12-30-1998 HUCMRegular Meeting
December 30, 1998
All Commissioners were present; also present were Manager Kadrmas, Attorney
Marc Sebora, Electric Superintendent Don Nelson, Natural Gas Superintendent,
John Webster, and Power Production Superintendent, Don Merkins.
President Carls called the meeting to order at 3:08 p.m.
After consideration of the November 25, 1998, minutes Vice President Gilmer
made a motion to approve the minutes as written. Seconded by Commissioner
Wetterling the motion passed unanimously.
Commissioner Wetterling made a motion to ratify the payment of bills in the
amount of $2,053,645.54. Seconded by Commissioner Ward the motion passed
unanimously.
The Commission reviewed the quotes on Steam Turbine #1 Inspection.
Commissioner Wetterling made a motion to approve Lovegreen Turbine
Company for the repair to Unit #1. Seconded by Secretary Ackland the motion
carried.
After discussion, Secretary Ackland made a motion to accept the quote from
RESCO for Class One (1) Poles for the Luce Line trail bridge. Vice President
Gilmer seconded the motion and it passed unanimously.
Commissioner Ward made a motion to accept the quote from RESCO for a
three -phase transformer for Cub Foods. Secretary Ackland seconded the motion
and it carried unanimously.
A motion was made by Vice President Gilmer to accept a quote from Dell
Computers. Commissioner Wetterling seconded the motion and it carried
unanimously.
Secretary Ackland made a motion to advertise for bids for Unit #9 replacement.
Secretary Gilmer seconded the motion and it passed unanimously.
Commissioner Wetterling made a motion to change the personnel policies
regarding on -call personnel use of company vehicles and deferred
compensation. Commissioner Ward seconded the motion, which passed
unanimously.
Don Nelson, Electric Superintendent gave a report on the electric distribution
department.
J 8
Natural Gas Superintendent, John Webster, reported on progress made in the
gas distribution department.
Don Merkins, Power Production Superintended, updated the commission on the
power plant accomplishments.
Manager Kadrmas updated the commission on Unit #9 and reported that Unit #1
was shipped today for rebuilding. He also noted that plans have been finalized
on the renovation of the utility center and meetings are scheduled for
transmission line upgrade with other entities. Union negotiations will be going to
mediation.
Vice President Gilmer and Commissioner Wetterling will attend the next
Labor /Management meeting January 6, 1999, at 9:00 a.m. and will suggest that
these meetings be held either every other month or quarterly.
The Commission commended Manager Kadrmas on an excellent job
performance, which exceeded their expectations over the last year.
Commissioner Wetterling made a motion for an increase in salary. Seconded by
Vice President Gilmer, the motion passed unanimously.
There being no further business, Vice President Gilmer made a motion to adjourn
the meeting at 6:15 p.m.
ATTEST ,��h cti�f'
Michael Carls, President
;14 1
Paul Ackland, Secretary
ADVERTISEMENT FOR BIDS
FOR
Unit #9 Replacement
HUTCHINSON UTILITIES COMMISSION
HUTCHINSON, MINNESOTA
Notice is hereby given that the Hutchinson Utilities Commission of the City of
Hutchinson, Hutchinson, Minnesota, hereinafter referred to as the Owner, will receive
sealed Bids at the Hutchinson Utilities office until 2:00 P.M. on the 21st day of January,
1999, and will publicly open and read aloud such Bids on the following work and
equipment:
" Unit #9 Replacement "
Proposals shall be properly endorsed and delivered in an envelope marked,
"Unit #9 Replacement" and shall be addressed to: Hutchinson Utilities Commission of
the City of Hutchinson, 225 Michigan Street, Hutchinson, Minnesota 55350.
All proposals shall be submitted in duplicate on the Bidder's own letterhead in
facsimile of the Proposal Form enclosed in the Specifications, or by utilizing the Proposal
Form enclosed with the Specifications by typing the official name of the Bidder at the top
of the form.
Each proposal shall be accompanied by a Bid Bond, made payable to the
Hutchinson Utilities Commission of the City of Hutchinson, Hutchinson, Minnesota, in the
amount of five per cent (5 %) of the Bid, as a guarantee that the Bidder will enter into the
proposed Contract and provide a Performance Bond after his Bid shall have been
accepted.
The successful Bidder shall furnish a Performance Bond in an amount equal to one
hundred per cent (100 %) of the Contract price to the Owner prior to the approval of the
Contract.
No Bidder may withdraw his Bid or Proposal for a Period of thirty (30) days after date
of opening of Bids.
At the aforementioned time and place, or at such later time and Place as the Owner
then may fix, the Owner will act upon Proposals received and with its sole discretion may
award Contract(s) for the furnishing of said equipment.
The work shall be started within ten (10) days after award of Contract(s).
Specifications and Plans are available at the Office of the Hutchinson Utilities, 225
Michigan Street, Hutchinson, Minnesota 55350.
The Hutchinson Utilities Commission of the City of Hutchinson, Hutchinson,
Minnesota reserves the right to reject any and all bids.
By�1.u;�
Mike Carls, President
Date I Z-/3 6
ATTESTED
l i � /
Paul Ackland, S c etary
Date (��d %9�'
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HUTCHINSON UTILITIES
COMMISSION
ANNUAL DEPARTMENT REVIEW
NATURAL GAS DEPARTMENT
JOHN C. WEBSTER
NATURAL GAS SUPERINTENDENT
DECEMBER 18, 1998
NATURAL GAS DEPARTMENT
1998
YEAR IN REVIEW
NATURAL GAS SERVICE LINES
As of December 18, 1998 the Natural Gas Department has installed 136
;service lines to residential and commercial installations. 112 of the lines
were installed to new establishments, 24 service lines were installed to
existing facilities. 5 service installations required 2" ips polyethylene pipe
while the remaining 131 installations were installed using 3/" ips
polyethylene pipe.
132 natural gas service lines were installed in 1997. New construction
accounted for 94 of the lines with 38 service lines being installed to
existing facilities.
1. The Meadows 390 ft. of 2" plastic main
880 ft. of 4" plastic main
(Addition distribution main under
construction)
2. Applebee's Rest.
3. 220 MAOP Dist. Line
4. County Fair Market Place
5. Island View Heights
1490 ft. of 4" plastic main
3460 ft. of 6" steel main
27 ft. of 8" steel main
226 ft. of 10" steel main
3300 ft of 4" plastic main
(Currently under Construction)
3950 ft. of 2" plastic main
I7
Ll
a
1
6. Cleveland Ave SW
100 ft. of 2" plastic main
7. Orchard Ave SE 730 ft. of 2" plastic main
TOTALS
2" PLASTIC MAIN - - -- 5170 FT
4" PLASTIC MAIN - - -- 5670 FT
6" STEEL MAIN - - - - - -- 3460 FT
8" STEEL MAIN ---- - - - - -- 27 FT
10" STEEL MAIN - - - - - -- 226 FT
_jj[qjjjLLVjfAjj _ ► �► —_ -.
1. Service Line Retirements 25 service lines were retired in
1998 due to remodeling,
demolition of buildings or leaks.
2. Service Line Relocates 9 service lines /meter installations
were relocated in 1998 due to
remodeling, building additions or
unattached garage construction.
3. 3rd. Party Damages The Natural Gas Department
experienced 5 third party hits by
outside contractors in 1998.
19j:1 MM UT40W*j2jUZjAUj&
The following DOT mandated operations and maintenance programs were
completed in 1998 by the Natural Gas Department:
192.465 External Corrosion Control — Monitoring
192.609 Class Location Study
192.625 Odorization of Natural Gas
192.705 Transmission Lines - Patrolling
192.706 Transmission Lines - Leakage Surveys
(1 mile of transmission line is surveyed each
year)
192.721 Distribution Systems - Patrolling
192.723 Distribution Systems - Leakage Surveys
(Approximately 20 miles of distribution main
and 920 service lines are walked each year
in performing the flame ionization survey)
192.739 Inspection and Testing of Pressure Limiting and
Regulating Stations
(2 Stations and 9 DRS's are Inspected and
maintained)
192.741 Inspection and Testing of Telemetering and
Recording Stations
192.743 Testing of Relief Valves
(13 Relief valves are tested and maintained)
192.745 Valve Maintenance - Transmission System
(13 Transmission valves inspected and
maintained)
192.747 Valve Maintenance - Distribution System
(306 Distribution valves are inspected and
maintained each year)
192.459 External Corrosion Control
(59 miles of steel distribution mains, 1 mile
of steel transmission line and approximately
3370 steel service lines are surveyed and
maintained each year)
192.501 System Pressure Test Requirements
MAJOR PROJECTS - 1998
1. Hutchinson Utilities' contractor, Northern Pipeline Construction Co.
installed approximately 1 mile of 6" steel distribution main from
Arch St SE to the intersection of Monroe St SE and Fair Ave SE.
The distribution main was installed 6' beneath the bed of the Crow
River through the use of the directional boring technology. A
Distribution Regulator Setting was installed at Monroe St and Fair
Ave in order to regulate the natural gas from 190 psig to 50 psig.
Miscellaneous items were completed at Station 2 in 1998. The
drive was paved to allow access to the station, all of the piping was
cleaned and painted, the station grading was completed, and
granite rock was put in place.
Start-up on the station odorizer and ultra -sonic flow meter was
completed in the fall of 1998. At this time this station is flowing
natural gas into Hutchinson's distribution system.
2. The Minnesota Office of Pipeline Safety conducted an audit March
10th through the 12th, 1998 of the Natural Gas Department's
Operations and Maintenance Manual, Drug and Alcohol Plan,
Emergency Plan, and all associated records. As a result of this
audit, much of the O &M and Emergency Plan had to be rewritten.
3. The Office of Pipeline Safety will be performing an audit in 1999 to
review Hutchinson Utilities' operational and training records. Also,
MnOPS will be reviewing operations and maintenance manuals
and emergency plans in accordance with NFPA 58 & 59.
Hutchinson Utilities is required to maintain the above manuals for
the storage and handling of liquefied petroleum gases. These
manuals must be prepared prior to spring 1999.
3. The Minnesota Office of Pipeline Safety presented Hutchinson
Utilities with a Certificate of Appreciation for quality work in the
pipeline safety area of "Municipal Gas System Enhancements ".
Lisa Kallberg, pipeline safety inspector, indicated that this is the
second year that the Office of Pipeline Safety has provided awards
to pipeline companies and utilities for programs that go beyond the
"standard" dedication to public safety.
Awards were also presented to Minnesota and Wood River
Pipelines, Lakehead Pipe Line Co., Great Lakes Gas Transmission
Company, and Minnegasco.
MIDWEST REGIONAL GAS TASK FORCE ASSOCIATION
The MRGTFA is an alliance of small Minnesota and Wisconsin natural gas
utilities. Quarterly meetings are conducted to protect the interests of
Hutchinson Utilities, its generation facilities and its customers. Northern
Natural Gas filed a rate increase in 1998. The Natural Gas
Superintendent from Hutchinson Utilities served as Vice - President of this
association in 1998.
1
TRAINING ATTENDANCE - NATURAL GAS DEPARTMENT
Steve Sturges
Ryan Ellenson
Wayne Barreth
Jon Hombach
John Webster
MEA Operations Roundtable
MEA Leak Detection Seminar
MEA Operations Roundtable
MEA Leak Detection Seminar
MEA Annual Operations Conference
MEA Annual Operations Conference
MnOPS 1998 Spring Conference
The Natural Gas Department continued in house training utilizing the
Midwest Energy Association's "Operator Qualification Training Course" in
1998 in preparation for the yet to be mandated Operator Qualification
ruling from DOT. This ruling is to be in place by June 1, 1999. Additional
information is attached.
Date
Clarence cw
Don M
a Don N
t,.Jluh n
Curt
Connection&v
Sue
Are You Ready For Major New
Pipeline Regulation?
Midwest Energy Association Has Complete Solution
T he Operaror Qualification Rule —
the most significant federal regula-
tion on pipeline safety in the last 20
,years —is within "minutes" of becoming
law. Are you ready for it?
This regulation will profoundly affect
LDCs, pipeline companies and contractors
who work on pipes. its effect will be felt
not only in the Operations division of these
companies, but also in Human Resources,
Legal, Government Relations and Safety
and Training. And to ensure compliance,
companies will have to invest some signifi-
cant time, effort, and dollars.
However, it could have been much
worse. The original draft of the rule would
have cost the industry millions more.
Thanks to industry persistence and the
Department of Transportation's willingness
to rewrite the rule in an open negotiation
process with industry, regulators, unions,
and other interested parries around the
table, we now have a rule that we can all
live with.
Once Congress directed DOT to devel-
op new regulations, your Midwest Energy
Association played a significant role in shap-
ing the rule for your benefit. (See story on
page 4.) In fact, we were the only regional
association at the negotiating table with
the DOT.
So, if any organization can help you meet
the mandates of this new rule, at the lowest
possible cost, MEA can. °
In simplest terms, the Operator
Qualification Rule sa} -s that by the year
2002, no person may" perform a covered
task on a pipeline (distribution or transmis-
sion) unless the company has evidence that
the person is qualified to perform that task.
Here are the basic requirements of the
rule and the MEA tools that are already
available. These tools were created by
MEA's national training division called
The Energy 7- raining Network or ETN.
Basic Requirement: Develop a written
plan within 18 months of the OQ Rule's
effective date (which wr estimate will be
June 1, 1999). Solution: The- -Ene1'
Training Network (ETN) has a plan
preparation aid with three sample plans
Plan Requirements:
I. Develop a list of "Covered Tasks" rhat
employees perform. (There is a four -
part test). Solution: ETN has devel-
o_ped a consensus covered task list
2. Determine which employees perform
which covered tasks. Solution, ETN
has the only consensus national jLQb
and task analysis for both utilities and
pipelines.
How expensive might the new Ope
much can MENEM helpP
A utility with 23,000 meters and 60 operati
$225,000 to provide qualification tools. The
vices will cost that same utility only 10% of
$200,000 for that one utility. And our mater
the protection of having over 200 utilities usi
'MEA
MIMVIIr I vi r., ,, \:., i.vu,\
Time is running out to prepare for the
DOT's Operator Qualification Rule.
.��4'4�siJawr°�d eciedso,;,figcartt�,.law
Evaluate the employees to make sure
they are qualified
to perform the tasks.
Solution: ETN has 49 tests in either
super or computer form There are
even hands -on performance tests too
where needed.
If some or all of the employees can not
be qualified without added training, then
training is needed. olution: The Enerev
Training Network '(ETN) has 49 training
modules in both classroom and self-
self-stud), versions
(continued wl p,xar •f)
Y
' ,fir"!;y�•
1
�1
If some or all of the employees can not be qualified without
added training, then training is needed. Solution: The Energy
Training Network (ETN) has 49 training modules in both class-
room and self -study versions
Record keeping is also required. Companies need to be able to
prove quickly that any specific employee or contractor employee is
qualified. This includes the when and how. Solution: ETN has
a built -in tracking system in its computer modules and has
arranged for the availability (at a substantial discount) of an
Operator Qualification specific computer software program
Need hands -on support to put your plan together and get the
most out of the ETN solutions? Solution: Come to ETN's
March 2 -5, 1999 conference on the rule and go home with your
plan all worked out
We have it all for you, because you and the other members of
MEA and the customers of MEA's Energy Train ing Network divi-
sion have been willing to pool your expertise and dollars. Over
100,000 field employees have already been through all or part of
this program. MEA is the only organization in the counts that
enjoys the power of support from over 300 utilities, pipelines and
contractors for its Operator Qualification services.
Please take a look at the ETN Operator Qualification Support
Form on page next page. Check the boxes and we'll help you
with whatever support you need. The Operator Qualification
Service System from MEA/ETN is one of the best examples of the
power of leveraging your resources through association.
id annual DOT Operator
arch 2 -5 in Phoenix, Arizona.
Df the Rule and its implications,
is -on support for putting your
)rogram together and getting
for implementing the OQ
and plan to attend!
Operator
n't qualified you can't work
e;who is qualified," the
and Human Resources issues
MEA will provide more
tc'members on these issues.
Midwest Bergy,involvement in OQ
The Midwest Energy Association has been at the forefront of
dealing with the Operator Qualification Rule from the begin-
ning. Here are just a few of the highlights of how ybutssocia-
don helped steer this Congressionally - mandated regulaygp:
1990- Supporre'd Missouri members to forminga�Gonsor-
tium to comply with Missouri regulation modeled after'
original "federal proposed rule of 1987:
' 1992 -- Organized the first regional conference q Sand crew ed'a consortium 6, build testing and tTnt erials
0f the common, required topics. z sir }
1994 — Delivered 46 training modules based:on 30.1 O
hours of volunteer labor and over $1.5 million in - rof '
,p esctoical
development fees at a cost per company far below any other
alternatives.
1995 — Opened the learning system to all utilines and'
pipelines in the U.S. Completed the gas industry's fizz.gtility
gas operations Job and Task Analysis.
1996— Delivered a multi media, CD-ROb :learning1 rs-
tem complete with testing record keeping system a ,. e
1997 4egan' national; ransmission ysis
co identify the exact workthr each catego r
forms This is critical to the, dew talc gnd; to eiiruig �'
emplyc�yee has lust the rrght,yy,�pp;;�iiount
.....tom.., �i .v �r r. T:i� �.xr.•rs�:a '�4�it�'. s '�, ,!�:
Ycrrorcnasttce.nasey: XM Che.oQly�teg�ti ., >Z at'
the:tablewicEt the "Depact{rlet�oETrans` b� t
O Office of Pipeline Safety
444 Cedar Street, Suite 147, St. Paul, Minnesota 55101 -5147
Phone: 651/296 -9636 FAX: 651.296.9641 TTY: 651/282 -5555
Internet: http: / /www.dps.state.mn.us
of
December 1, 1998
Alcohol & Mr. Doug Ward
Gambling president
Enforcement
Hutchinson Utilities
Bureau of 225 Michigan Street
Criminal
Apprehension Hutchinson, MN 55350
Capitol Security
Driver & Vehicle Dear Mr. Ward:
Services
Emergency The Minnesota Office of Pipeline Safety has selected Hutchinson Utilities to receive a
Management/ Certificate of Appreciation for quality work in the pipeline safety area of "Municipal
Emergency Gas System Enhancements ". Pipeline Safety Awards were presented at the Fall
Response Educational Conference at Madden's in Brainerd on September 27 -29 1998. This is
Commission p
the second year that the Office of Pipeline Safety has recognized pipeline companies
State Fire
Marshal/ and utilities for programs that we believe have committed an extra measure of
Pipeline Safety dedication to public safety.
State Patrol We regret that representatives of your utility were not able to attend the conference to
Traffic Safety accept the award in person. However, we want you to know the Office of Pipeline
Safety appreciates the improvements that have been made to Hutchinson's gas system
and we look forward to continued cooperation and success in the future.
Sincerely,
Charles R. Kenow
Administrator
Minnesota Office of Pipeline Safety
M NEA
Cc. John Webster, Superintendent/ Natural Gas Hutchinson
Thomas R. Brace, State Fire Marshal /Director MnOPS
EQUAL OPPORTUNITY EMPLOYER
POWER PRODUCTION DEPARTMENT
1998
YEAR IN REVIEW
1998 was another busy year for the Operation and Maintence Divisions, with a
15 % increase in total generation over the past year. The total engine hours of operation
were 14,080 hrs. and the total generation was 230,907 MWH. The peak hourly demand
reached 56.1 MWH, 3.9 MWH over 1997.
Projects included:
1. Maintenance on unit # 8, inspection and replacement of # 2 bearing and seals.
2. Working along with the Electric Distribution Department in the installation of a 69 kv
breaker and a 69 kv capacitor bank at the 69kv switchyard.
3. Assisting with the construction of the H.T.I. Substation and Switchgear Building.
4. The replacement of the Power Transformer at Plant # 1.
5. Assisting the Gas Distribution Department with the relay wiring of 3M and TBS -2.
UNIT # 1-
Completed its fourth year of commerical operation. Operating hours for 1998 were
4,711 hrs. and produced a combined total of 188,590 MWH of electricity. Total operating
time on the gas turbine is 20,283 hours, and on the steam turbine is 16,897 hours.
Up and coming events for unit # 1 -
1. Repair inlet gearbox bearing / Replace LPC bushings / Replace HPC bushings
2. 25,000 Hr. overhaul on the engine / 1999 -2000
UNIT # 8 -
Unit 8 was disassembled in April to inspect the # 2 bearing. Ron Struve a field rep. from
General Electric was hired to supervise our personnel in the inspection. The bearings and
seals were found to be out of manufacturer specifications, so they were replaced with new
ones.Operating hours for 1998 were 3682 hrs. and produced 35,934 MWH of electricity.
UNIT #9 -
Unit # 9 is presently in a Lock -out mode. Due to the fire damage to this unit on August
26th, it will be out of commission for at least 6 -8 months. Although, it did run 214 hrs.and
produced 3,674 MWH of electricity.
UNIT #3-
On June 18th the stator failed on this generator. The repair bid was let to Wilson
Electric Motor Repair of Oklahoma City. It should be back in operation by the middle of
Jan. 1999.
PROJECTS IN PROGRESS:
1. Unit #8's roof should be completed by the end of December.
2. Maintenance on unit # 1
Ongoing:
1. Inhouse training programs - operators / controllers / maintenance
2. Maintenance and preventative maintenance program
3. Schools and seminars
4. State / Federal / Local reports
5. Relay testing and upgrading
6. Y2K compliance
7. Substation maintenance
FYI:
The Operations center / System controllers issued approximately 3,000 Powerstat Cards
in 1998, during the weekday evenings and on weekends.
Attached you'll find a 1997 -1998 comparison graph and figures, as per the total
generation produced.
Donald R. Merkins
Production Superintentent
December 15,1998
CC: Clarence Kadrmas
Don Nelson
John Webster
HUC- Commissioners
Total Generation
Unit #1
Unit #2
Unit #3
Unit #4
Unit #5
Unit #6
Unit #7
Unit #8
Unit #9
Total MW Sold
Capacity Sales
Capacity Purchases
' 1998 Figures through November
Total Generation
Unit #1
Unit #2
Unit #3
Unit #4
Unit #5
Unit #6
Unit #7
Unit #8
Unit #9
J
0
Total Generation
50 100 150
MW
Thousands
Generation Fuel Cost
0 1 2 3 4 5
Dollars
Millions
■ 1987
� 1998
1997
MW
Fuel Cost
CostfMW
200371
$3,497,362.39
$17.45
188813
$3,137,745.51
$16.62
14
$186.91
$13.35
573
$18,544.47
$32.36
109
$4,776.43
$43.82
1
$132.52
$132.52
2
$36.99
$18.50
225
$7,921.67
$35.21
9258
$234,064.63
$25.28
1376
$93,953.26
$68.28
MW
Revenue
Cost/MW
40091
$688,696.55
$17.18
$276,000.00
$0.00
Total Generation
50 100 150
MW
Thousands
Generation Fuel Cost
0 1 2 3 4 5
Dollars
Millions
■ 1987
� 1998
01997
M 1998
200 250
1998"
MW
Fuel Cost
Cost/MW
230907
$4,470,641.08
$19.36
188590
$3,342,526.04
$17.72
22
$815.97
$37.09
438
$11,107.93
$25.36
1305
$35,821.35
$27.45
18
$592.27
$32.90
12
$389.36
$32.45
914
$25,738.68
$28.16
35934
$847,464.78
$23.58
3674
$206,184.70
$56.12
MW
Revenue
Cost/MW
57467
$1,199,370.42
$20.87
$422,000.00
$0.00
01997
M 1998
200 250
J
1998 POWER TOTALS
OFF ON TOTAL $ /MW TOTAL COST
REC TOT
33272
68693
101965
$17.76
$1,810,892.23
DEL TOT
-11363
-46104
-57467
$20.87
($1,199,370.42)
SYS CONT
44635
114797
159432
$0.38
$60,903.02
GEN
230907
$19.36
$4,470,641.06
NET MWH
275405
$18.67
$5,143,065.89
PART PWR
0
0
0
$0.00
$0.00
econ98.123 PAGE 1 OF 5
1998 POWER TOTALS
OFF ON TOTAL $ /MW TOTAL COST
BEPC -REC
0
0
0
$0.00
$0.00
BEPC -DEL
-4
-11
-15
$32.74
($491.14)
CPA -REC
0
2
2
$30.00
$60.00
CPA -DEL
0
-1
-1
$30.00
($30.00)
GSES -REC
900
1035
1935
$23.03
$44,562.50
GSES -DEL
-702
-194
-896
$18.10
($16,220.00)
NAES -REC
5219
7017
12236
$22.58
$276,327.25
ENRON -DEL
-315
-17670
-17985
$23.68
($425,862.40)
IESC -REC
0
0
0
$0.00
$0.00
IESC -DEL
-1
-1
-2
$33.00
($66.00)
MIPC -FEES
0
$0.00
$0.00
SJLP -DEL
-200
-780
-980
$20.89
($20,475.00)
IPW -REC
0
2
2
$30.00
$60.00
IPW -DEL
0
-1 1
-1
$33.00
($33.00)
LES -REC
0
0
0
$0.00
$0.00
LES -REC
0
0
0 1
$0.00
$0.00
econ98.123 PAGE 2 OF 5
1998 POWER TOTALS
OFF ON TOTAL $ /MW TOTAL COST
MHEB -REC
0
0
0
$0.00
$0.00
MHEB -DEL
0
-1
-1
$67.18
($67.18)
MDU -REC
0
0
0
$0.00
$0.00
MDU -DEL
0
0
0
$0.00
$0.00
MEAN -REC
0
0
0
$0.00
$0.00
MEAN -DEL
-10
-60
-70
$22.00
($1,540.00)
MLRP -REC
99
915
1014
$0.00
$0.00
MLRP -DEL
-70
-189
-259
$ -0.00
$0.00
MPC -REC
0
90
90
$28.00
$2,520.00
MPC -DEL
-10
0
-10
$17.00
($170.00)
MP -REC
0
233
233
$74.42
$17,340.00
MP -DEL
-8885
-10824
-19709
$14.74
($290,462.00)
MEC -REC
0
0
0
$0.00
$0.00
MEC -DEL
-4
-14
-18
$30.17
($543.00)
MPW -REC
0
0
0
$0.00
$0.00
MPW -DEL
0
0
0 1
$0.00
$0.00
econ98.123 PAGE 3 OF 5
1998 POWER TOTALS
OFF ON TOTAL $ /MW TOTAL COST
NPPD -REC
0
0
0
$0.00
$0.00
NPPD -DEL
-31
-168
-199
$23.58
($4,693.00)
NSP -REC
0
70
70
$25.71
$1,800.00
NSP -DEL
-62
-114
-176
$91.57
($16,116.20)
NWPS -REC
0
0
0
$0.00
$0.00
NWPS -DEL
0
0
0
$0.00
$0.00
OPPD -REC
150
60
210
$12.14
$2,550.00
OPPD -DEL
-35
-94
-129
$21.49
($2,772.00)
OTP -REC
60
490
550
$26.76
$14,720.00
OTP -DEL
-1
-5
-6
$30.00
($180.00)
RPU -REC
0
0
0
$0.00
$0.00
RPU -DEL
0
0
0
$0.00
$0.00
SMP -REC
0
1
1
$30.00
$30.00
SMP -DEL
-1
0
-1
$30.00
($30.00)
UPA -REC
26844
58478
85322
$16.91
$1,442,492.48
UPA -DEL
-1002
-5203
-6205
$32.27 1
($200,235.50)
econ98.123 PAGE 4 OF 5
�J
1998 POWER TOTALS
OFF ON TOTAL $ /MW TOTAL COST
WAPA -REC
0
300
300
$28.10
$8,430.00
WAPA -DEL
0
0
0
$0.00
$0.00
WPPI -REC
0
0
0
$0.00
$0.00
WPPI -DEL
-30
-390
-420
$22.00
($9,240.00)
CMMPA -REC
0
0
0
$0.00
$0.00
CMMPA -DEL
0
-10384
-10384
$20.24
($210,144.00)
ENRON CAP SALE
$180,000.00
90 2,000.00
UPA CAP SALE
$242,000.00
220
1 $1,100.00
UPA SPIN CHARGE
$8,105.00
3242 1 $2.50
UPA REG CHARGE
COST
MW -DMD
RATE
490.6
$lkw /12
$40,883.32
econ98.123 PAGE 5 OF 5