MINIMUM DISTRIBUTION SYSTEM - WPUIwpui.wisc.edu/wp-uploads/2013/05/Vogt-52113.pdf · Minimum...
Transcript of MINIMUM DISTRIBUTION SYSTEM - WPUIwpui.wisc.edu/wp-uploads/2013/05/Vogt-52113.pdf · Minimum...
MINIMUM DISTRIBUTION SYSTEM CONCEPTS AND APPLICATIONS
Larry Vogt Manager, Rates
Minimum Distribution System
What is MDS? MDS is an analysis module of the cost-of-service study in which distribution investment is classified between demand-related and customer-related cost components. Why is MDS important? MDS is key to determining the monthly fixed costs of providing basic electric service. It provides a cost justification basis for the Customer Charge portion of the rate structure.
Basic Cost Components
3
The classification step of the cost-of-service study assigns all of the functionalized cost elements to the cost causation components of Customer, Demand, and Energy.
Energy-related costs – variable costs which are dependent on kWh requirements.
Demand-related costs – fixed costs which are dependent on kW requirements.
Customer-related costs – fixed costs which are independent of load or energy requirements.
Cost Classification Categories
• CUSTOMER COSTS
• DEMAND COSTS
• ENERGY COSTS
Minimum Distribution
The Access Function Of The Distribution System
5 5
All primary and secondary customers are connected to a distribution voltage source, i.e., a local substation.
There is a physical path which brings voltage to the customer’s premise.
Maintaining the voltage path ensures customer access to electrical power.
SUB
The Capacity Function Of The Distribution System
6 6
Primary and secondary distribution system facilities and lines must be sized to adequately handle the customers’ demand for power.
Electric service facilities are rated in terms of kVA capacity (conductors rated in terms of ampacity).
Customer Load
Feeder Load
Distribution System Lines and Facilities
7 7
FERC Description 360 Land and Land Rights 361 Structures 362 Station Equipment 363 Storage Battery Equipment 364 Poles, Towers & Fixtures 365 OH Conductors & Devices
Switches Reclosers & Sectionalizers
366 UG Conduit 367 UG Conductors & Devices 368 Line Transformers
Regulators Capacitors Cutouts Arresters
369 Services 370 Meters 373 Street Lighting
SUB
S R
N.O.
N.C.
N.C. N.C.
1,500 cKVAR
333-333-333
50-50-50
75
15
25 37.5
336.4 MCM ACSR
4/0
CU
NO. 2 AL C/N
1/0 CU
M
Objective of the Minimum Distribution System Analysis
8
To assess each device utilized in the distribution system in terms of its “mission” in order to determine if its function is: Dependent on kW load requirements and therefore demand related,
or
Independent of kW load requirements and therefore customer related.
Customer or Demand?
9
MW
TIME
Capacitor-Based Voltage Control
SUB FEEDER
120 V
108 V
132 V +10%
-10%
DISTANCE
10
Customer or Demand?
11
Protection Scheme Temporary Fault Condition
R CB SUB
12
Protection Scheme Permanent Fault Condition
R CB SUB
13
Protection Scheme Permanent Fault Condition – No Load
R CB SUB
14
Customer or Demand?
Classification of Distribution Plant for the Cost-of-Service
16 16
Demand Customer
Distribution Substations X
Primary Lines* X X
Line Transformers* X X
Secondary Lines* X X
Other Line Equipment* X X
Service Lines X
Meters X * Minimum Distribution System facilities.
17
Zero-Intercept Methodology
THE Y-AXIS INTERCEPT IS THE UNIT COST OF ZERO CAPACITY
CAPACITY
UNIT COSTS
× ×
× ×
× COST OF A STANDARD SIZE UNIT
Applied to: Line Transformers Conductors Poles
Line Transformers
18
Weighted Linear Regression For Distribution Line Transformers
19 19
N = Total number of all transformers of a given type, e.g., 59,800 7.2 kV - 120/240 V, single-bushing, pole- mount units n = Number of a given size transformer, e.g., 9,935 15 kVA X = Transformer size in kVA, e.g., 5, 7.5, 10, 15, etc. Y = Transformer unit cost in $ per unit, e.g., $724.48 (cost of a 15 kVA unit)
[ ] [ ][ ] [ ]22 ∑∑
∑ ∑∑−×
×−×=
nXnXN
nYnXnXYNm
×−= ∑∑
NnX
NYn
mb
SLOPE
y-INTERCEPT
Zero-Intercept Example
20
Single-Phase Overhead Transformers
1. ZERO-INTERCEPT: $463.975/transformer Based on various kVA sizes of 7.2 kV - 120/240 V, single bushing, pole-
mount transformers
2. TOTAL NUMBER OF OVERHEAD TRANSFORMERS: 98,278 CUSTOMER COMPONENT = $ 463.975 × 98,728 = $45,807,307
3. TOTAL OVERHEAD TRANSFORMER COST: $109,960,813 DEMAND COMPONENT = $109,960,813 - $45,807,307 = $64,153,506
CUSTOMER COMPONENT = 41.7%
DEMAND COMPONENT = 58.3%
21
Zero-Intercept Analysis The Problem With Vintage Costs
$0
$200
$400
$600
$800
$1,000
$1,200
$1,400
$1,600
$1,800
$2,000
0 10 20 30 40 50 60 70 80 90 100
Analysis of Pad-Mount Line Transformers Based on Booked Installed Costs
kVA
Uni
t Cos
t
1Φ
3Φ
22
Zero-Intercept Analysis Use of Current Costs
3Φ
1Φ
Analysis of Pad-Mount Line Transformers Based on Rebuild Costs
kVA
Uni
t Cos
t
$0
$1,500
$3,000
$4,500
$6,000
$7,500
$9,000
$10,500
$12,000
$13,500
$15,000
0 10 20 30 40 50 60 70 80 90 100
Primary and Secondary Conductors and Poles
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PRIMARY
NEUTRAL
SECONDARY
Overhead Conductors Relative Frequency Distribution
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0%
10%
20%
30%
40%
50%
60%
70%
80%
CU BARE CU WP AL BARE AL WP
477 AAC 795 AAC 1,351 AAC0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
50%
4 ACSR 2 ACSR 1/0 ACSR 4/0 ACSR 336 ACSR 477 ACSR 795 ACSR
Weighted Linear Regression For Distribution Conductors
25 25
N = Total feet of all conductors of a given type, e.g., 47,557,568 ft of ACSR conductors
n = Number of feet of a given size conductor, e.g., 26,194,939 ft of #2 ACSR
X = Conductor size in MCM (a #2 wire is 66.36 MCM), e.g., 26.24, 41.74, 52.62, 66.36, etc.
Y = Conductor unit cost in $ per feet, e.g., $0.659/ft (cost of a #2 ACSR conductor)
[ ] [ ][ ] [ ]22 ∑∑
∑ ∑∑−×
×−×=
nXnXN
nYnXnXYNm
×−= ∑∑
NnX
NYn
mb
SLOPE
y-INTERCEPT
Zero-Intercept Example
26
Primary Overhead Conductor
1. ZERO-INTERCEPT: $0.396/ft Based on various MCM sizes of bare ACSR conductors
2. TOTAL LENGTH OF PRIMARY CONDUCTORS: 15,708,000 ft PRIMARY CIRCUIT LENGTH: 15,708,000 × 2 = 31,416,000 ft CUSTOMER COMPONENT = $0.396 × 29,898,000* = $11,827,081 * Minimum Distribution System Length
3. TOTAL PRIMARY CONDUCTOR COST: $56,416,253 DEMAND COMPONENT = $56,416,253 - $11,827,081 = $44,589,172
CUSTOMER COMPONENT = 21.0%
DEMAND COMPONENT = 79.0%
Determination Of Overhead Circuit Lengths For The MDS
27 27
SUB
PRIMARY
SECONDARY UNDERBUILD
PRIMARY NEUTRAL COMMON NEUTRAL SECONDARY NEUTRAL
SECONDARY TAPS
TOTAL POLE MILES
UNDERGROUND PRIMARY CABLE
CONDUCTOR
CONCENTRIC NEUTRAL
CONDUIT FOR UNDERGROUND CABLES
RIGID PVC FLEXIBLE
30
Distribution Poles Types Of Materials
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
ALUMINUM CONCRETE FIBERGLASS STEEL WOOD
0.0%
0.1%
0.2%
0.3%
0.4%
0.5%
0.6%
0.7%
0.8%
0.9%
1.0%
ALUMINUM CONCRETE FIBERGLASS STEEL
31
Pole Heights Relative Frequency Distribution
0%
5%
10%
15%
20%
25%
30%
35%
40%
30' 35' 40' 45' 50' 55' 60' 65' 70' 75' 80' 85' 90' 95'POLE HEIGHTS
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Pole Line Routing
SUB
Clearance Requirements
33 33
Poles lines must be designed to ensure proper safety clearances, such as specified in the National Electric Safety Code (NESC), Section 23.
The NESC provides specific minimum clearances of power lines located over:
Roadways, parking lots, driveways, pedestrian areas, railroad track rails, water ways, etc.
Other electric conductors and services, trolley/electric train cables, communications cables, etc.
34
Pole Line Grading
IMPROPER GRADING: POLES ALL HAVE THE SAME HEIGHT
PROPER GRADING: POLES WITH VARYING HEIGHTS
Distribution Pole Classification Conclusion On Pole Height
35 35
Pole lines are built to connect customers to the power source, i.e., the substation. The routing of these lines is predominantly a function of where customers are located.
Pole height requirements are predominantly a function of clearances and line grading, which are related to safety and mechanical design.
Thus, pole height is not a major function of load.
36
Pole Class
37
Standard Pole Classes Example: 35’ Wood Pole
No. 1 39.0”
No. 2 36.5”
No. 3 34.0’
No. 4 31.5”
No. 5 29.0”
No. 6 27.0”
No. 7 25.0”
MINIMUM CIRCUMFERENCE OF SOUTHERN YELLOW PINE POLES (@ GROUND LINE)
38
Pole Classes Relative Frequencies By Height
0%
10%
20%
30%
40%
50%
60%
1234567POLE CLASS
45 FT POLES 40 FT POLES 35 FT POLES 30 FT POLES
39
Pole Class Requirements Based On Transformer Capacity
0
1
2
3
4
5
6
7
10 15 25 37.5 50 75 100 167 250TRANSFORMER kVA
POLE
CLA
SS
1 TRANSFORMER 2 TRANSFORMERS 3 TRANSFORMERS
Distribution Pole Classification Conclusion On Pole Class
40 40
The physical sizes and weights of line transformers and wires are related to their current carrying capabilities.
Pole class must be increased (i.e., going from 7 to 1) to carry heavy mechanical loads caused by large line transformers and conductors (3Φ lines are indicative of greater electrical load density than 1Φ lines).
Thus, pole class is predominantly a function of load.
Pole Capacity
41 41
Poles have no electrical capacity component, but they do have a mechanical capacity (strength) component that can be viewed as a proxy for electrical loading.
Pole class (or circumference) can represent loading capability for wood poles, but it does not work for steel or concrete poles since different classes can have the same physical dimensions.
Ground line moment capacities do differ by class for all poles.
Transverse Wind Load of 1,200 lb
Example: 35’ 5-C Pole
GLMC = 33,000 ft-lbs = 33 kips
Weighted Linear Regression For Distribution Poles
42 42
N = Total feet of all poles of a given type, e.g., 55,642 ft of 40 ft wood poles n = Number of feet of a given size pole based on its GLMC, e.g., 21,137 ft of 76.80 kilopounds (kips) poles X = Ground Line Moment Capacity in kips, e.g., 48.0, 60.8, 76.8, 96.0, etc. Y = Pole unit cost in $ per feet, e.g., $12.05/ft (cost of a 76.8 kips pole)
[ ] [ ][ ] [ ]22 ∑∑
∑ ∑∑−×
×−×=
nXnXN
nYnXnXYNm
×−= ∑∑
NnX
NYn
mb
SLOPE
y-INTERCEPT
Zero-Intercept Example
43
Wood Poles
1. ZERO-INTERCEPT: $7.883/ft Based on various kip ratings of 40’ southern pine poles
2. TOTAL LINEAR FEET OF WOOD POLES: 5,579,390 ft CUSTOMER COMPONENT = $7.883 × 5,579,390 = $43,982,773
3. TOTAL WOOD POLE COST: $66,254,744 DEMAND COMPONENT = $66,254,744 - $43,982,773 = $22,271,971
CUSTOMER COMPONENT = 66.4%
DEMAND COMPONENT = 33.6%
Example MDS Analysis Results Poles, Transformers, and Conductors
44
Customer Demand Poles • Wood 66.4% 33.6% • Concrete 47.3% 52.7% • Steel 57.5% 42.5%
Transformers • 1Φ OH* 41.7% 58.3% • 1Φ UG** 61.5% 38.5% • 3Φ UG** 34.2% 65.8% * Basis for classifying transformer vaults ** Basis for classifying transformer pads
Customer Demand Conductors Primary • Bare ACSR OH 21.0% 79.0% • 15 kV CN UG* 57.4% 42.6%
Secondary • WP AL OH 38.4% 61.6% • Duplex OH 31.4% 68.6% • 1-Conductor UG* 60.7% 39.3%
* Basis for classifying conduit
Example MDS Analysis Results Distribution Line Devices
45
Primary Secondary Customer Demand Customer Demand Regulators & Capacitors 100%
Reclosers and Sectionalizers 100%
Cutouts & Arresters • Line Transformers (OH) 41.7% 58.3% • Regulators & Capacitors 100% • Reclosers & Sectionalizers 100% • Line Protection 100%
Bypass Switches • Regulators 100% • Reclosers & Sectionalizers 100%
OH Line Switches* 21.0% 79.0% UG Line Switches* 57.4% 42.6% * Based on conductors
Larry Vogt
Q&A