05-25-2016 HUCMMINUTES
Regular Meeting — Hutchinson Utilities Commission
Wednesday, May 25, 2016
Call to order — 3:00 p.m.
President Luhring called the meeting to order. Members present: President Donna
Luhring; Vice President Monty Morrow; Secretary Mark Girard; Commissioner Anthony
Hanson; Commissioner Robert Wendorff; Attorney Marc Sebora; General Manager
Jeremy Carter.
1. Conflict of Interest
None
2. Approve Consent Agenda
a. Approve Minutes
b. Ratify Payment of Bills
A motion was made by Commissioner Wendorff, seconded by Vice President
Morrow to approve the minutes. Motion was unanimously carried.
A motion was made by Commissioner Hanson, seconded by Secretary Girard to
approve the payment of bills. Motion was unanimously carried.
3. Approve Financial Statements
Jared Martig and GM Carter presented the financial statements. After discussion, a
motion was made by Vice President Morrow, seconded by Secretary Girard to
approve the financial statements. Motion was unanimously carried.
4. Open Forum
5. Communication
a. City Administrator — Matthew Jaunich (Absent)
b. Divisions
i. Randy Blake —
1. Nothing to report.
ii. Dan Lang —
1. Nothing to report.
iii. Jared Martig -
1. Nick Nelson is working on the CIP report due by June 1.
2. Hutchinson High School student, Ruby Redekopp, won the local and
overall 2016 MMUA Tom Bovitz Memorial Scholarship contest.
iv. John Webster -
1. Nothing to report.
c. Legal — Attorney Sebora
i. Nothing to report.
d. General Manager — Jeremy Carter
i. Attended the Clean Power Plan stakeholder meetings. The last several
meetings have focused around mass based approach modeling and how
emissions allowances would work in an open market format. Over the next
several months the meetings will shift focus to looking at a rate based
approach. APPA came out with their own modeling tool for members to use
to enter in their own production and emissions information to view results
from a more localized standpoint.
ii. Planning on scheduling a special commission meeting the week of June 20
to review the consultant's results on the compensation study.
iii. Continuing to work on capital expenditure information.
6. Policies
a. Review Policies
i. Training and Education Assistance
ii. Workplace Accommodation
iii. Natural Gas Meter Requirements and Placement
iv. Natural Gas Service Work
v. Locating Customer's Underground Utilities - Gas
No changes were recommended.
b. Approve Changes — None.
7. Unfinished Business
a. Update on Pack Gas Discussions
No new update. Waiting to hear back from New Ulm.
8. New Business
a. Approve Declaration of Surplus Equipment
GM Carter presented a list of surplus equipment to be sold. With the intention
to get HUC's equipment inventory as low as possible, staff created a list of
equipment which is no longer needed. After discussion, a motion was made by
Commissioner Hanson, seconded by Secretary Girard to approve the sale of
surplus equipment. Motion was unanimously carried. (Surplus equipment list
attached.)
b. Approve Capacity Sale Agreements
GM Carter presented two agreements and gave an overview of the major
points of the agreements. After discussion, a motion was made by Secretary
Girard, seconded by Vice President Morrow to approve the capacity sale
agreements. Motion was unanimously carried. (Capacity Sale Agreements
attached.)
c. Approve Requisition #6719 for Purchase of Specific Gravity Meters
John Webster presented Requisition #6719 for purchase of specific gravity
meters from Micro Motion Inc., in the amount of $72,531.29. After discussion, a
motion was made by Secretary Girard, seconded by Commissioner Hanson to
approve Requisition #6719 for $72,531.29. Motion was unanimously carried.
(Requisition attached.)
d. Discussion on Infrastructure Program
GM Carter gave a presentation on the proposed infrastructure program for
Commission consideration. GM Carter reviewed the infrastructure process,
prioritization of infrastructure, current valuations of HUC's infrastructure, and
the potential funding requirements for the program to include maintenance and
new investments. After discussion, a decision was made to table this agenda
item and bring back in about three months. (Presentation attached.)
9. Adjourn
There being no further business, a motion was made by Commissioner Hanson,
seconded by Secretary Girard to adjourn the meeting at 4:15 p.m. Motion was
unanimously carried.
ATTEST:
Donna Luhring, President
3
(I Z'Le�
Mafk Girard, Secretary
Surplus Equipment/Trailers/Vehicles
Year
Make
Est.
SalesValue
1988
John Deere 310C Tractor/Backhoe
$
15,000.00
1999
New Holland Skid Steer
$
12,000.00
2000
Ditch Witch 8020 Plow/Backhoe
$
20,000.00
2000
Case 660 Trencher/Backhoe
$
12,500.00
2000
FT- -20 Felling Trailer
$
8,000.00
2005
T-12T Towmaster Trailer
$
5,000.00
2005
Dodge Dakota Light Truck
$
8,000.00
NORTH AMERICAN ENERGY MARKETS ASSOCIATION
CAPACITY AND ENERGY TARIFF
SUPPLEMENTARY AGREEMENT
Between
Hutchinson Utilities Commission
and
AEP Energy Partners, Inc.
This Supplementary Agreement (Master Agreement) is made as of("Effective Date") by
Hutchinson Utilities Commission, Minnesota ("Party A") and AEP n re gy partners, Inc. ("Party
B") ("Supplementary Agreement").
Whereas Party A and Party B are NAEMA Members and desire to transact in accordance with
the terms and conditions contained in the Tariff, as amended, restated or replaced from time to
time;
And Whereas, if and to the extent that Party A and Party B carry on business, transact or act
pursuant to the Agreement, Party A and Party B wish to make elections with respect to certain
options contained in the Tariff, as set forth in this Supplementary Agreement. Such elections
shall not, however, apply as between Party A or Party B and any other NAEMA Members.
Now therefore, for good and valuable consideration, the receipt and sufficiency of which is
hereby acknowledged, the Parties agree that if and to the extent that Party A and Party B carry on
business, transact or act pursuant to the Agreement, the Parties agree as follows:
1. Article Three Election - Confirmations
® Written Confirmation
❑ Oral Confirmation
❑ Electronic Confirmation
If Electronic Confirmation is applicable, complete the appropriate specific confirmation
provisions below
Specific Confirmation Provisions
(i) Electronic Confirmation Method:
Electronic means of communication to be used by Party A and Party B shall be:
(ii) Other Provisions: (if required)
NAEMA with CT 4.30.13
2. Article Six Election —Events of Default; Remedies
For the purposes of Article Six, the Parties hereto make the following elections:
Article Six 6.1(i) Cross Default for Party A:
Events of Default; Remedies X: Party A: Hutchinson Utilities Cross Default Amount S 1,000,000
Commission
❑: Other Entity: Cross Default Amount S
6.1(i) Cross Default for Party B:
❑: Party B: Cross Default Amount $
X: Other Entity: American Cross Default Amount
Electric Power Company, Inc. $50,000,000
3. Article Nine Election - Credit Assurance
For the purposes of Article Nine, the Parties hereto make the following elections:
Section 9.2 Credit Assurances
® Option I
❑ Option 2
❑ Option 3
If Option 3 is applicable, complete the following:
Downgrade Event for Party A shall mean:
Downgrade Event for Party B shall mean:
❑ Option 4 (see Schedule A)
Article Nine
9.4 Partv A Credit Protection:
(a) Financial Information:
❑: Option A
X: Option B Specify: American Electric
Power Company, Inc.
❑: Option C Specify:
(b) Collateral Threshold:
X: Not Applicable
: Applicable
4. Amendments to Tariff
NAEMA with CT 4.30.13
Credit and Collateral Requirements
9.5 Partv B Credit Protection:
(a) Financial Information:
X: Option A
❑: Option B Specify:
❑: Option C Specify:
(b) Collateral Threshold:
X: Not Applicable
: Applicable
❑ Not Applicable
® Pursuant to Section 3.6 of the Tariff, Party A and Party B agree to amend the Tariff as
follows:
a. Section 2.28, "Letters of Credit", shall be deleted and replaced with the following:
"Letter(s) of Credit" means one or more irrevocable, transferable standby letters of credit
issued by a U.S., commercial bank or a foreign bank with a U.S. branch with such bank
having a credit rating of at least A- from S&P or A3 from Moody's, from a bank and in a
form acceptable to the Party in whose favor the letter of credit is issued. Costs of a Letter of
Credit shall be borne by the applicant for such Letter of Credit.
c. Section 2.49 Sales Price, is amended to insert after the phrase "commercially reasonable
manner" in the sixth line, the following phrase `; provided, however if the Seller is unable after
using commercially reasonable efforts to resell all or a portion of the Product not received by
Buyer, the Sales Price with respect to such unsold portion of the Product shall be deemed equal
to zero (0)."
d. Section 3.2 Written Confirmation, is amended by deleting all references to "two (2)" and
replacing with it with "four (4)", and in the 16`" line after the words "controlling confirmation"
place a period "." and delete the remaining portion of the Section.
e. Section 6.1, Events of Default, shall be amended by adding the following new subsection (h)
to the end of Section 6.1:
"(h) if the applicable cross default section in the Supplementary Agreement is indicated for
such Party, the occurrence and continuation of (i) a default, event of default or other similar
condition or event in respect of such Party or any other party specified in the Supplementary
Agreement for such Party under one or more agreements or instruments, individually or
collectively, relating to indebtedness for borrowed money in an aggregate amount of not less
than the applicable Cross Default Amount (as specified in the Supplementary Agreement),
which results in such indebtedness becoming immediately due and payable or (ii) a default
by such Party or any other party specified in the Supplementary Agreement for such Party in
making on the due date therefor one or more payments, individually or collectively, in an
aggregate amount of not less than the applicable Cross Default Amount (as specified in the
Supplementary Agreement);"
f. Section 6.1, Events of Default, shall be amended by adding the following new subsection (i)
to the end of section 6.1.
"(i) such Party: (i) defaults under a Specified Agreement and, after giving effect to any
applicable notice requirement or grace period, there occurs a liquidation of, an
acceleration of obligations under, or an early termination of, that Specified Agreement; or
(ii) defaults, after giving effect to any applicable notice requirement or grace period, in
making any payment or delivery due on the last payment, delivery or exchange date of, or
any payment on early termination of, a Specified Agreement (or such default continues
NAEMA with CT 4.30.13
for at least three Business Days if there is no applicable notice requirement or grace
period), where "Specified Agreement" means any privately negotiated forward, swap or
option on one or more commodities (including but not limited to, any Product, natural
gas, coal, oil, petroleum product(s) or other energy commodities), emission allowances,
or any other similar transaction (whether or not documented under or effected pursuant to
a Tariff) now existing or hereafter entered into between Party A and Party B."
g. Section 6. 1, Events of Default, shall be amended by adding the following new subsection 0) to
the end of section 6.1.
"o) such Party or such Party's Guarantor, if any, consolidates or amalgamates with, or
merges with or into, or transfers all or substantially all its assets to, another entity and
such action does not constitute an event described in Section 6.1(f) but the
creditworthiness of the resulting, surviving or transferee entity is materially weaker as
determined by commercially reasonable judgment under then current market conditions
than that of such Party or such Party's Guarantor, if any, immediately prior to the time of
such consolidation, amalgamation, merger or transfer, provided, however, that the
foregoing shall not constitute an Event of Default so long as in connection with or after
such consolidation, amalgamation, merger or transfer such Party or its successor or
transferee provides (or causes to be provided) to the other Party, within two (2) Business
Days after written notice, Performance Assurance in an amount satisfactory to the other
party in its sole discretion."
h. Section 6.3, Net Out of Settlement Amounts, shall be construed to encompass all physical
power Transactions between the parties under this or any other agreement and all such amounts
shall be netted out to a single liquidated amount.
i. Section 6.6, Closeout Setoffs, shall be deleted in its entirety and replaced with:
"After calculation of a Termination Payment in accordance with Section 6.3, if the
Defaulting Party would be owed or is owed the Termination Payment, the Non -
Defaulting Party shall be entitled, at its option and in its discretion, to (i) set off against
such Termination Payment any amounts due and owing by or owed to the Defaulting
Party to or from the Non -Defaulting Party under any other agreements, instruments or
undertakings between the Defaulting Party and the Non -Defaulting Party and/or (ii) to the
extent the Transactions are not yet liquidated in accordance with Section 6.2, withhold
payment of the Termination Payment to the Defaulting Party. The remedy provided for
in this Section shall be without prejudice and in addition to any right of setoff,
combination of accounts, lien or other right to which any Party is at any time otherwise
entitled (whether by operation of law, contract or otherwise).".
j. Section 7.4 Netting? of Pavments. Netting of Payments, shall be construed to encompass all
physical power Transactions between the parties under this or any other agreement where the
debts and payment obligations are due and owing to each other on the same date.
NAEMA with CT 4.30.13
k. Article 8, shall be amended by (i) deleting the phrase in the first sentence "EXCEPT AS SET
FORTH HEREIN," (ii) deleting the phrase in the sixth sentence "UNLESS EXPRESSLY
HEREIN PROVIDED,"
1. Section 9.2, Credit Assurances, Option 1, shall be amended by deleting the phrase "three (3)
Business Days" wherever it appears therein and replacing it with the phrase "four (4) Business
Days".
m. Article 9, CREDIT AND COLLATERAL REQUIREMENTS, shall have the following new
Sections 9.4, 9.5, 9.6 and 9.7 added as follows:
9.4 Partv A Credit Protection. The applicable credit and collateral requirements shall be as
specified on the Supplementary Agreement. If no option in Section 9.4(a) is specified on the
Supplementary Agreement, Section 9.4(a) Option C shall apply exclusively.
(a) Financial Information. Option A: If requested by Party A, Party B shall deliver (i)
within 120 days following the end of each fiscal year, a copy of Party B's annual report
containing audited consolidated financial statements for such fiscal year and (ii) within
60 days after the end of each of its first three fiscal quarters of each fiscal year, a copy of
Party B's quarterly report containing unaudited consolidated financial statements for such
fiscal quarter. In all cases the statements shall be for the most recent accounting period
and prepared in accordance with generally accepted accounting principles; provided,
however, that should any such statements not be available on a timely basis due to a
delay in preparation or certification, such delay shall not be an Event of Default so long
as Party B diligently pursues the preparation, certification and delivery of the statements.
Option B: If requested by Party A, Party B shall deliver (i) within 120 days following the
end of each fiscal year, a copy of the annual report containing audited consolidated financial
statements for such fiscal year for the party(s) specified on the Supplementary Agreement and
(ii) within 60 days after the end of each of its first three fiscal quarters of each fiscal year, a copy
of quarterly report containing unaudited consolidated financial statements for such fiscal quarter
for the party(s) specified on the Supplementary Agreement. In all cases the statements shall be
for the most recent accounting period and shall be prepared in accordance with generally
accepted accounting principles; provided, however, that should any such statements not be
available on a timely basis due to a delay in preparation or certification, such delay shall not be
an Event of Default so long as the relevant entity diligently pursues the preparation, certification
and delivery of the statements.
Option C: Party A may request from Party B the information specified in the
Supplementary Agreement.
Collateral Threshold. If at any time and from time to time during the term of this
Agreement (and notwithstanding I whether an Event of Default has occurred), the
Termination Payment that would be owed to Party A plus Party B's Independent
Amount, if any, exceeds the Party B Collateral Threshold, then Party A, on any Business
Day, may request that Party B provide Performance Assurance in an amount equal to the
amount by which the Termination Payment plus Party B's Independent Amount, if any,
NAEMA with CT 4.30.13
exceeds the Party B Collateral Threshold (rounding upwards for any fractional amount to
the next Party B Rounding Amount) ("Party B Performance Assurance"), less any Party
B Performance Assurance already posted with Party A. If Party B receives written notice
from Party A by 1:00 pm New York time on a Business Day, Party B shall post
acceptable Performance Assurance the next following Business Day and on the second
Business Day following the date of notice if received by Party B after 1:00 pm New York
Time on a Business Day. On any Business Day, Party B, at its sole cost, may request that
such Party B Performance Assurance be reduced correspondingly to the amount of such
excess Termination Payment plus Party B's Independent Amount, if any, (rounding
upwards for any fractional amount to the next Party B Rounding Amount). In the event
that Party B fails to provide Party B Performance Assurance pursuant to the terms of this
Article Nine when due, then an Event of Default under Article Six shall be deemed to
have occurred and Party A will be entitled to the remedies set forth in Article Six of this
Tariff.
For purposes of this Section 9.5(b), the calculation of the Termination Payment shall be
calculated pursuant to Section 6.3 by Party A as if all outstanding Transactions had been
liquidated, and in addition thereto, shall include all amounts owed but not yet paid by Party B
to Party A, whether or not such amounts are due, for performance already provided pursuant
to any and all Transactions.
9.5 Partv B Credit Protection. The applicable credit and collateral requirements shall be as
specified on the Supplementary Agreement. If no option in Section 9.5(a) is specified on the
Supplementary Agreement, Section 9.5(a) Option C shall apply exclusively.
(a) Financial Information. Option A: If requested by Party B, Party A shall deliver (i)
within 120 days following the end of each fiscal year, a copy of Party A's annual report
containing audited consolidated financial statements for such fiscal year and (ii) within 60 days
after the end of each of its first three fiscal quarters of each fiscal year, a copy of such Party's
quarterly report containing unaudited consolidated financial statements for such fiscal quarter.
In all cases the statements shall be for the most recent accounting period and prepared in
accordance with generally accepted accounting principles; provided, however, that should any
such statements not be available on a timely basis due to a delay in preparation or certification,
such delay shall not be an Event of Default so long as such Party diligently pursues the
preparation, certification and delivery of the statements.
Option B: If requested by Party B, Party A shall deliver (i) within 120 days following the
end of each fiscal year, a copy of the annual report containing audited consolidated financial
statements for such fiscal year for the party(s) specified on the Supplementary Agreement and
(ii) within 60 days after the end of each of its first three fiscal quarters of each fiscal year, a copy
of quarterly report containing unaudited consolidated financial statements for such fiscal 4uarter
for the party(s) specified on the Supplementary Agreement. In all cases the statements shall be
for the most recent accounting period and shall be prepared in accordance with generally
accepted accounting principles; provided, however, that should any such statements not be
available on a timely basis due to a delay in preparation or certification, such delay shall not be
NAEMA with CT 4.30.13
an Event of Default so long as the relevant entity diligently pursues the preparation, certification
and delivery of the statements.
Option C: Party B may request from Party A the information specified in the
Supplementary Agreement.
Collateral Threshold. If at any time and from time to time during the term of this
Agreement (and notwithstanding whether an Event of Default has occurred), the
Termination Payment that would be owed to Party B plus Party A's Independent
Amount, if any, exceeds the Party A Collateral Threshold, then Party B, on any Business
Day, may request that Party A provide Performance Assurance in an amount equal to the
amount by which the Termination Payment plus Party A's Independent Amount, if any,
exceeds the Party A Collateral Threshold (rounding upwards for any fractional amount to
the next Party A Rounding Amount) ("Party A Performance Assurance"), less any Party
A Performance Assurance already posted with Party B. If Party B receives written notice
from Party A by 1:00 pm New York time on a Business Day, Party B shall post
acceptable Performance Assurance the next following Business Day and on the second
Business Day following the date of notice if received by Party B after 1:00 pm New York
Time on a Business Day. On any Business Day, Party A, at its sole cost, may request that
such Party A Performance Assurance be reduced correspondingly to the amount of such
excess Termination Payment plus Party A's Independent Amount, if any, (rounding
upwards for any fractional amount to the next Party A Rounding Amount). In the event
that Party A fails to provide Party A Performance Assurance pursuant to the terms of this
Article Nine when due, then an Event of Default under Article Six shall be deemed to
have occurred and Party B will be entitled to the remedies set forth in Article Six of this
Tariff.
For purposes of this Section 9.5(b), the calculation of the Termination Payment shall be
calculated pursuant to Section 6.3 by Party B as if all outstanding Transactions had been
liquidated, and in addition thereto, shall include all amounts owed but not yet paid by Party A to
Party B, whether or not such amounts are due, for performance already provided pursuant to any
and all Transactions.
9.6 Interest Rate on Cash Amounts Held as Collateral. For Performance Assurance in the
form of cash that is held by a party pursuant to this Article Nine the interest rate will be the
Federal Funds Rate minus 0.25% as from time to time in effect. "Federal Funds Rate" means, for
the relevant determination date opposite the caption "Federal Funds (Effective)" as set forth in
the weekly statistical release designated as H.15 (519), or any successor publication, published
by the Board of Governors of the Federal Reserve System. Such interest shall be calculated
commencing on the date Performance Assurance in the form of cash is received by a Party but
excluding the earlier of. (i) the date Performance'Assurance in the form of cash is returned to a
Party; or (ii) the date Performance Assurance in the form of cash is appli�d to a Pledgor's
obligations pursuant to Section 9.3.
9.7 Transfer of Interest Amount. The Pledgor shall invoice the Secured Party monthly
setting forth the calculation of the interest amount due, and the Secured Party shall make
payment thereof by the later of (A) the third Business Day of the first month after the last month
NAEMA with CT 4.30.13
to which such invoice relates or (B) the third Business Day after the day on which such invoice is
received.".
n. Section 11.2, Representations and Warranties, shall be amended by deleting the text of
clause (ix) and replacing it with the following:
The Parties intend that (i) all Transactions constitute a "forward contract" within the meaning
of the United States Bankruptcy Code (the "Bankruptcy Code"); (ii) all payments made or to
be made by one Party to the other Party pursuant to this Agreement constitute "settlement
payments" within the meaning of the Bankruptcy Code; (iii) all transfers of
Performance Assurance by one Party to the other Party under this Agreement constitute
"margin payments" within the meaning of the Bankruptcy Code; and (iv) this Agreement
constitutes a "master netting agreement" within the meaning of the Bankruptcy Code.
o. Section 11.2 Representations and Warranties, shall be amended by adding a new clause
(xiii) as follows:
(xiii) It is an "eligible contract participant' within the meaning of Section la (18) of the
Commodity Exchange Act, as amended by the Commodity Futures Modernization Act of
2000.
q. Section 11.19, Fixed Rates, shall be added to Article Eleven as follows.
All rates, terms and conditions as specified in this Master Agreement shall remain in
effect in accordance with their terms and shall not be subject to change through
application to the Federal Energy Regulatory Commission ("FERC") pursuant to the
provisions of Section 205 or 206 of the Federal Power Act. Absent the agreement of all
Parties to the proposed change, the standard of review for changes to any rate, charge,
classification, term or condition of this Master Agreement, whether proposed by a Party,
a non-party, or the FERC acting sua sponte, shall solely be the "public interest'
application of the "just and reasonable" standard of review set forth in United Gas Pipe
Line Co. v. Mobile Gas Service Coro.. 350 U.S. 332 (1956) and Federal Power
Commission v. Sierra Pacific Power Co.. 350 U.S. 348 (1956) and clarified by Morgan
Stanlev Capital Group, Inc. v. Public Util. Dist. No. 1 of Snohomish, 554 U.S. 527 (2008)
U.S. 527 (2008) ), and NRG Power Marketiniz LLC v. Maine Public Utilities
Commission. 558 U.S. 165 (2010) (the "Mobile -Sierra" doct} ine).
I
NAEMA with CT 4.30.13
q. Party B is not authorized to sell Energy into Canada and all provisions of the Tariff related to
Canadian Law shall not be applicable to Party B, unless and until Party B notifies Party A that it
has obtained an export license to transact in Canada.
5. Notices
Party A:
Address: Hutchinson Utilities Commission
225 Michigan St. SE
Hutchinson. MN 55350
Duns: 154439301
Federal Tax ID: 41-6005251
Attention: General Manager
Telephone No.: (320)587-4746
Facsimile No.: (320)587-4721
Payments:
Attn: Jared Martig
Phone: (320) 234-0512
Facsimile: (320) 587-4721
Wire Transfer:
BNK: Citizens Bank & Trust Co.
ABA: 091-901-862
ACCT: 000086
Party B:
Address: AEP Energy Partners, Inc.
155 W. Nationwide Blvd.
Columbus, OH 43215
Attention: Contract Administration
Telephone No.: (614) 583-6463
Facsimile No.: (614) 583-1606
Duns: 825534923
Federal Tax ID: 77-0690681
With additional Notices of an Event of Default or Potential Event of Default to:
Address: AEP Energy Partners, Inc.
NAEMA with CT 4.30.13
155 W. Nationwide Blvd.
Columbus, OH 43215
Attention: Director — Credit Risk Department
Telephone No.: (614) 583-6828
Facsimile No.: (614) 583-1604
Payments:
Attn: Manager - Power Settlements
Phone: (614) 583-6158
Facsimile: (614) 583-1608
Wire Transfer:
BNK: Citibank N.A.
ABA: 021-000-089
ACCT:30646208
The Parties hereby agree that the General Terms and Conditions are incorporated herein, and to
the following provisions as provided for in the General Terms and Conditions:
Party B Tariff(s). Fifth Revised Rate Schedule FERC No. 1, effective June 28, 2007 in Docket
Number ER07-1130-000.
6. Effect. This Supplementary Agreement shall be applicable to all Transactions entered into
between Party A and Party B pursuant to the Agreement on or after the Effective Date without
the need to reference this Supplementary Agreement in any such Transaction unless Party A and
Party B mutually agree otherwise with respect to a particular Transaction. Capitalized terns
used but not defined in this Supplementary Agreement shall have the meanings ascribed to them
in the Tariff.
7. Entire Agreement. This Supplementary Agreement constitutes the entire agreement and
understanding of the Parties with respect to its subject matter and supersedes all oral
communication and prior writings (except as otherwise provided herein) with respect thereto.
8. Counterparts. This Supplementary Agreement may be executed and delivery in counterparts
(including by facsimile transmission), each of which will be deemed an original.
9. Authority to Bind. By signing below, each individual additionally warrants that he or she is
authorized to sign this Supplementary Agreement on behalf of the Party for which it was
executed.
10. Headings. The headings used in this Supplementary Agreement are for convenience of
reference only and are not to effect the costruction of or to be taken into consideration in
interpreting this Supplementary Agreement. ?In witness whereof, the Parties have executed this
Supplementary Agreement with effect from the date above written.
NAEMA with CT 4.30.13
Party A:
Party B:
HutchinsoEPresident
Commission AEP Energy Partners, Inc.
r
Name: Name:
Title: Title:
NAEMA with CT 4.30.13
Marketing Number: 2016-_
Trade Date: May , 2016
AEP Energy Partners, Inc.
155 West Nationwide Blvd, Ste 400
Columbus, OH 43215-2373
MASTER POWER PURCHASE AND SALE AGREEMENT
CONFIRMATION AGREEMENT
This Confirmation Agreement ("Agreement") shall confirm the agreement reached on
May , 2016 ("Transaction Date"), by and between Hutchinson Utilities
Commission, Minnesota ("HUC") and AEP Energy Partners, Inc. ("AEP EP") (herein
after HUC and AEP EP are sometimes referred to singly as a "Party" and collectively as
the "Parties") with respect to the purchase and sale of capacity under the terms and
conditions as follow:
Seller: HUC
Buyer: AEP EP
Schedule P Product:
[X] Other: Capacity, which for the purposes of this Transaction shall mean
"Zonal Resource Credits" ("ZRC") for and in Local Resource
Zone 1 ("Zone I"), as such term is defined in (i) the Midcontinent
Independent System Operator, Inc. ("MISO") Open Access
Transmission, Energy, and Operating Reserve Markets Tariff, as
may be amended from time to time ("MISO Tariff'); and (ii) the
MISO Resource Adequacy Business Practices Manual, as may be
amended from time to time ("RA BPM", or together with the
MISO Tariff referred to as the "MISO Rules").
For clarification purposes, the Parties acknowledge and understand
that, in accordance with the MISO Rules, one ZRC represents one
megawatt ("MW") of the Unforced Capacity from a Planning
Resource that has been converted to a credit in the MECT, which
is eligible to be offered by a Market Participant into the Planning
Resource Auction for and in Zone I and quaV-11
es to satisfy the
resource adequacy requirements of Module of the MISO
Tariff.
Contract Ouantitv and Contract Price:
The Quantity of ZRCs and the applicable Local Resource Zone 1 credits ("LRZI"), as
further described in Attachment VV of the MISO Tariff, associated with such ZRCs for
each Planning Year (i.e., June 1St of one year through May 31" of the following year)
encompassed by this Transaction, and the Contract Price(s) associated therewith shall be
as follows:
$1,350 per MW -month x 5 MW=$6,750 per month June 2019 -May 2020
$3,250 per MW -month x 45 MW=$146,250 per month June 2020 -May 2025
Seller represents and warrants that with respect to the Product, Seller: (A) Will timely
enter the ZRCs in the MISO Module E-1 capacity tracking system, or any successor
system ("MECT"); and (B) has not and will not sell such ZRCs (or the MWs of Unforced
Capacity associated with each ZRC) to any other counterparty.
Special Conditions:
1. Delivery and Receipt:
Seller shall accomplish delivery of the Quantity by submitting the appropriate
transaction(s) in MISO's MECT to electronically assign the Quantity to Buyer. Buyer
shall accomplish receipt of the Quantity by confirming the appropriate transaction(s)
submitted by Seller in the MECT. Seller and Buyer shall accomplish delivery and receipt
of the Quantity by submitting and confirming the appropriate transaction(s) in the MECT
no later than one (1) Business Days prior to each Planning Resource Auction, as such
term is defined in the MISO Tariff, for the first Planning Year and each subsequent
Planning Year encompassed by this Transaction in accordance with the MISO Rules and
any MECT requirements ("Transfer Deadline").
2. Pavment Terms:
The Parties agree that the payment schedule for the Product delivered and received
hereunder shall be governed by the terms and conditions of the North American Energy
Marketers Association ("NAEMA") Capacity and Energy Tariff, effective February 22,
2011 (the "NAEMA Tariff") and the Supplementary Agreement entered into between the
Parties. For the avoidance of doubt, as soon as practicable, after the end of each
electronic delivery for each Planning Year set forth above, Seller will render to Buyer
and invoice for the Product (e.g. ZRCs) attributable to the delivery for each month of the
Panning Year on a monthly basis.
3. Failures to Deliver and/or Receive:
(a) Seller's Failure to Deliver. In the event that Seller fails to deliver all or part of the
Product by the Transfer Deadline, and such failure is not excused by Buyer's failure to
perform, then Seller shall pay Buyer, within five (5) Business Days of invoice receipt, the
positive difference, if any, obtained by subtracting the Contract Price from the
Replacement Price and multiplying the positive difference, if any, by the portion of the
Quantity which Seller failed to deliver. For the purposes of this Confirmation, the
Replacement Price shall mean the Auction Clearing Price for Zone 1 for the relevant
Planning Year, provided, further, if there is no Auction Clearing Price for Zone 1 at the
time of the failure to deliver or other Event of Default, Buyer shall calculate its damages
for the Local Resource Zone 1 Product under this Confirmation in a commercially
reasonable manner at the Early Termination Date.
The invoice from Buyer to Seller for any amount owed by Seller to Buyer pursuant to this
provision shall include a written statement explaining in reasonable detail the calculation
of such amount. The Parties acknowledge and agree that with respect to this Transaction
only, Section 2.47 of the NAEMA Tariff shall be amended to delete all references to "at
the Delivery Point" and "to the Delivery Point" contained in such section.
(b) Buver's Failure to Receive.
In the event that: (i) Buyer fails to receive all or part of the Product by the Transfer
Deadline, and such failure is not excused by Seller's failure to perform, then Buyer shall
pay Seller, within five (5) Business Days of invoice receipt, an amount equal to the
positive difference, if any, obtained by subtracting the Sales Price from the Contract Price
and multiplying such positive difference, if any, by the portion of the Quantity which
Buyer failed to receive. For the purposes of this Confirmation, the Sales Price shall be
the Auction Clearing Price for the ZRCs in Local Resource Zone 1 for the relevant
Planning Year, provided, further, if there is no Auction Clearing Price at the time of the
failure to receive or other Event of Default, Seller shall calculate its damages for the
Local Resource Zone I Product under this Confirmation in a commercially reasonable
manner at the Early Termination Date.
The invoice from Seller to Buyer for any amount owed by Buyer to Seller pursuant to this
provision shall include a written statement explaining in reasonable detail the calculation
of such amount. The parties acknowledge and agree that with respect to this Transaction
only Section 2.49 of the NAEMA Tariff shall be amended to delete all references to "at
the Delivery Point" contained in such section.
(c) Limitation of Remedies. The Parties acknowledge and agree that the remedies set
forth herein regarding failures to deliver/receive shall supersede and replace Sections 5.1
and 5.2 of the NAEMA Tariff with respect to the Transaction only.
4. Governiniz Agreement:
This Confirmation is being provided pursuant to and in accordance with NAEMA Master
Power and Sale Agreement dated , 2016 (the "Master Agreement")
between AEP EP and HUC and constitutes part of and is subject to the terms and
provisions of such Master Agreement. The commercial terms and conditions of the
NAEMA Tariff shall apply to this Confirmation; provided, however, that to the extent
that there is an inconsistency between the terms and conditions of this Confirmation and
the NAEMA Tariff, the applicable terms and conditions of the Confirmation shall govern.
Terms used but not defined herein shall have the meanings ascribed to them in the
NAEMA Tariff. Capitalized terms used but not defined herein or in the NAEMA Tariff
shall have the meanings ascribed to such terms in the MISO Rules.
HUTCHINSON UTILITIES COMMISSION
By: �=Date:
Name: Donna Luhri ng
Title: President
AEP Energy Partners, Inc.
M
Name:
Title:
Date:
HUTCHINSON UTILITIES COMMISSION REQUISITION FORM
Supplier: MICRO MOTION INC Ship To: HUTCHINSON UTILITIES COMMISSION
7070 WINCHESTER CIRCLE 175 MICHIGAN ST SE
BOULDER, CO 80301-3501 HUTCHINSON, MN 55350
Phone: 612-670-5640 Phone: 320-587-4746
Fax: Fax: 320-587-4721
Item # Qty. I (Part Num.) Description
1 2 I (000-00000)
2 1 2
Line Remarks: ETOITEM MX_25532, Micro Motion Sample
Conditioning System, SG Meter, includes:
SGM3AAAAC2131 EZZZ(TG), 316 Insulated housing with 115 VAC
heater (NA -184-10), pressure regulator, coalescing filter, roto
meter, barriers, valves, wallmount brackets as a complete
assembly as per proposal number: 702766-2.
Line Remarks: DENSSTARTUP1, 3098SG/SGM Startup
assistance as per proposal number: 702766-2.
Requisition No. 006719
Request Date I Acct # I WO # I Unit Price I Per I Item Total
108/12/2016 11073690100 161602 1 31,878.50 1 Each I 63,757.00
08/12/2016 11073690100 161602
Requisitioned By: WEBSTER, JOHN
Approved By:
1,600.00 1 Each 1 3,200.00
Sales Tax 4,603.29
Special Charges 971.00
Total 72, 531.29
Date: 05/18/2016
Date:
Page 1 of 1
o Hutchinson Utilities Commission
UTlLITVL
2016 Infrastructure Presentation
Wednesday, May 25th, 2016
3:00 p.m.
00
(*D:Themes of Presentation
❑ Review the Infrastructure process
❑ Review prioritization of Infrastructure
❑ Provide current overview & valuations of HUC's
Infrastructure
❑ Discuss the potential funding requirements for the
Infrastructure program.
Maintenance Program
New Investments
❑ Solicit Commission Feedback on the preliminary
presented program
v
f
HUC's Infrastructure Process
Put together one current comprehensive inventory list
Type of infrastructure, year, current & future replacement value,
estimated useful life, and estimated replacement year
Adjusted future costs by inflation
Prioritization of Infrastructure
Critical, Very Important, Important, Future Consideration
New infrastructure
Reimbursable or non -reimbursable
Maintaining existing infrastructure vs new infrastructure
iIdentified the minimum annual fundin requirements f
or
maintaining existing infrastructure: 5- 0 year window
Based off current preventative maintenance program
o Funding between operating & capital budget
Level funding requirements for on-going maintenance of existing
infrastructure. New Infrastructure would need to be factored in.
N I N'T"
HUC's
PRatin9
Priority 1: Critical
Projects currently underway or prolects/equipment that are considered essential to HUCIs
operatio s, and should not be delayed beyond the yearrequested. Failure to fund these
projects/equipment c uld seriousl jeopardize HUC s ability to provide service reliability
to the customers and/ expose WUC to a potential liability and negative legal exposure.
Priority 2: Very Important
Projects or equipment that are needed by HUC to improve or maintain operations, and to
delay would cause deterioration or further deterioration of current operation and7or level
of service to the customers of HUC. These should not be delayed beyond the year
requested.
Priority 3: Important
Projects or equipment that are needed by HUC to improve or maintain operations, and
should be done as soon as funds can reasonably be made available.
Priority 4: Future Consideration
Projects or equipment which are desirable, but needing further study and may need to be
funded to maintain operations, safety, or infrastructure desired within the community
HUC's Current Inventory &Valuation
See detailed models
Total Gas Infrastructure
Current Est. Replacement Costs - $54,082,210
Total Electric Infrastructure
Current Est. Replacement Costs - $74,566,968
(3-1:
Infrastructure Min. Annual Funding — Maintain
Existing Infrastructure
$500,000
$400,000
E•IE ter,
$ 200,000
$100,000
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 Average
E -Dist/Trans
G - Dist/Trans
Production
■ Annual Funding
Commission Considerations
Existing Infrastructure annual funding level of $SOOK -600K for
Infrastructure maintenance/replacement program (5-1 � year outlook)
New Infrastructure or large Capital Purchases would need additional
funding requirements
Developments, Customers, Generators
Cash versus Debt Service
0 Revenue stream opportunities on capital purchase investments
o Revise Capital Expenditure Funding levels
® Start revising 5, 7,10,15 years from major capital purchases
❑ Commission Designated cash balance
o Could change at the discretion of the commission
o "Emergency Funds" Designation
13 Maintain Adequate Cash Balance for unplanned events
13 Designation for future major capital purchases
CHI
Hutchinson Utilities Commission
UTI UT1E
Discussion or Questions?
R.pke.
Stabs
RWS
RWS
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InBation Rab
I Target
I Ln.
1 40
1 40
I 40
1 40
1 40
1 40
1 40
1 40
I 40
I 40
1 40
I 40
1 40
1 40
1 40
1 40
1 40
I 40
1 40
I 40
I 40
1 40
I 40
I 40
60
60
60
60
60
60
60
60
60
60
50
60
80
50
50
60
80
60
50
40
40
40
40
40
40
40
an
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
Y... to m..l
2.00%
In47ervk.
Y.-
80
50
42
30
35
34
31
20
24
22
11
14
13
13
12
8
8
5
5
4
4
3
2
1
62
50
47
46
45
39
38
35
32
25
16
15
14
13
12
11
10
5
4
25
20
15
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10
10
7
5
4
1
25
20
18
15
12
10
10
7
5
4
1
15
7
5
1
40
40
aMklpaled Ids:
Less tlun:
Annual:
Cumulae.:
Y... I
Remaining I Comment
I
0 I
0 I
0 I
10 1
s I
6 I
9 I
20 I
16 1
18
29 1
26 I
27 :
27 :
28 I
32 I
32 I
35 I
35 I
36 I
36 1
37 I
38 1
39 1
0
10
13
14
15
21
22
25
28
35
44
45
46
47
48
49
50
55
56
15
20
25
28
30
30
33
35
36
39
15
20
22
25
28
30
w
33
35
36
39
25
33
35
39
0
0
I,; 6eMilubd PWOO. d
2016 2017
0 1
0.00% 2.00%
0.00% 2.00%
>IT14ti ��
296.389 1
296.389 1
2018 2019
2 3
2.04% 2.08%
4.04% 6.12%
2015 1 7019
Amlclnated InYear Acouisition [with 2% an ... I Infktionl
2020 2021 2022 2023
4 5 6 7
2.12% 2.16% 2.21% 2.25%
8.24% 10.41% 12.62 % 14.87%
2020 1 2021 1 2222 1 2023
I I 1
I 33,122 1
I I 84,462
I I I
I 33,122 1 84A62 1
I 33.1-22 1 34A52 1
- I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
2024
8
2.30
17.17%
2024
2025 2026 2027
9 10 11
2.34% 2,39% 2.44%
19.51% 21 BO% 24.34%
I I
2025 I 2025 I 2027
I I
-
--
--
1 375,938 1
-
--
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. I I -
. I I -
. I I -
--
. I I -
.-
.
-
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.
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- 1 1 -
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-
I
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-
.-
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--
.-
--
- I I -
.-
I I
-
-
I I
2028 2029
12 13
2.49% 2.54%
26.82% 29.36%
1 83,828 1
I I
1 83.826 1
I 83.826
I I
I I
I I
- I I
2030
14
2.50%
31.95%
u
2031
15
2.64%
34.59%
I I ANNUAL
2031 I TOTAL AVERAGE
I
- I I
- I I
- I I
- I I
- I I
- i I
- I I
- I I
- I I
- I I
I I I
I 753.632 1 47,102 1
- I 753,6321 47.1021
I I I
I I I
- I I
- I I
- I I
9,690 I 1
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- 1 I
- I I
- I I
- I 1
I I
9,690 1 216.470 I 13.529
9.690 I 216.470 13.529
-
I I
I I
I I
232,493 [
- I I
- I I
. I
- I
- I
_ I
- I
97,510 1
- I
- I
- I
_ I
_ I
- I
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_ I
_ I
- I
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- I
- I
- I
I
_ I
I
I
I
330.003 I 626.392
330.003 1 626.392
I
I
I
I
I
39.149 I
39.149 1
Budget Year:
2018
E4.91ab "
I
I
I
I
I
I
I Currant R*,la, mml,Cot I
Dept
I CapSal A+e.l
I Year
I Sla
I .-Ilptbn
I
I
I Total I
"Y.:,
IE.abkT.-Isslon
I
I
I
I
I
I I
I
Transformer
1(7) Transformers from ft 50'.
1 1955
1 24M
ITranafarmer
ITransformar
ITransformer
1 9.4001
2351
Transformer
1(4) Transformers from the fig's
1 1965
1 24M
11'ransfwmer
ITransfwmer
11'ransfarmer
1 6,6001
1651
Transformer
1(39) Transformers from the 70's
1 1973
1 Vandus
ITr... former
ITransbrmer
[Transform:
1 124,6001
3,1151
Transformer
1(115) Transformers from the 80's
1 1985
I Various
ITransformer
ITransformer
ITransformer
1 308,4001
7,7101
Transformer
1Gen:a1 Elactnc
1 1980
1 13800/7970
1Transformer
]Transformer
11'randomer
1 30.0001
7501
Transformer
I Heavy Duly Industries
1 1981
1 13800
11'ransformer
]Transformer
11'ransformer
1 75,0001
1,8751
Transformer
1Gen:al Ebctnc
1 1984
1 1380017970
ITransfonnar
ITransformer
ITrand-.r
1 100,000 1
2,500 1
Transformer
1(408) Transformers from the 90's
1 1995
1 Van...
]Transformer
]Transformer
11'ransbrmer
I 1,322,9001
33,0731
Transformer
1RTE
1 1991
1 1380077970
ITransformar
ITransformer
11'r -dormer
I 800,000 1
20.000 1
Transformer
1P. -Is
1 1993
1 13800/7970
11-ransformer
ITransfwmer
11'ransfwmer
I 1,000,0001
25,0001
Transformer
113991 Transformers from the 00's
1 2004
I VaMus
]Transformer
ITransfwmer
ITr-dourer
I 1,100,0001
27.5001
Trans(amer
1Pa-*L5
I 2001
1 230000
1Translwmer
1Tranarwmer
]Transformer
1 1,500,0001
37,5001
Transformer
[Waukesha
1 2002
I Regttabd
]Transformer
ITransformer
ITransfomer
1 1.000.0001
25,0001
Transformer
1KUNman
I 2002
: 13800/7970
ITransbrmer
1Transrwmer
1Transrwmer
I 1.000,0001
25,0001
Transformer
1T andR
1 2003
1 13800/7970
1Trand.-ar
ITransformer
11'ransf-ar
I 50,0001
1,2501
Trsnslormer
]Cooper Industries
I 2007
1 13800/7970
]Transformer
mm
ITransroer
ITransbrmer
I 50,0001
1,2501
Transformer
1B and B
1 2007
[ 13800/1970
]Transformer
1Trandonner
ITranaform:
I 30,000 1
750 1
Transformer
IKUNman
1 2010
1 13800/7970
ITranafwmar
ITransformer
[Transformer
1 800,000 )
20.000 I
Transformer
1(30) Transformers from 2010
1 2010
1 Varlow
ITransbrmer
[Transfwmer
[Transformer
1 82,0001
2,0501
Transformer
1McG-Edison
1 2011
1 1380077970
ITrand-.r
ITransformer
11'ransformar
1 600,0001
15,0001
Transformer
1(10)Transformere from 2011
1 2011
I Nanous
ITransformer
1Tranarwmer
]Transformer
1 12,800 1
585 1
Transformer
1(fi) Transformers from 2012
1 2012
1 Vanous
ITransformer
1Transfwmer
11'rensformer
1 2U00
5051
Transform:
113)Transbrnarshorn2013
1 2013
I Various
ITrand.-.r
ITransformer
1Trand mer
1 6,9001
1731
Transform:
1131 Tmnsfornars from 2014
1 2014
I Various
]Transformer
]Transformer
11'ransf-
1 15,0001
3751
I
1(1037Trans/ )
I
I
I
1
I
1Tramfxmer
I
I
I
11.
I I
I 10,053,8001
I
251.3411
I
I
I
1
I
1
I
1
I
1
I
:Transformer
I
1 10,053,6001
I I
251.3411
1
I
I
1E1
I.cbk poke
I 1
I
I
I 1
I
I
I I
I
I Pobs
1(12)Pobs
1 1953
150006
]Wood Pobs
[Poles
]Pobs
I 88.4001
1,4401
1 Perks
I(2)PCbs
1 1965
]Wood
[Wood Poles
1Pobs
1Polea
1 14,4001
2401
1 Perks
1191 Pobs
: 1988
1WOM
[Wood Pabs
1Pobs
1Pobs
1 64,8001
1,0801
I Perks
1121 Pdes
1 1969
1Wod
(Wood Poles
]Pobs
:Poles
1 4,6001
2401
1 Pols
Ill)Pole
1 1970
(Wood
[Wood Poles
IPOks
1Poba
1 7,2001
1201
I Perks
11291 Poles
1 1976
]Wood
[Wood Perks
IPobs
]Poles
1 208,8001
3,4801
: Perks
1(11 Pde
1 1977
]Wood
]Wood Pobs
IPobs
1Pobs
1 7.2001
1201
Pobs
I(1)Pole
1 1980
]Wood
]Wood Poles
IPobs
1Pobs
1 7.2001
1201
Perks
1(41 Pdes
1 1983
]Wood
]Wood Perks
IPobs
1Pobs
1 28.8001
4801
1 Perks
81 Pdes
1 1990
]Wood
]Wood Pobs
1Poles
1Pobs
1 57,6001
0601
1 P.I.s
1(1)Pd.
1 1999
[Wood
[Wood Poles
1PObs
1Pobs
1 7,2001
1201
I P.I.s
I(74)Poles
I 2000
[Wood
IWOod Poles
1Pobs
1Poba
1 532,8001
8,8801
1 Pobs
1(7)Poles
1 2001
[Wood
(Wood Poles
s
1Pos
b
1Pos
1 50,4001
8401
I Pobs
J(8) Poles
1 2002
1WOod
[Wood Poles
IPobs
1Poks
1 57,6001
9801
I Pobs
1141)Poles
1 2003
]Wood
(Wood Poles
1Pobs
1pobs
1 295,2001
4,9201
1 P.I.s
1113)Poles
: 2004
]Wood
(Wood Pols
1pobs
1Pobs
1 93,6001
1,5601
I Perks
113)Poles
I 2005
]Wood
]Wood Poles
1Pobs
IPobs
1 21,6001
3801
1 Poles
1(1)Pob
1 2010
]Wood
:Word Pobs
]Perks
IPobs
1 7,2001
1201
1 Poles
I
1(1)Pda
: 2011
]Wood
]Wood Poles
:Pobs
:Pobs
1 7,2001
1201
I
1(218 PWes In 5arvlc )
I
I
I
I
1
IPobs
:
[
I
[Total
I I
[ 1.569.600 1
I
26.160 1
1
I
:
I
1
1
I
I
I
IPobs
:
1 1,569.8001
26.1601
I 1
1Ebcbk- UM.rgroaM COMaebr
1
1
1
1
1
1
1
I I
I
Condudw
I
I Conductor (70,776 Fl installed)
I
1 1990
I
11/0
I
1Alumnvn Corsi-
I
]Conductor
I
IConductcr
I I
1 172,7461
:
4,3191
Conductor
1Conductw(249,066 Ft instalad)
1 1995
11/0
IN -urn Conductor
IC.M -
1C.Muctor
1 560,3981
14.0101
Conductor
IConJ cm (104,665 Ft installed)
1 2000
11/0
INunnun Cond-
ICOMucto
ICoMuctor
I 235.4961
5,8871
Conductor
IConducto(155,028 Ftnalalbd)
1 2003
IIA
IAluni,un Conductor
Komodo,
ICondudor
: 348,8121
8,7201
Com-
ICond-or(82,353 Flmlall.d)
1 2005
1110
INumnum COMuctor
1CoMuctor
IConhd
1 185.2931
4,6321
COMU-
1Conduclor(4.360 Ftmlabd)
1 2005
1110
Imemnum Conductor
1Cord.W
[Conductor
1 9.8101
2451
Conduct:
I COMuclw(43,404 Ftmtalbd)
1 2008
1110
1AAamhun Cond.c
ICOrd.W
ICondudor
1 97.6581
24411
Conductor
1Conlww(53.184 Ftnstaled)
1 2010
11/0
INumman Conductor
1Conduclw
:Conductor
1 119,8181
2.990I
Conductor
ICOMuotor(104,678 Flhstalbd)
1 2011
1110
]Alumimam Conductor
1Conoww
k cmduotar
1 235,5251
5,8881
Conductor
I Conductw(293,391 Ft installed)
1 2014
11/0
1Alumm,m Cord -b
[Conductor
1Conductor
1 660,1311
16,5031
Conductor
18,113 Ft nstalkd)
I 1990
INumilun Conductor
[Conductor
ICondudw
1 72,451 1
1.811 1
Conductor
jr-Muc-O
1CoM- (81,528 Fl installed)
1 1995
1500MCM
1500MCM
INumnun Conductor
1COMVLtw
1COMlnctw
1 248,1021
8,1531
1 C.Muctor
COMuclw (5, 074 Ft installed)
1 199]
1500MCM
INumnun Conductor
IC.Muctor
1C.Mu-
1 20,2941
5071
I COMUctw
1Conductor 131,969 Fl Installed)
I 2000
1500MCM
1Numnum Conductor
ICOMuctOr
]CoMuclw
1 127,8761
3,1971
1 COMuco
1 Cord=Fllnstalled)
1 2003
1500MCM
1Numnum Conductor
1Conductor
1Condudor
1 97,4571
2,4361
1 Conduce
1Conductor(18,495 Fl installed)
1 2005
1500MCM
IAM-C.Muctor
IConductw
IConductor
1 73,9781
1,8491
I COMu w
I Conductor(13,411 Fl insbfled)
1 2005
1500MCM
1Numian C.M-tor
1Conductw
ICOrd.Wr
1 53,8431
1,3411
1 COMu w
1Cond-r(25,765 Fl installed)
1 2008
1500MCM
1Num.num Conductor
]Conductor
1CoMuctor
1 103,0591
2,5761
1 Condu tor
1c 17,:1 x(35,960 Ft i..WW)
1 2010
1500MCM
INumnvn COMudw
IConductw
ICanducbr
1 143,8411
3,596 [
Conductor
I CoMuctOr(11,347 F1 installed)
1 2011
1500MCM
[Num.. Coro -or
ICord c
IConduclw
1 45,3861
1,1351
1 Conductor
I Conductor (7,507 Fl nstaled)
1 2014
1500MCM
:Alumnum Cord-
1Conductw
1Condudor
1 30.0291
7511
1 Conduco
Conductor (21,130 Ft nstalled)
1 2000
1500MCM
1Numnum Conductor
ICOMuolor
1COndudor
1 128.7771
3.1691
COMuctOr
Conducb(4,119 Ft
:C
1 2008
11000MCM
1AknCOndrb
1: Conductw
1I Comu
1 24,7121
6181
Conductor
78
1 2010
11000MCM
1Akani an CotlY
1c.
1cni-or
1 467 1
12 1
I11 O
Cno
-Wed)
[M(
12.503 Fln)
2014
11000MCM
1AI"m, Cnl
1 75.0201
1,8781
1 Condu
ICondu
Prbrb1990
--::5.993
ICOMuolw185.993 Flnsblbd)
]
1 1975
1lM
IAli
umum Conduclw
ICoMucbr
[Conductor
1 193,4831
4.8371
I Conductor
I
I
1 Conductor
I I
I 1975I500MCM
I
I
1N um nun COMucw
I
ICoMub
I
]Conductor
I
1 102,9061
II I
2,5731
I
I
I
I
I
1s-ke)
I
I
1
I
I
I
I
I
1GOrduOsor
I
I
I
I
I
I I
I I
1 4,162.91781
I
I
104.0721
I
I
1-297MIlea
I
I
I
[
[
:
I
:
[
IITolal
COMuclor
1 4.1620061
] t
104.0721
I
R.pke.
Stabs
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
RWS
InBation Rab
I Target
I Ln.
1 40
1 40
I 40
1 40
1 40
1 40
1 40
1 40
I 40
I 40
1 40
I 40
1 40
1 40
1 40
1 40
1 40
I 40
1 40
I 40
I 40
1 40
I 40
I 40
60
60
60
60
60
60
60
60
60
60
50
60
80
50
50
60
80
60
50
40
40
40
40
40
40
40
an
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
40
Y... to m..l
2.00%
In47ervk.
Y.-
80
50
42
30
35
34
31
20
24
22
11
14
13
13
12
8
8
5
5
4
4
3
2
1
62
50
47
46
45
39
38
35
32
25
16
15
14
13
12
11
10
5
4
25
20
15
12
10
10
7
5
4
1
25
20
18
15
12
10
10
7
5
4
1
15
7
5
1
40
40
aMklpaled Ids:
Less tlun:
Annual:
Cumulae.:
Y... I
Remaining I Comment
I
0 I
0 I
0 I
10 1
s I
6 I
9 I
20 I
16 1
18
29 1
26 I
27 :
27 :
28 I
32 I
32 I
35 I
35 I
36 I
36 1
37 I
38 1
39 1
0
10
13
14
15
21
22
25
28
35
44
45
46
47
48
49
50
55
56
15
20
25
28
30
30
33
35
36
39
15
20
22
25
28
30
w
33
35
36
39
25
33
35
39
0
0
I,; 6eMilubd PWOO. d
2016 2017
0 1
0.00% 2.00%
0.00% 2.00%
>IT14ti ��
296.389 1
296.389 1
2018 2019
2 3
2.04% 2.08%
4.04% 6.12%
2015 1 7019
Amlclnated InYear Acouisition [with 2% an ... I Infktionl
2020 2021 2022 2023
4 5 6 7
2.12% 2.16% 2.21% 2.25%
8.24% 10.41% 12.62 % 14.87%
2020 1 2021 1 2222 1 2023
I I 1
I 33,122 1
I I 84,462
I I I
I 33,122 1 84A62 1
I 33.1-22 1 34A52 1
- I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
I I I
2024
8
2.30
17.17%
2024
2025 2026 2027
9 10 11
2.34% 2,39% 2.44%
19.51% 21 BO% 24.34%
I I
2025 I 2025 I 2027
I I
-
--
--
1 375,938 1
-
--
119,SOB-
_ I I -
I I -
I _ I -
1 - 1 -
I - I -
I - I -
I I -
I - I -
.-
.-
'-
.-
_
-
" I I -
--
.
I I
119.509 1 375.938 1 -
119.500 1 375.938 1 -
I I
I I
I I
17,554 1
-
--
--
--
- I I -
. I I -
. I I -
. I I -
--
. I I -
.-
.
-
--
.
I 1
I 17.554 I
I 17.554 1
-
I I
I I
I I
-
. I I -
_
-
1 - 1 -
- 1 1 -
I I .
-
I
_ I I
_ I I
-
.-
--
_ I I -
--
.-
--
- I I -
.-
I I
-
-
I I
2028 2029
12 13
2.49% 2.54%
26.82% 29.36%
1 83,828 1
I I
1 83.826 1
I 83.826
I I
I I
I I
- I I
2030
14
2.50%
31.95%
u
2031
15
2.64%
34.59%
I I ANNUAL
2031 I TOTAL AVERAGE
I
- I I
- I I
- I I
- I I
- I I
- i I
- I I
- I I
- I I
- I I
I I I
I 753.632 1 47,102 1
- I 753,6321 47.1021
I I I
I I I
- I I
- I I
- I I
9,690 I 1
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- I I
- 1 I
- I I
- I I
- I 1
I I
9,690 1 216.470 I 13.529
9.690 I 216.470 13.529
-
I I
I I
I I
232,493 [
- I I
- I I
. I
- I
- I
_ I
- I
97,510 1
- I
- I
- I
_ I
_ I
- I
_ I
_ I
_ I
- I
- I
- I
- I
- I
I
_ I
I
I
I
330.003 I 626.392
330.003 1 626.392
I
I
I
I
I
39.149 I
39.149 1
Budget Year: 2016 I f -leate ,a
I I
Wth 2% annual
I
I
I
I I
Current Replacement
Replacement
Cost I
Replace
Capital Asset I
Year
I Size
I Description
I
I I
Total
Year I
Status
IG,. -Mains I
10
I
I
I
I I
I
I
2.39%
132.77 Miles 1
1901
12' or Less
I Distribution Mains
ISteel
ISteel 1
1,730,2561
57,6751
RWS
Miles 1
1971
12"-4"
10istribution Maine
ISteel
ISteel 1
1,160,7551
38,6921
RWS
113.74
7.77 Miles 1
1989
10ver 4'-8"
IDistribution Maine
ISteel
ISteel I
1,517,9471
50,5981
RWS
3.00 Miles 1
1996
10ver 8"-12'
1Dislributbn Maine
ISteel
ISteel 1
1,108,8001
36,9601
RWS
0.00 Miles 1
0
10-r 12"
10istribution Maine
ISteel
ISteel I
- I
- I
RWS
I
2820 Miles 1
1978
I
12- or Less
I
1Dislribulion Maine
I
1Polyethvlene
I I
!Polyethylene 1
I
1,383,3801
I
46,1121
RWS
2059 Miles 1
1989
12"-4"
1DiMributbn Maine
1Po1yethyiene
!Polyethylene 1
1,739,4431
57,9811
RWS
1.72 Miles I
1998
Oyer 4'-B"
IDistributbn Mains
1Polvelhvtene
IPolvethvtene 1
336,0191
11,2011
RWS
0.00 Miles !
0
10ver 8"-12'
113islribution Maine
IPolyelhylene
IPolyethNene I
- I
- I
RWS
0.00 Miles ,
0
10ver 12"
IDislributbn Mains
IPolvelhylene
IPolyethviene I
- 1
- 1
RWS
I
I
I
47,8481
I
I Gas-Ma
!ins
I
1
I II
ITolal
I
8,978,580 I
I
289,219
I
90 552-
I
(Distribution MainsI
I Steel I
5,517,758 I
183,925 ]
I
I
I
1
I
I
I
I
1
I
1Polyelhylem ]
I I
3,458,822 1
I
115,294 1
I
-
Gas I
3061 Service Lines !
1961
I
11" or less
I
IService Lines
I
ISteel
I I
ISteel I
1
2,203,920 1
1
73,464 1
RWS
24 Service Lines 1
1971
Over 1"-2"
IService Lines
ISteel
ISteel 1
21,600 1
720 1
RWS
2 Service Linea 1
1989
10ver2"-4"
1Service Lines
ISteel
ISteel I
2,8801
961
RWS
1 Service Line 1
1996
1Ove r 4"-8"
IService Lines
ISteel
ISteel I
3,3301
1111
RWS
0 Service Lines 1
0
10ver8"
IService Lines
ISteel
ISteel I
- I
- I
RWS
I
2274 Service Lines :
1978
I k
11"orss
I
Service Lines
I
1PoWethNena
I I
1Polvelhilene 1
I
1,637,2801
I
54.5761
RWS
42 Service Lines 1
1989
10ver 1"-2"
!Service Lines
1PolvethNene
[Polyethylene I
37,8001
1,2601
RWS
3 Service Lines 1
1998
10ver2"-4"
,Service Linea
IPolvethylen,
IPolvethvlene 1
4,3201
1441
RWS
0 Service Lines 1
0
10ver 4"-8"
!Service Lines
IPolvethvlene
1PolyethNene I
- 1
- 1
RWS
0 Service Linos 1
0
10-r 8"
1Service Lines
1Po1velhNene
(Polyethylene I
- I
- I
RWS
I
]
I
1
I
IGa-Ur ice Linea
I
1
I I
!Total 1
I
3,911,130 1
I
130,371 1
I
I
1Lirws
1
ISteel I
2.231,730 I
74,391 1
I 1
I
1
:
1
:PON.1thykne I
1,679,4001
55,9801
I
i2oa I
I
I
I
I
I
I
I I
I I
I
I
I
I
h High Drive 1
1960
INNG
IStatbn#1
IStation#1
IStalbn#1 1
- I
- I
RWS
INorth High Drive 1
2003
(HUC
lStallon#1
Isiah -#1
1Station #1 I
850,0001
28,3331
RWS
I Industrial Drive 1
I
2003
,HUC
Station #2
#
1Slalion #2 1
7,050,0001
35,0001
RWS
I
I 1
I
I
I
IGasstatlons
IStation
1
I2
I
1-rci 1
I
1,900,0001
I
63,3331
1 1
I
1DIstribution Stations
1
IStation #1 I
850,000 1
28,333 1
I I
I
I
I
I Statkn #2 1
1.050.000 1
35.000 1
I I
Ica, I
I
I
I
I
I
I
I
I I
I
1
I
1
15th Ave/Bluff Street I
1966
!Station#1
!District Regulator Station
IDRS
IDRS 1
85,0001
2,8331
RWS
15th
St. 1
1966
1Station#2
1 District Regulator Station
IDRS
IDRS :
85,0001
2,8331
RWS
!Calffomia Street I
1966
1Ste ion #3
10islrict Regulator Station
IDRS
IDRS 1
85,0001
2,8331
RWS
!Cara) 1
1997
Station#4
IDislrict Regulator Station
IDRS
IDRS 1
85,0001
2,8331
RWS
School Road South 1
2010
IStation#5
!District Regulator Station
IDRS
IDRS I
95,0001
3,1671
RWS
!Bluff Street(At River) !
1966
1Station #6
1 District Regulator Station
TORS
IDRS 1
85,0001
2,8331
RWS
,Judson Rd) !
1997
1Station #7
IDislrict Regulator Station
IDRS
IDRS I
55,0001
1,B33I
RWS
IMonmeStreet/FairAve,
1998
Station #9
1 District Regulator Station
IDRS
IDRS 1
105,0001
3,5001
RWS
IAdams Street South !
1999
Station #10
1 District Regulator Station
IDRS
IDRS I
85,0001
2,8331
RWS
I I
I
I
IGas-0RS
I
!
I I
!Total i
I
765,0001
I
25A98I
I
I
,Station
I
]
I
:DRS :
I I
785,000,
I
25-8]
I
GAS I
Miles (16"), 59 Miles 1
I
193
I
ITrensmissbn
I
ITrenami-i
I I
ITmnemissbn 1
I
1
I
1
(1
2003
Miles
Pipe
n
Pipe
32,550,000
723,333
RWS
County esANatonwen 1
2003
116* Pipe
1Rectffier#1
1Rectfier B Ground Bed
IRectdier B Ground Bed 1
70,0001
2,8001
RWS
Cly Rd 2513rown Coumyl
2003
116- Pipe
IRectifier#2
!Rectifier B Ground Bed
!Rectifier B Ground Bed l
70,0001
2,800,
RWS
595th Ave/Sibley County
2003
112'Pipe
JRectffler#3
lRectfier B Ground Bed
I Rectifier B Ground Bed!
70,000!
2,800!
RWS
County 1
2003
112"Pipe
1Rectffler#4
!Rectifier B Ground Bed
I Rectifier B Ground Bed!
70,0001
2,8001
RWS
County ,
2003
,i6"Pipe
,NBPL Interconnect Station ]Imercennect
linter-connect1
1,650,0001
47,1431
RWS
County !
2003
116"Pipe
,Side Valve #1
]Side Valve
ISide Valve ,
175,000,
3,889,
RWS
Milford/Broom County 1
2003
112"Pipe
ISide Valve #2
]Side Valve
ISide Valve I
175,0001
3,8891
RWS
Roundgrove/McLeod 1
2003
112" Pipe
ISide Valve #3
ISide Valve
[Side Valve I
175,000 I
3,889 I
RWS
Collins/Sibley County 1
2003
112" Pipe
,Side Valve #4
ISide Valve
[Side Valve ,
175,000 ,
3,889 ,
RWS
!Coumy 1
2003
116"Pip.
(Bbck Val -#1
IB]ock Valve
IBbck Valve 1
83,0001
1,84{1
RWS
ICounty 1
2003
116"Pipe
113bck Valve #2
IBbck Vahe
,Bbck Valve 1
300,0001
8,6671
RWS
ICounty 1
2003
112- Pipe
IBbck Valve #3
IBbck VaWe
18lock Vahe 1
75,0001
1,6671
RWS
ComkMSibley County 1
2003
112* Pipe
181ock Valve #4
1BIock Valve
Nock Valve 1
83,0001
1,8411
RWS
1HWY 22 ,
2003
112" Pipe
112" Lateral to Station #2
[Lateral
1Laterel 1
55,000 1
1,222 1
RWS
,(HutcWcl-eod) 1
2003
112"Pipe
1lnllet to Station #2
1lnlet
11nlet [
55,0001
1,2221
RWS
,(HutchMicLeod) 1
2003
112" Pipe
llniklto Station #1
inlet
I
lnlat ,
95,000 1
2,111 1
RWS
I I
I ,
I
,
I
IGaa-T--ission
I
I Transmission
I I
ITotal I
I
35,928,0001
I
813,8091
I I
I
(Transmission Equipmerdl Transmission
Tramissbn 1
Ins
32,550,0001
723,3331
1 1
1
1
I
Rectifier B Ground Bed l
280,000!
11,200,
I I
I
I
I
Ilyde=nnect I
1.Wo,000 I
41,143 I
1 I
I
I
I
ISide VaWe 1
700.000 !
15,558 I
I ]
1
1
I
Block Valve ,
541,0001
12,0221
!LateralI
55,000,
1,222,
,Inlet ,
150,000 ,
3,333 1
Inflation Rate
Target
I Life
1 30
1 30
1 30
I 30
I 30
1 30
1 30
I 30
I 30
1 30
30
30
30
30
30
30
30
30
30
30
Years to meal
2.00%
In-service
Years
54
44
26
19
2015
37
26
17
2015
2015
54
44
26
19
2015
37
26
17
2015
2015
anticipated If.
Less than
Annual
Cumulative
Years
Remaining
0
0
11
0
0
4
13
0
0
0
0
4
11
0
0
4
13
0
0
30 1 55 1 0
30 : 12 I 18
30 1 12 1 18
I I
I I
I I
I I
I I
I I
30 I 49 1 0
30 1 49 1 0
30 I 49 1 0
30 1 18 ] 12
30 I 5 I 25
30 : 49 1 0
30 1 16 1 12
30 1 17 I 13
30 I 16 I 14
I I
I I
I I
I I
I I
I I
45
25
25
25
25
35
45
45
45
45
45
45
45
45
45
45
45
12
12
12
12
12
12
12
12
12
12
12
12
12
12
12
12
12
33
13
13
13
13
23
33
33
33
33
33
33
33
33
33
33
33
Comment
Sol".11ad Pureltil►a I
2016 2017
0 1
0.00% 2.00%
0.00% 2.00%
2016 1 2017
1,730,256 I
1,160,755 ]
1,383,360 1
4.274,371
2,891,011
1,383,360 I
I
I
2,203,920 I
21,600 I
1.637.280 1
3,862,800 1
2.225,520 1
1,637,280 I
I
I
- I
- I
I
. I
_ 1
I
I
85,000 I
85,000 1
85.000 I
85,000 I
340.000 1
340,000 1
. I
I
I
2018
2
2.04%
4.04%
2018
2019
3
2.08%
6.12%
,7019
Anticipated Ir Year Acquisition
Wth 2% annual
irdlatinnl
2031
15
2020
2021
2022
2023
2024
2025
2026
4
5
6
7
8
9
10
2.12%
2.16%
2.21%
2.25%
2.30%
2.34%
2.39%
8.24%
1
10.41%
1
1262%
14.87%
17.17%
19.51%
21.90%
2020 I
2021 I
2022
I
1 2023I
I I
2024 I
2025
I I
1 2028 I
1,643,075 1
--
I
I I
434,8781 1
I
I I
800.850
I I
-
I
1,882,829 1
I
I
- 1
I
I
I I
I I
I
I
I I
I
I
I
3,700,865 I
I
I
I
I I
I
I
I I
1,643,0751
I
I
I
I
5,5681 I
I
1,882,829 (
I
I
I
I
I
I
4,1401
I
I
I
I I
I I
I I
I
1
I I
I I
I I
3.1171
I
- 1
I
I I
2,232,778 1
I I
I
40,916 1
I
I
5.5881 I
I I
I I
I I
I
I
I I
I I
105,237
I I
-
I
I
44,033 1
I
I
I
I
I
I
I I
I I
I
I I
I I
3,117 1
I
I
I
I I
I
I I
40,916 1
I
I
I
I I
- 1 112,156 I
I I
I
I
I
I
:
I
I
I
I
I
I
I
I
I
I
I
I
I
I
]
2027
it
2028
12
2029 2030
13 14
2031
15
2.44%
2.49%
2.54% 2.59%
2.64%
24.34%
26.82%
29.36% 31.95%
34.59%
I
I
I I
I
I
ANNUAL
2027 I
I
2028 1
I
2029 I 2030 1
I I
2031 I
I
TOTAL I AVERAGE
I
1,378,653
I
I
I I
I
I
I
I
434,6761 I
I
I
I
1.378,6531
I
- I
I I
434,8781 1
I
- 1
I
8,613,8051
800.850
1,378,8531
- I
- I 1
- 1
5,912,7391
389,548
I
I
I
I
434,676 I - I
I I
I I
- I
I
I
3,700,865 I
I
I
231,304
4,1401
I
I
I
I I
I I
I
I
I
I
I
5,5681 I
I
I
I
4,1401
I
- 1
I I
5.5681 ]
I
1
I
3,916,5621
244,795
4.1401
- 1
" I " 1
- 1
2,232,778 1
139.549
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I
I
I
- I
I
I
I
5.5881 I
I I
I I
I I
- I
I
I
I
1,683,7841
I
I
I
105,237
I
I
I
I
I
107,801 1
I I
I I
I I
I
I
I
I
I
I
I
I
69,7531
I I
I
I
I
I
I
135,829 1 I
I
I
I
I
I
- 1 112,156 I
I
I
I
I
- I
I
177.5541
I I
135.6291 1141681
I
- I
I
785,5381
I
47,8481
- 1
I
177.5541
I
135,8291 112,1581
I I
1
I
765,5381
I
47.8461
I
90 552-
I
90,5521 I
I
I
1
90.5521 ._._..T_...
_.. I
.. .. I
1
-
362,2101 - I
- 1
362,2101
22,638
-
GAS
103 Meters
52 Meters
41 Meters
66 Meters
58 Meters
74 Meters
55 Meters
70 Meters
64 Meters
"M"',
�75 Meters
78 Meters
176 Meters
175 Meters
160 Meters
133 Meters
170 Meters
183 Meters
1104 Meters
1101 Meters
`208 Meters
1136 Meters
175 Meters
1126 Meters
1145 Meters
74 Meters
128 Meters
132 Meters
107 Meters
100 Meters
158 Meters
51 Meters
1107 Meters
1101 Meters
1174 Meters
1153 Meters
110 Meters
1162 Meters
1128 Meters
1131 Meters
1199 Meters
1184 Meters
19 Meters
1185 Meters
1179 Meters
17 Meters
1246 Meters
I6 Meters
1180 Meters
1289 Meters
12 Meters
1239 Meters
1111 Meters
12 Meters
161 Meters
I
I
I
I
I
I
I
1
I
1960
1961
1962
1963
1964
1965
1966
1967
1968
1969
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
2011
2012
2013
2014
I
I
IMeters
IMeters
IMeters
IMeters
IMeters
I Meters
I Meters
I Meters
I Meters
I Meters
IMeters
IMeters
IMeters
IMeters
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IMeters
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I
1Ga.4&ters
IM.t.r R.Plec.m.rd
ITOTAL HUC•GAS
I
I
I
I
I
I
I
I
I
l
HUC-GAS
1EXPENDITURES:
I
I
I
IMeters
I
I
IMeters
I I
I I
1 15,0001
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I
4551
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I 33 1
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55 1
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1
I
IMeters
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1 41,0001
1,2421
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1 33 1
54 1
0
1 1
41,0001
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I
I
I
I
I
I
I
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IMeters
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1 5,0001
1521
RWS
1 33 1
53 1
0
1 1
5,0001
I
I
I
I
I
I
I
I
I
I
I
I
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IMeters
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1 12,0001
3641
RWS
1 33 1
62 1
0
1 1
12,0001
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
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IMeters
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1 7,3001
2211
RWS
1 33 1
51 I
0
1 1
7,3001
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
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IMeters
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1 22,0001
6671
RWS
1 33 1
50 I
0
1 1
22,0001
I
I
I
I
I
I
I
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I
I
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IMeters
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1 75,0001
2,2731
RWS
1 33 1
49 1
0
1 1
75,0001
1
I
I
I
I
I
I
I
I
I
I
I I
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IMeters
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1 50,0001
1,5151
RWS
1 33 1
46 1
0
1 1
50,0001
I
I
I
I
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IMeters
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1 8,2001
2481
RWS
1 33 1
47 1
0
1 1
8,2001
I
I
I
I
I
I
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I
I I
I I
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IMeters
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1 8,5001
2581
RWS
1 33 1
46 1
0
1 1
8,5001
I
I
I
I
I
I
I
I
I
I
I
I I
I I
I
IMeters
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1 10,0001
3031
RWS
1 33 1
45 1
0
1 1
10,0001
I
I
I
I
I
I
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I
I
I
I
I I
I I
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IMeters
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I 30,0001
9091
RWS
1 33 1
44 1
0
1 1
30,0001
I
I
I
I
I
I
I
I
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I
I
I I
I I
I
IMeters
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I 14,0001
4241
RWS
1 33 1
43 1
0
1 I
14,0001
I
1
I
I
I
I
I
I
I
I
I
I I
I I
I
IMeters
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I 25,0001
7581
RWS
1 33 1
42 1
0
1 I
25,0001
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
I
IMeters
IMeters
1 12,0001
3641
RWS
1 33 1
41 1
0
1 I
12,0001
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IMeters
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I 12,5001
3791
RWS
1 33 1
40 1
0
1 I
12,5001
I
I
I
I
I
I
I
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I
I I
I I
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IMeters
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1 17,0001
5151
RWS
1 33 1
39 1
0
1 I
17,0001
1
1
I
I
I
I
I
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I
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IMeters
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1 15,0001
4551
RWS
1 33 1
38 1
0
1 1
15,0001
1
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I
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IMeters
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1 30,0001
9091
RWS
1 33 1
37 1
0
1 1
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I
I
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IMeters
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1 15,0001
4551
RWS
1 33 1
36 1
0
1 1
15,0001
1
1
1
1
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I
I
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IMeters
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I 35,0001
1,0611
RWS
1 33 1
35 1
0
1 1
35,0001
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I
I
1
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I
I
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I
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I I
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IMeters
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1 30,0001
9091
RWS
1 33 1
34 1
0
1 1
30,0001
1
1
1
1
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I
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I
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I I
I I
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IMeters
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1 14,0001
4241
RWS
1 33 1
33 1
0
1 1
14,0001
1
1
I
1
I
I
I
I
I
I
I
I
I I
I I
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IMeters
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1 25,0001
7581
RWS
1 33 1
32 1
1
1 1
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25 500 1
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1
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IMeters
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1 18,0001
5451
RWS
1 33 1
31 1
2
1 1
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18,7271
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l
IMeters
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1 17,0001
5151
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3
1 1
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18,0411
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IMeters
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I 31,5001
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1 33 1
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4
1 I
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- 1
34,0971
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IMeters
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I 40,0001
1,2121
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44,1631
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I 41,0001
1,2421
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46,1731
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IMeters
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I 16,5001
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18,9531
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IMeters
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I 13,0001
3941
RWS
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8
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15,2321
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IMeters
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I 18,0001
5451
RWS
1 33 1
24 1
9
1 I
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I
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21,5121
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IMeters
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I 190,0001
5,7581
RWS
1 33 1
23 1
10
b00AMI Module{
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231,6091
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1 165,0001
5,0001
RWS
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11
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205,1571
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1 225,0001
6,8181
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1 33 1
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12
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- 1
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- 1
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1 233,0001
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13
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301,4101 - 1
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IMeters
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1 185,0001
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14
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- 1
- 1
- 1
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- 1
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- 1 244,1041
IMeters
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1 212,0001
6,4241
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18 1
15
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- I
- I
- 1
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- 1
- 1
- 1
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285,3241 1
1
IMeters
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1 47,0001
1,4241
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1 33 1
17 1
16
1 I
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I
I
I
I
I
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I
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I I
I
IMeters
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1 59,0001
1,7881
RWS
1 33 1
16 1
17
1 1
IMeters
IMeters
I 98,5001
2,9851
RWS
1 33 1
15 1
18
I I
I
I
I
I
I
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IMeters
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I 50,0001
1,5151
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1 33 1
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19
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1 36,0001
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20
1 I
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I
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IMeters
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1 50,0001
1,5151
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1 33 1
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21
1 I
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I I
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IMeters
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I 47,0001
1,4241
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22
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1
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IMeters
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I 28,0001
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RWS
1 33 1
10 1
23
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I
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I
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I
IMeters
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1 58,0001
1,7581
RWS
1 33 1
9 1
24
1 I
I
I
I
I
I
I
I
I
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I
I
I I
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IMeters
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1 24,0001
7271
RWS
1 33 1
8 1
25
1 I
I
I
I
I
I
I
I
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I
I
I
I
I I
I I
I
IMeters
IMeters
1 23,0001
6971
RWS
1 33 1
7 1
26
I I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
I
IMeters
IMeters
1 78,0001
2,3641
RWS
_
1 33 1
6 1
27
1 1
1
I
I
I
I
I
I
I
I
I
I
I
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IMeters
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1 8,0001
2421
RWS
1 33 1
5 1
28
1 1
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I
I
I
I
I
I
I
I
I
I
I
I I
I I
I
IMeters
We-
I 30,0001
9091
RWS
1 33 1
4 1
29
1 1
1
I
I
I
I
I
I
I
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I
I
I
I
I I
I I
I
IMeters
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1 18,0001
5451
RWS
1 33 1
3 1
30
1 1
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
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IMeters
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1 8,0001
2421
RWS
1 33 1
2 1
31
1 1
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I
I
I
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IMeters
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1 7,5001
2271
RWS
1 33 1
1 1
32
1 1
I
I
- I
- I
- I
I
I
I
I
I
I
I
I
I I
I I
I
I
I
I
ITotal
I I
1 2,603,500 1
I
78.8941
I I
1 1
I
1
I I
1 1
I
503.500 1
I
25,500 1
I
18,727 1
I
18,041 1
I
34,097 1
I
44,183 1
I
46.173 1
I
18,953 1
I
15,232 1
I
21,512 1
I
231.609 1
1
205.157 1
I
285,364 1
I I
301,410 1 244,104 1
I I
285,324 1 2,298,855 1
I
143,878 1
1
I
IMeters
I
1 2,803,5001
I I
78,8941
I
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I I
I
I
I I
I I
503,5001
I
25,5001
I
18,7271
I
18,0411
I
34,0971
I
44,1631
48,1731
18,9531
15,2321
21,5121
231,6091
205,1571
285,3541
301.4101 244,1041
285,3241 2,298.8551
143,8781
I
ITotai
I
I
1
I
I I
1 54,082,2101
I I
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1,411,1241
I
I I
1 1
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1
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1 1
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8,98%6711
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25,5001
I
18,7271
I
18,0411
I
3,604,0341
I
I
44,1631
I
I
46,1731
I
I
18,9531
I
I
15,2321
I
I
21,5121
I
I
231,6091
I
I
1,587,9511
I
I
462,9081
I I
I I
1,239,7141 356,2591
I I
I I
285,3241 16,958,7701
I
I
1,059,7981
IMeters
1
1 2,603,5001
78,8941
I 1
1
1 1
503,5001
I
25,5001
I
18,7271
I
18,0411
I
34,0971
I
44,1631
I
48,1731
I
18,9531
I
15,2321
i
21,5121
I
231,6091
I
205,1571
I
285,3541
I I
301,4101 244,1041
I I
285,3241 2,298,8551
I
143,6781
Istat
1
1 7,749,488 1
258,316 I
I I
I
1 1
5,116,531 1
1
- 1
- 1
1,848,192 1
- 1
- I
- I
- 1
- ]
i
1,382,794 1
- 1
_ I _ I
_ 1 8,145,517 1
509,095 1
]Potvethvlem
1
1 5,138,2221
171,2741
1 1
1
1 1
3,020,8401
- 1
- 1
- 1
1,923,7451
- 1
- 1
- 1
- 1
- I
- 1
- 1
- 1
440,2651 - 1
- 5,384,8501
338,5411
]Station#t
I
I 850,0001
28,3331
1 1
1
1 I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
I
Istation 92
I
I 1,050,0001
35,0001
I I
I
I I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I
I
IDRS
1
1 765,0001
25,4981
1 1
1
1 1
340,0001
- I
- I
- 1
- I
- 1
- I
- ]
- 1
- 1
1
- 1
177,5541
135,8291 112,1561
- 1 765,5381
47.846
ITrarramisslon
1
1 32.550,0001
723,3331
1 1
1
1 1
- I
I
I
I
I
I
I
I
I
]
I
I
I
- I - I
1 . I
- 1
1Rect8wr 3 Ground Bed 1
1 280,000 1
11,200 1
1 1
1
1 1
I
]
1
1
]
I
1
1
1
1
1
1
I
382,210 1 1
I 362,210 I
22,638
1lnterconnect
I
1 1,850,0001
47,1431
1 1
1
1 I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
ISid. VO-
I
I 700,000 I
15x56 I
I I
I
I I
I
I
I
I
I
I
I
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I
I
I
I
I
I I
I I
IBIockV.1-
1
1 541,0001
12,0221
I I
]
I I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
IL.mral
I
I 55.0001
1.2221
1 I-
Ilnlet
I
1 150,0001
3,3331-
I
ITotal
I
I
I
I
I I
I 54,082,210 1
I I
I
1,411,124 1
I
I I
1 1
] I
]
1
I
I I
I 1
I I
I
8,980,671 1
I
I
25,500 1
I
I
18,727 1
I
I
18,041 1
I
I
3,604,034 1
I
44,183 1
]
46,173 I
I
18,953 1
I
15,232 1
I
21,512 1
I
231,809 1
I
1,587,951 1
I
462,908 1
I I
1,239,714 1 356,259 1
I I
285,324 1 18,956,770 1
1,059,798
IMeters
1
0%
1 (
I
I I
I
I I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
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I
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I
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I
I I
I I
I I
I I
Istel
1
0%
1 1
1
1 1
1
1 1
1
I
1
I
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I
I
I
I
I I
I I
IPolwthvlen.
1
0%
1 1
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1 I-
ISt.tton#1
1
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1 1
1
I I
I
I 1
I
I
I
I
I
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I
I I
I I
]Station#2
1
0%
I I
I
I I
I
I I
I
I
I
I
I
I
I
I
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]
I I
I ]
IDRS
1
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1 1
I
I I
I
I I
I
I
1
]
I
I
I
I
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I
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]
I 1
I f
ITranamiasion
1
0%
I I
I
I I
I
I
I
I
I
I
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I
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I
I
I
I
I
I
I I
I I
11-titier
I
o%
I I
I
I I
I
I
I
I
I
I
1
I
I
I
I
I
I
I
I
I I
I I
IInterconn.ct
I
0%
I I
I
I I
1
I I
I
I
I
I
I
I
I
I
I
I
I
I
1
I I
I I
(Side valve
I
o%Block
V.1-
I
0%
IL.t.rsl
I
0%
I I
I
I I
I
I I
I
I
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]
I
I
I
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I
I
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I I
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Inlet
I
o%
]Total I I I I I I I I I I I I I I I I I I I I I I I I I I
I I I I I I I I I I I I I I I I I I I I I I I I I
1 I 1 1,411,124 I I I I 8,980.671 I 25.500 1 18,727 ] 18,041 ] 3,604.034 1 44.163 1 46,173 I 18,953 I 15.232 1 21,512 i 231.609 I 1,587.951 1 462,908 1 1,239,714 1 356.259 1 285,324 1 16.956.770 1 1.059.798
I I I I I I I I I I I I I I I I I I I I I I I I I I