HomeMy WebLinkAbout20040817Runyan Rebuttal.pdfRECE!\/ED IT)
Conley E. Ward (ISB No. 1683)
GIVENS PURSLEY LLP
601 W. Bannock Street
O. Box 2720
Boise, ID 83701-2720
Telephone: (208) 388-1200
Fax: (208) 388-1300
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Attorneys for U. S. Geothermal, Inc.
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BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
S. GEOTHERMAL, INC., an Idaho
corporation Case No. IPC-04-
Complainant
vs.
IDAHO POWER COMPANY, an Idaho
corporation
Respondent.
BOB LEWANDOWSKI Md MARK
SCHROEDER Case No. IPC-04-
Complainants
vs.
IDAHO POWER COMPANY, an Idaho
corporation
Respondent.
REBUTT AL TESTIMONY OF KIP W. RUNYAN
ON BEHALF OF U.S. GEOTHERMAL, INC.
August 19,2004
ORIGINAL
PLEASE STATE YOUR NAME AND ADDRESS FOR THE RECORD.
My name is Kip W. Runyan. My business address is 2233 Spring Mountain Drive
Boise, Idaho.
ARE YOU THE SAME KIP W. RUNYAN WHO PREVIOUSLY SUBMITTED
DIRECT TESTIMONY IN THIS PROCEEDING?
Yes.
WHAT IS THE PURPOSE OF YOUR REBUTTAL TESTIMONY?
The purpose of my rebuttal testimony is to respond to a number of comments and
concepts put forward in the testimony of Idaho Power witness Gale, A vista witness
Kalich, PacifiCorp witness Hale, and Staff witness Sterling (together referred to as the
The Other Witnesses
DO YOU HAVE A GENERAL COMMENT ABOUT THE NATURE AND CONTENT
OF THE TESTIMONY PROVIDED BY THOSE WITNESSES?
Yes. A common theme running through all of the utility witnesses' testimony is their
insistence that PURP A resources should receive something less than full avoided cost
rates because they don t provide capacity benefits and are less reliable or riskier than
utility owned resources. Later on in my testimony, I will submit evidence that proves
these contentions are demonstrably wrong, but as a preliminary matter I would like to
point out that" these issues were fully litigated when the Commission established avoided
cost rates. None of the pleadings in this case place the level or reasonableness of avoided
cost rates at issue, and the utilities' arguments about the value ofPURPA resources are
therefore irrelevant and a prohibited collateral attack on the Commission s prior orders.
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DO YOU HAVE ANY OTHER GENERAL OBSERVATIONS ABOUT THE
UTILITIES' TESTIMONY?
Yes. All three utility witnesses conjure up a parade of hypothetical PURP A abuses that
might be possible in certain "scenarios." Some of these hypotheticals are ludicrous on
their face, such as Mr. Gale s assertion at page 29 that a developer might build a 100
megawatt plant and then generate only 876 hours in order to qualify for a posted rate
based on 10 average megawatts. Moreover, none of the witnesses submit any evidence
whatsoever that any PURP A generator has ever perpetrated, or even attempted, any of the
practices the utilities allegedly fear, and they further ignore the fact that many of the
envisioned scenarios are prohibited by existing Commission orders or already barred by
provisions in the draft contract U.S. Geothermal tendered to Idaho Power. In short, the
utilities devote much of their testimony to beating up a strawman of their own invention.
None of this has anYthing to do with the real issues in this case.
WHAT ARE THE REAL ISSUES BEFORE THE COMMISSION IN THIS
COMPLAINT?
S. Geothermal's complaint raises three discrete issues:
(1)What is the definition of the 10 megawatt size limit for entitlement to the
Commission s Published Rates?
(2)Should Idaho Power be allowed to include contractual provisions that impose
financial penalties if a PURP A generator s energy deliveries vary by more than 10
percent from its forecasted performance?
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(3)Should Idaho Power be allowed to include a contract clause that allows Idaho
Power to unilaterally terminate PURP A contracts if certain regulatory actions occur in the
State of Idaho?
Subsequent to the filing of the complaint, an additional issue has arisen as a result of
the Renewable Energy of Idaho Project Order (Order No. 29487) and the response to that
Order by Idaho Power. The new issue CM be summarized as follows:
(4)Can a project larger than 10 MW generate more than the contract firm energy
amounts and sell that excess either to Idaho Power at market based rates or to a third
party and nevertheless remain eligible for the published rates for the first 10 megawatts of
generation, consistent with the terms and conditions of the contracts approved by the
Commission for the Tiber Montana Project (Order No. 29232) and the Renewable Energy
of Idaho Project (Order No. 29487)? Additionally, if the Commission changes its policy,
should U.S. Geothermal be "grandfathered" because of the extensive negotiations it
conducted with Idaho Power based on Idaho Power s contracting guidelines and the
previous Commission approvals?
THE OTHER WITNESSES ALL AGREE THAT THE "TEN MW PROJECT
CAP ACITY" CRITERIA FOR PUBLISHED RATE ELGIBILITY SHOULD BE
INTERPRETED TO MEAN THAT THE ACTUAL ENERGY DELIVERED IN ANY
HOUR DOES NOT EXCEED 10 000 KWH'S. WOULD YOU LIKE TO COMMENT
ON THAT CONCLUSION?
Yes, with a little background first. I believe Idaho Power witness Gale provides an
accurate summary of the current situation by concluding, on line 8 of page 25 of his
testimony, that "we still have no definitive Commission ruling as to the test to be applied
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to determine the capacity of a QF and its entitlement to the published rates." Earlier in
his testimony, beginning at line 30 of page 24, Mr. Gale points out that in 2002, Idaho
Power requested that "name plate capacity" be used to establish published rate
entitlement, but that the Commission declined to address this issue.
I am not familiar with A vista or PacifiCorp s practices, so I can t speak to their
situation. But in the case of Idaho Power, the utility has taken the position that it would
buy the first 10 megawatts through the meter on M hourly basis at published rates
without regard to the project's theoretical or actual capacity. Deliveries in excess of 10
megawatts were labeled "Optional Energy," which Idaho Power would purchase at the
lesser of 85% of Mid-C market prices or the published rates.
I believe the contracting parties have the capabilities to reach a logical and fair
determination of project capacity, if they are so inclined, and that it is reasonable for the
Commission to expect the parties to do so. I believe that U.S. Geothermal's proposed
definition is a reasonable resolution based on sound engineering principles. The utilities
proposed definition is not inherently unreasonable, but the Commission should
understand that it will have the effect of reducing the maximum size of many PURP
projects, specifically geothermal projects, well below the supposed 10 megawatt limit.
THE OTHER WITNESSES CHARACTERIZE THE U.S. GEOTHERMAL
APPROACH TO DEFINING PROJECT CAPACITY AS AN APPROACH BASED ON
AVERAGE ANNUAL ENERGY.DO YOU AGREE WITH THEIR CONCLUSION?
No I do not. When analyzing the U.S. Geothermal approach, I think it is important for
the Commission to focus solely on the 10 MW capacity definition that is actually in the
contract, rather than the utilities' hypothesized definition. U.S. Geothermal is not
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proposing an "average annual energy" basis for the calculation of the Project's capacity.
Instead, it is proposing that the facility s capacity be determined just as Staff witness
Sterling describes for the Idaho Power Danskin Project.
Staff witness Sterling states at line 17 page 11
, "
Idaho Power s Danskin project is
normally referred to as a 90 MW plant because it has the capability to generate at 90 MW
under normal conditions." (emphasis added). As explained in my direct testimony,
well as the extensive discussion in U.S. Geothermal witness Kitz s testimony, the U.
Geothermal Project is capable of generating only 10 MW under normal conditions. The
fact that both of the above facilities will actually generate at more than the stated
capacities under favorable ambient conditions and less than stated capacities at
unfavorable conditions does not change the fact that they are respectively a 90 MW and
10 MW thermal project. As discussed in the Runyan and Kitz testimony, to conclude
otherwise is to impose a bias against thermal proj ects in general, and specifically a bias
against the development of geothermal resources.
THE OTHER WITNESSES DISCUSS ABUSES THAT MAY OCCUR IF THE
COMMISSION WERE TO ALLOW A PROJECT TO UTILIZE A SO CALLED
AVERAGE ENERGY APPROACH". DO YOU BELIEVE THEIR CONCERNS ARE
VALID?
If one disregards the provisions of the U.S. Geothermal contract and assumes that the
Commission would actually approve published rates for a contract with a 100 MW
capacity, they might have a legitimate concern. But the facts in this case are substantially
different than the doomsday scenarios they described. The fact is that the contract before
the Commission limits deliveries to specified "Maximum Monthly Energy" amounts, and
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it further limits hourly deliveries to the "Maximum Capacity Amount " which in this case
is set at 12.7 MW. Article 14.2 goes on to state that "Seller s failure to limit deliveries by
the Transmitting Entity pursuant to this contract to the Maximum Capacity Amount will
be a Material Breach of this Agreement." The Project simply cannot do what The Other
Witnesses are forecasting without breaching the terms of the contract.
THE OTHER WITNESSES ALSO BRING UP THE POSSIBILITY OF OTHER
MANIPULATIONS THAT MIGHT OCCUR, PRIMARILY SHIFTING DELIVERIES
BETWEEEN PEAK AND OFF PEAK PERIODS TO F ACILIT A TE ADDITIONAL
PROFITS AT THE EXPENSE OF IDAHO POWERS CUSTOMERS. DO YOU
AGREE WITH THEIR CONCERN?
Later in this rebuttal testimony I will address those concerns since they relate to a project
that sells its output to multiple purchasers. This discussion, however, is about how
capacity eligibility for published rates is determined, and that determination has nothing
to do with any of the conjectured abuses.
DOES THE 10 MW FACILITY CAPACITY DEFINITION PROPOSED BY U.
GEOTHERMAL CREATE ANY RISK FOR THE COMMISSION OR THE
CUSTOMERS OF IDAHO POWER?
Absolutely not. The result of calculating the capacity of the thermal facility at normal
conditions is to adopt a rating standard that is consistent with standard utility and
engineering practices. Any strained interpretation or misrepresentation of this
methodology by contracting parties is easily dealt with in the existing contracting and
approval process. It is a matter of common sense, and Idaho Power and potential sellers
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should be expected to conduct the determination in a professional manner, supported by
solid engineering principles.
IF THE COMMISSION FEELS THAT SOME EXPOSURE IS CREATED BY THE
ADOPTION OF THE NORMAL CONDITIONS STANDARD FOR THERMAL
PROJECTS, ARE THERE WAYS TO ALLEVIATE THAT CONCERN?
Absolutely. Contracts could simply expand the definition of the Maximum Capacity
Amount to include an appropriate capacity amount for each month, determined by
utilizing accepted engineering principles. That provision, along with the Maximum
Monthly Energy Amounts previously specified by U.S. Geothermal in the Contract
would eliminate any risk of such an abuse. U.S. Geothermal witness Kitz presents
extensive testimony explaining how the U.S. Geothermal capacity definition is consistent
with the actual operating characteristics of a geothermal resource. U.S. Geothermal is not
attempting any slight-of-hand, it simply would like its geothermal resource analyzed like
a geothermal facility.
IDAHO POWER WITNESS GALE STATES AT LINE 17 OF PAGE 2, THAT IDAHO
POWER IS PROPOSING ADDITIONAL CONTRACT PENALTIES TO
ENCOURAGE GREATER FIRMNESS.DO YOU BELIEVE THESE CHANGES
ARE WARRANTED?
, I do not. Idaho Power is proposing finMcial penalties for CSPPs whose monthly
production deviates more than 10 percent from estimates required to be submitted two
years in advance. Idaho Power has presented no evidence to support this proposal, other
than the vague assertion that it will benefit Idaho Power and its customers. That may be
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true in the sense that it will effectively reduce CSPP rates, but the issue is whether the
proposal is fair and reasonable to all stakeholders.
DID YOU INVESTIGATE THE RELIABILITY OF THE CSPP INDUSTRY IN
COMPARISON TO IDAHO POWER'S FACILITIES?
Following a review of the testimony by witness Gale, I researched the past performance
of both the CSPP projects and Idaho Power s own facilities over the period 1997 through
2003 in order to compare the "firmness" of the two types of resources. I selected that
specific period because it required only minor modification of the raw data to be
consistent for the facilities operating throughout the period. Data for the CSPP projects
was taken from the annual "Report of Cogeneration / Small Power Production for Idaho
Power" submitted by Idaho Power to the Commission. The data for Idaho Power
facilities was taken from the FERC Form 1 reports filed annually by Idaho Power. The
results of the analysis are attached to this testimony as Exhibit No.
As the Exhibit indicates, over the last seven years the CSPP projects have been
more consistent in their output, and therefore more predictable, than Idaho Power s own
resources. Actual production over the period for all Idaho Power resources varied from
116% (1998) to 84% (2003) of their seven year average production. On the other hand
CSPP production varied from 1150/0 (1997) to 85% (2003) of their average. The figures
for Idaho Power are admittedly not directly comparable to CSPPs as a whole because
Idaho Power s thermal facilities are idled when market conditions allow more economic
purchases. But in reviewing only CSPP thermal projects, the deviation over the seven
year period was from 93 % to 106% of the seven year average, a very reliable and
predictable performance by any definition. Furthermore, comparing only Idaho Power
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hydroelectric projects with CSPP hydroelectric projects, the results clearly indicate that
the CSPP projects are more predictable and reliable. Idaho Power s hydro facilities
varied from 138% (1997) to 71 % (2002) of average over the period, while the CSPP
projects varied from 125% (1997) to 76% (2001).
WHAT CONCLUSIONS CAN BE DRAWN FROM THE CSPP HISTORIC
PERFORMANCE DATA?
This data refutes the utilities' repeated assertions that CSPP facilities provide only energy
and not capacity. In terms of reliability and predictability, the CSPP facilities have
operated as well as, and arguably better than, utility resources. A utility trying to balance
loads and resources knows it can count on the CSPP portfolio to produce base load
capacity and energy in much the same manner as the utility s own base load resources.
While it is true that the Commission has decided to limit payments to PURP A projects
for only energy delivered, that policy decision does not mean that CSPP projects are not
delivering both capacity and energy.
ARE THERE ANY OTHER CONCLUSIONS WE CAN DRAW FROM THE CSPP
PERFORMANCE DATA?
Yes. There is simply no evidence that the performance penalties Idaho Power is
requesting are justified. Mr. Gale would have the Commission believe that the 90/110
performance band is necessary to limit CSPP producers "discretion" over the operation of
their facilities. But the fact is that Idaho QF projects receive payment only for energy
delivered. This is the ultimate motivation for reliable and continuous production.
Considering the record, I find no justification for Idaho Power to make a radical change
in the pricing terms and conditions that have provided such a positive result. In light of
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Idaho Power s stated desire to achieve "simplicity of contract administration " the
inclusion of the complex performance banding requirements, and the contract disputes
they will inevitably cause, is counter productive and unnecessary.
DO THE SAME OBJECTIONS APPLY TO THE 80%/1200/0 PERFORMANCE BAND
PRESENTED BY STAFF WITNESS STERLING?
Yes. Like Mr. Gale, Mr. Sterling has not presented any analysis or documentation to
justify or support the bandwidth he proposes. As discussed above, Idaho Power s own
aggregated hydroelectric facilities, which represent a group of assets that any utility or
state would love to include in its generation portfolio, vary from 71 % to 138% of average
production over the last seven year period. It makes no sense that new resource additions
should be expected to operate at levels substantially superior to Idaho Power s admittedly
top- flight generation system. As the record indicates, even though certain assets, for a
variety of reasons , may operate at less than expected levels during certain periods, the
aggregate group of assets operates in a very satisfactory manner. This is not surprising
because a CSPP facility that does not operate at its maximum capability is already
penalized by the loss of revenue for the energy it could have delivered.
Given the fact that CSPPs already have a powerful motive to maximize
production, and considering that, in the aggregate, they are performing as well as the
utility s own resources, there is no justification for performance penalties of any type.
The fact that Mr. Sterling s proposal may be less onerous than Idaho Power s doesn
make it any less arbitrary. Mr. Gale s or Mr. Sterling s desire to see additional resource
firming," does not change the fact that the proposed treatment is completely opposite of
what is required by this Commission of Idaho Power s own resources (including the
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Surrogate Avoided Resource). In fact, the imposition of potential penalties on Idaho
Power makes far more sense than it does for CSPPs because, as our direct testimony
pointed out, the PCA eliminates for Idaho Power 90% of the penalty a CSPP faces under
the payment for delivered energy contracts now in place.
WHAT IS YOUR RESPONSE TO STAFF WITNESS STERLING'
RECOMMENDATION THAT MORE FREQUENT UPDATING OF MONTHLY
GENERATION ESTIMATES IS APPROPRIATE?
As I have just explained, the existing CSPP projects are just as predictable as utility
assets for planning purposes, and I therefore rej ect the notion that performance penalties
are appropriate. This unfairness is exacerbated by the fact that the two-year lead time for
generation estimates that Idaho Power has proposed is clearly arbitrary. As anyone
familiar with the weather in the Northwest knows, forecasting weather and stream flows
2 years in advance is a recipe for disaster. If the forecast of monthly generation estimates
is meant to be informative and useful, and not punitive, then the proposal by Staff witness
Sterling to shorten the intervals for updating generation estimates from 2 years to 6
months is superior to Idaho Power s proposal. I would suggest, however, that even a six
months forecast is too long. For example , who in their right mind would place any
credence in a November forecast of May stream flows? If the Commission deems such
forecasts necessary, a month ahead forecast will result in much more accurate
information, while minimizing the punitive nature of any penalties Idaho Power may be
allowed to impose.
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STAFF WITNESS STERLING REFERS TO IDAHO POWER'S PROPOSED
CONTRACT LANGUAGE ABOUT FORCED OUTAGES AND PROPOSES SOME
CHANGES. DO YOU AGREE WITH THE PROPOSED CHANGES?
The contract section referred to by Staff Witness Sterling is, in my view, unwarranted for
the reasons I've already discussed , as well as completely confusing as to the section
intent and purpose. In the first place, the contract does not allow for a 72 hour grace
period for forced outages as witness Sterling states. The section provides instead that any
delivery suspension will be for a minimum of 72 hours. It further states that any
suspension has to be for "all" deliveries, despite the representation by Idaho Power
witness Gale on page 9 of his testimony that "the net energy commitment amount can be
temporarily reduced." Neither of these provisions makes sense to me. For example, if
the facility has 3 generating units, why must "all" deliveries be suspended? Why not just
the damaged unit, or if the unit is capable of operating at ,some reduced level , why must
all" deliveries be suspended? If the equipment can be repaired in 24 hours, what public
good is served by the requirement to suspend deliveries a minimum of 72 hours?
simply don t understand the reason for the clause and its punitive nature.
EARLIER IN THE REBUTTAL YOU DISCUSSED THE 10 MEGAWATT LIMIT
ISSUE AS IT WAS FRAMED IN THE PLEADINGS IN THIS CASE. HAS
ANYTHING HAPPENED SINCE THE COMPLAINT WAS FILED THAT
COMPLICATES THIS ISSUE?
Yes. Throughout the negotiations, one of the primary sticking points between Idaho
Power and U.S. Geothermal was how to define the Commission s reference to a 10
megawatt limit. But both parties assumed that the 10 megawatt standard applied only to
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the amount of power that must be purchased at published rates, and that it did not limit a
seller to a nameplate or peak capacity of 10 megawatts in order to be eligible for the
published rates. That is why Idaho Power s draft contracts provided for the purchase of
Optional Energy above 10 megawatts at a market based price.
This view seemed to be supported by the Commission s Order No. 29232 in the
Tiber case, issued on April 28 , 2003 , which authorized the payment of published rates
notwithstanding the fact that the project might ultimately exceed 10 megawatts of
capacity. But on May 4, 2004, approximately 6 weeks after U.S. Geothermal filed its
complaint in this case, the Commission issued Order No. 29487 approving the Renewable
Energy of Idaho contract. That contract contained the "Optional Energy" concepts to
facilitate a 17.5 MW biomass facility. In the body of the Order, the Staff and
Commission admonished Idaho Power regarding its contracting methodology for projects
with a capacity in excess of 10 MW, and indicated that Idaho Power should determine the
price for such projects in accordance with the Aurora model IRP methodology.
Consequently, Idaho Power changed its position and now argues for the first time
that U.S. Geothermal is not entitled to published rates for 10 megawatts or less of
production, however defined, but instead is entitled only to the unknown rate that the
Aurora model will ultimately produce for the entirety of its output. Staff witness Sterling
now endorses this approach in his testimony.
IF THE COMMISSION DETERMINES THAT PROJECTS LARGER THAN 10
MEGAWATTS ARE NOT ELIGIBLE FOR PUBLISHED RATES, DO YOU FEEL
S. GEOTHERMAL SHOULD BE SUBJECTED TO THE AURORA MODEL IRP
METHODOLOGY?
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No. I believe U.S. Geothermal should receive a "grandfather" exemption from the IRP
requirement for the same reason that the Commission exempted Renewable Energy. The
Commission stated in its Findings, at page 10
, "
What is persuasive in this case is the
unfairness of holding the QF project hostage for the failure of the utility to follow the
Commission-approved avoided cost methodology. The project's viability, as configured
is dependent on the timely approval of the submitted Agreement."
DO THOSE SAME CONSIDERATIONS APPLY TO THIS CASE?
Yes. Following is a brief summary of the facts surrounding the effort by U.
Geothermal to obtain a PURP A contract at published rates:
(1)As presented in my direct testimony, early in 2003 Idaho Power sent several
standard form PURPA agreements to U.S. Geothermal. These agreements included terms
and conditions for the delivery of and payment for "Optional Energy.
" "
Optional
Energy" is defined as "The electric energy produced by the Facility, less Station Use, and
less Losses, scheduled and delivered by the Transmission Entity to Idaho Power at the
Point of Delivery that exceeds 10 000 Kwh in any single hour." Article VI of the
agreement goes on to state that "Idaho Power will purchase all of the Net Energy and
Optional Energy produced by the Sellers Facility
(2)On April 28 , 2003 , the Commission issued Order No. 29232. The Order
approved the Tiber Montana Contract. That contract included the same provisions that
are discussed above. The Order provided a substantial discussion of the "Optional
Energy" concept and the likelihood that the Tiber project mayor may not someday have
a capacity greater than 10 MW.
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(3)Extensive contract negotiations between Idaho Power and U.S. Geothermal were
conducted during the period from October of2003 to the filing of this Complaint. The
specifics of those negotiations are more completely discussed in my direct testimony at
pages 4 & 5 and pages 9 through 11. During the entire period of negotiation the
availability of published rates for the first 10 MW of output was never in dispute
(4)
(5)
On March 25 2004, U.S. Geothermal filed its Complaint with the Commission.
On May 4 2004, some 6 weeks after the filing of the U.S. Geothermal Complaint
the Commission issued Order No. 29487.
. (6)On May 21 , 2004, two months after U.S. Geothermal filed its Complaint, Idaho
Power sent a letter to U.S. Geothermal that, for the first time in the negotiation, denied
entitlement to the published rates for the U.S. Geothermal project.
(7)The hearing dates for this Complaint are scheduled for September 2nd and 3rd
2004. An Order addressing the complaint is expected sometime thereafter, over one and
one-half years after the contract negotiations were initiated.
THE OTHER WITNESSES RAISE A NUMBER OF CONCERNS ABOUT THE
POTENTIAL FOR ABUSE IF A PROJECT THAT IS LARGER THAN 10 MW (SAY
20 MW) SELLS THE OUTPUT OF THE PROJECT TO MULTIPLE PARTIES.
YOU AGREE WITH THEIR CONCERNS?
No. The stated concerns primarily center around two issues. The first is that a project in
this situation could force multiple 10 MW PURP A contracts on various utilities at the
published rates in the State of Idaho. The second is that the project would basically shop
its output to the most favorable purchaser at the most favorable periods of time. The
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Commission has already addressed the first of these concerns, and the second can be
addressed by contract terms and conditions that make such abuses impossible.
PLEASE EXPLAIN YOUR THOUGHTS ON THE CONCERN THAT MULTIPLE QF
CONTRACTS COULD BE OBTAINED.
This issue was fully discussed in the Staff Comments contained in the Tiber Montana
Case (Order No. 29232). On page 4 of that Order, Staff is quoted as stating, "In Order
No. 26772, the Commission equated the term 'project' as used in rate orders and
schedules with 'qualifying facility,' as that term is defined by FERC. Thus each
qualifying facility is only entitled to one PURP A contract." U.S. Geothermal agrees with
the Staff interpretation and is willing to stipulate that the Project, except for this contract
is not entitled to utilize the required purchase provisions of PURP A to contract with any
other utility doing business in State of Idaho.
TURNING TO THE SECOND ISSUE, CAN U.S. GEOTHERMAL GAME THE
SYSTEM BY SHIFTING DELIVERIES BETWEEN MULTIPLE PARTIES IN ORDER
TO MAXIMIZE ITS PROFITS?
If the intent of the contracting parties is clearly understood in the contract, I don t believe
such "gaming" can occur. If such practices were to occur, the purchaser under the
contract would have legal rights to claim a breach of performance and pursue appropriate
legal and financial remedies. It should be clearly understood that U.S. Geothermal has no
intent to, or any interest in, employing any of the activities referred to by The Other
Witnesses. If Idaho Power, or this Commission, has any concerns in that regard, U.
Geothermal is more than willing to include provisions in the contract that provide
adequate protection to all parties. U.S Geothermal intends to deliver Idaho Power its pro-
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rata share of the project output during all hours of each day of the contract period. Any
reasonable contract provision to assure this performance is acceptable to U.S Geothermal.
The contract provisions could be quite simple, and easily monitored through the right to
audit on demand all of the project production records.
The problem I have with the utilities' presentation is that having stated the
concerns, the only solution offered is to disallow any and all sales of additional output to
any third party, rather than proposing contract language that protects their interests.
cannot identify any public policy issue or concern that would lead to forbidding a sale of
excess energy to a third party. Again, reasonable parties attempting to provide adequate
and fair contract protections should have no problem agreeing on appropriate contract
terms and conditions.
STAFF WITNESS STERLING BELIEVES U.S. GEOTHERMAL SHOULD NOT BE
ENTITLED TO THE SAME "GRAND FATHERING" TREATMENT AS
RENEWABLE ENERGY OF IDAHO. DO YOU AGREE WITH HIS
CONCLUSIONS?
No. In Staff Witness Sterling s testimony on page 23 , he states that the Commission
reluctantly approved the Renewable Energy contract
, "
in part because it did not wish to
delay Renewable Energy s progress on completing the project and in part because it did
not wish to penalize Renewable Energy for mistakes not of its creation." I see no reason
why the Commission should treat U.S. Geothermal any differently than Renewable
Energy, simply because it has exercised its rights to challenge what it believes are unfair
contract terms in a six month complaint process before this Commission.
REBUTTAL TESTIMONY OF KIP W. RUNYAN - 18
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\1\Runyan Rebuttal FINAL. doc
STAFF WITNESS STERLING ALSO STATES THAT THIS CASE IS DIFFERENT
BECAUSE HE REMEMBERS "TELLING U.S. GEOTHERMAL ON ONE OR MORE
OCCASIONS THAT IF IT WANTED TO PURSUE A PROJECT 10 MW OR
LARGER, IT MUST REQUEST THAT IDAHO POWER COMPUTE A RATE USING
THE IRP-BASED METHODOLOGY.DO YOU AGREE WITH HIS
CONCLUSIONS?
No. PURP A developers do not follow the PUC's proceedings and orders with anYthing
like the utilities' intensity or expertise , and they should be entitled to rely on the
presumption that a utility s contractual approach is consistent with Commission orders
and policies. The QF developer has a significant number of development and contracting
issues it must manage. To further burden it with the responsibility to ensure that Idaho
Power s negotiation positions are entirely consistent with the Commissions intent is
simply unreasonable and unworkable.
STAFF WITNESS STERLING INDICATES, AT PAGE 22, THAT U.
GEOTHERMAL REQUESTS "GRANDF A THERING" FOR THE A AILABILITY OF
PUBLISHED RATES CONSISTENT WITH THE RENEWABLE ENERGY OF
IDAHO TERMS. IS THIS AN ACCURATE REPRESENT A TIION?
Not entirely. U.S. Geothermal is asking the Commission to "grandfather' U.
Geothermal for eligibility for published rates for the first 10 MW of project output, as
that is defined in the contract, with the right to sell any excess to other third parties.
discussed earlier in this rebuttal testimony, as well as in my direct testimony, U.
Geothermal is more than willing to include contract provisions that protect Idaho Power
REBUTT AL TESTIMONY OF KIP W. RUNYAN -
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\I\Runyan Rebuttal FINAL. doc
and its customers from any potential abuses it feels it is not now contractually protected
from.
IF THE COMMISSION DECIDES THAT U.S. GEOTHRMAL IS ENTITLED TO
TERMS CONSISTENT WITH THE RENEWABLE ENERGY OF IDAHO
CONTRACT, BUT IS NOT COMFORTABLE WITH ALLOWING THE SALE OF
EXCESS PRODUCTION TO A THIRD PARTY, WHAT EFFECT WILL THIS HAVE
ON THE VIABILITY OF THE U.S. GEOTHERMAL PROJECT?
The financial feasibility of the project under the described scenario is really outside the
scope of the services I am providing U. S. Geothermal. I would, in such a case, ask the
Commission to review the fairness of the provision Idaho Power has included in its
Market Based Pricing for Optional Energy. "Market Energy Cost" is defined as "eighty-
five percent (85%) of the weighted average of the daily on-peak and off-peak Dow Jones
Mid-Columbia Index (Dow Jones Mid-C Index) prices for non-firm energy.
" "
Optional
Energy," that is energy in excess of 10 000 Kwh in any single hour, is paid the current
month's Market Energy Cost or the published rates, whichever is lower. Idaho Power
enjoys the benefit if the Market Energy Cost is below the published rates, but denies the
seller the benefit of a Market Energy Cost that is above the published rates by limiting the
payments to the lesser of the published rates or Market Energy Costs. "Optional Energy
is treated as non-firm. Staff witness Sterling describes the terms under which "non firm
energy sales are made on page 4 of his testimony. "Non-firm energy projects less than
MW in size are paid 85% of Mid-C market prices." Idaho Powers inclusion of the "lesser
of' provision in the Optional Energy pricing is inconsistent with the pricing criteria the
Commission has established. The "lesser of' provision is unfair and inconsistent with
REBUTT AL TESTIMONY OF KIP W. RUNYAN - 20
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\1\Runyan Rebuttal FINAL. doc
Commission pricing criteria and Idaho Power should be instructed to remove that
provision from the contract.
DOES THAT COMPLETE YOUR REBUTTAL TESTIMONY?
Yes.
REBUTT AL TESTIMONY OF KIP W. RUNYAN - 21
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\1\Runyan Rebuttal FINAL. doc
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EXHIBIT 4.2 - CSpp GENERATION RECORD
Annual CSPP Production - Gi~ awatt hours
Total 58 Hydro.7 Thermal
Year 65-Projects Projects Projects
(see below)
1997 856 557 299
1998 807 509 298
1999 831 535 296
2000 757 472 285
2001 653 339 314
2002 665 358 307
2003 628 353 275
Average 742 446 296
Notes:
(1) The "7 Thermal Projects" include West Boise Waste , Pocatello
City Waste, Glenns Ferry Cogen, JR Simplot Thermal , Rupert
Cogen, Tamarack Wood Wate and the Tasco Thermal Projects,
(2) The "Total 65 Projects" do not include the Boise Cascade
Emmett Wood Waste and Vaagen Lumber Wood Waste Projects
because they were not in service the entire study period.
Annual CSPP Production - % of Average
Total 58 Hydro,7 Thermal
Year 65-Projects Projects Projects
(see below)
1997 115%125%101%
1998 109%114%101%
1999 112%120%100%
2000 102%106%96%
2001 88%76%106%
2002 90%80%104%
2003 85%79%93%
Exhibit No. 4.
Case Nos. IPC-E-O4-08 and IPC-E-O4-
K. Runyan, U.S. Geothermal
August 19, 2004
EXHIBIT 4.3 - IDAHO POWER GENERATION RECORD
Annual Idaho Power Production - Gigawatt hours
1997 1998 1999 2000 2001 2002 2003 Average
THERMAL:
Bridger 327 183 309 5,400 365 945 820 050
Boardman 142 322 349 354 444 353 424 341
Valmy 925 420 608 945 788 945 628 608
Danskin
Salmon Diesel
Total Thermal 394 925 266 702 619 286 915 015
Total w/o Danskin 394 925 266 702 601 243 873 001
HYDRO:
American Falls 733 596 579 386 230 210 206 420
Bliss 568 492 465 406 315 299 294 406
Brownlee 341 318 084 508 633 839 943 524
Cascade
Oxbow 421 370 171 088 707 823 838 060
Hells Canyon 951 794 786 172 385 621 630 191
Malad 167 186 187 182 170 165 159 174
C J Strike 636 631 643 493 377 364 351 499
Swan Falls 179 139 104 124 119 113 110 127
Twin Falls 399 349 339 185 201
Upper Salmon 269 262 285 278 218 193 179 241
Shoshone Falls 114 102 117 111 100
Lower Salmon 453 408 403 285 213 194 194 307
Milner 441 354 350 170 198
Clear Lakes
Thousand Springs
Total Hydro 806 11 ,135 652 497 638 038 148 559
Total Both - w/o 200 060 918 199 239 281 021 560
Danskin
Annual Idaho Power Production - % of Average
1997 1998 1999 2000 2001 2002 2003 Average
Thermal 77%99%104%110%109%103%98%
Hydro 138%1300/0 124%99%66%71%72%
Total 111%116%115%104%85%85%84%
Exhibit No. 4.
Case Nos. IPC-O4-O8 and IPC-E-O4-
K. Runyan, U.S. Geothermal
August 19, 2004
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 16th day of August 2004, I caused to be served a true
and correct copy of the foregoing document by the method indicated below and addressed to the
following:
Jean Jewell
Idaho Public Utilities Secretary
472 W, Washington Street
O, Box 83720
Boise, ID 83720-0074
S, Mail
Hand Delivered
Overnight Mail
Facsimile
Scott Woodbury
Deputy Attorney General
Idaho Public Utilities Commission
472 W, Washington Street
O, Box 83720
Boise, ID 83720-0074
S, Mail
Hand Delivered
Overnight Mail
Facsimile
Barton L, Kline
Monica B, Moen
Idaho Power Company
1221 W, Idaho Street
O, Box 70
Boise, ID 83707-0070
S, Mail
Hand Delivered
Overnight Mail
Facsimile
John p, Prescott
Vice President - Power Supply
Idaho Power Company
O, Box 70
Boise, ID 83707-0070
S, Mail
Hand Delivered
Overnight Mail
Facsimile
Peter 1. Richardson
Richardson & O'Leary
99 E, State Street, Ste, 200
O, Box 1849
Eagle, ID 83616
S, Mail
Hand Delivered
Overnight Mail
Facsimile
Don Reading
Ben Johnson Associates
6070 Hill Road
Boise, ID 83703
S, Mail
Hand Delivered
Overnight Mail
Facsimile
REBUTTAL TESTIMONY OF KIP W. RUNYAN - 22
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\1\Runyan Rebuttal FINAL.doc
Dan Kunz, President
S, Geothermal, Inc,
1509 Tyrell Lane, Ste, B
Boise, ID 83706
James F, Fell
Stoel Rives LLP
900 S,W, Fifth Avenue, Ste, 2600
Portland, OR 97204
Bob Lively
PacifiCorp
One Utah Center, 23 rd Floor
201 S, Main Street
Salt Lake City, UT 84140
R, Blair Strong
Paine, Hamblen, Coffin, Brooke &
Miller LLP
717 W, Sprague Avenue, Ste, 1200
Spokane, WA 99201-3505
Clint Kalich, Manager of Resource
Planning and Analysis
A vista Corporation MSC- 7
O, Box 3727
Spokane, W A 99220-3727
REBUTTAL TESTIMONY OF KIP W. RUNYAN - 23
IPUC Case Nos. IPC-04-08 and IPC-04-
S:\CLIENTS\6667\I\Runyan Rebuttal FINAL.doc
S, Mail
Hand Delivered
Overnight Mail
Facsimile
S, Mail
Hand Delivered
Overnight Mail
Facsimile
S, Mail
Hand Delivered
Overnight Mail
Facsimile
S, Mail
Hand Delivered
Overnight Mail
Facsimile
S, Mail
Hand Delivered
Overnight Mail
Facsimile
ConI