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ESMEC-ET Electric Supply Portfolio Report
November 12, 2015
2
Highlights
• FY16 YTD unit cost 14.9% below budget. FY16 full year forecast reduced from $76.00 to $70.00.
• Billing rate lowered to $.065 KWh effective with Nov 2015 billing month (covering Oct 2015 MRD to Nov 2015 MRD). The lowered rate can be held thru the balance of FY16 and if hourly rates remain at current low levels there may be an opportunity to either lower the FY16 billing rate further or lower the initial FY17 billing rate. Average working capital balance (WCB) for October 2015 was $2.2 million, a $139 thousand increase from September. The lower billing rates should begin reducing the WCB in starting in December.
• Record low block purchased in October for FY19 at $36.60 for ATC (around the clock) at DPL Zone.
• Given historical lows in forward electric market prices, recommendation is to buy now the final block purchase covering FY17 (4 MW On Peak).
3
Contents
I. Supply Portfolio Results Page #
A. Key Performance Measures 5
B. Electric Supply Cost Chart and Summary – FY16 6-7
II. Portfolio Hedge Strategy Review
A. Hedge Position Chart 9
B. Open Blocks Purchased and Scheduled Purchases 10
C. Proforma Hedge Position Chart 11
D. Forward Market Price Reports 12-13
E. Hourly Market Price Reports 14-15
III. Portfolio Billing Rates
A. Portfolio Cost and Billing Rate History 17
B. Electric Supply Portfolio vs. DPL SOS Rate Summary 18
C. Working Capital – Billing Rate Comparison 19
D. FY16 Billing Rates by Rate Schedule (Budget) 20
Appendix 22-28
4
I. Supply Portfolio Results
5
ESMEC-ET Electric Supply Portfolio
Key Portfolio Measures
November 2015
1. Total Supply Cost ($/MWh)
Actual O/(U) Budget % O/(U) Budget Actual O/(U) Budget % O/(U) Budget
Unit Cost, $/MWh $70.12 ($6.60) -8.6% $65.35 ($11.43) -14.9%
Cost @ Volume ** $891,043 ($83,857) -8.6% $3,661,638 ($640,159) -14.9%
* PJM reported MWh's equal metered MWh's grossed up for utility line losses and unaccounted for energy
** Represents unit cost variance to budget, does not reflect volumetric variance to budget
2. Replacement Value - Blocks - Current Market O/(U) Hedge Costs ($MM)
FY 2016 ($0.42)
FY 2017 (0.35)
FY 2018 (0.30)
FY 2019 (0.34)
Total ($1.41)
3. Hedge Summary
Peak Off Total Peak Off Total
FY 2016 80% 75% 78% 87% 67% 79%
FY 2017 60% 56% 58% 69% 69% 69%
FY 2018 20% 19% 19% 49% 36% 43%
FY 2019 0% 0% 0% 24% 36% 29%
4. Actual/ Forecasted Supply Cost ($ MWh)
Total
Supply Cost $/MWh %
FY 2015 $68.04 ($29.44) -30.2%
FY 2016 $70.00 $1.96 2.9%
FY 2017 $70.35 $0.35 0.5%
All unit costs based on PJM Reported MWh's *
YR to YR Incr/(Decr)
FY 2016 - Oct YTD
Minimum Guideline Actual
FY 2016 - Oct
6
$60
$65
$70
$75
$80
$85
$90
$60
$65
$70
$75
$80
$85
$90
$/MWh
ESMEC-ET Electric Supply Portfolio Cost - FY 2016
Monthly Actual Prior Year YTD Actual Portfolio Budget Billed Rate
All Unit costs based on PJM volumes except billed rate
7
Total Supply Cost, Cumulative FY 2016ESMEC-ETUpdated: 11/11/2015
Actual Actual Actual Actual
Jul-15 Aug-15 Sep-15 Oct-15 Cumulative
PJM Load Charges - WGL/ESMEC-ETActual PJM Volume, MWh 15,117 14,135 14,069 12,707 56,027
Energy - DA & RT $115,362 $84,953 $124,137 $36,462 $360,915
Ancillary Charges 34,726 19,433 18,748 23,346 96,252
Transmission 69,886 71,052 68,922 71,028 280,889
Capacity 172,556 174,913 169,942 175,093 692,504
ARR/FTR & Marginal Loss (29,172) (27,633) (24,329) (23,760) (104,894)
Reconciliation 8,105 18,538 (49,641) 17,234 (5,763)
PJM Electric Cost 371,462 341,257 307,779 299,403 1,319,902
Fixed Rate Block Cost 537,374 521,166 509,844 529,270 2,097,654
Other ChargesWGL Service Fee 17,384 16,255 16,179 14,613 64,432
WGL Cost to Carry 0 0 0 0 0
WGL Cost of Collateral 3,759 4,747 6,432 8,842 23,780
Renew able (RPS Requirement) 37,000 37,000 37,000 37,000 148,000
Other Fees (MD PSC) 2,083 1,983 1,890 1,915 7,870
Subtotal 60,226 59,984 61,501 62,370 244,082
Total Supply Cost $969,062 $922,408 $879,125 $891,043 $3,661,638
Unit Costs, $/MWh
Energy $43.18 $42.88 $45.06 $44.52 $43.88
Transmission $4.62 $5.03 $4.90 $5.59 $5.01
Capacity 11.41 12.37 12.08 13.78 12.36
Ancillary, PJM Other Charges & Credits 0.90 0.73 (3.93) 1.32 (0.26)
Renew able (RPS Requirement) 2.45 2.62 2.63 2.91 2.64
Other 1.54 1.63 1.74 2.00 1.71
Total Supply Cost $64.11 $65.26 $62.49 $70.12 $65.35
Expected Unit Price $79.65 $75.18 $75.36 $76.72 $76.78
Budget Variance ($15.54) ($9.92) ($12.87) ($6.60) ($11.43)
Hedge Settlement $175,997 $197,679 $135,778 $215,542 $724,996
Unit Cost, $/MWh $4.17 $4.68 $3.21 $5.10 $12.94
8
II. Portfolio Hedge Strategy Review
9
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
18,000
MWhESMEC-ET - Current Electric Hedge Status, 11/11/2015
Total Load Max Hedge Purchased Min Hedge
Based on FY2015 Gross Annual MWhs Adjusted for Planned Solar Projects
Peak Off Total
FY 2016 87% 67% 79%
FY 2017 69% 69% 69%
FY 2018 49% 36% 43%
FY 2019 24% 36% 29%
Actual Hedge %'s
10
ESMEC-ET 11/11/15
Open Blocks Purchased and Scheduled Purchases
FY 2016 - FY 2018
Block #Quantity
(MW)Type Index
Period
Start
Period
End
Purchase or
Target
Purchase
Date
Total
Contract
Quantity
(MWh)
Block Price
($/MWh) - PJM
West Hub
Block Price
($/MWh) - Basis:
PJM West Hub to
DPL Zone
Block Price
($/MWh) -
Delivered to
DPL Zone
Total Contract
Cost
14 5 ATC DA Jul-15 Jun-16 4/10/13 43,920 $45.55 2,000,556$
16 5 Peak DA Jul-14 Jun-16 11/5/13 40,960 $46.80 1,916,928$
17 5 ATC DA Jul-16 Jun-17 11/20/13 43,800 $40.25 1,762,950$
18 5 ATC DA Jul-15 Jun-16 4/29/14 43,920 $48.80 2,143,296$
19 5 Peak DA Jul-15 Jun-17 8/27/14 40,960 $54.50 2,232,320$
20 5 ATC DA Jul-17 Jun-18 5/5/15 43,800 $43.20 1,892,160$
21 5 ATC DA Jul-16 Jun-17 6/9/15 43,800 $42.60 1,865,880$
22 5 Peak DA Jul-17 Jun-18 7/10/15 20,320 $48.85 992,632$
23 5 ATC DA Jul-18 Jun-19 10/9/15 43,800 $36.30 1,589,940$
24 4 Peak DA Jul-16 Jun-17 12/15/15 16,320 $41.65 $5.50 $47.15 769,447$
Total Open Blocks Purchased 365,280 $44.89 16,396,662$
Total Scheduled Purchases (excludes declined blocks) 16,320 $47.15 769,447$
Total Open Blocks Purchased & Scheduled Purchases 381,600 $44.98 17,166,109$
West Hub NYMEX Close Prices as of 11/10/15, Basis Prices Estimated
11
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
18,000
MWh
ESMEC-ET Proforma Electric Hedge Status, 12/31/2015
Total Load Max Hedge Purchased Scheduled Min Hedge
Based on FY 2015 Gross Annual MWhs Adjusted for Planned Solar Projects
Peak Off Total
FY 2016 87% 67% 79%
FY 2017 87% 69% 80%
FY 2018 49% 36% 43%
FY 2019 24% 36% 29%
Pro Forma Hedge %'s
12
13
14
$0
$10
$20
$30
$40
$50
$60
$70
$80
$90
$100
$110
$120
$130
$140
ATC Average LMP-RT PJM Western Hub, 1998 - 10/2015
Avg-Monthly Avg-12 Mo
15
-$10
-$5
$0
$5
$10
$15
$20
$25
$30
ATC Average LMP-RT PJM DPL Zone Basis, 1999 - 10/31/2015
Avg Monthly Avg-12 Mo
16
III. Portfolio Billing Rates
17
ESMEC-ET Electric Supply Portfolio
Budget, Actual and Billing Rates
($ kWh)
FY 2007 FY 2008 FY 2009 FY 2010 FY 2011 FY 2012 FY 2013 FY 2014 FY 2015 FY2016
Portfolio budget rate $0.0912 $0.0900 $0.1000 $0.1000 $0.0950 $0.0840 $0.0870 $0.0830 $0.0720 $0.0760
Portfolio actual/forecast cost$0.0876 $0.0993 $0.0976 $0.0919 $0.0940 $0.0810 $0.0810 $0.0975 $0.0680 $0.0700
Actual o/(u) budget ($0.0036) $0.0093 ($0.0024) ($0.0081) ($0.0010) ($0.0030) ($0.0060) $0.0145 ($0.0040) ($0.0060)
Approximate Weighted Average Billing Rates - Metered Basis(1):
Billing months:
Jul - Oct $0.0992 $0.0992 $0.1094 $0.1094 $0.0954 $0.0944 $0.0954 $0.0894 $0.1004 $0.0844
Nov - Feb $0.0844 $0.0844 $0.0944 $0.0944 $0.0804 $0.0794 $0.0794 $0.0774 $0.0854 $0.0650
Mar - Jun $0.0814 $0.0844 $0.0944 $0.0944 $0.0804 $0.0794 $0.0794 $0.0849 $0.0854 $0.0650
W/A billing rate $0.0885 $0.0894 $0.0995 $0.0995 $0.0855 $0.0845 $0.0849 $0.0839 $0.0906 $0.0712
Portfolio budget rate (metered volumes) $0.0760 $0.0800
(1) Includes primary (GSP), secondary (LGS, SGS) and outdoor lighting (OL/ORL) rate schedules
Preliminary and forecast rates in blue
PJM VolumesEstimated Metered Volumes
18
$0.070
$0.075
$0.080
$0.085
$0.090
$0.095
$0.100
$0.105
$0.110
$0.115
$0.120
FY07 FY08 FY09 FY10 FY11 FY12 FY13 FY14 FY15
Portfolio Cost Weighted Average Billing Rate DPL Standard Offer Service Rate
ESMEC-ET
Electric Supply Rates ($/KWh)$/KWh$/
19
$0.050
$0.060
$0.070
$0.080
$0.090
$0.100
$0.110
$0.120
($1,500,000)
($1,000,000)
($500,000)
$0
$500,000
$1,000,000
$1,500,000
$2,000,000
$2,500,000Jul-
12
Au
g-1
2
Se
p-1
2
Oct-
12
No
v-1
2
De
c-1
2
Jan
-13
Feb-1
3
Ma
r-1
3
Ap
r-13
Ma
y-1
3
Jun
-13
Jul-
13
Au
g-1
3
Se
p-1
3
Oct-
13
No
v-1
3
De
c-1
3
Jan
-14
Feb-1
4
Ma
r-1
4
Ap
r-14
Ma
y-1
4
Jun
-14
Jul-
14
Au
g-1
4
Se
p-1
4
Oct-
14
No
v-1
4
De
c-1
4
Jan
-15
Feb-1
5
Ma
r-1
5
Ap
r-15
Ma
y-1
5
Jun
-15
Jul-
15
Au
g-1
5
Se
p-1
5
Oct-
15
W/C Avg Balance Actual Cost ($/KWh) Billing Rate($/KWh)
ESMEC-ET Electric Supply PortfolioAverage Working Capital (W/C) Balances Held with Supplier
All unit costs based on PJM volumes except billed rate $/KWh
Jan '14 $.166 KWh
Average Excess Working Capital Balance Target = $1.5 million
20
ESMEC-ET Electric Supply Portfolio 11/11/15
Total Supply Cost Billing Rates by Rate Schedule ($ KWh)
Fiscal Year 2016
Billing Period Summer Winter Spring
Status Approved Approved Approved
Supplier Billing Months July 2015 - Nov 2015 - Mar 2016 -
Oct 2015 Feb 2016 Jun 2016
Meter Read Beginning: Jun 2015 Oct 2015 Feb 2016
Meter Read Ending: Oct 2015 Feb 2016 Jun 2016
FY 2016
W/A Billing
Delmarva Power Rate Schedule Rate
Secondary (SGS / SGS SH / LGS) $0.0850 $0.0655 $0.0655 $0.0718
Primary (GSP) $0.0825 $0.0630 $0.0630 $0.0694
Outdoor Lights (OL / ORL) $0.0700 $0.0505 $0.0505 $0.0574
Weighted Average Rate $0.0843 $0.0649 $0.0648 $0.0712
Estimated Portfolio Cost
Portfolio Budget Rate (Metered Volumes) $0.0800
21
Appendix
22
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
kW
ESMEC Portfolio Hourly Load
Hourly Load 30 Day Average
RLR, 7/14 - 6/15 (through 6/15)
23
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,000
kW
ESMEC Portfolio Hourly Load
Hourly Load 30 Day Average
RLR, 7/15 - 6/16 (through 8/15)
24
($1,600,000)
($1,400,000)
($1,200,000)
($1,000,000)
($800,000)
($600,000)
($400,000)
($200,000)
$0
$200,000
Monthly Cumulative
ESMEC Electric Mark to Market, 11/11/2015
25
ESMEC-ET Electric Supply Portfolio
Capacity and Transmission Tag Summary (MW)
Incr/(Decr) in Incr/(Decr) in
14/15 Year 15/16 Year
Cost ($) Cost ($)
13/14 14/15 15/16 MW % MW %
Unforced Capacity Obligation 31.3 29.9 34.1 (1.4) -4.5% 4.2 14.1% ($74,820) $256,519
Incr/(Decr) in Incr/(Decr) in
Cal Year Cal Year
2014 Cost ($) 2015 Cost ($)
2013 2014 2015 MW % MW %
Transmission Capacity 26.7 24.3 22.0 (2.4) -9.0% (2.3) -9.5% ($67,048) ($75,226)
(1) PJM Year June 1 - May 31
2015 o/(u) 20142014 o/(u) 2013Calendar Year
14/15 o/(u) 13/14PJM Year (1) 15/16 o/(u) 14/15
Impact of Inc/(decr) in UCAP MW
Impact of Inc/(decr) in Trans Cap MW
26
$15.00
$197.16
$150.53
$196.54 $187.37
$116.15
$171.24
$248.30
$145.38
$166.54 $158.68
$147.61
$215.97
$0
$50
$100
$150
$200
$250
$300
06/07 -Pre
RPM
07/08 08/09 09/10 10/11 11/12 12/13 13/14 14/15 15/16 16/17 17/18 18/19
$/MWDPJM - DPL Capacity Prices
Final Zonal Net Load Prices through 15/16, PJM years 16/17, 17/18 and 18/19 include Capacity Performance Prices
27
ESMEC-ET
Maryland Renewable Portfolio Requirements
Based on Chapters 583, 556 and 653 enacted May 22, 2012
Required %'s Based on Grandfathered %'s per SB791 Estimates in Blue
Report as of: 10/31/15
Required
%
Amount
Total REC
Quantity
Requirement
REC
Quantity
Purchased
to Date
%
Requirement
Purchased
to Date
Purchase
Cost
($/MWh)
($)
Purchased
Cost to Date
Actual or
Estimated
Annual Cost
$/MWh
Cost per
Portfolio
Usage
Required
% Amount
Total REC
Quantity
Requirement
REC
Quantity
Purchased
to Date
%
Requirement
Purchased to
Date
Purchase
Cost
($/MWh)
($)
Purchased
Cost to
Date
Actual or
Estimated
Annual Cost
$/MWh
Cost per
Portfolio
Usage
2012 173,040 6.40% 11,075 11,075 100% 4.15$ 45,959$ 45,959$ 0.27$ 0.1000% 173 173 100% 170.00$ 29,417$ 29,417$ 0.17$
2013 171,402 8.00% 13,712 13,712 100% 15.67$ 214,870$ 214,870$ 1.25$ 0.2000% 343 343 100% 170.00$ 58,277$ 58,277$ 0.34$
2014 165,359 10.00% 16,536 16,536 100% 16.12$ 266,545$ 266,545$ 1.61$ 0.3000% 496 496 100% 170.00$ 84,320$ 84,333$ 0.51$
2015 165,359 10.10% 16,701 13,965 84% 15.85$ 221,377$ 264,754$ 1.60$ 0.4000% 661 161 24% 170.00$ 27,370$ 112,444$ 0.68$
2016 165,359 12.20% 20,174 -$ -$ 0.5000% 827 -$
2017 165,359 12.55% 20,753 -$ -$ 0.5500% 909 -$
2018 165,359 14.90% 24,638 -$ -$ 0.9000% 1,488 -$
2019 165,359 16.20% 26,788 -$ -$ 1.2000% 1,984 -$
2020 165,359 16.50% 27,284 -$ -$ 1.5000% 2,480 -$
2021 165,359 16.85% 27,863 -$ -$ 1.8500% 3,059 -$
2022 165,359 18.00% 29,765 -$ -$ 2.0000% 3,307 -$
2023 165,359 18.00% 29,765 -$ -$ 2.0000% 3,307 -$
Required
%
Amount
Total REC
Quantity
Requirement
REC
Quantity
Purchased
to Date
%
Requirement
Purchased
to Date
Purchase
Cost
($/MWh)
($)
Purchased
Cost to Date
Actual or
Estimated
Annual Cost
$/MWh
Cost per
Portfolio
Usage
Total Actual
or Estimated
Annual Cost
($)
$/MWh
Cost per
Portfolio
Usage
2012 173,040 2.5% 4,326 4,326 100% 0.69$ 2,985$ 2,985$ 0.02$ 78,361$ 0.45$
2013 171,402 2.5% 4,285 4,285 100% 3.35$ 14,355$ 14,355$ 0.08$ 287,501$ 1.68$
2014 165,359 2.5% 4,134 4,134 100% 7.33$ 30,283$ 30,283$ 0.18$ 381,161$ 2.31$
2015 165,359 2.5% 4,134 3,458 84% 2.59$ 8,957$ 10,707$ 0.06$ 387,905$ 2.35$
2016 165,359 2.5% 4,134 -$ -$ -$
2017 165,359 2.5% 4,134 -$ -$ -$
2018 165,359 2.5% 4,134 -$ -$ -$
2019 165,359 0.0% -$ -$
2020 165,359 0.0% -$ -$
2021 165,359 0.0% -$ -$
2022 165,359 0.0% -$ -$
2023 165,359 0.0% -$ -$
Calendar
Year
Compliance
Portfolio
Usage
(MWh)
Tier I Solar - SREC
Calendar
Year
Compliance
Portfolio
Usage
(MWh)
Tier II All Tiers