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From:
Shams Siddiqi <[log in to unmask]>
Reply To:
Date:
Tue, 25 Jun 2019 11:45:16 -0500
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Hi Everyone,

 

It was only a casual mention by ERCOT that we already have Ancillary Service
Demand Curves or differentiated penalty functions of $20k/MW/hr for NSRS,
$30k/MW/hr for RRS, $50k/MW/hr for RUS and $5k/MW/hr for RDS in the RUC
optimization and other penalties for power balance and transmission
constraints that ERCOT will be providing us soon. I could not find these in
any document and in my opinion these should be specified in the OBD on Max
Shadow Prices. ERCOT's description of its own KP3 proposal states: "RUC will
not use the RTM Ancillary Service Demand Curves (ASDCs) in RTM. Rather, RUC
will attempt to solve for a Resource commitment that meets the Load forecast
and AS Plan considering Resources' COPs and using a defined constant penalty
value. This is similar to the current process, except in the current process
the aggregate AS Plan capacity is within a Resource's' Current Operating
Plans (COPs)." This description is not consistent with the differentiated
multiple values for AS penalties mentioned by ERCOT and these values should
be part of KP3 document since they are important design elements. The DAM
uses at least $1,000,000/MW/hr penalty for AS - which is more like a hard
constraint which is what I assumed RUC was using. I look forward to getting
all the shadow price caps used in RUC for our consideration.

 

So, the real difference between what I'm proposing for RUC ASDCs and ERCOT's
proposed ASDCs is the demand curve prices and shapes and any scaling or
offer floors. ERCOT's proposal can also result in RUC not ensuring full AS
Plan amounts will be available although at a much higher price than the SCED
ASDCs. My proposal is that the same ASDCs should be used in RUC and SCED. If
ASDCs truly represent the willingness of the market to pay or forgo those AS
quantities, then they should be used in both. A unit with a $10,000 startup
cost should not be started for a 1 MW shortage of NSRS - which is what a
$20,000/MW/hr NSRS demand curve may do. Of course, this huge cost would not
set market prices since it's a RUC commitment. On the contrary, it would
have the impact of suppressing both the AS prices and energy prices
(assuming non-zero LSL) and resulting is possible uplift.

 

I would suggest that we ensure greater transparency in what is currently
being done and what is in ERCOT's proposal since these are important market
design elements that require careful consideration. Many stakeholders are
still catching up with the basics of RTC and may require more time and
discussion to understand the implications of their decisions. So, I would
recommend that we initially take more time before taking to TAC
non-consensus issues.

 

Regards,

Shams Siddiqi, PhD

President, Crescent Power, Inc.

11412 Bee Caves Rd, Suite 202

Austin, Texas 78738

Tel. +1.512.619.3532

Email:  <mailto:[log in to unmask]> [log in to unmask]

 <http://www.crescentpower.net> www.crescentpower.net 

 

 

 

From: [log in to unmask] <[log in to unmask]> 
Sent: Tuesday, June 18, 2019 12:16 PM
To: 'Maggio, Dave' <[log in to unmask]>; [log in to unmask]
<[log in to unmask]>
Subject: RE: Key Principle Templates

 

Hi Everyone,

 

I'm not sure if we're supposed to provide comments on these documents prior
to Friday's meeting - so, I'm providing comments just in case.

 

For KP3, based on feedback at the last meeting, I've introduced language to
truncate the ASDCs at the corresponding AS Plan amount - so, RUC will not
procure AS greater than minimum AS Plan amounts. E.g. if Non-Spin ASDC goes
from say $1800/MW to $200/MW for AS Plan amount of 1000MW - then RUC will
use this truncated ASDC. I also require that RUC apply a floor to Startup
Cost (TBD), Min Energy Cost (TBD) and EOC. EOC Floor would be the current
$1,500/MWh. This would imply that if there is scarcity, RUC would at most
procure the first 100-200MW of Non-Spin (if any) since the ASDC does not
justify the cost once offer floors are applied.

 

For KP1.5, I've clarified that Regulation Service deployments will always be
Resource Specific under both alternatives - the only difference is whether
the Resource Specific amounts are based on optional normalized Participation
Factors (PFs). There is no obligation to use Participation Factors and the
default would be as specified in Alternative 1. The concern raised at the
last meeting that normalized PFs may take time to compute within the
4-second LFC cycle is addressed by having normalized PFs being provided to
LFC for each SCED interval. Again, maintaining PFs does not alter the
economic efficiency of RTC and can increase efficiency by QSEs providing
deployed energy in an economic manner taking into account storage levels in
its portfolio of storage and controllable load assets.

 

There was also a good suggestion that we introduce Energy Storage Group
(similar to IRR Group) that can be utilized by a group of Energy Storage
assets for GREDP and Base Point Deviation purposes. I've added a paragraph
to incorporate this suggestion.

 

Regards,

Shams Siddiqi, PhD

President, Crescent Power, Inc.

11412 Bee Caves Rd, Suite 202

Austin, Texas 78738

Tel. +1.512.619.3532

Email: [log in to unmask] <mailto:[log in to unmask]> 

www.crescentpower.net <http://www.crescentpower.net>  

 

 

 

From: Maggio, Dave <[log in to unmask]
<mailto:[log in to unmask]> > 
Sent: Thursday, June 13, 2019 7:47 AM
To: [log in to unmask] <mailto:[log in to unmask]> 
Subject: Key Principle Templates

 


***** EXTERNAL email. Please be cautious and evaluate before you click on
links, open attachments, or provide credentials. ***** 

Good morning everyone,

 

I wanted to quickly let folks know that the key principle documents in the
updated template format have been posted on the 6/21/19 RTCTF meeting page
<http://www.ercot.com/calendar/2019/6/21/180300-RTCTF> .  We plan to have
the full agenda posted tomorrow and these documents will be discussed as
part of that agenda.  Additional material for the meeting will likely be
posted next week.

 

We look forward to seeing you all on the 21st.  

 


 

 <http://www.ercot.com/> 

 

Dave Maggio

Sr. Manager, Market Analysis & Validation

2705 West Lake Drive | Taylor, TX 76574

O: 512-248-6998 | M: 773-458-3215 

 

Confidentiality Notice: The information contained in this email message and
any attached documents may be privileged and confidential and is intended
for the addressee only.  If you received this email in error, please notify
the sender immediately.

 

 

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