LIGHT COMPANY
'* O e
ITEM:
WHOLESALE POWER FOR RESALE Section No, III E SCHEDULE WP-500 Sheet No.
2
[.
Effective Date July 1,1982 APPLICABLE:
Revision Fifth ALL AREAS Page 1
Of 2
APPLICATION To all electric service supplied to public utilities and municipalities for resale' where Customer contracts to purchase its entire power and energy requirements and where such service is supplied at one point of delivery and measured by one meter, except as noted below.
Not applicable to temporary, standby or supplemental service.
^
MONTHLY RATE
$550.00 customer charge 7.82 per kw all kw of Demand, plus 0.43C per kwh Trarsmission Service Credit If Customer takes service at a point of delivery at any available standard voltage of s
69,000 volts or higher, a credit of $1.26 per kw will be allowed on that portion of the billing Demand attributable to such point of delivery.
Plus a charge per kwh of energy taken for fuel cost calculated in accordance with Schedule FCF.
bETERMINATION OF DEMAND I
l The maximum 30-minute average kw supplied during the current month, but not less than 65% of the maximum kw similarly deter ed during the billing months of June, July, August, September, or October in the 12 months en ng with the current month, nor less than 500 kw.
MULTIPLE POINTS OF DELIVERY Company, at its option, will supply electric service to an interconnected system at more than one Point of Delivery. In such event, the simultaneous readings of the meters at the Points of Delivery will be used in determining the Demand, and there will be added to the " Monthly Rate" a charge of $550.00 for each point of delivery in excess of one plus the aforesaid charges for Demand shall be increased by 1.3%
1 b TEX AS POWI'R & LIGHT COMPANY
ITEM:
WHOLESALE POWER FOR RESALE Section No.
Ill-E SCHEDULE WP-300 Sheet No.
2
('
July 1,1982 Effective Date APPLICABLE:
Revision Fifth ALL AREAS p,
of 2
2 TYPE OF SERVICE Company will supply three-phase, 60 cycle, alternating current at any available standard voltage of 12,470 volts, or higher, as stated in the Agreement for Service. Metering will be at the delivery voltage, or, if otherwise, be compensated for transformer losses.
PAYMENT Bills for Electric Service will be rendered monthly and are due when rendered, and become delinquent if not paid within 15 days from the date of the bill.
CONTRACT PERIOD As provided for in the Agreement for Service.
(:
4 O
k
(
TEXAS POWER & LIGHT COMPANY
....',8-81 ITEM:
WHOLESALE POWER FOR RESALE III-E Section No.
((.
SCHEDULE WP-500 2
Sheet No-Effective Date See Sec.1. Sheet 2 APPLICA8LE:
Revision Fourth i
ALL AREAS 1
Of 2 p,
APPLICATION To all electric service supplied to public utilities and municipalities for resale where Customer contracts to purchase its entire power and energy requirements and where such service is supplied at one point of delivery and measured by one meter, except as noted below.
Not applicable to temporary, breakdown, standby or supplemental service.
MONTHLY RATE
$425.00 customer charge 6.85 per kw all kw of Demand, plus 0.41c per kwh C
Transmission Service Credit if Customer takes service at a point of delivery at any available standard voltage of 69,000 volts or higher, a credit of $1.17 per kw will be allowed on that portion of the billing Demand attributable to such point of delivery.
Plus a charge per kwh of energy taken for fuel cost calculated in accordance with Schedule FCF.
DETERMINATION OF DEM AND The maximum 30-minute average kw supplied during the current month, but not less than 70% of the maximum kw similarly determined during the billing months of June, July, August, September, or October in the 12 months ending with the current month, nor less than 500 kw.
MULTIPLE POINTS OF DELIVERY Company, at its option, will supply electric service to an interconnected system at more than one Point of Delivery. In such event, the simultaneous re. dings of the meters at the Points of Delivery will be used in determining the Demand, and there will be added to the " Monthly Rate" a charge of $425.00 for each point of delivery in excess of one plus the aforesaid charges for Demand shall be increased by 1.3%
TYPE OF SERVICE r-Company will supply three-phase, 60 cycle, alternating current at any available standard voltage of 12,470 volts, or higher, as stated in the Agreement for Service. Metering will be at the delivery voltage, or, if otherwise, be compensated for transformer l<
sseh1SLl0 UTILITY COMMISSION O AFT' ROVED G 24'01 r-eTco g TEXAS POWER & LIGHT COMPAN FILE.
I
~
. :-s!
'.... e ITEM:
WHOLESALE POWER FOR RESALE Section No.
III F SCHEDULE WP-M Sheet No.
2
\\
Effective Date See Sec. I, Sheet 2 APPLICABLE:
Fourth Rev..ision All Areas 2
p Of PAYMENT Bills for Electric Service will be rendered monthly and are due when rendered, and become '6elinquent if not paid within 15 days from the date of the bill.
CONTR ACT PERIOD As pavided for in the Agreement for Service.
r PUBLIC UTILITY COMP.!!SSION OF TEXAS APPROVED
-(
A3 24'81 occm e 8780 FILE.
.....BY.
TARIFF CLERK TEXAS POWER & LIGHT COMPANY
T
]
8-81 ITEM:
UHOLESALE POWER TO RURAL Ill-E ELECTRIC DISTRIBUTION COOPERATIVES
- t. ion No.
3 i
f SCHEDULE REA Sheet No.
Effective Date APPLICABLE:
Revision Fourth ALL AREAS p.g.
I of I AVAILABILITY Available in the territory in which the Company operates to Rural Electric Distribution Cooperatives for resale at retall.
MONTHLY RATE
$185.00 per Point of Delivery 6.15 per kw of Billing Demand, plus 0.42c per kwh Transmission Service Credit If Customer takes service at a point of delivery at any available standard voltage of 69,000 volts or higher, a credit equal to $0.94 per Kw of Demand will be allowed on that f
portion of the Billing Demand attributable to such point of delivery.
Plus a charge per Kwh of energy taken for fuel cost calculated in accordance with Schedule FCF.
The maximum demand shall be the average number of kilowatts supplied during the 30-minute period of maximum use at each point of delivery, except as to distribution cooperatives having multiple points of delivery whose maximum demand shall be the highest sum of such 30-minute maximum demands for the month at each point of delivery to such Cooperative; provided, that if at any point of delivery of Company to Cooperative hereunder, the power factor should be less than 85 percent lagging during said 30-minute period of maximum use, the maximum demand for such point of delivery shall be the average number of kilowatts supplied during such period multiplied by 85 percent and divided by the actual power factor in percent during such period.
l The billing demand shall be the maximum demand so determined, provided that in no event i
i shall such billing demand be less than 70% of the highest maximum demand similarly determined during the billing months of June, July, August, September, or October in the 12 months ending with the current month.
PUS $ UI. f..
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CF U;:A:,
Af rd.0\\ CD M 24'Ol LD;.,u L! 6J h.
s nu...............n.
TARIFF CLERK TEXAS POWER & LIGHT COMPANY
_