MIME-Version: 1.0 Content-Type: multipart/related; boundary="----=_NextPart_01CA889D.FF004050" This document is a Single File Web Page, also known as a Web Archive file. If you are seeing this message, your browser or editor doesn't support Web Archive files. Please download a browser that supports Web Archive, such as Windows® Internet Explorer®. ------=_NextPart_01CA889D.FF004050 Content-Location: file:///C:/F2E9C639/Businesspractice12-28-2009.htm Content-Transfer-Encoding: quoted-printable Content-Type: text/html; charset="us-ascii" CUS Current Business Practices (MLC3087.DOC;1)

 

 

 

 

Black Hills Power, Inc= .

Basin Electric Power Cooperative and Powder River Energy Corporation

 

Common Use System Transmission

CURRENT BUSINESS PRACT= ICES

Last Updat= e on: 12/29/2009<= o:p>

=  

 

Busin= ess Practices Revision Table

(Changes= to the business rules for this revision period are indicated in Red<= /b>)

Revision Date

Revision

12/29/200= 9

Updated AC Transmission Rates effective 01/01/2010

10/27/2009

Corrected typo in Schedule 2 Table<= o:p>

09/30/2009

Updated AC Transmission Rates as a result of FERC approval of Basin Electric Rate Filing

08/26/2009

Modified Schedule 2 Rates effective 09/01/2009

07/14/2009

Updated AC Transmission Rates as a = result of Basin Electric Settlement Agreement

07/06/2009

Modified Schedule 2 Rates

3/18/2009

Added submission of redispatch cost= s

02/27/2009

Updated Ancillary Service rates

01/08/2009

Updated Transmission Rates/Prices effective 12/01/2008 & 01/01/2009

12/29/2008

Updated Transmission Rates/Prices effective 1/1/2009

12/05/2008

Added RCDC Rate Table and note under General Information regarding transactions involving both the AC and DC systems.

02/01/2= 008

Updated Transmission Rates/Prices

02/01/2= 007

Updated Transmission Rates/Prices

05/28/2006

Update of Transmission Rates/Prices=

12/01/2005

New Transmi= ssion Rates and Prices

9/30/2005

New Transmi= ssion Rates and Prices

6/1/2005

New Transmi= ssion Rates and Prices

5/21/2004

New Transmi= ssion Rates and Prices

4/1/2004

Revised Ter= ms of Service Tables

 <= /o:p>

GENERAL INFORMATION

The Common Use System (“CUS”) consists of transmission facilities owned and operated = by Black Hills Power, Inc., Basin Electric Power Cooperative, and Powder River Energy Corporation (each “Transmission Provider”, collectively = “Transmission Providers”) in the south western area of South Dakota and the north eastern portion of Wyoming. Black Hills Power is the administrator of the CUS Joint Open-Access Transmission Tariff (“Joint Tariff”).  The owners of= the CUS have entered into an agreement with Western Area Power Administration, Rocky Mountain Region, which operates the WACM Control Area, to act as their designated agent for posting Available Transmission Capacity (“ATC”) and administering the OASIS.  WACM will process requests for short-term transmission service on the CUS and Black= Hills, as tariff administrator, will process requests for long-term transmission service.  The following are the Current Business Practices and timing requirements developed by WACM for administering the Joint Tariff.  This document provides requirements for the transmission reservation= and energy scheduling processes.  Capitalized terms have the meanings set out in the Joint Tariff.

Transactions that incl= ude service on both the AC and DC systems require a separate Transmission Servi= ce Reservation for each system.

 

ACCEPTANCE= OF OASIS REQUESTS

OASIS requests will be pr= ocessed in accordance with the ATC at the time the request is submitted. The methodology for determining ATC is stated in Attachment C to the Joint Tari= ff.

 

ACCEPTABLE QUANTITY OF REQUESTS

The submission of numerous duplicative requests to secure a single reservation seriously degrades the performance of multiple systems and negatively affects all transmission customers.  Therefore, the fol= lowing business practices will be STRICTLY adhered to and there will be = NO exceptions:

= ·   =     Multiple Transmission Requests= : WACM will deem EIGHT (8) or more requests for the same posted path submitte= d by the same customer within any ONE (1) clock hour to be an abuse of the system.  If the same customer submits EIGHT (8) or more of these requests within any ONE (1) clock hour, = all of those requests will be refused.  Requests include any request that is submitted, regardless of the st= ate that request may be in or become.<= u>

= ·   =     Monthly Non-firm Requests:= For the first twelve (12) hours of the request timing window (00:00:00 to 12:00= :00, 60 calendar days prior to the start of service), only ONE (1) request per posted path will be allowed per clock hour.  Multiple requests for service subm= itted during this time frame will result in ALL requests for the abused cl= ock hour being refused.  This prac= tice only applies to the first 12 hours of the request timing window.  After the 12 hours have passed, the practice of 8 requests, as stated above, will apply.  Requests include any request that = is submitted, regardless of the state that request may be in or become.

= ·   =     Confirmation: Pre-confirmed requests are optional.

SCHEDULING= PATHS

= ·   =     Transaction schedules must be tagged from the same POR/POD combination as identified in= the confirmed OASIS reservation.

·         Transaction schedules that do not match POR/= POD as identified in OASIS will not be allowed and the E-tag will be denied.

 

 

CHARGES AND CREDITS DURING OUTAGES/CURTAILMENTS AND INTERRUPTIONS

 

Non-Firm Point-to-Point Transmission Service:

= ·   =     Credit will be provided to the customer for all interruptions of service to accommodate higher-priority transmission service.  No credit will be provided for any Curtailment of transmission service.

 

Firm Point-to-Point Transmission Service and Network Transmission Service:

= ·   =     Credit will be provided for conditional firm point-to-point transmission service t= hat is displaced by higher priority service.

= ·   =     No credit will be provided for any Curtailment of transmission service.

Redirect:

  • Redirect will be available only= on firm reservations.  Reque= sts for firm redirects will be categorized based on the term of service.  Requests for non-firm redirec= ts shall be submitted as Secondary Hourly from Alternate POR/POD.

 

TRANSMISSION LOSSES ON THE CUS

      The Joint Tariff requires that Transmission Customers provide the losses associ= ated with their transmission service.  All energy transfers are subject to the factors set forth in Attachm= ent J of the Joint Tariff.  Schedu= led losses can be delivered to any POR on the CUS upon mutual agreement between= the transmission customer and Joint Tariff Administrator.

·<= span style=3D'font:7.0pt "Times New Roman"'>      =    Th= is arrangement must be set up in a pre-schedule by submitting a separate tag f= or the loss repayment.  The origi= nal wheeling transaction tag must reference the loss tag in the comments and the loss tag must reference the original wheeling tag in the comments.

·<= span style=3D'font:7.0pt "Times New Roman"'>      =    Lo= sses for all pre-scheduled transactions shall be submitted using one E-tag for losses for all aggregated losses for the pre-scheduled day.  The profile shall be in whole MW (rounding based on .49 and lower rounded down and .50 and higher rounded up) based on the cumulative MW’s for the day being scheduled for the on-p= eak and off-peak periods.

 

Losses for the path across the Rapid City DC Tie:

·         RCWEST to RCEAST, or, RCEAST to RCWEST   Losses =3D 1.50 %.

 

Losses = for any other path on the CUS:

·         Losses for schedules from any POR to any POD= on the CUS are 1.33%.

·         For schedules that flow over both Rapid City= DC Tie and other parts of the CUS, the loss rate will be 2.83% (sum of 1.50% f= or the DC Tie and 1.33% for the AC Transmission portion of the CUS).

·         The losses schedule should be coordinated wi= th pre-scheduling or real time staff at Black Hills Power, Rapid City, South Dakota, as specified above.

 

HOURLY NON= -FIRM REQUESTS

= ·   =     To maximize transmission availability, ATC for Hourly Non-Firm capacity is calculated hourly.

= ·   =     Requests for Hourly Non-Firm reservations must be submitted via the OASIS and in accordance with the timing requirements listed in the table below.

· =       All reservations must be requested through the OASIS node.  Telecopied, recorded telephone and emailed requests and confirmations will be permitted within the posted timing requirements should the WACM OAS= IS node become inoperative.  Tele= phoned requests must be confirmed by telecopy or e-mail.  No exceptions to the OASIS posting requirements will be allowed for operational problems originating at the customer’s site.

= ·   =     Some Real-Time Hourly requests may be refused for insufficient ATC based on syst= em conditions despite OASIS postings showing that ATC is available.

= ·   =     At no time will a request be accepted when the ATC posted as available is at z= ero, regardless of system conditions.

 

ENERGY SCHEDULES

= ·   =     Per WECC business practices, an approved transaction tag must accompany = all pre-scheduled non-real-time energy transactions.  If there is no valid tag, the schedule will not be implemented.

= ·   =     Tags for real-time energy transactions shall be submitted in accordance with NER= C Interchange Standards.

 

MONTHLY NON-FIRM TRANSMISSION REQUESTS

= ·   =     Requests for Monthly Non-Firm reservations may be requested for one month, which is the maximum term for non-firm transmission.

= ·   =     Customers= may submit requests for more than one month of Monthly Non-Firm Point-to-Point Transmission Service, provided that they comply with the requirement that no request be submitted more than 60 days prior to the commencement of service.  Howe= ver, a separate request must be submitted for each month of service.

 

FIRM TRANS= MISSION REQUESTS

All requests for Firm Transmission Service must be made through the OASIS.  Telecopied, recorded telephone and em= ailed requests and confirmations will be permitted within the posted timing requi= rements should the WACM OASIS node become inoperative.  Telephoned requests must be confir= med by telecopy or e-mail.  No except= ions to the OASIS posting requirements will be allowed for operational problems originating at the customer’s site.

The Transmission Provider= s of the CUS have entered into an agreement with Western Area Power Administration, Rocky Mountain Region, to act as their designated agent for posting ATC and administering the OASIS.  Unde= r this agreement, WACM will process all requests for short-term transmission servi= ce requests on the CUS and the Joint Tariff Administrator will process all requests for long-term transmission service.

= ·   =     For a valid request for Daily, Weekly or Monthly Firm Transmission Service for which ATC is available on the CUS, a response will be made by WACM to the requestor within the time limits listed below in the “Terms of Service” table.

= ·   =     All Long= -Term Firm Transmission requests must contain a written Complete Applicati= on, as defined in Section 17.1 & 17.2 of the Joint Tariff, must be received at least sixty days in advance of the calendar month in which service is to commence.  A request for service received in = less than 60 days will be considered when feasible, pursuant to Section 17.1 of = the Joint Tariff.

 

The Completed Application= must be sent to:

FERC Tariff and Compliance Manage= r

Black Hills Power, Inc.

P.O. Box 1400

Rapid City= , SD&nbs= p; 57709

 

The Transmission Service Application form can be down loaded from BHBE OASIS web site, http://www.oa= tioasis.com

= ·   =     All Long-Term Firm Transmission requests will initially be placed in STUDY mode= and will be reviewed by the Joint Tariff Administrator.  System Impact and Facilities Studi= es are typically needed to determine transmission availability for long term reque= sts.

  • If there is sufficient system capability to accommodate the transmission request without the need to do a System Impact Study, the Joint Tariff Administrator will tender a Long Term Firm Service Agreement to the Transmission Customer.  O= nce the Service Agreement is duly executed, the Joint Tariff Administrator will enter ACCEPTED as the status of the OASIS transmission request.
  • If a System Impact Study needs to be conducted to assess the transmission system capability to provide the requested service, then the Joint Tar= iff Administrator will tender a System Impact Study Agreement.
  • If a Facilities Study is required as a result of the System Impact Study, then the Joint Tariff Administrator will tender a Facilities Study Agr= eement to the Transmission Customer.

 

ROLLOVER RIGHTS<= /u>

Any existing Long-Term Fi= rm Transmission Customer that wishes to exercise its reservation priority to r= oll over its transmission service for a new term must make an application for i= ts new service term following the Jo= int Tariff procedures. Notification to exercise a rollover right for Long-Term Firm Transmission under Section 2.2 of the Joint Tariff must be received by the Transmission Provider no less than one year prior to the date the existing Long-term contract ends. Long Term ATC posting on paths associated with rollov= er rights will be posted based on the assumption that the existing customers w= ill not exercise their rollover rights, but the Transmission Provider will not grant any competing request until it determines whether the Transmission Customer will exercise its rollover rights.

 

 

TRANSMISSI= ON RATE

 

The posted charges for transmission service on the Common Use System are calculated from the annual transmission revenue requirements= of Black Hills Power, Inc., Basin Electric Power Cooperative, and Powder River Energy Corporation.

 

 

&nbs= p;

AC TRANSMISSION SYSTEM

RAPID CITY CONVERTER TIE=

Product

Firm Serv= ice

Non-Firm = Service

Firm Serv= ice

Non-Firm = Service

Yearly ($/kW year)

29.75

NA

23.52

NA

Monthly ($/kW month)

2.48=

2.48=

1.96

1.96

Weekly ($/kW week)

0.57=

0.57=

0.45

0.45

Daily (Monday-Saturday) ($/kW day)

0.0950

0.0950

0.075

0.075

Daily (Sunday) ($/kW day)

0.0814

0.0814

0.065

0.065

Hourly (On-Peak) ($/kW hour)

NA

0.00594

NA

0.0047

Hourly (Off-Peak) ($/kW hour)

NA

0.00339

NA

0.0027

 

 

On-Peak Days are Monday t= hrough Saturday.  The Off Peak Day is Sunday.

On-Peak Hours are the hou= rs between 7:00 AM and 11:00 PM, Mountain Prevailing Time, Monday through Saturday.  Off-Peak Hours are = all other hours.

 

 

ANCILLARY = SERVICES RATES

  • SCHEDULE 1 - Scheduling, Syst= em Control and Dispatch Service:

This service is required = to schedule the movement of power through, out of, within, or into the CUS por= tion of the WACM Control Area.  This service can be provided only by the Transmission Provider where the transmission facilities are located.  The Transmission Providers’ charges for Scheduling, System Con= trol and Dispatch Services are as follows:

Services

Cost

Hourly=

$0.108/MW H= our

Daily<= /o:p>

$3.00/MW Da= y

Weekly=

$18.00/MW W= eek

Monthly

$79.00/MW M= onth

 

  • SCH= EDULE 2 - Reactive Supply and Voltage Support:

In order to maintain transmission voltages on the Transmission Provider’s transmission facilities within acceptable lim= its, generation facilities under the control of the transmission provider or the control area operator are operated to produce or absorb reactive power.  Thus, the transmission customer mu= st purchase this service from the transmission provider.  The charges for such service are as follows:

=  

Service

Hourly ($/kW Hour)

Daily ($/kW Day)

Weekly ($/kW Week)

Monthly ($kW Month)

 

On-Peak

Off-Peak

On-Peak

Off-Peak

 

 

BHP Charge

0.0002891

0.0001647

0.0046000

0.0040000

0.0278000

0.1203000

CLFP Charge<= /b>

0.0001500

0.0002000

0.0024000

0.0139000

0.0142000

0.0616000

BHW Charge<= o:p>

0.0000600

0.0000800

0.0010000

0.0060000

0.0062000

0.0267000

Total Charg= e

0.0004991

0.0004447

0.0080000

0.0239000

0.0482000

0.2086000

 

The Transmission Customer= will be billed based on the above Total Charges – the BHW and CLFP charges ar= e annual charges calculated monthly= as a result of actual activity.  Transmission Customers will receive an annual adjustment based on the monthly variations.

 

DISCOUNTED TRANSMISSION RATE

Discount information for = non-firm point-to-point transmission services is posted on the BHBE OASIS home page under the “Notices” button. The discount information is updated= as necessary to reflect market conditions and other factors. The information contained on the OASIS home page is dated to allow users an easy reference = for changes to the discount policy.

 

GENERATION REDISPATCH FOR RELIABILITY

Costs incurred by Network Customers as a result of generation redispatch for reliability by the Transmission Provider must be submitted by the 15th day of the month following the month the costs were incurred to be eligible for recovery pursuant to Section 34.4 of the Joint Tariff.

 

Submit costs to:

 

Black Hills Power, Inc.

Attn: Accounting Manager

P.O. Box 1400

Rapid City, SD 57709

 

 

FIRM TRANSMISSION SERV= ICE REQUESTS

TERMS OF SERVICE<= /p>

 

TRANSMISSION REQUESTS

RESPONSE TIME

DISPLACE/SUPERSEDE

Service Type

Term

Curtailment

Priority

No Later

Than

No Earlier

Than

Provider Evaluation Time Limit

System

Impact

Study

Cus= tomer Confirmation Time Limit after ACCEPTED or COUNTEROFFER

No Later

Than

Right of First Refusal

Network

1-10 Years

7=

(60) Calendar Days Prior To Initial Month

10-Years Prior To Start of Service

(30) Calendar Days

(60) Calendar Days

(15) Calendar Days

N/A<= /span>

N/A<= /span>

Fixed Or Sliding Yearly 1-10 Yr.

Fixed Or Sli= ding Yearly 1-10 Yr.

7=

(60) Calendar Days Prior To Initial Month

10-Years Prior To Start of Service

(30) Calendar Days

(60) Calendar Days

(15) Calendar Days

N/A<= /span>

N/A<= /span>

Firm Point-to-Point

Fixed Monthly (Calendar Month) 1-11 Months

7=

(14) Calendar Days Prior To Start Of Service

120 Calendar days Prior To Start of Service

(30) Calendar Days 1

 

(60) Calendar Days

4 Days

1-Month Prior To Commencement Of Service

24-Hours

Firm Point-to-Point

Fixed  = or Sliding Weekly  1-4 Weeks

7=

(2) Business Days Prior To Start of Service

60 Calendar days Prior To Start of Service

(30) Calendar Days 1

 

(60) Calendar Days

48 Hours

1-Week Prior To Commencement Of Service

24-Hours

Firm Point-to-Point

Fixed Daily (Calendar Day)1-6 Days

7=

1400 Day Prior To Start of Service

30 Calendar days Prior To Start of Service

(30) Calendar Days 1

 

(30)<= /b> Calendar Days<= o:p>

<24 Hrs= 2 – 120= Min 2

>24 Hrs= 2 – 24 = Hrs

 

1-Day Prior To Commencement Of Service

24-Hours Or Up To 1-Day Prior To schedule Start, Which= ever Is Less

Network Service From Non-Designated Resources

Based On Net= work Reservation<= /p>

6

1400 Day Prior To Start of Service

As Soon As Practicable

(1) Business Day

N/A<= /span>

Optional

1000 Day Prior<= o:p>

N/A<= /span>

1.=       = Subj= ect to expedited time requirements of Section 17.1 of the pro forma tariff.  Transmission Providers should make= best effort to respond within 72 hours, or prior to the scheduling deadline, whichever is earlier.

2.=       = Time= QUEUED prior to start of service.  Le= ss than (<), Greater than (>). 

  Example:  <24 Hrs – Request submitt= ed within 24 hours prior to the start of service.

NON-FIRM TRANSMISSION SERVICE REQUESTS

TERMS OF SERV= ICE

 

TRANSMISSION REQUESTS

RESPONSE TIME

DISPLACE/SUPERSEDE

Service Type

Term

Curtailment

Priority

No Later

Than

No Earlier

Than

Provider Evaluation Time Limit

System

Impact

Study

Cus= tomer Confirmation Time Limit after ACCEPTED or COUNTEROFFER

No Later

Than

Right of  First Refu= sal1

Non-Firm Point-to-Point

(Fixed Month= ly)

 1-Calendar Month

5=

1400 Day Prior To Start of Service

60-Calendar Days Prior To Start of Service

2-Calender Days=

N/A<= /span>

24 Hours

1400 Day Prior To Start of Service

24-Hours Or 1400 Prior To Schedule Start – Which= ever Is Less

Non-Firm Point-to-Point

(Fixed or Sliding Weekly)

 1- 4 Weeks

4=

1400 Day Prior To Start of Service

(14) Calendar Days Prior To Start of Service

4 Hours or As Soon as Practicable

N/A<= /span>

24 Hours

1400 Day Prior To Start of Service

24-Hours Or 1400 Prior To Schedule Start – Which= ever Is Less

Non-Firm Point-to-Point

(Fixed Daily) 1-6 days

3=

1400 Day Prior To Start of Service

(2) Calendar Days Prior To Start of Service

30-Minutes or As Soon as Practicable

N/A<= /span>

120 Minutes<= /span>

1400 Day Prior To Start of Service

24-Hours Or 1400 Prior To Schedule Start – Which= ever Is Less

Non-Firm Point-to-Point

(Fixed Hourl= y)

1-24 Hrs Wit= hin One Calendar Day

2=

30-Mins Prior To Start of Service

0600 Day Prior to Start of Service

30-Minutes or As Soon As Practicable

N/A<= /span>

<1 Hrs = 2- 5 Min.

1>24 Hrs = = 2 – 5 M= in.

24 Hrs = 2 > - 10 M= in.

 

1400 Day Prior To Start of Service

Immediately On Notification

Firm Point-to-Point from Secondary POD &/or POR<= /b>

Based On Firm Reservation =

1

30-Mins Prior To Start of Service

0600 Day Prior To Start of Service

30-Minutes or As Soon As Practicable

N/A<= /span>

<1 Hrs = 2- 5 Min.

1>24 Hrs = = 2 – 5 M= in.

24 Hrs = 2 > - 10 M= in.

 

1400 Day Prior To Start of Service

N/A<= /span>

 

1.&n= bsp;      The right of first refusal applies only with respect to requests for service that are be= ing preempted by competing, longer-term requests for non-firm point-to-point transmission service.

2.=       = Time= QUEUED prior to start of service.  Le= ss than (<), Greater than (>). 

  Example:  <1 Hrs – Request submitted within 1 hour prior to the start of service.

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