HomeMy WebLinkAboutBPMC Meeting October 9, 1992 1RECORD UOPY FILE NO
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BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE
“ APPROVED MEETING MINUTES
October 9, 1992
1. CALL TO ORDER
Chairman Highers called the Bradley Lake Hydroelectric Project Management
Committee to order at 10:15 a.m. in the Training Room at Chugach Electric
Association in Anchorage, Alaska to conduct the business of the Committee per
the agenda and the public notice.
2. ROLL CALL
Alaska Energy Authority
Ron Garzini, Designated Alternate Representative
Chugach Electric Association
David L. Highers, Designated Representative and Chairman
Golden Valley Electric Association
Mike Kelly, Designated Representative
City of Seward
Paul Diener, Designated Representative
Homer Electric Association
Norm Story, Designated Representative
Matanuska Electric Association
Ken Ritchey, Designated Representative
Municipal Light & Power
Tom Stahr, Designated Representative
Others Present:
Ron Saxton, Ater, Wynne, Hewitt, Dodson & Skerritt
David Burlingame, Chugach Electric Association
Tom Lovas, Chugach Electric Association
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John Cooley, Chugach Electric Association
Gene Bjornstad, Chugach Electric Association
Bradley Evans, Golden Valley Electric Association
Bob Hufman, AEG&T
Dave Fair, Homer Electric Association
Dave Calvert, City of Seward
Tim McConnell, Municipal Light & Power
Bob Price, Municipal Light & Power
Stanley E. Sieczkowski, Alaska Energy Authority
Larry Wolf, Alaska Energy Authority
Denise Burger, Alaska Energy Authority
Dennis Lewis, Petersburg Municipal Power & Light
3. PUBLIC COMMENT
There being no public comment, the meeting continued to the next agenda item.
4. AGENDA COMMENTS
Item 12 B, APPROVAL OF UTILITY AGREEMENTS, was removed from the
agenda.
5. APPROVAL OF MINUTES - August 24, 1992
Mr. Stahr objected to the inclusion of Attachment 2, Bradley Lake Operations
and Dispatch Summary of Meeting on August 18, 1992 for Bradley Project
Managers' Committee, as part of the approved permanent record of the
August 24, 1992 PMC meeting. Mr. Stahr took exception to the following
statement contained in paragraph eight:
"After a lengthy discussion of scheduling procedures, it was the
consensus of the committee that Bradley was agreed to, by the
managers, to be operated as an energy project."
Mr. Stahr firmly stated that he was not a part of that consensus and that the
utilities had purchased a lot more than energy (i.e. capacity and spin.)
Mr. Kelly, offering his comments on behalf of the remaining utility managers,
agreed that the language used in the summary was incorrect.
Mr. Stahr moved that the Bradley PMC meeting minutes of August 24, 1992 be
approved with the exception of the August 18, 1992 O&D Meeting Summary
(Attachment 2). The motion was seconded by Ron Garzini. Mr. Ritchey
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questioned whether the Bradley PMC had the authority to approve the O&D
Subcommittee meeting summary. Mr. Saxton clarified that if the summary was
an accurate account of the O&D Subcommittee meeting, then the PMC should
not change it, but if the summary was inaccurate, then the O&D Subcommittee,
itself, should change it. Mr. Saxton stated that the Bradley PMC had the right
to disagree with the summary. Responding to Mr. Saxton's comments,
Mr. Sieczkowski confirmed that the relationship of energy and capacity was
discussed at the O&D Subcommittee meeting and that the summary reflected the
discussion.
With the understanding that the BPMC record will reflect the managers'
disapproval of the O&D Subcommittee statement, the August 24, 1992 BPMC
meeting minutes were approved by acclamation.
6. TECHNICAL COORDINATION SUBCOMMITTEE REPORT
Dave Burlingame distributed a report (synopsis) of the TCS meeting held
October 8, 1992 (Attachment 1). Mr. Burlingame informed the PMC that the
DECnet had been installed but had not yet been put into operation.
Mr. Burlingame noted that the SVC work was on schedule (the transformer,
reactors, and buswork had been installed.) The contractor has tentatively
requested an outage of the 115 kV transmission system October 16, 1992 to
hook up the SVC.
It was reported that the reservoir water elevation was significantly lower than
projected for this time. Mr. Burlingame explained that AEA had uncovered a
potential error in the lake level survey which, if verified, contributed to the
lower than anticipated lake level. It was noted that AEA would be issuing a
revised allocation schedule.
Because of the discrepancies between the results of the actual SVC simulator
tests and the Power Technology Incorporated (PTI) prediction, Mr. Burlingame
stated that Stone & Webster Engineering Corporation (SWEC) had been
requested to analyze both the ABB simulator test data and PTI studies. It was
noted that the TCS utility representatives objected to the conclusions of SWEC's
analysis due to the fact that SWEC used outdated PTI data. SWEC will
continue to investigate the problem.
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Mr. Burlingame reported that the TCS had developed possible short term and
long term solutions to the unstable Kenai oscillation problem.! The TCS
approved the implementation of two procedures to resolve the problem when the
Kenai was exporting more than 10 megawatts of power: (1) to automatically
place the unit into deflector mode via SCADA and, (2) to disable the gain
acceleration function within the governor. Mr. Burlingame noted that the
second procedure would slow the needle response time (allowing more time for
system response) resulting in the waste of some water. Mr. Burlingame
reported that no short term solution to the unstable oscillation problem had been
identified for when the Kenai was importing power, or exporting less then 10
megawatts of power. SWEC is investigating possible short term solution
options using the Bradley governor and is concurrently investigating long term
solutions. It was noted that when the Kenai is importing more than 5 megawatts
of power and is islanded, the unstable oscillation will cause the Kenai to go
through all three stages of load shed (effectively resulting in only one stage of
load shed.)
De BUDGET SUBCOMMITTEE REPORT
Mr. Ritchey reported that there had been no official Budget Subcommittee
meetings. However, the RFP for the construction cost audit was nearly ready to
issue and the proposals were expected by the first of November 1992.
Mr. Ritchey noted that the subcommittee would be reviewing a proposal for the
audit of yearly operating expenses. Mr. Saxton stated that the PMC had
authorized the expenditure of funds for the construction cost audit, but not the
yearly operating cost audit. Mr. Ritchey clarified that funds for the yearly
operating cost audit had already been approved as part of the fiscal year budget
and that no additional approval was needed. Mr. Saxton recommended that the
PMC address the upcoming fiscal year budget at the next meeting.
8. AGREEMENT SUBCOMMITTEE REPORT
Mr. Sieczkowski distributed the Agreement List and Assignment Schedule,
Updated October 8, 1992 (Attachment 2). Mr. Sieczkowski reported that HEA
and ABA met October 2, 1992 and discussed the Soldotna Substation
Agreement and Transmission Facilities Maintenance Agreement. New drafts of
the agreements developed at that meeting were currently being reviewed by
HEA, CEA, AEA, and the Agreement Subcommittee members. The
! Unstable oscillations are those oscillations which grow in magnitude once started and do no subside
until either corrective action has been taken or the system has suffered considerable loss of load and/or
generation to obtain stability.
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Agreement Subcommittee was expected to meet later this month to review the
draft agreements. The SVC Maintenance Agreement was currently being
reviewed by the Energy Authority's attorney. In response to inquiry by
Mr. Lovas, Mr. Sieczkowski noted that AEA was presently awaiting receipt of
a revised draft of the Transmission Interconnect Agreement from HEA.
9. OPERATION AND DISPATCH SUBCOMMITTEE REPORT
A summary of the October 2, 1992 O&D Subcommittee meeting was distributed
(Attachment 3). Mr. Sieczkowski highlighted the following topics:
Request for installation of kW metering on the station service system for
better accounting of energy flows.
Annual maintenance of both units scheduled for November 9 - 19, 1992
Modification of the fish water bypass release software program to
improve system response time (in order to avoid violation of FERC
minimum flow requirements.)
Exhibit B, Allocation and Scheduling Procedures acted upon by the
O&D Subcommittee will be presented under "NEW BUSINESS."
Amendment to Allocation and Scheduling Procedures acted upon by the
O&D Subcommittee will be presented under "NEW BUSINESS."
Notification by CEA of a formal agreement between CEA and HEA for
the purchase of scheduling rights (originally misstated as capacity and
allocation at the October 2, 1992 O&D Subcommittee meeting.)
In response to the CEA / HEA agreement, Mr. Sieczkowski stated the O&D
Subcommittee requested clarification of whether HEA still had voting rights on
the Subcommittee since HEA was no longer a scheduling utility. Chairman
Highers pointed out that the Power Sales Agreement included all Bradley Lake
participants (as opposed to scheduling utilities.) Mr. Saxton stated that the
contract did not specify anything about the subcommittees, giving the PMC the
authority to make those rules. Mr. Stahr stated that the utilities had purchased
capacity and energy, not water allocation, further explaining that water
allocation was an operational procedure. Mr. Story took exception to the
language in the last paragraph on page 1 of the October 2, 1992 O&D meeting
summary where it stated that CEA had purchased HEA capacity and water
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allocation. Mr. Story explained that, rather, CEA had purchased HEA
scheduling rights.
Mr. Stahr expressed concern over potential impact (if any) of the CEA / HEA
agreement on the rights of the other purchasing utilities. Mr. Stahr suggested
that the Bradley PMC assure the prevention of any infringement on another
utility's rights or provide a mechanism for review of such agreements by all of
the participating utilities.
Mr. Kelly brought attention to the responsibility for spinning reserve, noting
that CEA had originally taken the position that HEA was required to provide
spinning reserve. Mr. Kelly raised the question of a utility's responsibility to
carry spinning reserve if the utility assigned its scheduling right.
Mr. Fair noted that the spinning reserve issue to which Mr. Kelly referred was a
temporary Intertie Operating Committee (IOC) arrangement that would dissolve
on January 1, 1993. Mr. Fair informed the PMC that HEA was preparing a
letter explaining the HEA agreement with CEA. Mr. Fair explained that the
agreement was a scheduling agreement and did not impact the "rights,
obligation, cost, payment, etc. in relation to AEG&T's share of Bradley Lake
associated HEA participation." Mr. Fair reiterated that HEA had only sold its
right to schedule, noting HEA purposely avoided a power sale, kilowatt hour
sale, or kilowatt sale.
Mr. Kelly again questioned HEA's spinning reserve requirement stating that the
issue of spinning reserve was "hooked" to the issue of scheduling and
participant voting rights. Mr. Fair stated that HEA's spinning reserve
requirement was taken care of by the agreement with CEA.? Mr. Fair further
stated that HEA had no intent to modify its participation in the Bradley Lake
Project. Mr. Kelly stated that if HEA was no longer obligated to spin, it would
have an impact on the other participants. Mr. Lovas clarified that CEA's
agreement with HEA pooled the resources of both utilities similar to its
agreements with SES and MEA.
Mr. Burlingame re-focused the discussion on the question raised at the
October 2, 1992 O&D Subcommittee meeting regarding Bradley Lake
participant voting rights. Mr. Burlingame phrased the following question:
"Does CEA have the right to schedule 57% of the project, or does CEA
2 Mr. Stahr later stated that, by his interpretation of the Alaska Intertie Agreement, only utility
participants had spinning reserve obligations (i.e. Eklutna and AEA have no spin obligations.)
Mr. Lovas also confirmed this interpretation, stating that the generating utility (representing a pool of
resources) was responsible for the spin obligation (i.e. CEA picked up the spin requirement for HEA.)
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schedule 31% + 12% + 13% + 1% of the project?" Mr. McConnell noted
that it depended on which way CEA dispatched, explaining that if all the water
of all the participants was depleted in proportion to their project share, there
was no difference. If CEA however used all of one utility's share but still
claimed 57% (for apportioning spin), there would be a "dramatic difference."
Mr. Burlingame stated that the Allocation and Scheduling Procedure does not
state that CEA must draw all shares down equally and pointed out that there
were no operating restraints defined in the Allocation and Scheduling
Procedure. Mr. Burlingame stated each utility would incur spinning reserve
obligation if the participant shares were treated in an additive manner (i.e. 31%,
12%, 13% and 1%.) Mr. Kelly expressed concern over the possibility that
utilities could avoid the spinning reserve requirement. Mr. Lovas noted that the
combined spinning reserve obligation was not reduced, and that it was an
allocation problem as opposed to an electrical problem.
It was the general consensus of the PMC that a determination of the effect of the
CEA / HEA agreement could not be made without further review of the actual
contract or a contract summary. Mr. Lovas informed the Committee that the
scheduling agreement would become public information within the next few
days when it was filed as part of (APUC) Docket U 92-25. Mr. Stahr moved
that no change be made to the voting rights and membership in the PMC
subcommittees, and that the "status quo" be maintained. The motion passed by
a. unanimous roll call vote.
Mr. Kelly asked Mr. Saxton to research answers to the following questions:
i Does Bradley require spin?
2: Do the arrangements between SES and MEA and CEA effect
their spin requirement?
3. Does the new HEA / CEA arrangement effect their spin
requirement?
Mr. Fair pointed out that there is no spinning reserve obligation imposed by any
of the Bradley Lake agreements, stating that it was an IOC issue.
Mr. Burlingame clarified that, for now, CEA was carrying the extra spin.
Mr. Burlingame, referring to the motion, asked if the "status quo" meant that
CEA then operated 57% of the project. Mr. Burlingame explained that CEA
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11,
would provide some water allocation to each participant that CEA scheduled for
and would carry each participants spin obligation. Mr. Burlingame added that
the water share of participants CEA scheduled for would not be depleted in
proportion to their project share. Mr. McConnell noted that if the water was
depleted at rates determined by CEA, entitlement to capacity and entitlement to
spin changes dramatically. Mr. Burlingame disagreed, stating that CEA had
never operated according to proportion of share.
Mr. Stahr recommended that spin obligation and the selling of spin also be
researched.
Chairman Highers, citing the need to have several questions answered, asked
Mr. Saxton to provide this information to the PMC. To ensure a response to all
issues, Mr. Saxton responded with a plan to first put together a list of the
questions that had been raised for review by the managers.
A. BRADLEY SCHEDULING VS. SPIN REQUIREMENT
This item was included in the discussion of Item 9, OPERATION AND
DISPATCH SUBCOMMITTEE REPORT.
REVIEW OF PROJECT STATUS
In the absence of Dave Eberle, Mr. Wolf noted that information regarding
project status was presented in the TCS report to the Committee (Item 6).
OLD BUSINESS
A. SPINNING RESERVES/UNDER FREQUENCY LOAD SHEDDING -
UPDATE
Mr. Lovas reported that the ASCC had met the day before and was
continuing to make progress in its discussions of spinning reserve and
load shed. The ASCC discussed the use of utility staff to perform
technical studies and concluded that it was more timely and cost effective
than using consultants. Mr. Lovas informed the PMC that the Intertie
Subcommittee was close to finalizing a load shedding schedule proposal
and that the ASCC had approved a $159,000 budget for the Reliability
Criteria Subcommittee's work.
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13. | NEW BUSINESS
A. APPROVAL OF COMMITTEE EXPENSES
Noting that documentation of the current expenses had been submitted to
Brent Petrie, Mr. Saxton stated that future Committee expenses should
be forward to Ken Ritchey (Chairman of the Budget Subcommittee).
Mr. Saxton presented the following expenses to the PMC for approval:
Homer Electric: $228.84 for TCS work
$544.87 for PMC related activities
Ater Wynne: $23,760 for July, August, and September legal
expenses
Mr. Saxton noted that the remainder of Section 31 funds would be
depleted and a portion of these expenses would come directly from the
Committee budget. Mike Kelly moved to approve the submitted
expenses. The motion, seconded by Norm Story, was approved by
unanimous roll call vote.
APPROVAL OF UTILITY AGREEMENTS
Deleted from the agenda.
APPROVAL OF AMENDED ALLOCATION AND SCHEDULING
PROCEDURES
Mr. Sieczkowski distributed a revision to Section 5 of the Allocation and
Scheduling Procedure (Attachment 4) and recommended action by the
PMC. Additionally, Mr. Sieczkowski distributed a copy of the Exhibit
B language to the Allocation and Scheduling Procedure (Attachment 5)
and recommended that the PMC review it for consideration at the next
meeting. Mr. Kelly moved that the Section 5 revision be approved.
Ken Ritchey seconded the motion.? Mr. Stahr asked if the proposed
amendment would result in increased lead time on the scheduling. In
response to Mr. Sieczkowski's answer that it would, Mr. Stahr
expressed his opposition, stating that there was too much lead time now.
3 No action was taken on this motion.
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Mr. Burlingame disagreed and pointed out daily changes could still be
made to the schedule.
Mr. Kelly motioned, seconded by Mr. Stahr to table the previous motion
until the next PMC meeting and allow CEA to implement the revised
procedure in the manner described until then. The motion was approved
by a unanimous roll call vote.
HISTORICAL REVIEW OF PMC ACTIONS
Mr. Saxton noted that a list of PMC actions delegating assignments to
various subcommittees had been prepared and previously distributed to
the utility managers (Attachment 6). It was noted that the
subcommittees had not been given any authority to act independently of
the PMC.
14. COMMUNICATIONS
Mr. Kelly informed the PMC that Mr. Brad Evans had been appointed GVEA's
alternate representative to the PMC.
A. SCHEDULE NEXT MEETING
Friday, November 20, 1992
10:00 a.m.
CEA Training Room
15. ADJOURNMENT
There being no further business before the committee, the meeting adjourned at
11:45 .m.
Gut Go tor— ttest:
ie Ronald A. Garzini, Designated Alternate Representative
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10.
11.
12.
BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE
October 9, 1992
Chugach Electric Association, Inc. Training Room
10:00 a.m.
CALL TO ORDER 10:00 a.m.
ROLL CALL
PUBLIC COMMENT
AGENDA COMMENTS
APPROVAL OF MEETING MINUTES - August 24, 1992
TECHNICAL COORDINATING SUBCOMMITTEE REPORT
BUDGET SUBCOMMITTEE REPORT
A. Bradley Lake Construction Cost Review - Update
B. FY93 Budget, AEA Administrative Costs - Update
AGREEMENTS SUBCOMMITTEE REPORT
OPERATION AND DISPATCH SUBCOMMITTEE REPORT
A. Bradley Scheduling vs. Spin Requirements
REVIEW OF PROJECT STATUS
OLD BUSINESS
A. Spinning Reserves/Under Frequency Load Shedding Update
NEW BUSINESS
A. Approval of Committee Expenses (nest wot.) — 8 Aiea ot ily Agremcnty—
13.
14,
Cc. Approval of Amended Allocation & Scheduling Procedures
D. Historical Review of PMC Actions
COMMUNICATIONS
A. Schedule Next Meeting
ADJOURNMENT
RECORD VOPY
FILE NO
RO 3-b! ww
10/9 /4a
Highers
Burlingame
Ritchey
Sieczkowski
Sieczkowski
Kelly
Eberle
Lovas
Petrie
Sieczkowski
Sieczkowski
Saxton
BRADLEY LAKE FY93 BUDGET
FERC ACCOUNT Acct. ACCOUNT DESCRIPTION COMMENT TOTAL HYDRAULI
ay POWER GENERATIO
535 Operation Supervision and Engineering _ Supervision, Engineering and Administrative Support - 3.2 FTE 257,926 257,926
537 Lea Operation Expenses Inspection of Three Diversions 6,000]
‘Snow measurement, SCS 20,000]
Siesmic Monitoring, UAF 50,000
Climatologic - NOAA Weather Service 5,460
Semi-Annual Dam Settlement Survey 2,000
Conservation Studies for Fish and Game 18,000)
101,460
538 Electric Operation Expense SCADA Technical Maintenance 25,000
Powerplant Operations - .4 FTE 42,000,
‘Supplies 15,000
82,000
539 Hydraulic Power Generation Operation Expense Mechanical vibration and balance testing, consumables such as oil and filters, die checks 20,000 20,000
and pressure nitrogen cylinder recharges.
540.1 Transportation Helicopter Transportation for Project Facility Inspections 91,000)
Barge Rental to Transport Materials and Dock Fees 27,500
Project Site Contract Transportation - Scheduled Fixed Wing Service to Site 70,000:
Commercial Transportation 14,400 |Safety Technical and-Operations Training 14,000 |Maintenance Management System Software Upgrade Modification and Training _ 4,000
|Communications Divcom Maintenance Fee 40,000 | Project radios, pagers, and telephones 6,000 | 266,900
542 Maintenance of Structures Routine Supplies, Materials and Maintenance Items 60,000: 60,000:
Page i\ of 3 FY93BUDB.XLS 1:41 PM 8/24/92 T LN3WHOVLLY
BRADLEY LAKE FY93 BUDGET
RODIN DESCRIPTION
544 Maintenance of Electric Plant Electrical Spare Parts
Contract Labor for Testing Protective and Revenue Meters, Generators, Transformers,
70,000)
545 Maintenance of Misc. Hydraulic Plant
_}
45,000
545.1 __|Maintenance of Hydraulic Plant 392,000
547 Fuel Stock Fuel for Bradley Vehicles, Loaders, Graders 40,000
556 |System Control and Load Dispatching Labor - CEA 1 FTE Training - CEA Dispatchers Economic Dispatch Program (10 yr. Armortization ) - CEA
Bradley Junction Substation Switchyard Inspection and Tests - HEA
Maintenance of Overhead Lines
ADMINISTRATIVE, GENERAL AND
EXPENSES
‘Transmission Line Inspection and Maintenance - HEA
39,000
Administration and General Expenses |a. Bradley PMC Costs
| _ PMC Travel Cost 6 PMC Meetings each year in Anchorage
Subcommittee Travel Cost 12 Subcommittee Meeting each year
Meeting General Expenses PMC Adminstrative Support
Litigation Expenses
81,000
b. Administration Expe
AEA Administrative and General Costs
Page of 3
396,011
FY93BUDB.XLS 1:43 PM 8/24/92
BRADLEY LAKE FY93 BUDGET
ACCOUNT DESCRIPTION
Contract Services
a, Legal Attorney Fees (AEA & Utilities) 10,000
b. Project Audit Professional Audit Services 15,000
25,000
Insurance a, Property $IM Deductible 160,824
b. Boiler and Machinery $50K Deductible 50,000:
c. General Liability One-Sixth of AEA State Policy Premium 10,000
d, Watercraft & Aviation One Sixth of AEA State Policy Premium 10,000)
e. Directors and Officers Liability Liability Insurance for the Directors and Officers of the PMC 15,000
245,824
928 Regulatory Commission Expenses
a, FERC
Land Use Fees FY92 Billing $97,000
Administrative Fees Estimate USGS Streamgaging
Five Year Inspection Engineering Consultant (est. $75,000 in FY96)
b. Permitting AEA Permits Specialist
TOTAL FY93 BRADLEY O&M BUDGET
Page3 of 3 FY93BUDB.XLS 1:43 PM 8/24/92
ATTACHMENT 2
Bradley Lake Operations and Dispatch
Summary of Meeting on August 18, 1992 for Bradley Project Manager's Committee
Correspondence - received for discussion of Scheduling Procedures, Spinning Reserve, Bradley
Lake Project Summary Reports, Operational Procedures and Allocation Update.
Operation - the lake elevation was 1139.2 ft. on August 17. Inflow is beginning to slow down.
45,680 MWH was delivered during July.
The communication, DECNet and SCADA systems were being worked on by project and
contract personnel.
There was an outage on August 13. Unit one tripped off-line. This problem was detected when the project was islanded. Load changes, under this condition, greater than 1/2 MW/minute
creates problems in the system. This problem is being investigated.
Increased unit start-stops have caused other control problems to surface that previously were not
detected in the synch circuits.
The Division of Information will be requested to initiate the dispatcher ring down circuit upon
receipt of approval and transfer of funds.
The storing water criteria need committee review and input and will be presented at the next
meeting for discussion.
After a lengthy discussion of scheduling procedures, it was the consensus of the committee that
Bradley was agreed to, by the managers, to be operated as an energy project. The declared
capability versus project capacity causes difficulty at times in scheduling, therefore, this philosophy may need to be revisited if capacity becomes an issue.
To accomodate the scheduling issue, there were two motions passed which are summarized:
1. Utilities scheduling above their 9OMW sfare willbe cut back proportionately to 9OMW for unit trips or system emergencies. Under normal load changes, the approved schedule
will not be allowed to change;
2: The utilities will submit a weekly schedule by Tuesday, reviewed on Wednesday, confirmed by Thursday and implemented on Saturday at 0001 hours.
Spinning reserve calculation methods were discussed. Chugach Electric Association (CEA) provided an example of a proposed method. The discussion addressed the issue of being able to
use an utilities capacity when they committed that capacity to another utility. This led to an unresolved problem in the O&D. There was a motion to refer this issue to the Bradley PMC.
The method suggested by CEA to calculate the spinning reserve was accepted by the O&D noting
that the method of calculation only was approved.
Annual maintenance on the Bradley units was discussed and the schedule will be coordinated with
the participating utilities.
The next meeting is set for September 15, 1992.
92Q3\IT3449(1) Page | of |
ATTACHMENT 1
CHUGACH ELECTRIC ASSOCIATION, INC.
Anchorage, Alaska
October 8, 1992
TO: Bradley Lake PMC
FROM: David W. Burlingame, TCS Secretary
SUBJECT: TCS Meeting Report
The following is a synopsis of the TCS meeting held on October 8,
1992.
SCADA SubCommittee has reviewed the DECNET installation at Bradley
Lake. SWEC is waiting for the final points list to be received
from Golden Valley and AML&P prior to implementing. SWEC has
requested Landys & Gyr investigate alternative methods of supplying
HEA with requested information other than the present design.
Svc Project Status - The transformers at both sites are installed,
reactors installed, switches and buswork installed and the valves
are on-site. The Daves Creek SVC is tentatively scheduled to be
connected to the power system October 16, 1992. The SVC is not
scheduled to begin any testing until November.
Bradley Lake Water Elevation - The water elevation is down
significantly and project allocations are expected to be adjusted
downward. SWEC/AEA found an error in the field survey which
resulted in the water elevation at the dam being reported 2' lower
than it actually is.
svc Simulator Studies - SWEC presented an analysis of the analog
and digital simulator studies ABB performed at AEA's request. The
studies were performed due to the apparent discrepancy between the
stability numbers found by ABB in their initial tests and the PTI
numbers we are operating under. The utilities objected to the SWEC
conclusion as SWEC was using numbers from a superseded PTI study
and the not the numbers currently in use. SWEC will investigate
further. SWEC was requested to run an additional case to ascertain
the stability limit after the SvC's are installed as this now
appears to be in question.
Kenai Oscillations - SWEC presented its findings an the cause of
the Kenai oscillations and the recommended short term solutions.
The committee accepted two of the recommendations with motions as
follows:
Motion 1 - Move to put one Bradley Lake unit in deflector
automatically as soon as possible via Chugach's SCADA control upon
detection of islanding to prevent or mitigate Kenai frequency
oscillations.
The above action has previously been implemented by Chugach and
according to the SWEC studies, should prevent oscillation during
those times when the Kenai is exporting more than 10 MW of power.
Motion 2 - Move to disable the gain acceleration function within
the Bradley governor to allow more time before the needle valve and
deflectors equalize and begin the Kenai system frequency
oscillations.
The above action will be implemented by SWEC as soon as possible.
The only detriment to the above is a small amount of water that is
wasted on overfrequency conditions since it slows down the time it
takes for the needles to close and match the deflectors, ie the
units are running on their deflectors for a slightly longer period
of time.
The committee has not been able to identify any short term
solutions which mitigate the Kenai loadshedding during import
conditions. SWEC estimates that any import more than 5 MW will
result in total Kenai loadshedding.
SWEC was asked to investigate the possibility of automatically
tripping a unit to deflector control on overfrequency as opposed to
waiting for SCADA control. This may help the Kenai avoid further
loadshedding during import conditions.
SWEC recommended disabling AGC control for Bradley Lake during
transient period immediately after islanding. Chugach will
investigate and implement if possible.
SWEC will investigate the possible long term solutions including
the installation of a new governor control mode at Bradley Lake,
new intertie, batteries, surge tanks etc.
ATTACHMENT 2
BRADLEY LAKE AGREEMENTS SUBCOMMITTEE
AGREEMENT LIST AND ASSIGNMENT SCHEDULE
UPDATED: October 8, 1992
COMPLETION Organiz- AGREEMENTS DRAFT DATE DATE RESPONSIBILITY ation
Dispatch Agreement 3-6-91 2-19-92 Tom Lovas CEA between AEA and CEA 6-19-91 S. Sieczkowski AEA
9-4-91
Maintenance S. Sieczkowski AEA Agreement between Sam Mathews HEA AEA and Maintenance
Contractor
Transmission Facilities 04/05/89 Sam Mathews HEA Maintenance 08/06/89 S. Sieczkowski AEA
Agreement between 09/13/91
AEA and HEA 11/08/91
03/03/92
05/15/92
08/21/92
10/05/92
Allocation and 09/15/89 7/2/91 S. Sieczkowski AEA Scheduling Procedures 10/90 O&D Members Utilities Exhibit A 12/91 3/92
Exhibit B 10/92 12/91
Exhibit C 11/91 12/91
Exhibit D 11/91
Deleted
Transmission 06/21/91 Sam Mathews HEA
Interconnect 11/08/91 Stan Sieczkowski AEA Agreement between 03/02/92
AEA and HEA 05/18/92
Communications 9/92 Afzal Khan AEA Equipment MOU
between AEA and Div
of Infor
Soldotna #1 Dispatch Done + Sam Mathews HEA Agreement between
CEA and HEA
Transmission 3/7/89 Sam Mathews HEA Capability Agreement
between HEA and
CEA, ML&P, AEG&T,
GVEA
4 Dare not avai bole
bradagre/ds9/91
10.
Ly;
12.
13.
14,
15.
AGREEMENTS
Power Sales Agreement
between AEA, & CEA,
GVEA, ML&P,
AEG&T, HEA, City of
Seward
Wheeling of Electric
Power (Services
Agreement) between
CEA & HEA, GVEA,
MEA ML&P, AEG&T,
Seward
Static Var
Compensator Systems
at Daves Creek and
Soldotna Maintenance
Agreement between
AEA and CEA
Daves Creek Substation
Soldotna Substation
Right of Entry
Agreement between
AEA and HEA
Power Revenue Bond
Resolution
DRAFT DATE
1/92
2/92
8/91
11/8/91
3/2/92
8/91
11/08/91
03/02/92
03/27/92
05/18/92
08/06/92
08/21/92
10/02/92
COMPLETION
DATE
12/8/87
12/8/87
3/92
9/7/89
RESPONSIBILITY
Afzal Khan
D. Burlingame
S.Sieczkowski
D. Burlingame
S. Sieczkowski
Sam Mathews
D. Burlingame
AEA
ORGANI ZATION
AEA
CEA
AEA
CEA
AEA
HEA
CEA
ATTACHMENT 3
BRADLEY LAKE HYDROELECTRIC PROJECT OPERATION AND DISPATCH SUBCOMMITTEE
OCTOBER 2, 1992 MEETING
SUMMARY
BRADLEY PR‘ T OPERATION
The Chugach Electric Association (CEA) dispatcher was requested to provide the
generation schedule to the plant maintenance personnel. This will assist in maintenance scheduling to reduce conflicts and enable maintenance to be coordinated with dispatchers.
Additional KWH metering on the station service system is desired for Bradley energy accountability. The weather station communications are still being put into service because new crystals were required. Deflector mode operating tests are scheduled for
November 7 and 8, 1992. This is part of the investigation to determine why the
oscillation occurred after islanding on the Kenai.
Annual maintenance of the project units is scheduled for November 9-19, 1992.
The fish releases require close monitoring. A software revision is necessary to prevent dropping below minimum required flows, Because of the four hour time lag from release at the dam and the recording of the flow at the lower Bradley River Gaging Station.
Alaska Energy Authority (AEA) utilities and Division of Information Services (DIS) are
working to complete installation of project communications. There is still a gap in direct
communications from the dispatcher's with personnel in the field. This needs to be
resolved so the switchmen can be contacted directly by the dispatchers. Homer Electric
Association (HEA), CEA, AEA and DIS are working to correct this problem.
COMMITTEE DI ION AND ACTION:
The committee took action to recommend "Approval of the Allocation and Scheduling
Procedures, Exhibit B Language, Presented in the CEA September 12, 1992 Memo as Modified." (Copy attached)
The "Storing Water Criteria" proposal was presented and discussed. A discrepancy arose
when the generation projections were presented. There was a substantial acre-foot storage accounting error in addition to a two foot transducer level indication error detected this past week. This discrepancy will be resolved and the projections updated for the dispatchers. The committee is to review the Storing Water Criteria proposal and
discuss at the next meeting.
Operating the Bradley Lake units in condenser mode was discussed. The consensus of the
committee was to continue operating the system without running the unit in condenser mode unless requested by a utility. The project will continue to be operated according to
established procedures and approved criteria.
CEA and HEA have formalized an agreement for CEA to purchase HEA capacity and water allocation. Discussion followed and it was noted that clarification was needed from
the Bradley Project Management Committee (BPMC) regarding HEA's spinning reserve
obligation.
92Q4\NK3718(1) Page | of 2
Summary of October 2, 1992
Operation & Dispatch Subcommittee Meeting
October 8, 1992
Another issue arose when this was discussed. "Since CEA has HEA's capacity and water allocation, and is therefore no longer a scheduling utility, does HEA have the right to vote on issues within the Operation and Dispatch subcommittee." This issue needs clarification from BPMC.
SS:nk
Attachment as Stated.
92Q4\NK3718(2) Page 2 of 2
DATE:
TO:
FROM:
SUBJECT:
ATTACHMENT 4
Alaska Energy Authority
MEMORANDUM
October 8, 1992
Bradley Lake Hydroelectric Project
Project Management Committee
Stanley E. Sieczkowski eal
Director Facilities Operation and Engineering
Alaska Energy Authority
Revised Allocation and Scheduling Procedure
The following revision to the Bradley Lake Allocation and Scheduling
Procedure was approved for recommendation to the Bradley PMC at the
August 18, 1992 Operations and Dispatch Subcommittee meeting:
"In the interim, Section 5, Project Scheduling, (b), Hourly
Schedules of the Allocation and Scheduling Procedures, revised
November 19, 1991 shall be changed to:
The utilities' weekly schedule shall be submitted to the dispatcher
no later than 1400 hours on Tuesday; a preliminary summary of
schedule requests shall be distributed to all utilities no later than
1400 hours on Wednesday for review; the schedule shall be
confirmed by the dispatcher no later than 1400 hours on
Thursday; and implemented at 0001 hours on Saturday. (The
energy week is established to be Saturday to Friday.)"
The motion passed by unanimous roll call vote.
DB:SES:db
ce: Ronald A. Garzini, Alaska Energy Authority
Brent N. Petrie, Alaska Energy Authority
DATE:
TO:
FROM:
SUBJECT:
Alaska Energy Authority
MEMORANDUM
October 8, 1992
Bradley Lake Hydroelectric Project
Project Management Committee
Stanley E. Sieczkowski -
Director Facilities Operation and Engineering
Alaska Energy Authority
Exhibit B - Allocation and Scheduling Procedure
Exhibit B of the Bradley Lake Allocation and Scheduling
Procedure was approved for recommendation to the Bradley
PMC at the October 2, 1992 Operations and Dispatch
Subcommittee meeting.
Attached is a copy of the approved Exhibit B for your
consideration.
DB:SES:db
cc: Ronald A. Garzini, Alaska Energy Authority
Brent N. Petrie, Alaska Energy Authority
ATTACHMENT 5
10/06/92 16:55 39077624540 CEA DISPATCH CTR Hoo2
Exhibit B
The following sections are intended to replace the existing
schedule B in the Allocations and Scheduling Procedures
Turbine Operation
The following schedule shall be used to determine the operation of the Bradley Lake generators, assuming both units are available for operation:
Plant Schedule (MW) Speed Mode Condense Mode Notes
Schedule< 10 MW no units none, one or both
units #1
10 MW<schedule <20 MW one unit one unit #2
20 MW <schedule < 30 one unit one unit/no unit #3
Schedule > 30 MW both units no units
Notes #1 - If any participant could utilize the spinning reserve
from a unit or a second unit in the condense mode, one or both
units will be operated in condense. If no utility requests the
additional spinning reserve, only one unit will be operated in
condense if required for voltage control unless a unit is changed
to condense to avoid a shutdown.
Notes #2 - depending on spin requirements, either one unit will be
operated alone in the speed mode or both units will be operated,
ene in speed and one in the condense mode. A utility can request
the unit be operated in the condense mode as opposed to altering
its schedule if in conflict with the minimum 4 hour down time.
Note #3 - any scheduling utility can require both units to he Placed on-line between 20 and 30 MW if desired by that utility,
although it would be possible to operate one unit in speed and one
unit in condense mode at these levels to obtain the entire spinning
reserve allocation for the plant, the more efficient operation would be for both units to be operated above 10 MW each in speed
mode.
10/06/92 16:55 39077624540 CEA DISPATCH CTR oo03
Minimum Unit Shut Down
Each unit scheduled for shutdown shall be shut down for a minimum of 4 hours. Operation of a unit in the condense mode will not constitute a shut down and does not have a 4 hour minimum time associated with it.
The following criteria shall generally govern the operation of the plant during islanded and non-islanded conditions;
Islanded Operation
Unscheduled Tslanding
If the Kenai is operating with only Bradley Lake or Bradley Lake and Cooper Lake prior to islanding, one Bradley Lake unit will automatically be placed in deflector by the Chugach scada system upon detection of islanding. The unit will remain in deflector until a Kenai area gas turbine has been synchronized with the islanded Kenai system.
After a gas turbine has been synchronized with the Kenai system the unit will be changed to the speed mode from the deflector mode.
During load restoration on the Kenai, one unit may be placed in deflector control to aid the gas turbine in load pickup and
frequency restoration. The unit will be returned to speed mode
after restoration has been completed.
Scheduled Islanding
Prior to scheduled islanding a Kenai area gas fired generator will
be synchronized with the Kenai system. Bradley generation will remain in the speed mode.
on - Ss
While running islanded, a gas-fired generator shall be operated in conjunction with Bradley Lake. The Bradley Lake units shall he operated in the speed mode.
If an on-line gas-fired turbine suffers a forced outage and it is
the only gas-fired unit on-line in the islanded system , one Bradley Lake unit shall be placed in deflector mode and operated in
deflector until a gas-fired generator is placed on-line in the islanded area.
10/06/92 16:56 9077624540 CEA DISPATCH CTR @oo4
Interconnected Operation - Steady State
While Bradley Lake is interconnected to the Anchorage system, its
normal mode of operation shall be the speed mode for both units.
During times of system load restoration, one Bradley Lake unit may be placed in the deflector mode if the amount of load to be
restored will not exceed the export or operating limits of the
Kenai systen.
ATER WYNNE
HEWITT
DODSON
& SKERRITT
ATTORNEYS AT LAW
MEMORANDUM
TO: Bradley PMC Representatives
FROM: Ron Saxton
DATE: October 6, 1992
RE: Duties Assigned to Subcommittees
ATTACHMENT 6
Suite 1800
222 SW. Columbia
Portland, Oregon 97201-6618
(503) 226-1191
Fax (503) 226-0079
In response to a request at our last BPMC meeting to outline
the assignments delegated to the various subcommittees, I had my
legal assistant (Liz Westby) review the BPMC meeting minutes from
1989 to present and prepare the attached list of tasks.
Note that some of the tasks have been completed, but are
included on the list for your reference.
Distribution: BPMC Utility Managers
Paul Diener, City of Seward
Ken Ritchey, MEA
Dave Highers, CEA Norm Story, HEA
Mike Kelly, GVEA
Tom Stahr, ML&P
ACA
j= ae. \>ReV t
ot teal
Seattle, Washington Washington, D.C. San Francisco, California
(206) 623-4711 (202) 785-0303 (415) 421-4143
Fax (206) 467-8406 Fax (202) 785-8676 Fax (415) 989-1263
Affiliated offices in
Anchorage, Fairbanks
and Juneau, Alaska
TO: Ron Saxton
FROM: Liz Westby
DATE: October 6, 1992
RE: Duties Assigned to the Bradley Lake PMC Subcommittees
The following are tasks assigned to the Bradley Lake PMC Subcommittees
(as referenced in the meeting minutes).
AGREEMENTS SUBCOMMITTEE
Tasks:
e Look at other agreements for consolidation and coverage.
(Minutes 7/2/91, p. 4)
e Review Dispatch Agreement. (Minutes 11/19/91, p. 3)
e Update Allocation and Scheduling Agreement Exhibits C and D.
(Minutes 1/13/92, p. 3)
e Work on Maintenance and Right of Way Agreements with Homer,
(Minutes 1/13/92, p. 3)
e Review and follow-up on:
- Allocation and Scheduling Agreement Exhibit A
- Dispatch Agreement
- Transmission Facility Maintenance
- Facilities Interconnected Dispatch
- Communications MOU
- SVCS Draft Agreement
- Daves Creek Substation
~ Soldotna Substation (Minutes 3/26/92, p. 4)
BUDGET (AND FINANCE) SUBCOMMITTEE
Tasks:
Develop draft definitions of Project (construction) costs versus utility
costs. (Minutes 7/28/89, p. 4)
Establish uniform accounting procedures for utility cost
reimbursement. (Minutes 7/28/89, p. 4)
Review issues:
- cash flow timing;
~ budget revisions subsequent to budget adoption;
- reserve accounting;
~ AEA staffing and overhead costs;
- transmission costs;
- environmental studies costs;
- Intertie budget component. (Minutes 2/27/90, p. 3-4)
Review issues:
~ HEA Transmission Line Maintenance;
- AEA Costs;
- CEA Software;
~ Dispatching labor costs. (Minutes 5/17/90, p. 4-5)
Review of CEA and HEA Wheeling Agreement costs, and
insurance. (Minutes 5/17/90, p. 6)
Address the sinking fund payment that SWEC came up with for the
scheduled maintenance and replacement of equipment.
(Minutes 7/17/90, p. 8)
Look at Homer Electric O&M expenses for the transmission line.
(Minutes 7/2/91, p. 3)
Analysis and discussion of (1) payments to the trustee to eliminate
the cashflow problem, and (2) timing of payments. (Minutes
7/2/91, p.4)
Prepare FY93 budget. (Minutes 11/19/91, p. 2)
Resolve wheeling issue with HEA. (Minutes 1/13/92, p. 2)
INSURANCE SUBCOMMITTEE
Tasks:
Review need for formal risk assessment of Bradley Lake Project
required by insurers in order to develop quotes for property
insurance. (Minutes 5/4/89, p. 3)
Inventory types of insurance required, such as business interruption
Insurance. (Minutes 6/8/89, p. 5)
Review of possibility of pooled insurance coverage with the Alaska
Intertie and/or Four Dam Pool. (Minutes 10/19/89, p. 5)
Prepare insurance alternatives for the budget. (Minutes 11/30/89,
p. 3)
Consideration of errors and omissions insurance for SWEC. (Minutes
11/30/89, p. 3)
Review Stone & Webster Risk Management Report. (Minutes
4/6/90, p. 3)
Review property insurance premium quotes from the Division of
Risk Management. (Minutes 11/28/90, p. 2)
Look (to Corroon & Black) for a provider interested In providing
boiler and machinery as well as business interruption insurance.
(Minutes 6/6/91, p. 5)
Look at coverage of debt service payment and operation and
maintenance debt service for at least one year. (Minutes 6/6/91,
p. 5-6)
Request quotes on insurance premiums. (Minutes 10/25/91, p. 3)
Review shop and crew facilities insurance coverage. (Minutes
4/28/92, p. 2)
Review options and present recommendations for the level and
types of insurance, including an option of not renewing the
insurance (self-insurance), extra insurance, and not increasing the
contingency fund. (Minutes 4/28/92, p. 3)
OPERATING AND DISPATCH AGREEMENT SUBCOMMITTEE
Engage services of a consultant to assist with drafting language for
the Allocation and Scheduling Agreement. (Minutes 5/4/89, p. 6)
Draft Bradley Lake Allocation and Scheduling Agreement.
(Minutes 10/19/89, p. 5)
Develop agreements and distribute to members. Agreements
include:
- Dispatch Agreement between AEA and CEA
= Maintenance Agreement between AEA and Maintenance
Contractor
- Transmission Facilities Maintenance Agreement between
AEA and HEA
- Participants Allocation & Scheduling Agreement
- Substation Maintenance Agreement between AEA and HEA
- Joint Operations Agreement between CEA and HEA
~ Communications Equipment Agreement between AEA and
Division of Telecommunications
- Soldotna #1 Dispatch Agreement between CEA and AEG&T
(Minutes 7/28/89, p. 4)
Select a representative to review and provide comments on the
Four Dam Pool draft technical standards. (Minutes 7/28/89, p. 6)
Review of presentations on project hydrology, turbine efficiencies
and reservoir model for forecasting reservoir inflow and utility
demands. (Minutes 1/18/90, p. 5)
Review of draft Dispatch Agreement. Work on 2 issues: (1)
spinning reserve, and (2) losses on the Homer transmission system.
(Minutes 2/27/90, p. 4)
Review results of SWEC model on spill allocation. (Minutes 4/6/90,
p. 5)
Discuss the Allocation and Scheduling Draft Agreement, the
operation of the transmission line after Homer Electric has
completed their construction. (Minutes 3/5/91, p. 5)
Determine the allocation method to be used for Bradley Lake
power prior to commercial operation. (Minutes 3/5/91, p. 6)
offs
TECHNICAL COORDINATING SUBCOMMITTEE
Develop a method for tracking and accounting for costs
associated with dispatching during generation tests from Bradley
Lake. (Minutes 6/6/91, p. 2)
Discuss load restoration procedures, loss and billing procedures.
(Minutes 6/6/91, p. 4)
Develop procedures to allow the Bradley participants to readily
note or record Chugach's service needs for Kenai area
combustion turbine versus those conditions of providing
combustion turbine to support the operation of Bradley Lake.
(Minutes 7/2/91, p. 3)
Review comments on Dispatch Agreement and reservoir model.
(Minutes 11/19/91, p. 3)
Meet and discuss maintenance and outage schedule with
dispatchers. (Minutes 11/19/91, p. 3)
Continue work on Allocation and Scheduling Agreement, Dispatch
Agreement, Transmission Maintenance Agreement, Facilities
Interconnected Agreement. (Minutes 2/28/92, p. 3)
Participate in National Weather Service demonstration (to aid in
allocation). (Minutes 2/28/92, p. 4)
Review of SCADA communications problem. (Minutes 3/26/92, p.
5)
Review and make recommendations on Bradley Lake project
start-up charges. (Minutes 3/26/92 p. 7)
Discussion of common ring-down circuit and communications
problems. (Minutes 6/16/92, p. 5)
Develop draft operation and maintenance definitions and
responsibilities. (Minutes 8/29/88, p. 4)
Appoint a member to serve on the Power Authority Configuration
Control Board. (Minutes 9/27/88, p. 2)
=5
Meet with SEI regarding their assessment of reliability of the Bradley
Junction to Fritz Creek transmission line. (Minutes 1/20/89, p. 2)
PTI presentation on Phase II Stability and Reliability. (Minutes 3/3/89, p. 2)
Review bids for SCADA system. (Minutes 3/3/89, p. 2)
Make presentation to PMC regarding proposed PTI 115 kv
additions. (Minutes 4/6/89, p. 2)
Review scope of work for system stability studies prepared by
SWEC and proposal from PTI to complete additional stability work.
(Minutes 6/8/89, p, 3)
Review of software program DECNET. (Minutes 6/8/89, p. 3)
Continue review of stability issues (Woodward governor). (Minutes
7/28/89, Pp. 2)
Work on surge tank analysis. (Minutes 7/28/89, p. 3)
Review and presentation of Load Acceptance Analysis report
prepared by SWEC. (Minutes 1/18/90, p. 2)
Prepare testing procedures prior to commercial operation.
(Minutes 1/18/90, p. 3)
Study of microwave link between Divcom and CEA main
headquarters. (Minutes 1/18/90, p. 8)
Provide an opinion on test period power agreement, interim
operational period. (Minutes 7/17/90, p. 7)
Approve SCADA point list. (Minutes 9/21/90, p. 2)
Review, approve SWEC's recommendation on the installation of
the braking resistor, installation of digital stabilizers on the units,
installation of one SVS at the Daves Creek side and in Soldotna.
(Minutes, 11/28/90, p. 2)
Review how the project should be operated under different
scenarios and define certain operation constraints. (Minutes
11/28/90, p.2 )
abe
Review overfrequency tripping for Cooper Lake to try and control
the frequency during times of high Kenai energy export. (Minutes
3/5/91, p. 2)
Determine the maximum Kenai import (i.e. minimum Bradley Lake
operating limit without a gas turbine on-line, assuming that any
single contingency event will not result in more than a reasonable
loss of load (and define "reasonable."). (Minutes 3/5/91, p. 3)
Review of PTI study of operating restraints for the testing and
commissioning phase. (Minutes 6/6/91, p. 2)
TCS work with SWEC to gather all operating restrictions and
recommendations relating to Bradley Lake within the past 2-3
years into one document for reference. (Minutes 6/6/91, p. 3)
Develop operating scenarios with 80 MW and 90 MW caps.
(Minutes 6/6/91, p. 7)
Set the operating criteria for Bradley based on Homer Electric and
Seward being subject to no more than stage two load shedding
for any single contingency event, using interim operating criteria
until such time as the final operating conditions are adopted by
the PMC. (Minutes 7/2/91, p. 3)
Oversee SWEC sponsored tests and other utility required tests.
(Minutes 8/23/91, p. 3)
Review Bradley Lake Operating Manuals. (Minutes 8/23/91, p. 3)
Review of PTI Bradley Lake/Kenai Operating Guidelines. (Minutes
11/19/91, p. 2)
Review of Bradley Lake Dispatcher Guidelines Summary. (Minutes
1/13/92, p. 4)
Report on results of exciter tests. (Minutes 2/28/92, p. 2)
Appoint a representative to accompany the tunnel inspectors.
(Minutes 3/26/92 p. 7)
Expansion of Bradley Lake Operating Conditions, interim operating
levels. (Minutes 4/28/92, Attachment A, p. 2)
a
.., 16788792 18:27 & 503 226 3879 ATER WU t 82 » 1992 As Submitted fo After Wynne
PROJECT COSTS
UNREIMBURSED BRADLEY LAKE COSTS
COSTS INCURRED
July through ay} i a al Hl lols R=91% 503 226 0079 10-08-92 05:35PM POO2 #23
e16=a 6L00 922 €0S WdS€:S0 26-80-01 €c# €00d a a SECTION 31 OR OPERATING BUDGET COSTS
&2(a) BPM ORGANI-
ZATION
=) 23,760.58 | 21760.50
BPMC
LEGAL Cs ee ee
APPROVED AT BPMC MEETING __(0/9/ 7 SIGNED: [Nash FE Dbghe
CHEGACH: No costs submited.
GVEA: No costs submitied. inclucies cost information ffrough April, 1992.
HOMER: Inctudes cost information from May through Septernber, 1992.
MATANUSKA: No costs submiited. Cost form ciaims zero expenses itrough May 15, 1992.
MLEP: Mo costs submitted.
SEWARD: No costs submilted. includes cost information through April, 1992.
ATER WYNNE: Inclucies legol fees and costs fom July through September 1992.
reayemec 87:8 76788781 620e 9z7z ses & a yale £8
R=91%
10788792 18:28 S 503 226 6879 ATER &
Porward completed chart to:
Ron Saxton
Atar 222 sW Columbia, Ste. 1800
Portland, OR 97201
UNREIMBURSED BRADLEY LAKE COSTS
UTILITY _Ater Wynne ss MONTH July - September, 1992
RETURN NO LATER THAN
PROJECT COSTS
1990 FINANCE TEAM PARTICIPATION All travel-related expanses for members of the Finance Taam for trip and meetings associated
‘with the second financing.
LECAL EXPENSES FOR PINANCING EFFORTS
Legal fees of the Committees atterney rolating
to the second finansing effort
OPINIONS OF COUNGEL Scope of work on 1990 second financing effort to be determined later,
TCC EXPENSES Travel and meeting expenses associated with your utility’s participation on the Technical Coordinating Committes.
Do not include amounta for staff time.
SECTION 31 OR OPERATING BUDGET COSTS
BPMC ORGANIZATION
(a) BPMC-approved costs for conducting Committee meetings and general business.
(b) Legal expenses for representation of Committee.
PREPARED BY Liz Westby = = ~=~=—=»- APPROVED BY
4
503 .226 0079 10-08-92 05:35PM P0004 #23
“wit ee
R=91%
10708792 16129 & 503 226 0079 ATER E
Porward completed chart to: Sena copy tor Lin westhy iTaeka anaryy htcnority Scott vies etal.
Jetcrage, aiuaxa vva.s-0503 . Part innn. OR Nigh eat T
UNREIMBURSED BRADLEY LAKE COSTS
UTILITY Momet Electric Accociation, Inc. MONTHS. May, June, July, August & Sept., 1992 RETURN NO LATER THAN
PROJECT COSTS
Al
1990 FINANCE TEAM PARTICIPATION
All travel-related expenses for
meubers of tha Pinance Team for trips
and meetings associated with the
second #innanaing.
LEGAL EXPENSES FOR FINANCING FFFORTS
Legel eee of the Committee alvoracy Saxton will provide
talating to the second financing ta ARA
effort. = eel
1990 OPINIONS OF COUNSEL
Scope of vork on 199M aannnd fLnanciag None unti] requseted
OtforL Lu be determined lates, by AHA
May -0- |
TCC EXPENSES June -0-
Travel and meeting expenses associated Tuly = $114.45
with your ucility’s partdeipacion on Aug. ~- $114.39 the Technical Coordinating Committee. Scpt. - -0-
Be act inejun amounts for atafft tina.
SECTION 31 COSTS
ioe $15.39
BPMC ORGANIZATION $117.48
(a) M¥NC-approved Lusts for sendueting $ 99.00
Committee meetings and geussal busiowse. : ae
Leqel expenses for representation Gaxteo vill provide
of Comittas,
‘April Charges not previously submi'
te ABA
rte ,
PREPARED BY Corel A Mashagited—- NPPROVED BY eb fbr Carol A. Wumbyrd 9 “Yela/pe— Rick Eckert
Admin. /Races Analyst Manager. Accnunring & Rates
503 226 0079 10-06-92 05:35PM POOS #23
d
Bradley Lake PROJECT MANAGEMENT COMMITTEE MEETING
RECORD VOPY —Oclidseh) FY, 1992 FILE NO (Date) ; Pep) 3-}
7 (Location) /
16
PLEASE SIGN IN
No. NAME REPRESENTING
1 e lyolF AER
2 | Abe'm SY y HEA |
3 Dawe Fare HLA
4| J304 Hutma— AEG iz
s| DAVs CacvuérRe SLS
6 “‘Rewores fuwny Ged 1 | om SAL Ll EP
8 | Tin ME Conn-el) Miy¢pr
9 | Lob /rice MLE
10 “ie * <l| GvEA
uff | hoa ¢ hengeeLk
12 | Ren Lyle Darchuing VA tay
13 | Om LOVAS - HOC ACH-
14 | Geve ‘eens7Tad Che gee
| 15_| Mines LS epoch
17
92Q2\IT9884
RECORD VCOPY FILE NO Alaska Energy Authority r
BRADLEY PMC VOTING oe 9
(gor
0 = MAJORITY
YOTING METHOO A:
REQUIRING 4 YEAS W/ 51% OF UTILITIES, WITH NO APA
VOTE;
1) PROCEDURES FOR SCHEDUUNG, PRODUCTION AND
DISPATCH OF PROJECT POWER.
2) ESTABUSHMENT OF PROCEDURES FOR USE OF
EACH PURCHASER'S WATER ALLOCATION (APA ASSENT
REQUIRED FOR FERC UCENSE REQUIREMENTS).
3) SELECTION AMONG ALTERNATIVE METHOOS THAT
(0 NOT INVOLVE APA FOR FUNDING REQUIRED
PROJECT WORK.
VOTING METHOD C:
UNANIMOUS VOTE BY ALL (INCLUDING APA):
ADOPTION OF PROCEDURES FOR DISPUTE RESOLU-
TION.
MAJORITY VOTE (INCLUDING APA).
ELECTION OF OFFICERS.
VOTING METHOO §:
REQUIRING 4 YEAS W/ 51% OF UTILITIES, AND APA
CONCURRENCE;
1) ARRANGING OPERATION AND MAINTENANCE OF
PROJECT.
2) ADOPTION OF BUDGET OF ANNUAL PROJECT
costs.
3) ESTABUSHMENT OF FY ESTIMATED ANNUAL PAY-
MENT OBUGATION AND SCHEDULE OF EACH PUR-
CHASER.
4) DETERMINATION OF ANNUAL PROJECT COSTS
AFTER EACH FY.
5) EVALUATION OF NECESSITY FOR AND SCHEDUUNG
OF REQUIRED PROJECT WORK.
6) DETERMINATION OF APPROPRIATE AMT. OF IN-
SURANCE.
7) ADOPTION OF ADO'L MIN. FUNDING AMTS. FOR
RENEWAL AND CONTINGENCY RESERVE FUND ABOVE
THAT REQ. BY BOND RES.
8) SELECTION AMONG ALT. METHOOS THAT INVOLVE
APA FOR FUNDING REQ. PROJECT WORK.
pour Cree O27 sk le Wel sake | || ate a eae he
V CITY OF SEWARD 01% iat REM
/ MATANUSKA ELEC ASSOC 14% eee | idl
/ CHUGACHELECASSOC 30% rg
// HOMER ELEC ASSOC wm WL)
“ GOLDEN VALELECASSOC 17% MLL Ce
/ MUNI LIGHT & POWER snes a VET] VL] Ae ll dae ek
/ ALASKA ENERGY AUTH 291 %ugze™'* Poo a A
9) ADOPTION_OR AMENOMENT OF PROCE-
DURAL COMMITTEE RULES (EXCEPT Dis-
PUTE RES)
10) ADOPTION OF PROJECT MAINTENANCE
SCHEDULES.
11) DETERMINATION OF RULES, PROCE-
DURES AND ACCOUNTS NECESSARY TO
MANAGE PROJECT WHEN NO BONDS OUT-
‘STANDING.
12) EVALUATION AND APPROVAL OF OPTION-
AL PROJECT WORK AND COMPENSATION
FOR SUCH WORK
13) APPUCATION OF INSURANCE CLAIMS
PROCEEDS NOT GOVERNED BY BOND
RESOLUTION.
14) APPROVAL OF PROCEDURES ANO ANY
INOMOUAL UTILITY AGREEMENTS RELATING
TO ELECTRIC POWER RESERVES FOR
PROJECT.
15) APPROVAL OF CONSULTANTS.
Mr. Everett P. Diener City of Seward 5th & Adams P.O. Box 167 Seward, Alaska 99664
Mr. David L. Highers
Chugach Electric Association 560I Minnesota Drive P.O. Box 196300 Anchorage, Alaska 99519-6300
Mr. Michael P. Kelly Golden Valley Electric Association 758 Illinois P.O. Box 1249 Fairbanks, Alaska 99707
Mr. Fred Arvidson
Perkins Coie 1029 W. 3rd Avenue, Suite 300 Anchorage, Alaska 99501
Mr. James Hall
Matanuska Electric Association 163 Industrial Way P.O. Box 2929 Palmer, Alaska 99645-2929
Mr. S.C. Mathews Homer Electric Association 3977 Lake Street Homer, Alaska 99603
Mr. Ron Saxton
Ater Wynne Dobson & Skerritt 225 S.W. Columbia, Suite 1800
Portland, OR 97201-6618
90Q1D0068L(1)
Distribution List Bradley Lake Hydroelectric Project Project Management Committee October 9, 1992
Mr. Ken Ritchey
Matanuska Electric Association 163 Industrial Way P.O. Box 2929 Palmer, Alaska 99645-2929
Mr. N. L. Story Homer Electric Association 3977 Lake Street Homer, Alaska 99603
Mr. Thomas R. Stahr Municipal Light and Power 1200 E. Ist Avenue Anchorage, Alaska 99501-1685
Mr. Eugene N. Bjornstad Chugach Electric Association 560I Minnesota Drive
P.O. Box 196300 Anchorage, Alaska 99519-6300
Mr. John Cooley Chugach Electric Association 5601 Minnesota Drive P.O. Box 196300 Anchorage, Alaska 99519-6300
Mr. Bob Hansen Golden Valley Electric Association 758 Illinois P.O. Box 1249 Fairbanks, Alaska 99707
Mr. Kurt Dzinich
4511 N. Riverside Drive Juneau, Alaska 99801
Mr. Robert Hufman Utilities Consulting Services 1018 Galena Street Fairbanks, Alaska 99709
Mr. David Burlingame
Chugach Electric Association, Inc. P.O. Box 196300 Anchorage, Alaska 99519-6300
Mr. Tom Lovas Chugach Electric Association, Inc. P.O. Box 196300 Anchorage, Alaska 99519-6300
90Q1\D0068L(1)
Distribution List Bradley Lake Hydroelectric Project Project Management Committee October 9, 1992
Lapaeive Research Agency Box Y Juneau, Alaska 99811-3100
Mr. Hank Nikkels Anchorage Municipal Light & Power 1200 East 1st Street Anchorage, Alaska 99501
Mr. Bob Orr
Golden Valley Electric Association 758 Illinois
P.O. Box 1249 Fairbanks, Alaska 99707
DATE:
TO:
FROM:
SUBJECT:
RECORD VOPY Alaska Energy Authority — =i no
MEMORANDUM “
September 28, 1992
Bradley Lake Hydroelectric Project
Project Management Committee
Brent N. Petrie 8, Ge
Secretary
Project Management Committee Meeting
October 9, 1992
The next meeting of the Bradley Lake Project Management
Committee is scheduled Friday, October 9, 1992. The meeting
will begin at 10:00 a.m. in the Training Room at Chugach
Electric Association, Anchorage.
The following items are enclosed for your information and
review:
° PMC Meeting Agenda - October 9, 1992
° Draft Minutes - August 24, 1992 PMC Meeting
Approved Minutes - July 23, 1992 PMC Meeting
° Memorandum - August 21, 1992 Bradley Lake
Seismic Data Collection
(w/attachments)
Please provide any comments regarding the upcoming
October 9, 1992 PMC meeting agenda items to
Chairman Highers.
DB:BNP:db ue Dist.
ae eegiee Aw Se
DRE
DATE:
TO:
FROM:
SUBJECT:
Alaska Energy Authority
MEMORANDUM
August 21, 1992
Bradley Lake Project Management Committee
Ronald A. Garzini
Interim Executive Director Rac
Alaska Energy Authority
Bradley Lake Seismic Data Collection
As requested by the Project Management Committee (PMC) during the July 23
meeting, the Alaska Energy Authority recently met with the University of Alaska Geophysical Institute regarding seismic monitoring at Bradley Lake. During our
meeting of August 6, 1992, Larry Wolf and I discussed with University
representatives, Dr. Niren Biswas and Syun Akasofu, the project's seismic
monitoring requirements and how the Institute could continue to support those
needs.
For the benefit of the PMC members to better address this issue, I believe it
would be helpful to first explain the various seismic monitoring requirements at
Bradley Lake.
Design/Construction Requirements
During the design/construction period, the seismic monitoring requirements at
the project site consisted of data collection and analysis for purposes of
establishing baseline historical records and verifying engineering design criteria
for the project features. This task was initially being accomplished by the USGS until 1987 when the USGS began scaling back its data colleeticn efforts in Alaska. At that time the Energy Authority entered into a Reimbursable Services
Agreement (RSA) with the University's Geophysical Institute to continue these services.
The University purchased and installed seismic motion monitoring equipment
onsite and interfaced this equipment with their state-wide database in Fairbanks.
Utilizing the information collected, the University then provided a summary
report of this data annually to the Energy Authority.
Operational Requirements
Now that project construction has been completed, the seismic monitoring
requirements have changed. The primary emphasis is to support operational
needs which consist of two basic elements. First, is a FERC requirement that we
monitor the dam site for seismic events of 5.0 Richter scale or greater.
92Q3\JD3409(1) Page 1
Memorandum to Bradley Lake Project Management Committee
Subject: Bradley Lake Seismic Data Collection
August 21, 1992
2 Project Maintained System
An alternative means of fulfilling the project's seismic monitoring
requirements would be the purchase and installation of seismic equipment which would be entirely operated and maintained by onsite personnel.
The proposed monitoring system (see attached Stone & Webster letter dated June 5, 1992) would provide for operator alarm via the SCADA
network for earthquakes over 5.0, and would also automatically record and store the seismic information. In the event this seismic data base was
needed to support future engineer studies, it could easily be analyzed by
the Geophysical Institute or through the use of an engineering consultant. This project data base could also be made available to the Institute for
their state-wide research effort.
The estimated cost for the initial equipment purchase, installation and operator training is $30,000. The subsequent annual maintenance of the
system is estimated at $5,000 per year. The only additional cost would be
the cost of data analysis if and when it became necessary.
Summary
The seismic monitoring requirements at Bradley Lake can be accomplished using
either of the two methods outlined above. The Energy Authority's previous intent to discontinue the services of University's Geophysical Institute was based
primarily on economics and system reliability. However, we recognize that
beyond the operational requirements there may be additional scientific benefits in
monitoring the site for induced earthquake activity during the initial years of
operation and being part of the Institute's state-wide seismic data collection and
research program.
For this reason, the Energy Autherity is willing to extend the RSA agreement with the University to continue seismic data collection services related to
monitoring and analyzing seismic activities for a period of three years. The
Energy Authority, for reliability reasons, will also be installing and maintaining a
separate monitoring device for the operator alarm function.
We recommend that after the three year period, the Bradley PMC review the
University's seismic data collection program to determine whether or not continuation of program is in the project's best interest.
I must also point out that the current FY93 budget allowance for seismic data
collection is only $20,000. To fund the University's program and install the additional monitoring device, the total budget requirement for this year will be approximately $50,000. Therefore, with the PMC concurrence, a $30,000
increase in this budget item will be made.
Unless I am advised otherwise, we will proceed as outlined above.
DE:RAG;jd
92Q3\JD3409(3) Page 3
Memorandum to Bradley Lake Project Management Committee Subject: Bradley Lake Seismic Data Collection August 21, 1992
(Whenever these occur, we must inspect the project features for damage and report to FERC). Second, is the desire to record ground motion data during
such events so that the data would be available to support any future
engineering/design analysis which may become necessary.
In addition to these operational needs, but of a lesser importance, is the interest
in continuous seismic monitoring and analysis for induced earthquakes caused by
the variation in reservoir levels.
Monitoring Alternatives
1. Continued use of Geophysical Institute
The Energy Authority's original plan to meet the seismic monitoring
during construction and to support the long term operational
requirements of the project, was to utilize the service of the University's Geophysical Institute. Although several factors (and in particular
increased costs) induced us to re-evaluate this alternative, the University
remains a possible option for accomplishing the work.
The Institute can continue to record and store the Bradley Lake
information in their state-wide data base, analyze the data, and report annually to the Energy Authority. Although this analysis would have the
added benefit of identifying any reservoir induced earthquake activity, the
report itself would be of little or no benefit to project operations unless
there was a significant event over 5.0 on the Richter scale. In questioning the Institute regarding possible cost reductions, they advised us that analyzing data on an "as-needed basis only" would not be feasible,
because the data for Bradley would be difficult to retrieve from the Institute's computer data base after an extended period of time. The
Institute's projected annuai cost for providing the data collection and analysis service is $38, [00 (see attached University of Alaska letter dated
March 6, 1991).
Technically, the University's onsite equipment could also be equipped to provide the alarm signal for earthquakes over 5.0. However, based on
our experience to date, we would recommend the installation of a separate monitoring device for this purpose. This added device would be maintained by onsite project personnel and would therefore be much
more reliable and immediately responsive to any significant events.
Alarming via the Institute's equipment may not be responsive to our needs as their equipment is sometimes inoperable for extended periods of time due partly to the accessibility of their personnel. The fact that the
Institute is not manned on a continuous basis, and the relatively complex
nature of their equipment increases the system reliability problems. The estimated cost for purchase and installation of the additional monitoring
device is approximately $10,000. Annual maintenance cost is projected
to be approximately $1,000 per year.
9203\JD3409(2) Page 2
STONE & WEBSTER ENGINEERING CORPORATION
ReCOKD COPY 7677 EAST BERRY AVENUE FILE NO
A ENGLEWOOD, COLORADO 80111 - 2137
ADORESS ALL CORRESPONDENCE TO P.O. BOX 5406, DENVER, COLORADO 80217-5406
W.U. TWX: 910 935-0105 TELEPHONE: 303 741-7700 FAX: 303-741-7670
W.U. TELEX: 45-4401 RCA TELEX: 289251 303-741-7671 BOSTON MA NEW YORK NY CHATTANOOGA. TN OAK RIOGE TN CHERRY HILL NJ PORTLAND ME CHICAGO. IL PORTLAND. OR DALLAS Tx RICHLAND WA DECATUR AL RICHMOND VA DENVER CO PLEASANTON. CA FT LAUDERDALE. FL TAMPA FL HOUSTON. TX WASHINGTON OC
-. THORITY
Mr. D. R. Eberle ‘ June 5, 1992
Project Manager
Alaska Energy Authority J.O. No. 15800.50
701 East Tudor Rd. WP 20A
Anchorage, AK 99503 SWEC/AEA/2866
SEISMIC MONITOR
BRADLEY lY
In reference to our letter of May 20, 1992 (SWEC/AEA/2857), attached is the information we
received from Kinemetrics/Systems regarding the seismic monitoring system for the Bradley
Lake Dam. We recommend this system for the Bradley Lake Project, which may already be
in place and the property of AEA. The training package available from Kinemetrics may be
purchased separately as indicated in the quote from Kinemetrics. The Operations personnel
at the Bradley Lake Project are well qualified to receive this training and then will be able to
preform the necessary calibration and maintenance required for the equipment, as well as,
retrieve the data from the seismic monitors. The data retrieval and maintenance is about the
same complexity as other project equipment and should be done easily by the current
personnel. Actual analysis of the data needs to be performed by qualified personnel when a
significant seismic event occurs. We can provide this service to you, or there are several
qualified organizations within Alaska that can perform this analysis.
Regarding the gate closing logic, as mentioned in our above referenced letter, the trigger
switches available with these monitors have not demonstrated reliable enough operation for
automatic power tunnel gate closure or unit shutdown applications. We recommend that the
trigger switch be used for an alarm with the operators determining the need to retrieve data,
shutdown units, or close the gate.
— WM
000869. wpt/BLO0S : 1889 + STOWE @ WEBSTER : LLY Ys 1989
£o f
Mr. D. R. Eberle
June 5, 1992
Page 2
Messrs. John Yale and Jonathan Hodges plan to investigate the existing seismic equipment
currently at Bradley Lake during their next visit to the site for testing of the DECnet and the
remote RTUs. Once we have determined what equipment is presently on site, we will advise
you of additional equipment and installation work recommended for an operational system.
If you have any questions or comments, please call.
nil Hedger
Theodore Critikos
Project Manager
Attachments
TC/JH/swg
ce: Mr. Larry Wolf
CORRESPONDENCE DISTRIBUTION
1D00869.wpf/BLOOS
KKK —— May 7, 1992
KINEMETRICS
Jim Meisenheimer
Stone & Webster
P.O. Box 5406
Denver, Colorado 80217-5406
Subject: Bradley Reservoir, SSA-1 Replacement System
Refernence: Our telecon, May 4 1992
Dear Jim,
The budgetary numbers you requested for two solid state accelero-
graphs and training follow.
As we discussed, the new generation of solid state accelerographs
are intended to be less subject to the skills of the technician performing the preventative maintenance activity. If a board is
not functioning, someone with a general knowledge of the instrument
could be reasonably expected to swap boards and send the faulty board to Pasadena for repair.
Operation and maintenance level training for the solid state
accelerographs could be provided in two days for two to three
students. Three days would be required for four to six students.
The SWS-1 Strong Motion Analysis software package can be taught in
one day. However, I recommend that the processing of any strong
motion data be performed by or, at least reviewed by, an engineer
or scientist experienced in this work prior to publication of the
processed data.
Thank you for your interest in Kinemetrics products and services.
Please feel free to contact me should you have any questions or
comments regarding this proposal.
Sincerely, Noted J. K.MEISENHEIMER Mly 19 ‘92
Rod Merril
Manager of Services
RAM: 1lpc
enclosures: noted
cc: John Diehl, Vice-President, Kinemetrics, Inc.
Mel Lund, Vice-President, Kinemetrics, Inc.
KINEMETRICS/SYSTEMS, 222 VISTA AVENUE, PASADENA, CA 91107 - (818) 795-2220 - TELEX 67-5402 KMETICS PSD - FAX (818) 795-0868
KKK ae
KINEMETRICS PROPOSAL
INVOICE TO: SHIP TO*
Stone & Webster Please Advise
P.O. Box 5406
Denver, Colorado 80217-5406
Attn: Jim Meisenheimer
Customer
RFP No.: Verbal/Meisenheimer Date: 4/MAY/92
FOB: Jobsite
Proposal No.: K2-022 Date: 7/MAY/92
CIF/CF: ---
Payment Terms: Net 30 days
Delivery: Hardware 90 days ARO, Training Representative
30 days after shipment.
Quotation Validity: 120 days Approved by:
Item Qty Type Description
1s 2 Model: SSA-1 Solid State Accelerograph $ 13,000.00
2g full-scale, 0.5 Mbyte CMOS RAM.
Unit price is $6,500.00
as Lot Memory expansion to 1 Mbyte total per 750.00
accelerograph. Unit price is $375.00.
35 Lot Communications and Utility Software N/C
QuickTalk (QTSSA) Communications Software “
Package, 2 disks including; QuickLook
(QLSSA) for SSA, ASCII file converter, and
related utility programs. Supplied with
each SSA-1 order.
4. ak Model OM-PCB-251 Omega Receiver Option, 1750500
includes: antenna, 50’ coax and PA-12 pre-
amp. Additional coax cable, 50 ft,
$80.00.
SPARES AND SUPPLIES
S- ak Analog to Digital Converter Board 875.00
6: £ I/O Processor Board 630.00
oe 1 Data RAM Controller Board 465.00
8. a Data Storage Module, 1 Mbyte 970.00
O42 1 Power Supply and Sequencer Board 650.00
KINEMETRICS/SYSTEMS, 222 VISTA AVENUE, PASADENA, CA 91107 - (818) 795-2220 - TELEX 67-5402 KMETICS PSD - FAX (818) 795-0868
Quotation KMS K2-
Stone & Webster
May 7, 1992
Page 2 of 3
11.1-Lot 72
11.2 Lot 72
12:.1; Lot 72
022
Description Price
Subtotal, hardware $ 19,090.00
SWS-1 Strong Motion Analysis 1,500.00 Software package; will run on any 100% IBM
compatible PC operating with 8087 math co-
processor and EGA graphics, PC-DOS (MS-
DOS) Version 3.1 or compatible. Suggested
hardware is:
Compaq DeskPro 386/20e or equiv.
40 Mbyte hard disk
4 Mbytes RAM
1 Serial Port
1 Parallel Port
80387 Coprocessor
VGA monitor and adapter
Dot matrix printer (Epson) w/ cable
MS-DOS Version 3.3
On-site training for installation, maint- 7,055.00
enance and operation of Kinemetrics Model
SSA-1 units. Price includes all student
course materials and instructor expenses
(i.e. airfare, hotel, meals, ground
transportation, etc.).
Optional SWS-1 training to plant $ 1,200.00
engineers including; data retrieval, data
reduction, and data analysis. Analysis
includes differentiating seismic from non-
seismic events, filter selection criteria
and analyis of sample data. Pe 1 ese
assumes training provided immediately
following delivery of Item 11.1 and
requires one (1) additional day on-site.
Optional factory training per Item 11.1.
$1000/student, minimum three and maximum
six students. Price includes all student
course materials. Student expenses not
included.
Quotation KMS K2-022
Stone & Webster
May: 7, 1992
Page 3 of 3
Item Qty Type Description Price
12752 Lor F2 Optional factory SWS-1 training per Item 11.2.
No charge if provided in conjunction with
factory SSA-2 training. Otherwise,
$600/student, minimum three and maximum
six students.
Subtotal, on-site SSA-2 and analysis soft- S) 1 9i:755,,.00
ware training; includes analysis software
package.
TOTAL, hardware, software and training $ 28,845.00
SCOPE OF WORK
Kinemetrics shall provide a three day training course per blocks 1 through 12
of the attached SSA-1 Course Outline.
Kinemetrics shall supply the course materials for the students (6 max.) in
attendance plus one (1) extra set.
DELIVERY SCHEDULE
Not currently scheduled. December, January, February, June, July and August
are months in which training can be provided.
INCLUSIONS
The firm, fixed price includes the following:
All mobilization labor including travel planning, preparation of special test
equipment, file search to determine original system specifications.
All portal-to-portal travel labor, including overtime charges, for the
Instructor/Field Engineer (based in Pasadena, California).
All on-site labor, including any overtime charges, for the scheduled duration
of the work.
All portal-to-portal travel and living expenses including air and ground
transportation, parking, lodging and meals for the instructor.
Air freight fees for shipment of all training materials.
COURSE OUTLINE
OPERATION AND MAINTENANCE OF THE
MODEL SSA-1 SOLID-STATE ACCELEROGRAPH
KINEMETRICS/SYSTEMS
222 No. Vista Avenue
Pasadena, California 91107
(818) 795-2220
REV.E, 2-18-91
COURSE NAME: Operation and Maintenance of the Page 2 Model SSA-1 Solid-State Accelerograph
Instructor References:
Operating Instructions: Model SSA-1 Solid State Accelerograph
Service Information Manual: Model SSA-1 Solid State Accelerograph
Interface Manual: SSA-1
Operating Instructions: QL16 Quick-look* Display Utility
All Acceptance Test Procedures for SSA-1.
All Schematic diagrams
All wiring diagrams
Training Materials Required:
1 SSA-1 for each three students
1 IBM-compatible computer for each three students
Computer/SSA interconnect cables/MS-DOS**
Crosstalk***program on diskette
Quick-look program on diskette
Standard SSA-1 Support Software
Operating Instructions: Model SSA-1 Solid-State Accelerograph
Operating Instructions: QL16 Quick-look Display Utility
SSA-1 Interface Manual
Classroom Requirements:
Whiteboard with markers
Tables and workbenches
Typical shop support such as small tools, test lead, and instrumentation
including voltmeters and oscilloscopes.
Prerequisites
Anyone may attend this course. A working knowledge and background in
analog electronics, digital electronics, and microprocessors is recommended in
order for the student to understand the theoretical portions of the course.
Evaluation
This course does not include formal testing and evaluation of students. Each
student is, however, expected to report promptly for classes, attend all
designated blocks of instruction and actively participate in laboratory portions
of the course.
Class Size
Kinemetrics will try to accommodate any number of students that the
customer wishes to have attend this course. Experience has shown, however,
that six students is the optimum number and about ten students is the
practical maximum.
*Quicklook is a Trademark of Kinemetrics/Systems
**MS-DOS is a trademark of Microsoft
***Crosstalk is a trademark of Microsuff
COURSE NAME: Operation and Maintenance of the Page 3
Model SSA-1 Solid-State Accelerograph
Training Objectives:
This course may be tailored and priced to meet the requirements of
Customer’s formal task analysis and specific requirements. In the absence of
such input, the standard course is designed to meet the following objectives.
At the completion of the course, the student will be able to:
1. sy | ae Identify the major assemblies of the SSA-1 and describe their
purposes and relationships.
Install the SSA-1 in a typical field or structural situation
including physical attachment and electrical interconnection.
Using a "laptop" computer and commercially available
communications software, establish communication with the SSA-1.
Set header parameters.
Perform, display and interpret functional tests.
Retrieve EQ records.
Scale dominant frequencies and peak acceleration levels of earthquake
using Quick-look.
Perform field exchanges of malfunctioning boards.
Have sufficient background in SSA-1 theory that, given the trainee’s
existing skills in analog and digital electronics, laboratory repair to the
component level may be performed in an efficient manner.
COURSE NAME: Operation and Maintenance of the Page
Model SSA-1 Solid-State Accelerograph
Presentation:
This course is divided into four sections. The customer may select one or more sections for
presentation.
Each section is divided into blocks of instruction lasting about 3-1/2 hours per block.
BLOCK 1: INTRODUCTION
Introductions
Preview of class, etc.
Comparison of SSA-1 to previous designs
SSA-1 concept and construction
Typical Applications
BLOCK 2: PORTABLE COMPUTERS
PC-compatible laptop computers
Keyboards, disk drives, floppy and hard
MS-DOS; booting up, copying files, Crosstalk, Etc.
Includes time for students to practice with computers.
BLOCK 3: INSTALLATION
Physical installation - mounting SSA-1
Electrical connections
a. power
b. signal
c. interconnection with computer
d. modems, extended interconnect option, etc.
e. balancing accelerometers
f. connecting batteries, etc.
BLOCK 4: BASIC OPERATIONS
Establishing communication with SSA-1
Basic commands and setting parameters
Performing functional test
Standard maintenance program
Using Quick-look to evaluate functional tests.
BLOCK 5: BASIC OPERATION (continued)
Expanded discussion of commands and parameters.
Retrieval and proper handling of earthquake records.
Scaling frequencies and acceleration levels using Quick-look.
Students practice with computers and SSA-1’s.
COURSE NAME: Operation and maintenance of the
BLOCK 6:
BLOCK 7:
BLOCK 8:
BLOCK 9:
BLOCK 10:
BLOCK 11:
BLOCK 12:
Model Solid-State Accelerograph
TRIAXIAL AND UNIAXIAL FORCE BALANCE ACCELEROMETERS
Theory of operation
Construction, acceptance Testing anc Calibration
Trouble shooting Malfunctions
Students Test and Calibrate Acclerometers
Page 5
OVERVIEW: SSA-1 CHASSIS, POWER SUPPLY, AND TRANSITION BOARD
Lecture on theory of operation and signal/power path.
Discussion of construction, acceptance testing and calibration.
Discussion of possible malfunctions and troubleshooting.
Students examine and test chassis as time permits.
OVERVIEW: A TO D CONVERTER
Lecture on design, theory of operation and signal path.
Discussion of construction, acceptance testing and calibration.
Discussion of possible malfunctions and troubleshooting.
Students examine and test A to D converter as time permits.
OVERVIEW: 3 POLE FILTER
Lecture on design, theory of operation and signal path.
Discussion of construction, acceptance testing and calibration
Discussion of possible malfunctions and troubleshooting.
Students examine and test filter as time permits.
OVERVIEW: I/O PROCESSOR
Lecture on design, theory of operation and signal path.
Discussion of construction, acceptance testing and calibration
Discussion of possible malfunctions and troubleshooting.
Students examine and test I/O processor as time permits.
OVERVIEW:DATA RAM CONTROLLER AND DATA STORAGE MODULE
Lecture on design, theory of operation and signal path
Discussion of construction, acceptance testing and calibration
Discussion of possible malfunctions and troubleshooting.
Students examine and test controller and data storage module as time permits.
OVERVIEW: RADIOS AND TIMING DEVICES
Lecture on design, theory of operation and signal path.
Discussion of construction, acceptance testing and calibration
Discussion of possible malfunctions and troubleshooting.
Students examine and test various timing options for the SSA-1 as time permits.
COURSE NAME: Operation and Maintenance of the
Model SSA-1 Solid-State Accelerograph
BLOCKS 13 SWS-1 SEISMIC WORKSTATION
and 14: Lecture on design, application and operation
Software and hardware requirements
Discussion of operation of SWS-1
Students process sample earthquake records.
BLOCKS 15 SWS-1 SEISMIC WORKSTATION
and 16: in depth discussion and study of SWS-1 programming.
BLOCKS 17 to SSA-1 CALIBRATION
25:(1 week)
BLOCK 26+: SSA-1 TROUBLESHOOTING
BLOCK 27+: INDEPENDENT STUDY AND PRACTICE
Students utilize training aids and test equipment for self-paced practice
any desired level of operation or testing.
Kinemetrics instructors are made available to assist and answer questions.
This block may be repeated as many times as desired by Customer.
Page 6
Solid State Accelerographs
Domestic INSTRUMENTS
List 3-1 SYSTEMS
SERVICES
Model Part Number Description Price
SSA-1 107200 Solid State Accelerograph, 2g, .5 Mbyte CMOS RAM 6,500.00
SSA-1 with 1g, 1/2g, 1/4g full-scale optional sensors 6,500.00
SSA-1 without FBA deck, for use with FBA-23 5,760.00
(includes option P/N 107315)
SOFTWARE
300130 QuickTalk for the SSA (QTSSA) Communications Software No Charge Package, 2 disks. Includes: QLSSA (QuickLook for SSA),
ASCII file converter, and related utility programs. This
software is supplied with each SSA-1 order.
OPTIONS
107354-01 Memory Expansion to 1 MByte Total (in place of .5 MByte) 375.00
107354-02 Memory Expansion to 2 MBytes Total (in place of .5 MByte) 1,345.00
107354-03 Memory Expansion to 3 MBytes Total (in place of .5 MByte) 2,315.00
107354-04 Memory Expansion to 4 MBytes Total (in place of .5 MByte) 3,285.00
107305 Additional 3-Pole Filter Board 200.00
107310 Provision for Fourth Channel FBA-11 Input 95.00
107315 Provision for Extemal FBA-23 140.00
TCG-1A 107215-01 Time Code Generator (standard accuracy) 980.00
TCG-2 107210 Time Code Generator (high accuracy) 1,225.00
86-4 107220-04 WWVB Receiver, mounted in accelerograph 645.00 A60-FS 790011 Antenna for WWVB Receiver 325.00
86-5 107220-05 DCF-77 Receiver, mounted in accelerograph 790.00
A77.5-FS 790029 Antenna for DCF-77 Receiver, with 50 ft. coax 325.00
OM-PCB-251 107335 Omega Receiver Option, includes antenna, 50 ft. coax and 1,750.00
PA-12 pre-amp
Additional coaxial cable, 50 ft. 80.00
SPARES
107300 Analog to Digital Converter Board 875.00
107325 I/O Processor Board 630.00
107340-01 Data RAM Controller Board 465.00
107350-01 Data Storage Module, 1 MByte 970.00
107350-02 Data Storage Module, .5 MByte 595.00
Prices are FOB Factory, Pasadena, California.
Effective October 1, 1991. Printed in the U.S.A.
Subject to change without notice.
ee UU aaa ESSIEISS ESSE SSISSESSSSSSISSS SSSI nan
KINEMETRICS INC, 222VISTAAVENUE, PASADENA, CALIFORNIA 91107 U.S.A. (818) 795-2220 TELEX 67-5402 KMETRICS PSD FAX (818) 795-0868
Solid State Accelerographs
Domestic
List 3-2 KKK SYSTEMS
KINEMETMIC S&S
Model Part Number Description Price
107290 Power Supply and Sequencer Board 650.00
107240 FBA Accelerometers and Deck Plate 1,840.00
(specify full-scale range: 1/4g, 1/2g, 1g, or 2g)
700181 Charger, battery (110/220 Vac) 45.00
ACCESSORIES
Portable PC: NEC MultiSpeed HD, with 640kB RAM, 3.5" 3,075.00 720kB floppy disk drive, 20MB Fixed Drive, EL backlit
screen, cigarette lighter adapter and carrying case.
(For additional computer hardware, see price list 21)
Extended Interconnect System, consists of: 1,030.00
¢ Interface Box
interconnect cable, SSA-1 to Box
700302 Cable, Box to Box, bulk, per foot 1.80
107375 Extender Board Assembly for SSA-1 115.00
107395 External Mounting Kit, including 3 hold down clamps, bolts, 45.00
concrete anchors and sealing plug for internal hole
700170-02 Internal Anchor Kit, including bolt, thread seals, washer and 4.00
concrete anchor
XCELITE P4 7/16" Nut Driver for installation 8.00
TDC-1 790012 Time Display Controller for TCG-1 1,155.00
TDC-2 790013 Time Display Controller for TCG-1, with reference, TCG-1B 4,675.00
500305-02 Cable, local interconnect, SSA-1/2, 3 ft. 130.00
107393 Cable, SSA-1/2 to Modem RS-232C interface, 25 ft. 110.00
107392-01 Cable, SSA-1/2 to PC RS-232C interface, 25 ft. 145.00
107316 Cable, FBA-23 to SSA-1, with connectors, 10 ft. 210.00
840356 Additional cable, per foot 2.50
104022 Cable, FBA-11 to SSA-1, with connectors, 10 ft. 150.00
700277 Additional cable, per foot 1.50
SUPPLIES
103413 Battery Set, rechargeable, 12V ( 2 of LCR12V6.5P) 100.00
700300 Memory or Clock Back-up Battery, Lithium 15.00
700049 Desiccant 3.00
Prices are FOB Factory, Pasadena, California.
Effective April 1, 1991. Printed in the U.S.A.
‘Subject to change without notice.
KINEMETRICS/SYSTEMS, 222 VISTA AVENUE, PASADENA, CA 91107 - (818) 795-2220 - TELEX 67-5402 KMETICS PSD - FAX (818) 795-0868
Solld State Accelerographs
Domestic | INSTRUMENTS
List 3-3 KKK J SYSTEMS
KINEMETRICS SERVICES
Model Part Number Description Price
SSA-2 108000 Solid State Accelerograph, with Internal Triaxial 3,850.00
Accelerometers, 256kB CMOS RAM
(Specify full scale sensitivity: 2g, 1g, or 1/2g)
SSA-2 without internal accelerometers, for use with FBA-23 3,350.00
(includes option P/N 108080)
SOFTWARE
300130 QuickTalk for the SSA (QTSSA) Communications Software No Charge
Package, 2 disks. Includes: QLSSA (QuickLook for SSA),
ASCII file converter, and related utility programs. This
software is supplied with each SSA-2 order.
OPTIONS
108006 FBA accelerometers (in place of standard accelerometers), add 400.00
108094-01 Memory Expansion to .5 MByte (in place of 256kBytes) 230.00
108094-02 Memory Expansion to 1 MByte (in place of 256kBytes) 685.00
108094-03 Memory Expansion to 2 MBytes (in place of 256kBytes) 1,675.00
108080 Provision for External FBA-23 130.00
108065 Provision for Local Interconnect 130.00
108070-01 Provision for Extended Interconnect of SSA-1/2 665.00
(installed internal to SSA-2)
108070-02 Provision for Extended Interconnect of SSA-1/2 and SMA-1s 785.00
(installed internal to SSA-2) E
108100-01 Transient Protection Box with additional TransZorb protection 400.00
for Extended Interconnect
700302 Cable, Extended Interconnect to Extended Interconnect, per ft. 1.80
TCG-1A 108090-01 Time Code Generator (standard accuracy) 980.00
TCG-2 108088 : Time Code Generator (high accuracy) 1,225.00
86-4 108092-04 WWVB Receiver, mounted in accelerograph 645.00
A60-FS 790011 Antenna for WWVB Receiver, with 50 ft. coax 325.00
86-5 108092-05 DCF-77 Receiver, mounted in accelerograph 790.00
A77.5-FS 790029 Antenna for DCF-77 Receiver, with 50 ft. coax 325.00
OM-PCB-252-0 108085 Omega Receiver Option, includes antenna, 50 ft. coax and 1,750.00
PA-12 pre-amp
Additional coaxial cable, 50 ft. 80.00
Prices are FOB Factory, Pasadena, California.
Effective October 1, 1991. Printed in the U.S.A.
‘Subject to change without notice.
KINEMETRICS INC. 222 VISTAAVENUE, PASADENA, CALIFORNIA 91107 U.S.A. (818) 795-2220 TELEX 67-5402 KMETRICS PSD FAX (818) 795-0868
Solid State Accelerographs
Domestic .
List 3-4 SYSTEMS
KINEMETRICS
Model Part Number Description Price
ACCESSORIES
Portable PC: NEC MultiSpeed HD, with 640kB RAM, 3.5" 3,075.00
720kB floppy disk drive, 20MB Fixed Drive, EL backlit
screen, cigarette lighter adapter and carrying case.
(For additional computer hardware, see price list 21)
107392-01 Cable, SSA-1/2 to PC RS-232C interface, 25 ft. 145.00
107393 Cable, SSA-1/2 to Modem RS-232C interface, 25 ft. 110.00
500305-02 Cable, local interconnect, SSA-1/2, 3 ft. 130.00
108003 Cable, FBA-23 to SSA-2, with connectors, 10 ft. 210.00
840356 Additional cable, per foot (for cable lengths less than 1000 ft.) 2.50
700045 Additional cable, per foot (for lengths from 1000 to 3000 ft.) 4.10
TDC-1 790012 Time Display Controller for TCG-1 1,155.00
TDC-2 790013 Time Display Controller for TCG-1, with reference, TCG-1B 4,675.00
SUPPLIES
840301 Battery, rechargeable, 12V (LCR12V6.5P) 50.00
700300 Clock or Memory Back-up battery, Lithium 15.00
700049 Desiccant 3.00
SPARES |
108020 Data Processor Board 1,280.00
108030 Analog to Digital and Power Supply Board 1,380.00
108035-01 256kByte Memory Board 305.00
108035-02 512kByte Memory Board 535.00
108035-03 1 MByte Memory Board 990.00
Prices are FOB Factory, Pasadena, California.
Effective April 1, 1901. Printed in the U.S.A. Subject 10 change without notice.
SS SSS
KINEMETRICS/SYSTEMS, 222 VISTA AVENUE, PASADENA, CA 91107 - (818) 795-2220 - TELEX 67-5402 KMETICS PSD - FAX (818) 795-0868
Solid State Accelerographs
Domestic
List 3-5 KKK SYSTEMS
KINEMETRICS
Model Part Number Description Price
SENSORS
Extemal Force Balance Accelerometers:(Specify full scale
range)
FBA-11 105000 Uniaxial Force Balance Accelerometer 1,030.00
FBA-23 105610 Triaxial Force Balance Accelerometer 2,945.00
FBA-13DH 105085 Triaxial Downhole Accelerometer Package 6,970.00
Options for FBA-13DH:
105080 Yoke Adapter (one per FBA-13DH) 250.00
102516 Vulcanization of mating connector to cable (required for each 365.00 FBA-13DH)
*Note: To complete downhole cable assembly, add:
Cable, waterproof to 1000 psi, per foot 6.45
105060 Orientation Poles: Master Pole (one per order) 400.00
105071 Orientation Poles: 10 foot extension pole 100.00
105075 Clamp, loading pole (one per order) 415.00
105058 Wellhead Box (one per FBA-13DH) 380.00
107625 EPRI/YOUD Wedging System (requires yoke adapter and 1,420.00
orientation poles for installation, one per FBA-13DH)
107635 Wedging System Tamping Sleeve (one needed per order) 450.00
3/16 retrieval cable, per foot 1.95
Prices are FOB Factory, Pasadena, California.
Effective April 1, 1901. Printed in the U.S.A. Subject to change without notice.
———— — ——————————————_—————————————
KINEMETRICS/SYSTEMS, 222 VISTA AVENUE, PASADENA, CA 91107 - (818) 795-2220 - TELEX 67-5402 KMETICS PSD - FAX (818) 795-0868 . te Te IIS ITS
March 6, 1991
Mr. David R. Eberle
Project Manager
Alaska Energy Authority
P.O. Box 190869
701 East Tudor Road
Anchorage, Alaska 99519
Re: Proposal GI 91-25
Earthquake Monitoring for the Bradley Lake Hydroelectric Project
Dear Mr. Eberle:
I could not write to you any earlier as I had to look over significant amount
of paperwork to respond to your letter of January 31, 1991. However, I have
addressed your inquiries as follows:
(1) The Geophysical Institute of the University of Alaska Fairbanks has a
yearly budget of about $12M per year of which 70 to 80% is derived mostly from
federal grants and contracts issued to individual faculty for specified research
projects. The remaining 20 to 30% is appropriated by the State of Alaska which is
mostly for library maintenance, emergency support for salary, etc. Thus, the
Geophysical Institute has no flexibility to support any specified project, like the
seismic monitoring for the hydroelectric project or any part of it from its own
resources.
(2) The Office of Naval Research (ONR) has been designated by the federal
government to set rates for the University overhead (OH) charges across the
nation. It varies from 80 to 30% depending on the local costs. Our OH rate has
been set by ONR to 45.5%; we have to apply it uniformly to all grants, contracts,
RSA, etc., whether we like it or not.
(3) The minimum requirement for the location of an earthquake is 5 to 6 station data gathered around the foci. This is because the location is an iterative
least squares regression process. Accordingly, you have supported such an effort
for the assessment of background seismicity of the hydroelectric project site by the
U. S. Geological Survey. I was approached by your office te handle the earthquake
monitoring project during and post reservoir impoundment phases. Being a
member of a state University, I felt obligated to undertake the task, though it has
nominal direct research component. I hoped to work closely with your office to
establish a reliable and efficient system and once that system is established, to
reduce the cost of operation to a minimum.
Geophysical Institute, University of Alaska
Fairbanks, Alaska 99775-0800
PHONE: 907-474-7558 TELEX: 35414 GEOPH INST FBK
FAX: 907-474-7290 TELEMAIL: GEOPH.INST.FBK
Established by Act of Congress, dedicated to the maintenance of geophysical research concerning the Arctic regions
Geophysical Institute, University of Alaska
(4) For the purpose mentioned in (3), I have taken the following steps: (a)
establish a calibrator station near the reservoir to monitor in real-time both the
weak and strong ground motions, (b) establish a strong motion station at the gate
site as stipulated by the project for providing warning to the personnel at the site
following a strong nearby earthquake, (c) locate routine earthquakes in and
around the reservoir site using a similar seismic coverage as used by USGS to
establish the background seismicity. Use the data from the calibrator station
under (a) to estimate magnitude precisely, and (d) archive the data gathered
under this project separately, and if required by the Alaska Energy Authority
(AEA), transmit the data for strong earthquakes on diskette.
(5) For the last ten years or so, our seismology program involved with
projects costing $6 to $7M; about half of this amount has been invested for the
acquisition of hardware. A significant amount of the above figure has been
utilized for the development of computer programs for data acquisition, reduction,
etc. These activities are an ongoing part of our operation as everyday we discover
a new problem, a phenomenon common to all laboratories of our kind. However,
on the basis of the last two fiscal years budget, our per station cost (station
installation, maintenance, data telemetry, data acquisition, data reduction and reporting) is around $17K and with 45.5% OH, it is averaging around $25K.
(6) For the last year or so, every project has been asked to cover student
tuition cost; this is again not an individual campus decision, rather a national
policy. Accordingly, we had to incorporate student tuition with the budget of the
current RSA. I must point out here that every Principal Investigator, like myself,
invariably wants to keep the budget to a minimum just to be competitive with
others, yet tries to maintain the best standard of the output of the contract to
preserve his or her professional status among the colleagues.
(7) The last eruption of the Mt. Redoubt volcano completely saturated our data acquisition system and caused considerable interruption in routine
recording of earthquake data. To avoid similar problems in the future, with the
consent from your office, I have diverted a part of the budget of the last RSA (1988-
1989) to acquire data acquisition-computer peripherals dedicated to the project.
(8) The budget submitted with the renewal RSA (GI 91-25) are for the following reasons:
(a) Task 1 deals with a one time procurement for the expansion of the data
recording system. The volume of the daily digital data for the five stations used
for the project, including the calibrator station near the dam site is very large. I
am hoping that the proposed addition will alleviate the current memory problem.
(b) Task 2a deals with the elimination of some residual problems with the
field sites. I draw your attention under materials and travels. The insistence of
your office for arranging these items from Anchorage is an inefficient way of
solving technical problems. We are constantly faced with the problems of
adapting microelectronics to Alaskan environmental conditions. Consequently,
unpredictable failure of components at field sites is not uncommon. After a few
Geophysical Institute, University of Alaska
attempts, we have always solved these problems. From my past experience of
operating seismic stations in Alaska, I must say that I would require another two
field seasons (Summer 1991 and 1992) to eliminate all component failure at the
field sites. After that, I will be in a position to reduce the cost to a minimum
under this task, as shown under (10).
(c) Task 2b deals with the following: We routinely locate the earthquakes across the state without examining the details. The works under this task begin
after that. We sort the data between longitudes 147°W to 154°W and latitudes
58.5°N to 61°N for detailed analysis (rescale, relocate, recompute magnitudes,
determine source mechanisms for larger events and clustering of epicenters and
hypocenters, etc.). Graduate student assistance is the most economical technical
assistance available in a University system as 30% of his/her cost is shared by the
institution plus the reliability of work output is an asset to the project. If we hire
assistance from other sources, the cost will be twice than that incurred for a
graduate assistant. As a matter of fact due to the utilization of graduate assistance, it has been possible for me to meet the project obligation by devoting 2-3 hours a week and about 2-3 weeks/yr. for the preparation of the annual report for your project. However, I had to spend 3 months for the preparation of the last annual report (a copy enclosed for your review), though the RSA was budgeted a month of my salary. This was again due to the interruption of our routine operation caused by the Redoubt eruption.
(9) The cost benefit of the project shared by your organization and the University of Alaska Fairbanks may be summarized as follows:
Alaska Energy Authority (AEA)
(i) For the purpose of earthquake monitoring, hardware standardized and/or developed by the Geophysical Institute (GI) over many years at large cost could be adapted for the Bradley Lake Project (BLP) at nominal cost to AEA.
(ii) Services of well equipped electronic and machine shops, manned by highly skilled workers have been used at various phases of BLP on the basis of hourly charge to AEA. Similarly, assistance of highly trained computer programmers is being used from time to time for BLP. These services would not be available to other organizations at the same rate charged to AEA by the Geophysical Institute.
(iii) The Geophysical Institute as an integral part of the University of Alaska Fairbanks (UAF), a state University system, has been able to obtain access to dedicated data circuit for BLP at nominal cost. Moreover, we are able to telemeter the data in real-time from Bradley Lake to Fairbanks, using the facilities of the State Communication Division at no cost. This is saving BLP approximately $20K per year.
Geophysical institute, University of Alaska
Gadbiesiial Tati aD
(i) GI is able to advance its image to the citizens of Alaska as an active
participant in a project which is going to serve the most important population
center of the state.
(ii) GI has been able to acquire a set of state-of-the-art seismographic
system and it is gaining experience in operating it under Alaskan environmental
conditions.
(iii) The graduate students in the seismology program get an opportunity to
engage in technical reviews of literature and discussions on the phenomenon of
induced seismicity.
(10) Maintenance Budget Estimate
Principal Investigator, 1 month $ 7K
Reserve for annual, sick leave, etc. 1.4K
Staff Benefits (Social Security, Retirement, etc.) 1.7K
Graduate Asst. (1/2 time), 12 months 7.6K
Office supplies, replacement of
equipment parts at the field and recording sites 1.5K
Preparation of annual report 2K
Usage of Institute's computer
peripherals (printer, plotter, etc.) 2K
Electronic shop charges for the
maintenance of the field site,
including site visit if necessary 3K
Subtotal $26.2K
Indirect Costs (45.5% TMDC) -LLOK
TOTAL $38.1K
Geophysical Institute, University of Alaskz
If you have any further inquiries on the above project, please feel free to
pass them on to me or call me at 474-7373.
Sincerely,
Niren N. Biswas
Professor of Geophysics
NNB:mkw
Enclosures: as stated.