agenda - integral care · 4/24/2017 · finance committee minutes . date: march 27, 2017 time:...
TRANSCRIPT
FINANCE COMMITTEE MEETING Integral Care’s mission is to improve the lives of people affected by behavioral health and
developmental and/or intellectual challenges.
DATE: Monday, April 24, 2017 TIME: 12:00 p.m. PLACE: 1430 Collier St. – Board Room Austin, Texas 78704
AGENDA I. Citizens’ Comments (Presentations are limited to 3 minutes)
II. Approval of Finance Committee Minutes for March 27, 2017 – pages 1-8
III. Discuss and Take Appropriate Action on Cash & Investment Report – March,
2017 (Weden) – pages 9-11
IV. Discuss and Take Appropriate Action on Financial Statements and Amendments (if applicable) for the Period Ending March 31, 2017 (Subject to Audit) (Weden, Thompson) – pages 12-21
V. Update on Transformation 1115 Waiver (Weden, Macakiage) – pages 22-27
VI. Facilities Report (Spencer) – pages 28-100
VII. Announcements – page 101
VIII. New Business – page 102
• Identify Consent/Non-Consent Agenda Items IX. Citizens’ Comments (Presentations are limited to 3 minutes) – page 103
FINANCE COMMITTEE MINUTES
DATE: March 27, 2017 TIME: 12:00 p.m. PLACE: 1430 Collier St. – Board Room Austin, Texas 78704 MEMBERS PRESENT: Tom Young, Robert Chapa, Vince Torres (via phone) GUEST PRESENT: Melissa Rowan of Wertz & Rowan Center staff were in attendance. The meeting was called to order by Mr. Young at 12:00 p.m. I. CITIZENS’ COMMENTS None. II. APPROVAL OF FINANCE COMMITTEE MINUTES No changes were noted to the minutes of the February 20, 2017 meeting. They stand approved as submitted. III. DISCUSS AND TAKE APPROPRIATE ACTION ON CASH & INVESTMENT REPORT FOR FEBRUARY, 2017 Mr. Chapa made a motion to recommend to the Board the acceptance of the Cash and Investment Report for February, 2017. Mr. Young seconded. Mr. Weden reviewed the Cash and Investment Report for February, 2017 stating the interest earned in 2/2017 was $8,730 and total market and book value at end of month was $30,401,332. He also stated there were no significant changes for the month. A comparison of FY 2016 vs. FY 2017 cash and investment amounts was reviewed. Discussion followed. All were in favor. Motion carried.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 2 IV. DISCUSS AND TAKE APPROPRIATE ACTION ON FINANCIAL STATEMENTS AND AMENDMENTS (IF APPLICABLE) FOR THE PERIOD ENDING FEBRUARY 28, 2017 (SUBJECT TO AUDIT) Mr. Young made a motion to recommend to the Board the acceptance of the Financial Statements and amendments (if applicable) for the period ending February 28, 2017 subject to audit. Mr. Chapa seconded. Mr. Weden and Ms. Thompson discussed the following information from the schedules found in the packet: Financial Summary, Balance Sheet General Operating Fund and Notes (Schedule N2), Combined (Schedule C1), Statement of Revenue and Expenditures and Notes (Schedule C2), Waiver (Schedule C3), and HCC. Discussion followed. All were in favor. Motion carried. V. DISCUSS AND TAKE APPROPRIATE ACTION APPROVING RESOLUTIONS REGARDING APPROVAL OF TAX CREDIT DOCUMENTS Mr. Young made a motion to recommend to the Board the approval of Resolutions regarding approval of tax credit documents. Mr. Chapa seconded. Mr. Weden presented a brief introduction for agenda items V – XIII. Discussion followed. All were in favor. Motion carried. VI. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE AGREEMENT OF LIMITED PARTNERSHIP OF HOUSING FIRST OAK SPRINGS, LP Mr. Young made a motion to recommend to the Board the approval for the Chief Executive Officer and/or his designee to sign the agreement of limited partnership of Housing First Oak Springs, LP. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 3 VII. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE COMPANY AGREEMENT OF HOUSING FIRST OAK SPRINGS, GP, LLC Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign the Company Agreement of Housing First Oak Springs, GP, LLC. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. VIII. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE CONSENT OF SOLE MEMBER AND SOLE MANAGER IN LIEU OF ORGANIZATIONAL MEETING OF HOUSING FIRST OAK SPRINGS, GP, LLC Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign the Consent of Sole Member and Sole Manager in Lieu of Organizational Meeting of Housing First Oak Springs, GP, LLC. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. IX. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE CONSENT OF MEMBER AND MANAGERS IN LIEU OF SPECIAL MEETING OF HOUSING FIRST OAK SPRINGS, GP, LLC Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign the Consent of Member and Managers in Lieu of Special Meeting of Housing First Oak Springs, GP, LLC. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. X. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING LISA OTT LAKY TO SIGN THE CERTIFICATE OF FORMATION OF HOUSING FIRST, LLC AS ORGANIZER Mr. Young made a motion to recommend to the Board the approval to authorize Lisa Ott Laky to sign the Certificate of Formation of Housing First, LLC as Organizer.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 4 Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. XI. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE COMPANY AGREEMENT OF HOUSING FIRST, LLC Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign the Company Agreement of Housing First, LLC. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. XII. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN THE CONSENT OF SOLE MEMBER AND MANAGER IN LIEU OF ORGANIZATIONAL MEETING OF HOUSING FIRST, LLC Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign the Consent of Sole Member and Manager in Lieu of Organizational Meeting of Housing First, LLC. Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried. XIII. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN A PROMISSORY NOTE BETWEEN HOUSING FIRST OAK SPRINGS, LP AND AUSTIN-TRAVIS COUNTY MENTAL HEALTH AND MENTAL RETARDATION CENTER (DBA INTEGRAL CARE) Mr. Young made a motion to recommend to the Board the approval to authorize the Chief Executive Officer and/or his designee to sign a Promissory note between Housing First Oak Springs, LP and Austin –Travis County Mental Health and Mental Retardation Center (dba Integral Care). Mr. Chapa seconded. Discussion followed. All were in favor. Motion carried.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 5 XIV. REQUEST TO ACCEPT FUNDING IF AWARDED FROM THE AUSTIN HOUSING FINANCE CORPORATION FOR THE HCC DEVELOPMENT OF HOUSING FIRST OAK SPRINGS Mr. Young made a motion to recommend to the Board acceptance of funding, if awarded, from the Austin Housing Finance Corporation for the HCC Development of Housing First Oak Springs. Mr. Chapa seconded. Ms. Casey discussed background information on this funding. Discussion followed. All were in favor. Motion carried. XV. DISCUSS AND TAKE APPROPRIATE ACTION ON RECOMMENDATION TO APPROVE GENERAL CONTRACTOR FOR RENOVATION SERVICES AT 1165 AIRPORT Mr. Chapa made a motion to recommend to the Board the approval of staff’s recommendation of the General Contractor for renovation services at 1165 Airport. Mr. Young seconded. Ms. Spencer reviewed the background and current status information found in the packet. Discussion followed. All were in favor. Motion carried. XVI. DISCUSS AND TAKE APPROPRIATE ACTION TO APPROVE FUNDING FOR ROOF REPLACEMENT AT 1430 COLLIER ST. Mr. Chapa made a motion to recommend to the Board the approval of funding for roof replacement at 1430 Collier St. Mr. Young seconded. Ms. Spencer reviewed the background and current status information found in the packet. Discussion followed. All were in favor. Motion carried.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 6 XVII. DISCUSS AND TAKE APPROPRIATE ACTION REGARDING AUTHORIZING THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO ACCEPT, IF AWARDED, THE DRUG-FREE COMMUNITIES SUPPORT PROGRAM GRANT Mr. Young made a motion to recommend to the Board the approval authorizing the CEO and/or his designee to accept, if awarded, the Drug-Free Communities Support Program Grant. Mr. Chapa seconded. Mr. Weden reviewed the background and current status information found in the packet. Discussion followed. All were in favor. Motion carried. XVIII. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING THE CHIEF ADMINISTRATIVE OFFICER/CHIEF FINANCIAL OFFICER AND/OR DIRECTOR OF ACCOUNTING TO OPEN A BROKERAGE ACCOUNT WITH EDWARD D. JONES AND COMPANY, LP (DBA EDWARD JONES) Mr. Young made a motion to recommend to the Board the authorization for the CAO/CFO and/or Director of Accounting to open a brokerage account with Edward D. Jones and Company, LP (dba Edward Jones). Mr. Chapa seconded. Mr. Weden discussed the background and current status information found in the packet. Discussion followed. All were in favor. Motion carried. XIX. DISCUSS AND TAKE APPROPRIATE ACTION AUTHORIZING APPROVAL FOR THE CHIEF EXECUTIVE OFFICER AND/OR HIS DESIGNEE TO SIGN A CONTRACT WITH ALERTMEDIA FOR SAFESIGNAL AND ALERTMEDIA NOTIFICATION CENTER. Mr. Young made a motion to recommend to the Board the approval for the CEO and/or his designee to sign a contract with AlertMedia for SafeSignal and AlertMedia Notification Center. Mr. Chapa seconded. Mr. Weden discussed the background and current status information found in the packet. Discussion followed. All were in favor. Motion carried.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 7 XX. RECOMMENDATION TO APPROVE CONTRACT FOR MILITARY VETERANS PEER NETWORK (MVPN) SERVICES TO THE SAMARITAN CENTER (P&O AGENDA ITEM) Mr. Young made a motion to recommend to the Board approval of a contract for Military Veterans Peer Network Services to the Samaritan Center. Mr. Chapa seconded. Ms. Lynch and Mr. Dominguez discussed the background, projected workload, RFP Review Committee evaluation, PNAC follow-up and discussion, and award information. Discussion followed. All were in favor. Motion carried. XXI. DISCUSS AND TAKE APPROPRIATE ACTION ON FY 2018 BUDGET DEVELOPMENT CALENDAR Mr. Young made a motion to recommend to the Board approval of the FY 2018 Budget Development Calendar. Mr. Chapa seconded. Mr. Weden discussed the proposed budget calendar and the primary challenges of implementing the FY 2018 budget. Discussion followed. All were in favor. Motion carried. XXII. DISCUSSION OF INVITATION FOR BID (IFB) FOR NEW AUDITING FIRM Mr. Weden stated that the IFB will be prepared by staff which will include a list of qualifications and experience, i.e. previous work with community centers, experience with 990’s, audit plans, price, etc. Discussion followed. XXIII. DISCUSSION OF FINANCIAL RATIOS Mr. Weden reviewed the information including Current Ratio, Acid Test Ratio, Days Cash on Hand, Days of Operation (Unrestricted fund balance w/o capital expenditures) and Days of Operation (Total fund balance). Discussion followed.
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Finance Committee Minutes/Integral Care March 27, 2017 Page 8 XXIV. UPDATE ON FISCAL YEAR 2017 BUSINESS PLAN Mr. Weden discussed the information found in the Business Plan notebook given to the Board. He stated that this information is shared with the Executive Management Team at their weekly meeting. Discussion followed. XXV. UPDATE ON NEW MILESTONES FOUNDATION Ms. Irwin discussed the following information regarding NMF: 2017 Slate of Officers, Strategic Plan Update, 2017 Bridging the Gap Gala, 2017 Bridging the Gap Gala Committee, and the next Board meeting scheduled for April 4, 2017. Discussion followed. XXVI. DISCUSSION OF FY 2017 DASHBOARD FINANCIAL METRICS Dr. Baker and Melissa Rowan discussed the information found in the packet on pages 123-138. Dr. Baker stated that there are three levels of the Dashboard – information for Planning and Operations Committee, for Finance Committee, and for the full Board of Trustees. Discussion followed. XXVII. ANNOUNCEMENTS None. XXVIII. NEW BUSINESS • Non-Consent: Item IV, XIII, XV • Consent: Items: III, V, VI, VII, VIII, IX, X, XI, XII, XIV, XVI, XVII, XVIII, XIX, XX, XXI XXIX . CITIZENS’ COMMENTS None. There being no further business, the meeting adjourned at 1:10 p.m. __________________________________ ___________________________ Tom Young, Chair Date Libby Worsham, Finance Committee Executive Assistant
Libby Worsham
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Mar'15 Mar'16 Mar'17Interest Rate 0.29% 0.36% 0.41%Earnings 5,067 5,426 8,944
0.00%
0.05%
0.10%
0.15%
0.20%
0.25%
0.30%
0.35%
0.40%
0.45%
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
Mar
-15
Apr
-15
May
-15
Jun-
15
Jul-1
5
Aug
-15
Sep-
15
Oct
-15
Nov
-15
Dec
-15
Jan-
16
Feb-
16
Mar
-16
Apr
-16
May
-16
Jun-
16
Jul-1
6
Aug
-16
Sep-
16
Oct
-16
Nov
-16
Dec
-16
Jan-
17
Feb-
17
Mar
-17
Inte
rest
Rat
es
Dol
lars
Interest Rates and EarningsComparison
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LIST OF SECURITIESFor the month ended March 31, 2017
Investments AverageCash and Purchase Book Interest Maturity Days to
Cash Equivalents Dates Values Rates Dates Maturity
Chase Bank of TexasChase Bank Depository Account 6/1/2007 16,037,989 0.30% 1
Frost BankFrost Bank Depository Account 2/1/2017 10,005,737 0.53% 1
Short-term Investments:TexPool Fund - Operating 6/1/2007 1,913,386 0.62% 1TexPool Fund - Midelburg Trust 6/1/2007 311,665 0.62% 1
Total 28,268,778$ 0.41% 1
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Operations Waiver
Sub-Total Operations &
Waiver Capital Projects Total
Total Annual Budget - Current $ 75,327,424 $ 17,288,685 $ 92,616,109 $ 26,352,978 $ 118,969,087 Total Annual Budget - Original $ 74,299,518 $ 17,313,179 $ 91,612,697 $ 26,352,978 $ 117,965,675 Total Budget Amendments $ 1,027,906 $ (24,494) $ 1,003,412 $ - $ 1,003,412
Year-to-Date (YTD) Net $ 315,273 $ 818,968 $ 1,134,241 $ (938,369) $ 195,872 Year-to-Date Planned Fund Balance Exp $ (107,629) $ (107,629) (921,334)$ $ (1,028,963) Year-to-Date Net (without FB planned loss) $ 422,902 $ 818,968 $ 1,241,870 $ (17,036) $ 1,224,834 Note: Settlement on outstanding FFS claims, $76,180
Notes: 1) Reserve
$ 218,473
2) Fund Balance Fund Balance
Category 2016 Ending
Fund Balance FY2017 YTD
Net Operations FY2017 YTD Fund Balance
Fund Balance Days of
Operation Operations Unassigned 9,854,862$ $ (407,504) $ 9,447,358 $ 9,447,358 Midelberg Restricted 6,653 - $ 6,653 Waiver Assigned 6,673,245 818,968 $ 7,492,213 $ 7,492,213 Sale of NLJ/Purchase Renovation 1165 Airport Assigned 4,281,431 (215,593) $ 4,065,838
Total Fund Balance 20,816,191$ $ 195,872 $ 21,012,063 $ 16,939,571
Annual Budget Used to Date Budget Balance Total Unrestricted / Waiver FB $ 16,939,571 FY17 Fund Balance Budget (1,225,175)
(1,000,000)$ $ (118,887) $ (881,113) FY2017 YTD Adj Fund Balance $ 15,714,396 (600,000) - (600,000) YTD Average Operations Expense $ 226,131 (659,139) (586,854) (72,285) YTD Unrestricted Days of Operation 69(137,478) (57,616) (79,862)(150,000) (50,013) (99,987)
(2,546,617)$ (813,370)$ (1,733,247)$ 508,072 508,072
(2,038,545)$ (813,370)$ (1,225,175)$ (4,500,000) (215,593) (4,284,407)(6,538,545)$ (1,028,963)$ (5,509,582)$
21,851$ (6,516,694)$
3) Capital Projects Include: Budget YTD Revenue YTD Expense YTD Net IT Project Plan Future EMR 1,000,000$ -$ $ 118,887 $ (118,887)Collier Facility Roof Replacement 600,000 - - - The Herman Center Facility Construction 4,331,821 2,549,096 3,135,950 (586,854)HCC Oaksprings Facility 15,921,157 1,400,000 1,403,477 (3,477)Airport Facility Renovation 4,500,000 - 215,593 (215,593)S. Lamar New Lease Build-Out - - 13,559 (13,559)
Total Capital Projects $ 26,352,978 $ 3,949,096 $ 4,887,465 $ (938,369)
Integral CareFinancial Summary Period Ending March 31, 2017
Included in budget are reserves, DSHS Adult ($174,136) and Child ($44,337)
2017 Fund Balance BudgetUnrestricted:IT Project Plan Future EMR
Total FY2017 Original Fund Balance Budget
Collier Facility Roof ReplacementThe Herman Center Facility Construction Early Child Intervention (ECI) ProgramUnallowable Type Expenses (recurring type expenses)
Total Unrestricted Fund Balance BudgetWaiver Fund Balance Contribution Budget (Profit)
FY2017 Unrestricted & Waiver Fund Balance Budget Airport Facility Renovation (restricted sale of NLJ Property)
Total FY2017 Amended Fund Balance Budgette: Sept Budget Amendment reduce Waiver FB Contribution Budget (fr $529,923 to $508,072)
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Balance Sheet - General Operating Fund - Schedule N2As of 03/31/2017
Schedule N2 Balance Sheet Gen. Op. Fund
BeginningBalance
9/01/2016
Prior PeriodBalance
2/28/2017
Current PeriodBalance
3/31/2017
Notes Current Period % Change
Year To Date % Change
AssetsCurrent Assets
Cash 17,689,459$ 30,410,219$ 28,274,704$ (7.02%) 59.84%Accounts Receivable 16,032,605 12,248,138 13,251,005 (1) 8.19% (17.35%)Deposits and Prepaids 599,366 559,020 486,412 (12.99%) (18.85%)Inventory 0 0 0
Total Current Assets 34,321,430$ 43,217,376$ 42,012,121$ (2.79%) 22.41%Noncurrent Assets
Investment in Tejas -$ -$ -$ Investment in NMF 128,649 128,649$ 128,649$ 0.00% 0.00%Investment in Housing First Oak Springs 0 0 0
Total Noncurrent Assets 128,649$ 128,649$ 128,649$ 0.00% 0.00%Total Assets 34,450,079$ 43,346,025$ 42,140,770$ (2.78%) 22.32%
LiabilitiesCurrent Liabilities
Interfund Payables 436,571$ 419,447$ 414,212$ (1.25%) (5.12%)Accounts Payable 4,480,801 1,749,222 1,478,427 (2) (15.48%) (67.01%)Deferred Revenue 4,631,854 14,982,001 16,291,415 (3) 8.74% 251.73%Fringe Payables 2,506,735 2,958,686 1,267,619 (57.16%) (49.43%)
Total Current Liabilities 12,055,961$ 20,109,356$ 19,451,672$ (3.27%) 61.34%Noncurrent Liabilities
Accrued Compensated Absences 1,577,927$ 1,740,232$ 1,677,035$ (3.63%) 6.28%Total Noncurrent Liabilities 1,577,927$ 1,740,232$ 1,677,035$ (3.63%) 6.28%
Total Liabilities 13,633,888$ 21,849,588$ 21,128,707$ (3.30%) 54.97%
Fund EquityFund Balance - Operations
Fund Balance - Operations 9,861,515$ 9,861,515$ 9,861,515$ 0.00% 0.00%Net Income - Operations 0 205,410 315,273 53.48%Net Income - Capital Projects (excluding Airport) 0 (123,074) (722,777) 487.27%
Total Fund Balance - Operations 9,861,515$ 9,943,851$ 9,454,011$ (4) (4.93%) (4.13%)Fund Balance - 1115 Waiver
Fund Balance - 1115 Waiver 6,673,245$ 6,673,245$ 6,673,245$ 0.00% 0.00%Net Income - 1115 Waiver 0 663,416 818,968 23.45%
Total Fund Balance - 1115 Waiver 6,673,245$ 7,336,661$ 7,492,213$ (5) 2.12% 12.27%Fund Balance - Airport Building Capital Project
Fund Balance - Airport Building Capital Project 4,281,431$ 4,281,431$ 4,281,431$ 0.00% 0.00%Net Income - Airport Building Capital Project 0 (65,506) (215,593) 229.12%
Total Fund Balance - Airport Building Capital Projec 4,281,431$ 4,215,925$ 4,065,839$ (6) (3.56%) (5.04%)Total Fund Equity 20,816,192$ 21,496,437$ 21,012,063$ (2.25%) 0.94%Total Liabilities and Fund Equity 34,450,079$ 43,346,025$ 42,140,770$ (2.78%) 22.32%
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Note 1 Accounts Receivable, $13,251,0053rd Party FFS A/R 1,000,7373rd Party FFS A/R - Allowance (311,840)
Sub-Total 3rd Party FFS A/R 688,897Contracts Receivable 7,911,726Contracts Receivable - Accrued Revenue (Central Health, MAC, etc/) 3,826,023Employee Advances - Payroll Pay Period Conversion 492,061Payroll Accrued Exp - Match Revenue Cost Reimbursement Contracts 166,931Employee Insurance Receivable 155,883Rental Operations 9,485
Total Accounts Receivable 13,251,005
Note 2 Accounts Payable, $1,478,427:Accrued Accounts Payable (mainly Contract Provider Exp and DSHS/DADS 2016 unspent cost reimb advances) 1,246,923Other 231,504
Total Accounts Payable 1,478,427
Note 3Waiver Funds 6,800,136 DSHS 3,690,911 St. David's EOU 1,730,405 DADS 1,246,071 Central Health 636,623 City of Austin Interlocal 735,258 DSHS Match - Rehab/CM Match 322,012 HCC MATCH (NMF, DACC, Lola Wright) 366,382 All Other 763,616
Total Deferred Revenue 16,291,415
Note 4 Fund Balance Operations, $9,454,011(includes Midelberg):Fund Balance Ending 8/31/2016 (includes operations & Midelberg) 9,861,515FY2017 YTD Net Operations 315,273FY2017 Capital Projects Net (excluding Airport Facility) (722,777)
Fund Balance Ending (Operations & Midelberg) 9,454,011
Note 5 Fund Balance Waiver, $7,492,213:Fund Balance Ending 8/31/2016 6,673,245FY2017 YTD Net Waiver 818,968
Total Waiver Fund Balance 7,492,213
Note 6 Fund Balance Airport Building Sale/Purchase/Renovation, $4,065,838:Fund Balance Ending 8/31/2016 4,281,4312017 Renovation Airport Building (215,592)
Total Building Sale/Purchase Fund Balance 4,065,839
BALANCE SHEET NOTES Period Ending 3/31/2017
Deferred Revenue, $16,291,415:
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Statement of Revenues and Expenditures - Schedule C1 - CombinedFrom 3/01/2017 Through 3/31/2017
Schedule C1 - Combined Original Budget Budget
Revisions Revised Budget Current Month
Actual YTD Actual YTD Budget YTD Variance Percent
VarianceREVENUES Local Funds City of Austin 8,101,521$ -$ 8,101,521$ 397,997$ 2,262,173$ 4,725,903$ (2,463,730)$ (52.13%) Travis County 5,454,161 476,008 5,930,169 425,400 2,913,115 3,459,274 (546,159) (15.79%) Central Health 10,085,269 - 10,085,269 968,883 5,685,640 5,883,073 (197,433) (3.36%) Other Local 19,522,655 267,920 19,790,575 (66,710) 4,302,539 11,544,533 (7,241,994) (62.73%)Total Local Funds 43,163,606$ 743,928$ 43,907,534$ 1,725,570$ 15,163,467$ 25,612,783$ (10,449,316)$ (40.80%) State Funds DSHS Mental Health 27,473,901$ 190,877$ 27,664,778$ 3,215,538$ 15,596,720$ 16,137,828$ (541,108)$ (3.35%) DSHS Substance Abuse 2,420,402 (209,350) 2,211,052 219,440 1,317,132 1,289,792 27,340 2.12% DADS 4,226,581 6,053 4,232,634 306,714 2,288,077 2,469,054 (180,977) (7.33%) TCOOMMI 1,821,958 - 1,821,958 205,740 1,029,478 1,062,803 (33,325) (3.14%) DARS (Early Childhood Intervention) 636,610 - 636,610 52,058 376,364 371,357 5,007 1.35% Other State 351,286 120,214 471,500 16,037 151,681 275,037 (123,356) (44.85%)Total State Funds 36,930,738$ 107,794$ 37,038,532$ 4,015,527$ 20,759,451$ 21,605,871$ (846,420)$ (3.92%) Federal Funds Medicare/Medicaid/HMO 10,738,243$ 129,839$ 10,868,082$ 972,437$ 5,799,727$ 6,339,704$ (539,977)$ (8.52%) HCS/Tx Hm Lvg Waiver 297,273 - 297,273 24,193 137,444 173,411 (35,967) (20.74%) Other Federal 3,747,123 - 3,747,123 320,705 1,951,175 2,185,820 (234,645) (10.73%)Total Federal Funds 14,782,639$ 129,839$ 14,912,478$ 1,317,335$ 7,888,346$ 8,698,935$ (810,589)$ (9.32%) Waiver Funds 1115 Waiver 16,571,998$ -$ 16,571,998$ 1,317,429$ 9,211,490$ 9,666,993$ (455,503)$ (4.71%)Total Waiver Funds 16,571,998$ -$ 16,571,998$ 1,317,429$ 9,211,490$ 9,666,993$ (455,503)$ (4.71%)
Total REVENUES 111,448,981$ 981,561$ 112,430,542$ 8,375,861$ 53,022,754$ 65,584,582$ (12,561,828)$ (19.15%)
EXPENDITURES Operating expenditures Salaries 46,222,643$ 559,001$ 46,781,644$ 3,574,012$ 24,867,524$ 27,289,388$ 2,421,864$ 8.87% Fringe benefits 12,844,427 48,038 12,892,465 812,329 6,268,526 7,520,863 1,252,337 16.65% Travel/Workshop 892,265 48,862 941,127 51,671 494,171 549,101 54,930 10.00% Prescription Drugs & Medicine 1,857,310 - 1,857,310 32,868 290,041 1,083,460 793,419 73.23% Consumable Supplies 282,159 16,500 298,659 32,466 168,410 174,314 5,904 3.39% Contracts & Consultants 21,586,868 139,771 21,726,639 2,842,098 11,569,909 12,673,878 1,103,969 8.71% Capital Outlay 23,259,798 100 23,259,898 566,425 3,233,326 13,568,275 10,334,949 76.17% Furniture & Equipment 1,063,383 59,157 1,122,540 100,961 674,459 654,948 (19,511) (2.98%) Facility/Telephone/Utility 5,199,584 27,897 5,227,481 611,240 3,122,565 3,049,662 (72,903) (2.39%) Insurance Costs 310,529 1,246 311,775 24,420 173,556 181,888 8,332 4.58% Transportation Costs 120,270 - 120,270 5,683 48,156 70,161 22,005 31.36% Professional Fees 651,427 - 651,427 251,573 620,948 379,981 (240,967) (63.42%) Other Operating Costs 2,442,398 39,917 2,482,315 53,744 425,283 1,448,027 1,022,744 70.63% Client Support Costs 1,232,614 62,923 1,295,537 107,692 870,438 755,790 (114,648) (15.17%)Total Operating expenditures 117,965,675$ 1,003,412$ 118,969,087$ 9,067,183$ 52,827,312$ 69,399,736$ 16,572,424$ 23.88%Total EXPENDITURES 117,965,675$ 1,003,412$ 118,969,087$ 9,067,183$ 52,827,312$ 69,399,736$ 16,572,424$ 23.88%
Total Gain/Loss Operating before FB (6,516,694)$ (21,851)$ (6,538,545)$ (691,322)$ 195,442$ (3,815,154)$ 4,010,596$ (105.12%)
Fund Balance Fund Balance 6,516,694$ 21,851$ 6,538,545$ 3$ 429$ 3,814,153$ (3,813,724)$ (99.99%)Total Fund Balance 6,516,694$ 21,851$ 6,538,545$ 3$ 429$ 3,814,153$ (3,813,724)$ (99.99%)
Total Gain/Loss Operating With FB -$ -$ -$ (691,318)$ 195,871$ (1,001)$ 196,872$ 15 of 103
Statement of Revenues and Expenditures - Schedule C2 - OperationsFrom 3/01/2017 Through 3/31/2017
Schedule C2 - Operations Original Budget
Budget Revisions Revised Budget
Current Month Actual YTD Actual YTD Budget YTD Variance Notes
Percent Variance
REVENUES Local Funds City of Austin 5,101,521$ -$ 5,101,521$ 397,997$ 2,262,173$ 2,975,903$ (713,730)$ (1) (23.98%) Travis County 5,454,161 476,008 5,930,169 425,400 2,913,115 3,459,274 (546,159) (2) (15.79%) Central Health 10,085,269 - 10,085,269 968,883 5,685,640 5,883,073 (197,433) (3) (3.36%) Other Local 3,061,625 396,417 3,458,042 (72,605) 1,726,384 2,017,211 (290,827) (4) (14.42%)Total Local Funds 23,702,576$ 872,425$ 24,575,001$ 1,719,675$ 12,587,312$ 14,335,461$ (1,748,149)$ (12.19%) State Funds DSHS Mental Health 25,394,036$ 190,877$ 25,584,913$ 2,081,067$ 14,196,720$ 14,924,574$ (727,854)$ (5) (4.88%) DSHS Substance Abuse 2,420,402 (209,350) 2,211,052 219,440 1,317,132 1,289,792 27,340 2.12% DADS 4,226,581 6,053 4,232,634 306,714 2,288,077 2,469,054 (180,977) (6) (7.33%) TCOOMMI 1,821,958 - 1,821,958 205,740 1,029,478 1,062,803 (33,325) (3.14%) DARS (Early Childhood Intervention) 636,610 - 636,610 52,058 376,364 371,357 5,007 1.35% Other State 351,286 120,214 471,500 16,037 151,681 275,037 (123,356) (7) (44.85%)Total State Funds 34,850,873$ 107,794$ 34,958,667$ 2,881,056$ 19,359,451$ 20,392,617$ (1,033,166)$ (5.07%) Federal Funds Medicare/Medicaid/HMO 9,373,702$ 1,342$ 9,375,044$ 823,550$ 4,995,686$ 5,468,764$ (473,078)$ (8) (8.65%) HCS/Tx Hm Lvg Waiver 297,273 - 297,273 24,193 137,444 173,411 (35,967) (20.74%) Other Federal 3,747,123 - 3,747,123 320,705 1,951,175 2,185,820 (234,645) (9) (10.73%)Total Federal Funds 13,418,098$ 1,342$ 13,419,440$ 1,168,447$ 7,084,305$ 7,827,995$ (743,690)$ (9.50%) Waiver Funds 1115 Waiver 2,040,493$ 46,345$ 2,086,838$ 164,593$ 1,156,812$ 1,217,321$ (60,509)$ (10) (4.97%)Total Waiver Funds 2,040,493$ 46,345$ 2,086,838$ 164,593$ 1,156,812$ 1,217,321$ (60,509)$ 4.97%
Total REVENUES 74,012,040$ 1,027,906$ 75,039,946$ 5,933,771$ 40,187,880$ 43,773,394$ (3,585,514)$ (8.19%)
EXPENDITURES Operating expenditures Salaries 36,708,192$ 442,370$ 37,150,562$ 2,873,397$ 19,810,166$ 21,671,237$ 1,861,071$ 8.59% Fringe benefits 10,273,827 52,731 10,326,558 655,390 5,023,287 6,024,088 1,000,801 16.61% Travel/Workshop 716,647 48,862 765,509 44,321 428,076 446,649 18,573 4.16% Prescription Drugs & Medicine 446,567 - 446,567 30,552 256,752 260,519 3,767 1.45% Consumable Supplies 237,512 16,500 254,012 27,450 140,977 148,246 7,269 4.90% Contracts & Consultants 18,152,171 276,203 18,428,374 1,594,074 9,645,538 10,749,886 1,104,348 (13) 10.27% Capital Outlay 111,362 100 111,462 1,127 22,672 65,023 42,351 65.13% Furniture & Equipment 838,310 59,157 897,467 84,965 533,593 523,642 (9,951) (1.90%) Facility/Telephone/Utility 4,232,434 27,897 4,260,331 477,542 2,500,814 2,485,413 (15,401) (0.62%) Insurance Costs 244,544 1,246 245,790 19,808 140,616 143,388 2,772 1.93% Transportation Costs 100,150 - 100,150 3,906 37,759 58,415 20,656 35.36% Professional Fees 182,480 - 182,480 14,576 95,182 106,428 11,246 10.57% Other Operating Costs 888,598 39,917 928,515 52,471 380,282 541,646 161,364 (14) 29.79% Client Support Costs 1,166,724 62,923 1,229,647 106,600 857,323 717,346 (139,977) (15) (19.51%)Total Operating expenditures 74,299,518$ 1,027,906$ 75,327,424$ 5,986,179$ 39,873,037$ 43,941,926$ 4,068,889$ 9.26%Total EXPENDITURES 74,299,518$ 1,027,906$ 75,327,424$ 5,986,179$ 39,873,037$ 43,941,926$ 4,068,889$ 9.26%
Total Gain/Loss Operating before FB (287,478)$ -$ (287,478)$ (52,408)$ 314,843$ (168,532)$ 483,375$ (286.82%)
Fund Balance Fund Balance 287,478$ -$ 287,478$ 3$ 429$ 167,699$ (167,270)$ (11) (99.74%)Total Fund Balance 287,478$ -$ 287,478$ 3$ 429$ 167,699$ (167,270)$ (99.74%)
Total Gain/Loss Operating With FB -$ -$ -$ (52,404)$ 315,273$ (833)$ 316,106$
(12)
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Note 1: City of Austin - YTD Budget Variance ($713,730):City HCC Bond Operations ($350,000) City of Austin ACT (City's 1115 project) (343,323) Cost ReimbursementOther (5 cost reimbursement type contracts) (20,407)
Total City of Austin Budget Variance ($713,730)
Note 2: Travis County - YTD Budget Variance ($546,159):SAMSO contract $221,705Child System of Care (124,927)Travis County - Families With Voice (FWV) (197,447)Travis County Correctional Complex (286,325)All Other (6 contracts) (159,165)
Total Travis County Budget Variance ($546,159)
Note 3: Central Health - YTD Budget Variance ($197,433):In-Patient ($243,147) Cost Reimbursement, contract end 9/30 spend DSHS 1stCommUnity Care- EMERGE Program 45,714 Anticipate contract increase
Total Central Health Budget Variance ($197,433)
Note 4: Other Local -YTD Budget Variance ($290,827):St. David's Herman Center (EOU) ($692,502) Anticipate opening JuneSt. David's Mental Health First Aid ($206,293) Contract recently executed, variance based on 1/2 half fiscal yearSeton In-School ($89,658)Cost Reimbursement - Contra Budget on Est Unearned Contract 464,765 Cost Reimbursement contracts that may not spend total contract Payroll Accrued Exp - Match Revenue Cost Reimbursement Contracts 166,931 No BudgetAll Other (20 line items) 65,930
Total Other Local Budget Variance ($290,827)
Note 5: DSHS MH - YTD Budget Variance ($727,854):DSHS - General Revenue Reserve ($145,914) DSHS - In-Patient (704,953) DSHS - Rental Assistance 107,620DSHS - RA1SE (1st psychotic episode) (49,559)DSHS - HCC (billing HCS 1st then COA $600K end of year) 193,684DSHS - All Other, 8 programs (128,732)
Total DSHS MH Budget Variance ($727,854)
REVENUE BUDGET VARIANCE NOTES - OPERATIONSPeriod Ending 3/31/2017
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Note 6: DADS - YTD Budget Variance ($180,977):Crisis Respite 63,946Transitional Support (HUB) (77,662)Crisis Intervention Specialist (60,507)PASRR (75,348)CLOIP / Enhanced Community Coordination (31,406)
Total DADS Budget Variance ($180,977)
Note 7: Other State - YTD Budget Variance ($123,356):CPRIT (unallowed billing prior years $21K) (123,356)
Total TCOOMMI Budget Variance ($123,356)
Note 8: Medicare/Medicaid/HMO - YTD Budget Variance ($473,078):MH - HMO & Medicaid $10,841SUD - HMO & Medicaid 12,324Case Management - HMO & Medicaid (62,062)Rehab - HMO & Medicaid (527,404)Medicare (51,425)IDD Service Coordination (10,941)Reserve - Unearned FFS contra budget 155,589
Total Medicare/Medicaid/HMO Budget Variance ($473,078)
Note 9: Other Federal - ($234,645):VA Safehaven ($86,936)HUD Supported Housing (36,022)MAC (47,797) EOU ytd bud (70,658) All Other, 5 programs (63,890)
Total Other Federal Budget Variance ($234,645)
Note 10: Waiver - ($60,509): Waiver in Program Indirect-reserve match expenses Program Indirect ($60,509) UT medical school collaboration
Total Waiver Budget Variance ($60,509)
Note 11: Fund Balance - ($167,270):Total Annual Fund Balance Budget Unallowable $150,000, no rev, ytd budget is variance ($87,500)Total Annual Fund Balance Budget ECI $137,478, no rev, ytd budget is variance (80,199)Midelberg Interest Income 429
Total Fund Balance Budget Variance ($167,270)
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EXPENSE BUDGET VARIANCE NOTES - OPERATIONSPeriod Ending 3/31/2017
Note 12: Note 13: Note 14: Note 15: Total
Major Funding Types:
Salaries & Fringe
BenefitsContracts & Consultants
Other Operating
Client Support
Cost
Expense Categories
with Budget Variances > or < $50k
1.) Capital Projects $ - $ - $ - -$ -$ 2.) Cost Reimbursement 1,705,650 1,066,983 14,971 (102,901) 2,684,703$ 3.) FFS Contract Max 216,865 (107,435) 4,234 (24,546) 89,118$ 4.) DSHS Adult & Child / Housing 350,429 39,945 16,927 (5,767) 401,534$ 5.) DADS 160,809 16,845 5,300 (54) 182,900$ 6.) TxHmLvg 16,371 19,753 (56) 3,538 39,606$ 7.) Program Support & Community Collaboratives 30,328 45,547 81,588 (10,823) 146,640$ 8.) Admin / Authority 381,420 22,710 38,400 576 443,106$
Total Expense (over)/under YTD Budget 2,861,872$ 1,104,348$ 161,364$ (139,977)$ 3,987,607$
Major Funding Category Notes YTD Budget Variances $50,000 & >:Contracts & Consultants - Cost Reimbursement 1,066,983$
Contracts & Consultants - FFS Contract Max (107,435)$
Note 14Other Operating - Program Support & Comm Collaboratives
81,588$
Note 15 Client Support Cost - Cost Reimbursement (102,901)$ DSHS Rental Assit ($75K); HUD $44K; SAMSO ($48K); Travis County System of Care ($49K); All Other 25 programs $25K under budget
General Note: All contracts are budgeted at contract amount. In some instances we will budget a contra budget if we believe that we do not have the capacity to earn all funds, ie some DSHS SUD contracts.
Note 13
DSHS In-Patient $705K; DSHS HCC $113K; Travis County Family with Voices $140K; Travis County System of Care $197K; Extended Observation Program $120K; SAMSO ($136K); Community Care ($109K); All Other 17 programs $37K under budget
YES Waiver ($127K); 5 Other programs $20K under budget
Unallowable Exp Unit $27K; CTAAFC $38; All Other 7 Programs $17K
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Statement of Revenues and Expenditures - Schedule C3 - WaiverFrom 3/01/2017 Through 3/31/2017
Schedule C3 - Waiver Original Budget
Budget Revisions Revised Budget
Current Month Actual YTD Actual YTD Budget YTD Variance
Percent Variance
REVENUES Local Funds Other Local 1,947,056$ (128,497)$ 1,818,559$ 5,895$ 27,059$ 1,060,836$ (1,033,777)$ (97.45%) Total Local Funds 1,947,056$ (128,497)$ 1,818,559$ 5,895$ 27,059$ 1,060,836$ (1,033,777)$ (97.45%) Federal Funds Medicare/Medicaid/HMO 1,364,541 128,497 1,493,038 148,888 804,041 870,940 (66,899) (7.68%)Total Federal Funds 1,364,541$ 128,497$ 1,493,038$ 148,888$ 804,041$ 870,940$ (66,899)$ (7.68%) Waiver Funds 1115 Waiver 14,531,505 (46,345) 14,485,160 1,152,836 8,054,678 8,449,672 (394,994) (4.67%)Total Waiver Funds 14,531,505$ (46,345)$ 14,485,160$ 1,152,836$ 8,054,678$ 8,449,672$ (394,994)$ (4.67%)Total REVENUES 17,843,102$ (46,345)$ 17,796,757$ 1,307,619$ 8,885,778$ 10,381,448$ (1,495,670)$ (14.41%)
EXPENDITURES Operating expenditures Salaries 9,514,451$ 116,631$ 9,631,082$ 700,615$ 5,057,357$ 5,618,151$ 560,794$ 9.98% Fringe benefits 2,570,600 (4,693) 2,565,907 156,939 1,245,239 1,496,775 251,536 16.81% Travel/Workshop 175,618 - 175,618 7,350 66,095 102,452 36,357 35.49% Prescription Drugs & Medicine 1,410,743 - 1,410,743 2,316 33,290 822,941 789,651 95.95% Consumable Supplies 44,647 - 44,647 5,016 27,433 26,068 (1,365) (5.24%) Contracts & Consultants 2,161,170 (136,432) 2,024,738 218,845 856,133 1,181,103 324,970 27.51% Furniture & Equipment 225,073 - 225,073 15,996 140,865 131,306 (9,559) (7.28%) Facility/Telephone/Utility 967,150 - 967,150 80,717 539,508 564,249 24,741 4.38% Insurance Costs 65,985 - 65,985 4,612 32,940 38,500 5,560 14.44% Transportation Costs 20,120 - 20,120 1,777 10,397 11,746 1,349 11.48% Professional Fees 237 - 237 196 621 140 (481) (343.57%) Other Operating Costs 91,495 - 91,495 1,272 43,816 53,368 9,552 17.90% Client Support Costs 65,890 - 65,890 1,091 13,116 38,444 25,328 65.88%Total Operating expenditures 17,313,179$ (24,494)$ 17,288,685$ 1,196,743$ 8,066,810$ 10,085,243$ 2,018,433$ 20.01%Total EXPENDITURES 17,313,179$ (24,494)$ 17,288,685$ 1,196,743$ 8,066,810$ 10,085,243$ 2,018,433$ 20.01%
Total Gain/Loss Operating 529,923 (21,851) 508,072 110,875 818,968 296,205 522,763
Fund Balance Fund Balance (529,923)$ 21,851$ (508,072)$ -$ -$ (296,373)$ 296,373$ (100.00%)Total Fund Balance (529,923)$ 21,851$ (508,072)$ -$ -$ (296,373)$ 296,373$ (100.00%)
Total Gain/Loss Operating With FB -$ -$ -$ 110,875$ 818,968$ (168)$ 819,136$
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Statement of Revenues and Expenditures - Schedule C4 - Capital ProjectsFrom 3/01/2017 Through 3/31/2017
Schedule C4 - Capital Projects Original Budget
Budget Revisions Revised Budget
Current Month Actual YTD Actual YTD Budget YTD Variance
Percent Variance
REVENUES Local Funds City of Austin 3,000,000$ -$ 3,000,000$ -$ -$ 1,750,000$ (1,750,000)$ (100.00%) Other Local 14,513,974 - 14,513,974 - 2,549,096 8,466,486 (5,917,390) (69.89%) Total Local Funds 17,513,974$ -$ 17,513,974$ -$ 2,549,096$ 10,216,486$ (7,667,390)$ (75.05%) State Funds DSHS Mental Health 2,079,865 - 2,079,865 1,134,472 1,400,000 1,213,254 186,746 15.39%Total State Funds 2,079,865$ -$ 2,079,865$ 1,134,472$ 1,400,000$ 1,213,254$ 186,746$ 15.39%Total REVENUES 19,593,839$ -$ 19,593,839$ 1,134,472$ 3,949,096$ 11,429,740$ (7,480,644)$ (65.45%)
EXPENDITURES Operating expenditures Contracts & Consultants 1,273,527$ -$ 1,273,527$ 1,029,180$ 1,068,239$ 742,889$ (325,350)$ (43.80%) Capital Outlay 23,148,436 - 23,148,436 565,298 3,210,654 13,503,252 10,292,598 76.22% Facility/Telephone/Utility - - - 52,981 82,243 - (82,243) 0.00% Professional Fees 468,710 - 468,710 236,801 525,145 273,413 (251,732) (92.07%) Other Operating Costs 1,462,305 - 1,462,305 - 1,185 853,013 851,828 99.86%Total Operating expenditures 26,352,978$ -$ 26,352,978$ 1,884,261$ 4,887,465$ 15,372,567$ 10,485,102$ 68.21%Total EXPENDITURES 26,352,978$ -$ 26,352,978$ 1,884,261$ 4,887,465$ 15,372,567$ 10,485,102$ 68.21%
Total Gain/Loss Operating (6,759,139) - (6,759,139) (749,789) (938,369) (3,942,827) 3,004,458
Fund Balance Fund Balance 6,759,139$ -$ 6,759,139$ -$ -$ 3,942,827$ (3,942,827)$ (100.00%)Total Fund Balance 6,759,139$ -$ 6,759,139$ -$ -$ 3,942,827$ (3,942,827)$ (100.00%)
Total Gain/Loss Operating With FB -$ -$ -$ (749,789)$ (938,369)$ -$ (938,369)$
FUND BALANCE NOTE Prior Period
Balance Current Month
Actual YTD Actual to Balance Sheet
FY2017 Renovation Airport Blvd Building (65,506) (150,086) (215,593) - Fund Balance Airport Building Sale/Purchase/Renovation
FY2017 Capital Projects (excluding Airport Facility) (123,074) (599,703) (722,777) - Fund Balance Operations
Capital Projects Total (188,580) (749,789) (938,369)
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V. Update on Transformation 1115 Waiver
David WedenKim Macakiage
Handout Pg. 110-115
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Update on Transformation 1115 Waiver
April 24, 2017
Kim MacakiageDirector of Practice Management – 1115 Medicaid Waiver Projects
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DY6 Achievements
April DY 6 ReportingValuation reported as achieved $5,259,649.91Associated IGT (43.82%) $2,304,778.60
Federal Funds (56.18%) $2,954,871.31
Completed DY5 Carry Forward MetricsEarly DY6
Achievement for 3 ProjectsReporting of MLIU
P4R metrics
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1115 Waiver Transition ScheduleSchedule Estimated End Date
Submits Request for 21 Month Extension to CMS January 26, 2016
Gather stakeholder feedback on PFM Protocol February 28, 2017
Submit PFM Protocol to CMS for approval March 31, 2017 [Delayed]
Gather stakeholder feedback on the measure bundles led by Texas
Council
February – May 2017
DY7-8 proposed rules posted for public comment June/July 2017
HHSC Submits Measure Menus to CMS June 30, 2017
Targeted CMS Approval August 2017
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Change Management Plan
• February 2017Financial Impacts
• February 2017Technical Feasibility
• May 2017Operational Impacts
• June 20171115 Waiver Impacts
• OngoingStakeholder Communications
Financial ImplicationsTechnical ImplicationsData AnalyticsOperational Impacts1115 Waiver Impacts
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Change Management in Action!
On track to meet DY6 Targets Closely monitoring metrics while also focusing on transition plans
Program Managers are engaged in transition and sustainability planning EMCOT proposal to Travis County First Steps grant opportunities Evaluation grant for Integrated Care in Schools Integration of Cultural Competency, Peer Support and Chronic Disease Management
Staff Planning meeting on May 12
Streamlining the reporting process Completed test reports for BMI metric
Ongoing discussions with partners Tour of Manor Mustang Clinic with County, City and Central Health Crisis Planning Workgroup hosted by Central Health Involved in Seton, Dell Medical School, Central Health Planning Meeting Data Evaluation Workgroup, Texas Council
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VI. Facilities Report (Additional Information at meeting)
Donna Spencer
Handout Pg. 110-115
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2017 Energy Conservation Audit
and Disclosure (ECAD) Report
For:
Austin Travis County Integral Care
1430 Collier
Conducted by:
Blue Ocean Energy Management
April 2017
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1 4 3 0 C o l l i e r P a g e | 2 E C A D R e p o r t
Executive Summary
Blue Ocean Energy Management (Blue Ocean) is an energy consulting firm. We develop and
implement energy management strategies for clients who have significant exposure to energy
costs. The main objective of an energy management strategy is to manage energy-related costs and
other risks associated with energy consumption.
The objective of this Energy Conservation Audit and Disclosure (ECAD) report is to benchmark
energy usage, as well as look at specific energy consumption patterns. The assessment for this
report was completed using utility information for 2016 supplied by Austin Travis County Integral
Care, as well as information supplied by Austin Energy and Texas Gas Service. The information
has been analyzed using Blue Ocean Energy’s analytical tools and the Department of Energy’s
ENERGY STAR® Portfolio Manager.
Austin Travis County Integral Care is now in compliance with the City of Austin’s Energy
Conservation Audit and Disclosure Ordinance for 1430 Collier, Austin, TX.
As a result of ECAD compliance, 1430 Collier is eligible for the following benefits:
• Austin Energy rebates for qualifying energy efficiency improvement. Without ECAD
compliance, commercial properties are not eligible to receive rebates.
• Avoid Class C misdemeanor for non-compliance of ECAD ordinance.
• Current ECAD rating required for sales/transfers of commercial properties.
Findings:
• The ENERGY STAR rating improved to “66” for 2016
• Total energy costs in 2016 equaled $41,235: a 7% decrease from 2015
• Total electricity charges equaled $39,855 in 2016: a 6% increase versus 2015
• Total natural gas charges equaled $1,380 in 2016: a 34% decrease versus 2015
• Electricity unit cost ($/kWh) decreased 5% compared to 2015 (to $.099)
• Demand costs (kW) increased 12% from 2015 to 2016
• Peak Demand constitutes 41% of electric charges 2013-2016
Blue Ocean confirmed that the 2016 Austin Energy charges were calculated correctly and that the
appropriate rate plan was used.
Recommendations and Comments:
This facility obtained an ENERGY STAR score of “66” in 2016 which is an improvement versus
the past year. 1430 Collier is considered “above average” from an energy efficiency point of view.
Peak Demand Cost increased 12% in 2016 and should be monitored as demand constitutes 41%
of electric charges.
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1 4 3 0 C o l l i e r P a g e | 3 E C A D R e p o r t
Blue Ocean recommends that ATCIC consider adopting an energy management strategy to
continue to energy efficiency improvements to the building and to mitigate the risks of future
increases in energy prices.
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1 4 3 0 C o l l i e r P a g e | 4 E C A D R e p o r t
Benchmarking:
Utility Invoice Audit:
As part of Blue Ocean’s ECAD compliance work, all electrical invoices are verified for billing
and rate accuracy. The 2016 Austin Energy invoices are calculated correctly and this account is
now on the new rate plan >10kW <300kW.
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1 4 3 0 C o l l i e r P a g e | 5 E C A D R e p o r t
Table of Contents
1. Introduction .......................................................................................... 7
1.1 Authorization ............................................................................................................................................... 7 1.2 Scope of Services ......................................................................................................................................... 7 1.3 Limitations ................................................................................................................................................... 7
2. ECAD Energy Rating and Filing with City of Austin ........................ 8
2.1 Portfolio Manager Statement of Energy Performance: ........................................................................................ 9 2.2 Portfolio Manager Energy Performance Explanation: ....................................................................................... 10
3. Historical Energy Consumption Analysis ......................................... 11
3.1 Onsite Energy Sources ............................................................................................................................... 11 3.2 Austin Energy Electricity Charges ............................................................................................................. 11 3.2 Texas Gas Service Charges ........................................................................................................................ 13
4. Electricity “Demand” (kW) Analysis ................................................. 14
4.1 Austin Energy Demand Charges ................................................................................................................ 14 4.2 Demand Charges ........................................................................................................................................ 15
5. Load Factor .......................................................................................... 16
6. Power Factor ........................................................................................ 17
7. Climatic Variation ............................................................................... 18
8. Electricity Price Forecasting ............................................................... 19
9. Greenhouse Gas Emissions ................................................................. 21
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1 4 3 0 C o l l i e r P a g e | 6 E C A D R e p o r t
Glossary of Commonly Used Abbreviations and Terms
1. AE – Austin Energy
2. ASHRAE – American Society of Heating, Refrigerating and Air Conditioning Engineers
3. BOE – Blue Ocean Energy
4. Btu – British Thermal Unit
5. CCF – 100 Cubic Feet
6. CDD – Cooling Degree Day
7. COA – City of Austin
8. Demand Charge – Proportion of monthly AE invoice that is demand charges
9. DOE – U.S. Department of Energy
10. ECAD – Energy Conservation Audit and Disclosure
11. Electricity Cost – Proportion of monthly AE invoice that is electricity charges
12. ERCOT – Electric Reliability Council of Texas
13. EUI – Energy Use Intensity
14. GHG – Greenhouse Gas
15. HDD – Heating Degree Day
16. HVAC – Heating, Ventilation, and Air Conditioning
17. KATT– NOAA designation for the weather station at Camp Mabry
18. kW – Thousand Watts (measure of electrical load)
19. kWh - Thousand Watt Hours
20. LF – Load Factor
21. Monthly AE Invoiced – Total $ of electricity including taxes on AE monthly invoice
22. MW - Megawatt
23. NOAA – National Oceanic and Atmospheric Administration
24. PF – Power Factor
25. PM – Department of Energy’s Energy Star Portfolio Manager
26. PUC – Public Utility Commission of Texas
27. REP – Retail Electric Provider
28. RSF – Rented Square Foot
29. SF – Square Foot
30. TDP – Transmission/Distribution Provider
31. TGS – Texas Gas Service
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1. Introduction
1.1 Authorization
Blue Ocean Energy Management conducted the Energy Conservation Audit and Disclosure
(ECAD) report on behalf of Austin Travis County Integral Care for the facility located at 1430 Collier,
Austin, Texas 78704, in accordance with the contract BOE2017-0112 that was authorized by Ms.
Donna Spencer on January 20, 2017. The facility will from this point forward be referred to as
“1430 Collier.”
1.2 Scope of Services
The ECAD report is a proprietary procedure developed by Blue Ocean Energy for commercial
buildings and facilities. The ECAD report is an assessment of 1430 Collier in terms of an energy
consumption, cost, and Greenhouse Gas emissions point of view. This assessment can be used to
further develop a strategy to manage energy-related risks facing 1430 Collier.
This ECAD report also ensures compliance for 1430 Collier with the City of Austin’s ECAD
ordinance for the year 2017 (using 2016 utility data). The ECAD ordinance requires this type of
energy rating to be supplied to the City of Austin on a yearly basis.
1.3 Limitations
This ECAD report was conducted in accordance with industry standards; its conclusions are based
on information collected and a review of records and data that were reasonably assessable and
practically reviewable in consideration of constraints of the project schedule and budget.
This report is prepared for the sole use of the Austin Travis County Integral Care and should not
be distributed to or relied upon by third parties without written authorization from Blue Ocean
Energy Management.
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2. ECAD Energy Rating and Filing with City of Austin
In order to comply with the City of Austin’s ECAD ordinance, Blue Ocean utilized the EPA’s
Portfolio Manager to generate the energy rating. The energy rating for 1430 Collier has been
communicated to the City of Austin and is in compliance with the City of Austin’s ECAD
ordinance for the 2017 reporting period, as can be seen below. The ECAD rating was submitted
on April 1, 2017, well in advance of the June 1st, 2017 deadline.
Figure 1: Proof of ECAD Compliance for 2017 Reporting Year
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2.1 Portfolio Manager Statement of Energy Performance:
In Figure 2, below, the ENERGY STAR rating for 2016 can be observed. The building achieved
an ENERGY STAR score of “66,” which indicates that the building performs above average in
terms of energy efficiency.
Figure 2: Portfolio Manager's 2016 Energy Rating
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2.2 Portfolio Manager Energy Performance Explanation:
The City of Austin requires that the ECAD rating be calculated utilizing a 12-month range from
January – December of a given year. The rating has to be calculated yearly and communicated to
the City of Austin. The yearly energy ratings were calculated using the Department of Energy’s
ENERGY STAR Portfolio Manager.
The ENERGY STAR score is a measure of how well a property is performing from an energy
efficiency perspective relative to similar properties, when normalized for climate and operational
parameters.
The ENERGY STAR scores are based on data from national building energy consumption surveys.
This allows Portfolio Manager to control for key variables affecting a building’s energy
performance, including climate, hours of operation, and building size. What this means is that
buildings from around the country, with different operating parameters and subject to different
weather patterns, can be compared side-by-side in order to see how they stack up in terms of energy
performance.
The 1-100 scale is set so that 1 represents the worst performing buildings and 100 represents the
best performing buildings. A score of 50 indicates that a building is performing at the national
median, taking into account its size, location, and operating parameters. A score of 75 indicates
that at a property is performing in the 75th percentile and may be eligible to earn ENERGY STAR
certification.
PM measures the Energy Use Intensity (EUI) per square foot. Intuitively, this can be thought of
as the aggregated energy used per square foot converted to British Thermal Units (Btu)i PM uses
kBtu, which is 1,000 Btu. In addition, PM distinguishes between “Site” and “Source” energy. A
simplified explanation is that “Site” energy is the energy consumed at the “Site” and “Source”
energy represents the total amount of raw fuel that is required to operate the building. It
incorporates all transmission, delivery, and production losses, thereby enabling a complete
assessment of energy efficiency in a building.
Austin Energy states the following regarding the ECAD rating on their website:
The energy evaluation online tool will give you a rating number, a single number between 1 and 100
which indicates the overall energy use of your building compared to similar buildings. Factors such
as weather and operating hours are part of the calculation.
The Austin City Council has set the following voluntary goals to help you interpret your rating:
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3. Historical Energy Consumption Analysis
In most commercial buildings, the second largest operational expense after property taxes is energy
cost. Unlike property taxes, building management can effectively mitigate this operational expense
by running a building as efficiently as possible.
The City of Austin’s ECAD ordinance does not require a detailed analysis of historical energy
usage or cost developments. Blue Ocean includes this analysis as part of our compliance work, as
we deem that the understanding of the energy profile of a building is the first step in operating the
building efficiently and thereby mitigating energy costs.
Blue Ocean believes that you cannot manage what you do not measure.
3.1 Onsite Energy Sources
1430 Collier has one Austin Energy (AE) electricity meter and one Texas Gas Service meter
serving the facility, located on-site.
3.2 Austin Energy Electricity Charges
The analysis done in this section is completed utilizing gross energy as invoiced by Austin Energy.
For this report, Blue Ocean Energy utilized electricity data from 2013 - 2016. These 48 months
make up the base period.
As can be observed in Figure 3, below, the trendline for electricity consumption for the base period
is rather flat over time. During the 48 months of data used for this report, 1430 Collier used
1,644,720 kWh of electricity at a cost of $166,732.
Figure 3: kWh Consumed in 2013 – 2016
In Table 1, below, the base period’s electricity consumption (kWh), costs, demand usage (kW),
and demand cost are summarized.
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Table 1: Energy Consumption (kWh), Demand (kW) Usage and Costs 2013 - 2016
More important, perhaps, than consumption, is the actual cost of the electricity and the breakdown
in cost between kWh and demand charges. 1430 Collier has incurred a total of $166,732 in Austin
Energy charges during the base period. As shown in Figure 4, below, the monthly electricity costs
for 1430 Collier are rather flat over the base period.
Figure 4: Monthly Cost of Electricity 2013– 2016
During the base period, the average monthly electricity cost was $3,474.
During 2016, Austin Energy had three different rate changes. The table below shows the current
rates and not the rates that were in effect in 2016.
1430 Collier is currently on the Austin Energy fixed rate called “SECONDARY VOLTAGE
>10kW <300 kW.” This rate structure has five major components. The five components, as well
as the current rate, can be observed in Table 2, below.
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Table 2: Current Electric Utility rates
The unit cost ($/kWh) for electricity is a function of the relationship between peak demand (Load
Factor) and energy prices for a particular billing period.
One variable that will change the unit cost is the peak demand (kW) in a particular billing period.
If a particular billing period has an increase in the peak demand but a reduction in kWh
consumption, the kWh unit cost will increase, as there would be fewer kWh to “absorb” the
demand charges.
Figure 5: Unit Cost ($/kWh) in 2013 – 2016
The unit cost (see Figure 5, above) is the total invoice divided by kilowatt hours. The average unit
price for the 48-month base period is $.101 /kWh.
3.2 Texas Gas Service Charges
As mentioned previously, there is one natural gas (NG) meter located 1430 Collier. Blue Ocean
Energy obtained 48 months of natural gas consumption from January 2013 to December 2016.
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Figure 6: Natural Gas Consumption/cost and electricity consumption 2013–2016
Figure 6, above, shows natural gas usage by month compared to electricity consumption. As
expected natural gas use is primary used for space heating which peaks in the winter months and
declines to almost nothing in the summer.
Natural gas represents about 5% of the total energy costs for 1430 Collier as can be seen in Figure
7, below.
Figure 7: Natural Gas Cost in 2013 – 2016
4. Electricity “Demand” (kW) Analysis
4.1 Austin Energy Demand Charges
Austin Energy, like all other utilities in the U.S., charges peak demand (kW) fees. In fact, Austin Energy
has some of the highest peak demand rates in the state of Texas. The reason why Austin Energy has
implemented this rate strategy is to financially incentivize commercial customers to manage their peak
demand.
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Demand charges are billed by Austin Energy to its customers based on the numerically largest average
power demand in 1000 Watts (kW) during any 15-minute period within a given billing period. The
following hypothetical example explains the demand charge pricing structure:
• Case 1: Given a 10kW motor and a 15kW motor, if both units were operated for 1 hour at the
same time, the demand meter will record 25 kW for the purposes of calculating the demand
charge. If the two motors were the only two electricity-consuming operations measured by the
account meter, then the demand charge portion of the monthly invoice would be based on 25
kW.
• Case 2: Given the same 10kW motor and 15kW motor, if the units could be operated
alternately, operating each for 1 hour, but the 15kW only when the 10kW unit is off, then the
kW demand would only be 15kW.
Austin Energy implemented its last rate change in January 2017 and no longer has seasonal charges for
peak demand. Currently Austin Energy is charging $12.44/kW for the rate plan >10kW<300kW.
Calculating cost of the two cases utilizing AE’s rate for peak demand ($12.44/kW) and $0.02421/kWh,
the cost would be as seen in Table 3:
kWh kW Cost
Simultaneously (Case 1) 25 25 $311.00
Alternately (Case 2) 25 15 $186.60 Table 3: Demand Cost Example
This is sometimes referred to as “load shifting.” The key point is that in the example above, the same
amount of kWh was used but a 60% savings was achieved ($311.00/186.60) by simply “shifting”
operations of the units.
4.2 Demand Charges
Over the base period, 1430 Collier had an aggregated total of 4,597 kW in peak demand equaling
charges of $68,210, representing 41% of total electric costs.
Over the 48-month base period, the monthly demand average for 1430 Collier has been 96 kW,
with a corresponding average monthly demand charge of $1,421. The trendline for demand charges
for the base period is increasing, as can be seen in Figure 8, below.
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Figure 8: Peak Demand (kW) Cost for 2013 – 2016
The split between the demand charge (kW) and electricity charges (the “fuel” and “energy” charges
discussed above) can be seen in Figure 9, below.
Figure 9: Demand and Electricity Charges from 2013 -2016
1430 Collier incurred a total of $98,522 in electricity costs (non-demand charges) from 2013
through 2016. As can be observed in Figure 9, above, $68,210 or 41% of total electricity cost is
attributable to the demand charges over the last two years.
To think of the demand charge another way, a series of 15-minute peaks of electricity each month
over the period have determined 41% of the total electricity cost.
5. Load Factor
Load Factor (LF) is a parameter which compares average consumption of electricity against peak
demand. Load Factor is indexed on a scale from “0 to 1,” with a Load Factor of “1” being the
maximum, as it implies that the consumer’s demand is constanti. The lower the Load Factor the
greater the difference is between average consumption and peak demand. Utilities prefer even or
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constant demand as it is easier to plan for power production and supply. This is why utilities place
a premium on demand charges (kW).
LF = [(Total kWh) / (# Days in Bill Cycle x 24 hrs/day)] x [Peak kW Demand]
A simpler, more intuitive way of looking at Load Factor is to think of it as the relationship between
the average load and the peak load.
If the LF is low, one should look for ways to level the electrical usage (i.e., shift energy intensive
processes to periods of otherwise low usage). By increasing LF, the impact of monthly demand
(kW) charges will be reduced. Peak demand (kW) in a billing period is what Austin Energy
utilizes in its demand charge calculations discussed earlier in this section.
If a Load Factor of “1” is achieved, it does not mean that demand charges will not be incurred or
that a building is operating efficiently from an energy point of view. For example, if all lights and
HVAC systems in a building were left running all the time, a very high LF would be observed.
The theoretical ideal Load Factor is a LF close to “1” with the fewest kWh possible consumed.
Load Factor for the base period can be observed in Figure 10, below.
Figure 10: Load Factor for 1430 Collier 2013 – 2016
Over the 48-month base period, 1430 Collier averaged a Load Factor of 0.49.
6. Power Factor
Power Factor (PF) is another measurement of how efficiently electricity is used in a building.
Austin Energy, along with many other utilities, are applying additional utility charges if the PF is
below a certain threshold.
In general, utilities are moving to a pricing structure that intends to financially “punish” clients
with poor or below average Power Factor and Load Factor (demand) measurements. Austin
Energy currently imposes additional charges when the Power Factor is below “.9.”
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If any such power factor charges are incurred, they will appear as a separate line item on the AE
bill (Power Factor Adjustment Below 90%).
Figure 11: Power Factor 2013 – 2016
In Figure 11, above, the PF readings as reported by Austin Energy for 1430 Collier are shown.
During the 48-month base period this property did not incur any PF charges. Therefore, we can
conclude that PF issues are not a problem for this location. However, PF charges should be
monitored moving forward to ensure that total electricity costs are minimized.
7. Climatic Variation
The climate plays a significant role in the consumption of electricity in buildings, especially
heating, ventilating, and air conditioning (HVAC). The weather-related impacts on energy
consumption make it difficult to evaluate energy efficiencies. However, one method for
normalizing for temperature variations is the use of published degree days.
Degree days are either Heating Degree Days [HDD] or Cooling Degree Days [CDD]ii. When
rationing kWh of energy used by the number of degree days for a period, the impact of temperature
variation on energy consumption is normalized so that a truer picture of energy efficiency can be
visualized.
As can be seen in Figure 12, below, the proportions of HDDs to CDDs vary significantly from
year to year. In general, during the past 16 years, there has been an upward trend in CDDs, whereas
HDDs have remained flat.
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Figure 12: Degree days, 2001 - 2016
Specifically, for 2016, it can be stated that it was a fairly typical climatic year from a CDD point
of view, whereas the very mild winter of 2016 meant fewer HDDs. The implication of the 2016
degree days is that all commercial buildings using strip heat should have seen reductions in energy
consumed (kWh) and cost.
In the benchmarking table, we offer a simplified climatic normalization by converting kWh/degree
day.
8. Electricity Price Forecasting
In a regulated market like Austin, customers do not have the option to contract with competitive
energy suppliers or use different types of priced energy contracts. Austin Energy is the only choice
for electricity.
Based on criticism from commercial and industrial customers, Austin Energy has initiated a new
rate structure. In the fall of 2016, Austin Energy announced new rate structures for residential,
commercial and industrial customers. The various rate and rate class changes were implemented
in Q4 of 2016, resulting in most commercial customers in Austin experiencing a slight decrease in
energy costs.
Historically, Austin Energy has imposed high demand (kW) charges, which often make up 40%
to 50% of commercial customers’ bills. Paradoxically, some of our customers have reduced
electricity consumption (kWh) significantly, only to see their electricity “all-in unit” ($/kWh)
increase due to peak demand (kW) remaining the same. We anticipate similar confounding factors
to be part of future rate plans, leading to increasing energy costs for customers who do not
strategically manage the components of their electricity bills such as peak demand, power factor
and load factor.
In 2016, natural gas prices have increased slightly from historic lows. As the percent of electricity
generation that comes from natural gas is increasing, natural gas impact on fuel charges are also
increasing. In spite of the slightly increasing natural gas prices in 2016, AE twice reduced the fuel
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charges. It is our anticipation that later in 2017, AE will be forced to increase the fuel charges
again.
As a result of these multiple factors, each affecting future electricity costs in different ways, Blue
Ocean assumes a modest 2% per year increase in electricity costs, as well as a less likely aggressive
3.5% annual increase in electricity costs for our price forecasting exercise.
If we model current electricity costs for this facility over the next decade, assuming a constant
occupancy rate and no energy efficiency improvements, the following forecast can be observed:
Figure 13: 1430 Collier Yearly Projected Cost of Electricity Only
If we assume this price increase to occur evenly over the next 10 years, we can calculate the
additional cost for 1430 Collier over the period using 2016 as the reference year and the $166,732
paid for electricity in 2016 as the base cost. The cost for electricity would reach $48,583 /year by
2026 in the best-case scenario and $56,219 /year in the worst scenario.
This corresponds to an additional $46,579 to $85,369 in cumulative projected electricity costs over
the 10-year period attributable to the price increase as can been seen in Figure 14, below.
Figure 14: Projected Cumulative Increase in Energy Costs
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9. Greenhouse Gas Emissions
Portfolio Manager produces a defensible Greenhouse Gas (GHG) number. The methodology
employed is used by all GHG registers and is a standard that is sanctioned by the federal
government. The GHG calculated in the table below is considering the actual energy consumption
of this particular building and the electricity generation fuel mix of Austin Energy.
GHG can be viewed as a measurement of waste. If GHG emissions are reduced, holding all other
parameters constant, it will mean a more efficient utilization of energy and lower energy cost.
Table 4: GHG Emission Table from Portfolio Manager
As can be seen in Table 4, above, the total Greenhouse Gas (GHG) emissions for 2016 was 214.9
Metric Tons of Carbon Dioxide equivalent (MT CO2e).
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Footnotes
i A Btu is defined as amount of heat required to raise the temperature of one 1 pound (0.454 kg) of liquid water by 1 °F (0.556 °C)
at a constant pressure of one atmosphere. As is the case with the calorie, several different definitions of the Btu exist, which are
based on different water temperatures and therefore vary by up to 0.5%: A Btu can be approximated as the heat produced by burning
a single wooden match[2] or as the amount of energy it would take to lift a one-pound weight to a height of 778 feet (237 m)
ii Heating degree days,” or “HDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was lower than a specific “base temperature” (or “balance point”). They are used for calculations relating to the energy consumption
required to heat buildings.
“Cooling degree days,” or “CDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was higher than a specific base temperature. They are used for calculations relating to the energy consumption required to cool
buildings.
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2017 Energy Conservation Audit
and Disclosure (ECAD) Report
For:
Austin Travis County Integral Care
5225 N. Lamar
Conducted by:
Blue Ocean Energy Management
April 2017
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Executive Summary
Blue Ocean Energy Management (Blue Ocean) is an energy consulting firm. We develop and
implement energy management strategies for clients who have significant exposure to energy
costs. The main objective of an energy management strategy is to manage energy-related costs and
other risks associated with energy consumption.
The objective of this Energy Conservation Audit and Disclosure (ECAD) report is to benchmark
energy usage, as well as look at specific energy consumption patterns. The assessment for this
report was completed using utility information for 2016 supplied by Austin Travis County Integral
Care, as well as information supplied by Austin Energy. The information has been analyzed using
Blue Ocean Energy’s analytical tools and the Department of Energy’s ENERGY STAR® Portfolio
Manager.
Austin Travis County Integral Care is now in compliance with the City of Austin’s Energy
Conservation Audit and Disclosure ordinance for 5225 N. Lamar, Austin, TX.
As a result of ECAD compliance, 5225 N. Lamar is eligible for the following benefits:
• Austin Energy rebates for qualifying energy efficiency improvement. Without ECAD
compliance, commercial properties are not eligible to receive rebates.
• Avoid Class C misdemeanor for non-compliance of ECAD ordinance.
• Current ECAD rating required for sales/transfers of commercial properties.
Findings:
• The ENERGY STAR rating improved from “88” in 2013 to “91” in 2016
• Total electricity charges equaled $19,306 in 2016; this is a 10% decrease from 2015
• Electricity unit cost ($/kWh) decreased 6% compared to 2015
• Electricity consumption decreased 3% in 2016 versus 2015
• Demand costs (kW) decreased 2% in 2016 versus 2015
• Peak Demand constitutes 49% of electric charges 2013-2016
• The property incurred $931 in total power factor charges 2013-2016
Blue Ocean confirmed that the 2016 Austin Energy charges were calculated correctly and that the
appropriate rate plan was used.
Recommendations and Comments:
The ENERGY STAR rating increased over the last year, continuing to demonstrate that 5225 N.
Lamar is one of the top-performing buildings from an energy efficiency point of view. This
building may be eligible for the ENERGY STAR certification which requires buildings to obtain
a “75” or higher.
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Demand costs (kW) represent 49% of the building’s electricity costs. ATCIC should monitor
demand from the building’s larger loads to identify potential modifications to operating procedures
that will likely reduce these charges.
Blue Ocean recommends that ATCIC implement an energy management strategy to continue to
improve the energy efficiency metrics of the building.
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Benchmarking:
Utility Invoice Audit:
As part of Blue Ocean’s ECAD compliance work, all electrical invoices are verified for billing
and rate accuracy. The 2016 Austin Energy invoices are calculated correctly and this account is
now on the new rate plan >10kW <300kW.
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Table of Contents
1. Introduction .......................................................................................... 7
1.1 Authorization ............................................................................................................................................... 7 1.2 Scope of Services ......................................................................................................................................... 7 1.3 Limitations ................................................................................................................................................... 7
2. ECAD Energy Rating and Filing with City of Austin ........................ 8
2.1 Portfolio Manager Statement of Energy Performance: .................................................................................. 9 2.2 Portfolio Manager Energy Performance Explanation: ................................................................................. 10
3. Historical Energy Consumption Analysis ......................................... 11
3.1 Onsite Energy Sources ............................................................................................................................... 11 3.2 Austin Energy Electricity Charges ............................................................................................................. 11
4. Electricity “Demand” (kW) Analysis ................................................. 13
4.1 Austin Energy Demand Charges ................................................................................................................ 13 4.2 Demand Charges ........................................................................................................................................ 14
5. Load Factor .......................................................................................... 15
6. Power Factor ........................................................................................ 16
7. Climatic Variation ............................................................................... 17
8. Electricity Price Forecasting ............................................................... 18
9. Greenhouse Gas Emissions ................................................................. 20
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Glossary of Commonly Used Abbreviations and Terms
1. AE – Austin Energy
2. ASHRAE – American Society of Heating, Refrigerating and Air Conditioning Engineers
3. BOE – Blue Ocean Energy
4. Btu – British Thermal Unit
5. CCF – 100 Cubic Feet
6. CDD – Cooling Degree Day
7. COA – City of Austin
8. Demand Charge – Proportion of monthly AE invoice that is demand charges
9. DOE – U.S. Department of Energy
10. ECAD – Energy Conservation Audit and Disclosure
11. Electricity Cost – Proportion of monthly AE invoice that is electricity charges
12. ERCOT – Electric Reliability Council of Texas
13. EUI – Energy Use Intensity
14. GHG – Greenhouse Gas
15. HDD – Heating Degree Day
16. HVAC – Heating, Ventilation, and Air Conditioning
17. KATT– NOAA designation for the weather station at Camp Mabry
18. kW – Thousand Watts (measure of electrical load)
19. kWh - Thousand Watt Hours
20. LF – Load Factor
21. Monthly AE Invoiced – Total $ of electricity including taxes on AE monthly invoice
22. MW - Megawatt
23. NOAA – National Oceanic and Atmospheric Administration
24. PF – Power Factor
25. PM – Department of Energy’s Energy Star Portfolio Manager
26. PUC – Public Utility Commission of Texas
27. REP – Retail Electric Provider
28. RSF – Rented Square Foot
29. SF – Square Foot
30. TDP – Transmission/Distribution Provider
31. TGS – Texas Gas Service
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1. Introduction
1.1 Authorization
Blue Ocean Energy Management conducted the Energy Conservation Audit and Disclosure
(ECAD) report on behalf of Austin Travis County Integral Care for the facility located at 5225 N.
Lamar, Austin, Texas 78704, in accordance with the contract BOE2017-0112 that was authorized
by Ms. Donna Spencer on January 20, 2017. The facility will from this point forward be referred
to as “5225 N. Lamar.”
1.2 Scope of Services
The ECAD report is a proprietary procedure developed by Blue Ocean Energy for commercial
buildings and facilities. The ECAD report is an assessment of 5225 N. Lamar in terms of an energy
consumption, cost, and Greenhouse Gas emissions point of view. This assessment can be used to
further develop a strategy to manage energy-related risks facing 5225 N. Lamar.
This ECAD report also ensures compliance for 5225 N. Lamar with the City of Austin’s ECAD
Ordinance for the year 2017 (using 2016 utility data). The ECAD ordinance requires this type of
energy rating to be supplied to the City of Austin on a yearly basis.
1.3 Limitations
This ECAD report was conducted in accordance with industry standards; its conclusions are based
on information collected and a review of records and data that were reasonably assessable and
practically reviewable in consideration of constraints of the project schedule and budget.
This report is prepared for the sole use of the Austin Travis County Integral Care and should not
be distributed to or relied upon by third parties without written authorization from Blue Ocean
Energy Management.
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2. ECAD Energy Rating and Filing with City of Austin
In order to comply with the City of Austin’s ECAD ordinance, Blue Ocean utilized the EPA’s
Portfolio Manager to generate the energy rating. The energy rating for 5225 N. Lamar has been
communicated to the City of Austin and is in compliance with the City of Austin’s ECAD
ordinance for the 2017 reporting period, as can be seen below. The ECAD rating was submitted
on April 1, 2017, well in advance of the June 1st, 2017 deadline.
Figure 1: Proof of ECAD Compliance for 2017 Reporting Year
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2.1 Portfolio Manager Statement of Energy Performance:
In Figure 2, below, the ENERGY STAR rating for 2016 can be observed. The building achieved
an ENERGY STAR score of “91,” which indicates that the building performs above average in
terms of energy efficiency.
Figure 2: Portfolio Manager's 2016 Energy Rating
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2.2 Portfolio Manager Energy Performance Explanation:
The City of Austin requires that the ECAD rating be calculated utilizing a 12-month range from
January – December of a given year. The rating has to be calculated yearly and communicated to
the City of Austin. The yearly energy ratings were calculated using the Department of Energy’s
ENERGY STAR Portfolio Manager.
The ENERGY STAR score is a measure of how well a property is performing from an energy
efficiency perspective relative to similar properties, when normalized for climate and operational
parameters.
The ENERGY STAR scores are based on data from national building energy consumption surveys.
This allows Portfolio Manager to control for key variables affecting a building’s energy
performance, including climate, hours of operation, and building size. What this means is that
buildings from around the country, with different operating parameters and subject to different
weather patterns, can be compared side-by-side in order to see how they stack up in terms of energy
performance.
The 1-100 scale is set so that 1 represents the worst performing buildings and 100 represents the
best performing buildings. A score of 50 indicates that a building is performing at the national
median, taking into account its size, location, and operating parameters. A score of 75 indicates
that at a property is performing in the 75th percentile and may be eligible to earn ENERGY STAR
certification.
PM measures the Energy Use Intensity (EUI) per square foot. Intuitively, this can be thought of
as the aggregated energy used per square foot converted to British Thermal Units (Btu)i PM uses
kBtu, which is 1,000 Btu. In addition, PM distinguishes between “Site” and “Source” energy. A
simplified explanation is that “Site” energy is the energy consumed at the “Site” and “Source”
energy represents the total amount of raw fuel that is required to operate the building. It
incorporates all transmission, delivery, and production losses, thereby enabling a complete
assessment of energy efficiency in a building.
Austin Energy states the following regarding the ECAD rating on their website:
The energy evaluation online tool will give you a rating number, a single number between 1 and 100
which indicates the overall energy use of your building compared to similar buildings. Factors such
as weather and operating hours are part of the calculation.
The Austin City Council has set the following voluntary goals to help you interpret your rating:
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3. Historical Energy Consumption Analysis
In most commercial buildings, the second largest operational expense after property taxes is energy
cost. Unlike property taxes, building management can effectively mitigate this operational expense
by running a building as efficiently as possible.
The City of Austin’s ECAD ordinance does not require a detailed analysis of historical energy
usage or cost developments. Blue Ocean includes this analysis as part of our compliance work, as
we deem that the understanding of the energy profile of a building is the first step in operating the
building efficiently and thereby mitigating energy costs.
Blue Ocean believes that you cannot manage what you do not measure.
3.1 Onsite Energy Sources
5225 N. Lamar has one Austin Energy (AE) electricity meter serving the facility, located on-site.
3.2 Austin Energy Electricity Charges
The analysis done in this section is completed utilizing gross energy as invoiced by Austin Energy.
For this report, Blue Ocean Energy utilized electricity data from 2013 - 2016. These 48 months
make up the base period.
As can be observed in Figure 3, below, the trendline for electricity consumption has decreased
slightly over time. During the 48 months of data used for this report, 5225 N. Lamar used 654,720
kWh of electricity at a cost of $81,770.
Figure 3: kWh Consumed in 2013 – 2016
In Table 1, below, the base period’s electricity consumption (kWh), costs, demand usage (kW),
and demand cost are summarized.
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Table 1: Energy Consumption (kWh), Demand (kW) Usage and Costs 2013 - 2016
More important, perhaps, than consumption, is the actual cost of the electricity and the breakdown
in cost between kWh and demand charges. 5225 N. Lamar has incurred a total of $81,770 in Austin
Energy charges during the base period. As shown in Figure 4, below, the monthly electricity costs
for 5225 N. Lamar are rather flat.
Figure 4: Monthly Cost of Electricity 2013– 2016
During the base period, the average monthly electricity cost was $1,704.
During 2016, Austin Energy had three different rate changes. The table below shows the current
rates and not the rates that were in effect in 2016.
5225 N. Lamar is currently on the Austin Energy fixed rate called “SECONDARY VOLTAGE
>10kW <300 kW.” This rate structure has five major components. The five components, as well
as the current rate, can be observed in Table 2, below.
Table 2: Current Electric Utility rates
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The unit cost ($/kWh) for electricity is a function of the relationship between peak demand (Load
Factor) and energy prices for a particular billing period.
One variable that will change the unit cost is the peak demand (kW) in a particular billing period.
If a particular billing period has an increase in the peak demand but a reduction in kWh
consumption, the kWh unit cost will increase, as there would be fewer kWh to “absorb” the
demand charges.
Case in point is the December 2015 Peak Demand, which for reasons we do not know, increased
almost 150% (From 43 kW to 107 kW) from one month to the next. As the kWh stayed fairly
consistent that means the all-in unit cost ($/kWh) increased as the additional peak demand charges
were “absorbed” by the kWh’s consumed. Hence the $0.22/kWh unit cost for December 2015 as
can be observed in Figure 5, below.
Figure 5: Unit Cost ($/kWh) in 2013 – 2016
The unit cost (see Figure 5, above) is the total invoice divided by kilowatt hours. The average unit
price for the 48-month base period is $.125 /kWh.
4. Electricity “Demand” (kW) Analysis
4.1 Austin Energy Demand Charges
Austin Energy, like all other utilities in the U.S., charges peak demand (kW) fees. In fact, Austin Energy
has some of the highest peak demand rates in the state of Texas. The reason why Austin Energy has
implemented this rate strategy is to financially incentivize commercial customers to manage their peak
demand.
Demand charges are billed by Austin Energy to its customers based on the numerically largest average
power demand in 1000 Watts (kW) during any 15-minute period within a given billing period. The
following hypothetical example explains the demand charge pricing structure:
• Case 1: Given a 10kW motor and a 15kW motor, if both units were operated for 1 hour at the
same time, the demand meter will record 25 kW for the purposes of calculating the demand
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charge. If the two motors were the only two electricity-consuming operations measured by the
account meter, then the demand charge portion of the monthly invoice would be based on 25
kW.
• Case 2: Given the same 10kW motor and 15kW motor, if the units could be operated
alternately, operating each for 1 hour, but the 15kW only when the 10kW unit is off, then the
kW demand would only be 15kW.
Austin Energy implemented its last rate change in January 2017 and no longer has seasonal charges for
peak demand. Currently Austin Energy is charging $12.44/kW for the rate plan >10kW<300kW.
Calculating cost of the two cases utilizing AE’s rate for peak demand ($12.44/kW) and $0.02421/kWh,
the cost would be as seen in Table 3:
kWh kW Cost
Simultaneously (Case 1) 25 25 $311.00
Alternately (Case 2) 25 15 $186.60 Table 3: Demand Cost Example
This is sometimes referred to as “load shifting.” The key point is that in the example above, the same
amount of kWh was used but a 60% savings was achieved ($311.00/186.60) by simply “shifting”
operations of the units.
4.2 Demand Charges
Over the base period, 5225 N. Lamar had an aggregated total of 2,693 kW in peak demand equaling
charges of $39,725, representing 49% of total electric costs.
Over the 48-month base period, the monthly demand average for 5225 N. Lamar has been 56 kW,
with a corresponding average monthly demand charge of $828. The trendline for demand charges
for the base period is increasing, as can be seen in Figure 6, below.
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Figure 6: Peak Demand (kW) Cost for 2013 – 2016
The split between the demand charge (kW) and electricity charges (the “fuel” and “energy” charges
discussed above) can be seen in Figure 7, below.
Figure 7: Demand and Electricity Charges from 2013 -2016
5225 N. Lamar incurred a total of $42,045 in electricity costs (non-demand charges) from 2013
through 2016. As can be observed in Figure 7, above, $39,725 or 49% of total electricity cost is
attributable to the demand charges over the last two years.
To think of the demand charge another way, a series of 15 minute peaks of electricity each month
over the period have determined 49% of the total electricity cost.
5. Load Factor
Load Factor (LF) is a parameter which compares average consumption of electricity against peak
demand. Load Factor is indexed on a scale from “0 to 1,” with a Load Factor of “1” being the
maximum, as it implies that the consumer’s demand is constanti. The lower the Load Factor the
greater the difference is between average consumption and peak demand. Utilities prefer even or
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constant demand as it is easier to plan for power production and supply. This is why utilities place
a premium on demand charges (kW).
LF = [(Total kWh) / (# Days in Bill Cycle x 24 hrs/day)] x [Peak kW Demand]
A simpler, more intuitive way of looking at Load Factor is to think of it as the relationship between
the average load and the peak load.
If the LF is low, one should look for ways to level the electrical usage (i.e., shift energy intensive
processes to periods of otherwise low usage). By increasing LF, the impact of monthly demand
(kW) charges will be reduced. Peak demand (kW) in a billing period is what Austin Energy
utilizes in its demand charge calculations discussed earlier in this section.
If a Load Factor of “1” is achieved, it does not mean that demand charges will not be incurred or
that a building is operating efficiently from an energy point of view. For example, if all lights and
HVAC systems in a building were left running all the time, a very high LF would be observed.
The theoretical ideal Load Factor is a LF close to “1” with the fewest kWh possible consumed.
Load Factor for the base period can be observed in Figure 8, below.
Figure 8: Load Factor for 5225 N. Lamar 2013 – 2016
Over the 48-month base period, 5225 N. Lamar averaged a Load Factor of 0.39. The Load Factor
for this property is rather low indicating Peak Demand is high.
6. Power Factor
Power Factor (PF) is another measurement of how efficiently electricity is used in a building.
Austin Energy, along with many other utilities, are applying additional utility charges if the PF is
below a certain threshold.
In general, utilities are moving to a pricing structure that intends to financially “punish” clients
with poor or below average Power Factor and Load Factor (demand) measurements. Austin
Energy currently imposes additional charges when the Power Factor is below “.9.”
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If any such power factor charges are incurred, they will appear as a separate line item on the AE
bill (Power Factor Adjustment Below 90%).
Figure 9: Power Factor 2013 – 2016
In Figure 9, above, the PF readings as reported by Austin Energy for 5225 N. Lamar are shown.
This property obtained PF charges in 39 months out of the 48-month base period. Although the
cost was only $931 during this time period, PF charges should be monitored moving forward to
ensure that total electricity costs are minimized.
7. Climatic Variation
The climate plays a significant role in the consumption of electricity in buildings, especially
heating, ventilating, and air conditioning (HVAC). The weather-related impacts on energy
consumption make it difficult to evaluate energy efficiencies. However, one method for
normalizing for temperature variations is the use of published degree days.
Degree days are either Heating Degree Days [HDD] or Cooling Degree Days [CDD]ii. When
rationing kWh of energy used by the number of degree days for a period, the impact of temperature
variation on energy consumption is normalized so that a truer picture of energy efficiency can be
visualized.
As can be seen in Figure 10, below, the proportions of HDDs to CDDs vary significantly from
year to year. In general, during the past 16 years, there has been an upward trend in CDDs, whereas
HDDs have remained flat.
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Figure 10: Degree days, 2001 - 2016
Specifically, for 2016, it can be stated that it was a fairly typical climatic year from a CDD point
of view, whereas the very mild winter of 2016 meant fewer HDDs. The implication of the 2016
degree days is that all commercial buildings using strip heat should have seen reductions in energy
consumed (kWh) and cost.
In the benchmarking table, we offer a simplified climatic normalization by converting kWh/degree
day.
8. Electricity Price Forecasting
In a regulated market like Austin, customers do not have the option to contract with competitive
energy suppliers or use different types of priced energy contracts. Austin Energy is the only choice
for electricity.
Based on criticism from commercial and industrial customers, Austin Energy has initiated a new
rate structure. In the fall of 2016, Austin Energy announced new rate structures for residential,
commercial and industrial customers. The various rate and rate class changes were implemented
in Q4 of 2016, resulting in most commercial customers in Austin experiencing a slight decrease in
energy costs.
Historically, Austin Energy has imposed high demand (kW) charges, which often make up 40%
to 50% of commercial customers’ bills. Paradoxically, some of our customers have reduced
electricity consumption (kWh) significantly, only to see their electricity “all-in unit” ($/kWh)
increase due to peak demand (kW) remaining the same. We anticipate similar confounding factors
to be part of future rate plans, leading to increasing energy costs for customers who do not
strategically manage the components of their electricity bills such as peak demand, power factor
and load factor.
In 2016, natural gas prices have increased slightly from historic lows. As the percent of electricity
generation that comes from natural gas is increasing, natural gas impact on fuel charges are also
increasing. In spite of the slightly increasing natural gas prices in 2016, AE twice reduced the fuel
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charges. It is our anticipation that later in 2017, AE will be forced to increase the fuel charges
again.
As a result of these multiple factors, each affecting future electricity costs in different ways, Blue
Ocean assumes a modest 2% per year increase in electricity costs, as well as a less likely aggressive
3.5% annual increase in electricity costs for our price forecasting exercise.
If we model current electricity costs for this facility over the next decade, assuming a constant
occupancy rate and no energy efficiency improvements, the following forecast can be observed:
Figure 11: 5225 N. Lamar Yearly Projected Cost of Electricity Only
If we assume this price increase to occur evenly over the next 10 years, we can calculate the
additional cost for 5225 N. Lamar over the period using 2016 as the reference year and the $19,306
paid for electricity in 2016 as the base cost. The cost for electricity would reach $23,534 /year by
2026 in the best-case scenario and $27,233 /year in the worst scenario.
This corresponds to an additional $22,563 to $41,353 in cumulative projected electricity costs over
the 10-year period attributable to the price increase as can been seen in Figure 12, below.
Figure 12: Projected Cumulative Increase in Energy Costs
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9. Greenhouse Gas Emissions
Portfolio Manager produces a defensible Greenhouse Gas (GHG) number. The methodology
employed is used by all GHG registers and is a standard that is sanctioned by the federal
government. The GHG calculated in the table below is considering the actual energy consumption
of this particular building and the electricity generation fuel mix of Austin Energy.
GHG can be viewed as a measurement of waste. If GHG emissions are reduced, holding all other
parameters constant, it will mean a more efficient utilization of energy and lower energy cost.
Table 4: GHG Emission Table from Portfolio Manager
As can be seen in Table 4, above, the total Greenhouse Gas (GHG) emissions for 2016 was 80.3
Metric Tons of Carbon Dioxide equivalent (MT CO2e).
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Footnotes
i A Btu is defined as amount of heat required to raise the temperature of one 1 pound (0.454 kg) of liquid water by 1 °F (0.556 °C)
at a constant pressure of one atmosphere. As is the case with the calorie, several different definitions of the Btu exist, which are
based on different water temperatures and therefore vary by up to 0.5%: A Btu can be approximated as the heat produced by burning
a single wooden match[2] or as the amount of energy it would take to lift a one-pound weight to a height of 778 feet (237 m)
ii Heating degree days,” or “HDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was lower than a specific “base temperature” (or “balance point”). They are used for calculations relating to the energy consumption
required to heat buildings.
“Cooling degree days,” or “CDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was higher than a specific base temperature. They are used for calculations relating to the energy consumption required to cool
buildings.
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2017 Energy Conservation Audit
and Disclosure (ECAD) Report
For:
Austin Travis County Integral Care
6222 N. Lamar
Conducted by:
Blue Ocean Energy Management
April 2017
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Executive Summary
Blue Ocean Energy Management (Blue Ocean) is an energy consulting firm. We develop and
implement energy management strategies for clients who have significant exposure to energy
costs. The main objective of an energy management strategy is to manage energy-related costs and
other risks associated with energy consumption.
The objective of this Energy Conservation Audit and Disclosure (ECAD) report is to benchmark
energy usage, as well as look at specific energy consumption patterns. The assessment for this
report was completed using utility information for 2016 supplied by Austin Travis County Integral
Care, as well as information supplied by Austin Energy. The information has been analyzed using
Blue Ocean Energy’s analytical tools and the Department of Energy’s ENERGY STAR® Portfolio
Manager.
Austin Travis County Integral Care is now in compliance with the City of Austin’s Energy
Conservation Audit and Disclosure ordinance for 6222 N. Lamar, Austin, TX.
As a result of ECAD compliance, 6222 N. Lamar is eligible for the following benefits:
• Austin Energy rebates for qualifying energy efficiency improvement. Without ECAD
compliance, commercial properties are not eligible to receive rebates.
• Avoid Class C misdemeanor for non-compliance of ECAD ordinance.
• Current ECAD rating required for sales/transfers of commercial properties.
Findings:
• The ENERGY STAR remained “100” for 2016.
• Total electricity charges equaled $20,859 in 2016, a 3% decrease versus 2015.
• Electricity unit cost ($/kWh) decreased 4% compared to 2015.
• Demand costs (kW) increased 15% in 2016 versus 2015.
• Peak Demand now represents 38% of electric charges 2013-2016.
• Power Factor charges increased in 2016 totaling $452.
Blue Ocean confirmed that the 2016 Austin Energy charges were calculated correctly and that the
appropriate rate plan was used.
Recommendations and Comments:
The facility scores a perfect “100” again in 2016. This is due to the solar panels installed at the
facility. The rating nonetheless reflects that 6222 N. Lamar is a top-performing building from an
energy efficiency point of view.
The building actually increased energy consumption in 2016 by 1% versus 2015 and Peak Demand
cost increased 15% over the same time period.
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This building may be eligible for the ENERGY STAR distinction based on consecutive years of
ENERGY STAR ratings above “75.” Blue Ocean recommends validation of parameters if this
certification is desired.
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Benchmarking:
Utility Invoice Audit:
As part of Blue Ocean’s ECAD compliance work, all electrical invoices are verified for billing
and rate accuracy. The 2016 Austin Energy invoices are calculated correctly and this account is
now on the new rate plan >10kW <300kW.
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Table of Contents
1. Introduction .......................................................................................... 7
1.1 Authorization ............................................................................................................................................... 7 1.2 Scope of Services ......................................................................................................................................... 7 1.3 Limitations ................................................................................................................................................... 7
2. ECAD Energy Rating and Filing with City of Austin ........................ 8
2.1 Portfolio Manager Statement of Energy Performance: .................................................................................. 9 2.2 Portfolio Manager Energy Performance Explanation: ................................................................................. 10
3. Historical Energy Consumption Analysis ......................................... 11
3.1 Onsite Energy Sources ............................................................................................................................... 11 3.2 Austin Energy Electricity Charges ............................................................................................................. 11
4. Electricity “Demand” (kW) Analysis ................................................. 13
4.1 Austin Energy Demand Charges ................................................................................................................ 13 4.2 Demand Charges ........................................................................................................................................ 14
5. Load Factor .......................................................................................... 15
6. Power Factor ........................................................................................ 16
7. Climatic Variation ............................................................................... 17
8. Electricity Price Forecasting ............................................................... 18
9. Greenhouse Gas Emissions ................................................................. 20
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Glossary of Commonly Used Abbreviations and Terms
1. AE – Austin Energy
2. ASHRAE – American Society of Heating, Refrigerating and Air Conditioning Engineers
3. BOE – Blue Ocean Energy
4. Btu – British Thermal Unit
5. CCF – 100 Cubic Feet
6. CDD – Cooling Degree Day
7. COA – City of Austin
8. Demand Charge – Proportion of monthly AE invoice that is demand charges
9. DOE – U.S. Department of Energy
10. ECAD – Energy Conservation Audit and Disclosure
11. Electricity Cost – Proportion of monthly AE invoice that is electricity charges
12. ERCOT – Electric Reliability Council of Texas
13. EUI – Energy Use Intensity
14. GHG – Greenhouse Gas
15. HDD – Heating Degree Day
16. HVAC – Heating, Ventilation, and Air Conditioning
17. KATT– NOAA designation for the weather station at Camp Mabry
18. kW – Thousand Watts (measure of electrical load)
19. kWh - Thousand Watt Hours
20. LF – Load Factor
21. Monthly AE Invoiced – Total $ of electricity including taxes on AE monthly invoice
22. MW - Megawatt
23. NOAA – National Oceanic and Atmospheric Administration
24. PF – Power Factor
25. PM – Department of Energy’s Energy Star Portfolio Manager
26. PUC – Public Utility Commission of Texas
27. REP – Retail Electric Provider
28. RSF – Rented Square Foot
29. SF – Square Foot
30. TDP – Transmission/Distribution Provider
31. TGS – Texas Gas Service
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1. Introduction
1.1 Authorization
Blue Ocean Energy Management conducted the Energy Conservation Audit and Disclosure
(ECAD) report on behalf of Austin Travis County Integral Care for the facility located at 6222 N.
Lamar, Austin, Texas 78704, in accordance with the contract BOE2017-0112 that was authorized
by Ms. Donna Spencer on January 20, 2017. The facility will from this point forward be referred
to as “6222 N. Lamar.”
1.2 Scope of Services
The ECAD report is a proprietary procedure developed by Blue Ocean Energy for commercial
buildings and facilities. The ECAD report is an assessment of 6222 N. Lamar in terms of an energy
consumption, cost, and Greenhouse Gas emissions point of view. This assessment can be used to
further develop a strategy to manage energy-related risks facing 6222 N. Lamar.
This ECAD report also ensures compliance for 6222 N. Lamar with the City of Austin’s ECAD
Ordinance for the year 2017 (using 2016 utility data). The ECAD ordinance requires this type of
energy rating to be supplied to the City of Austin on a yearly basis.
1.3 Limitations
This ECAD report was conducted in accordance with industry standards; its conclusions are based
on information collected and a review of records and data that were reasonably assessable and
practically reviewable in consideration of constraints of the project schedule and budget.
This report is prepared for the sole use of the Austin Travis County Integral Care and should not
be distributed to or relied upon by third parties without written authorization from Blue Ocean
Energy Management.
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2. ECAD Energy Rating and Filing with City of Austin
In order to comply with the City of Austin’s ECAD ordinance, Blue Ocean utilized the EPA’s
Portfolio Manager to generate the energy rating. The energy rating for 6222 N. Lamar has been
communicated to the City of Austin and is in compliance with the City of Austin’s ECAD
ordinance for the 2017 reporting period, as can be seen below. The ECAD rating was submitted
on April 13, 2017, well in advance of the June 1st, 2017 deadline.
Figure 1: Proof of ECAD Compliance for 2017 Reporting Year
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2.1 Portfolio Manager Statement of Energy Performance:
In Figure 2, below, the ENERGY STAR rating for 2016 can be observed. The building achieved
an ENERGY STAR score of “100,” which indicates that the building performs above average in
terms of energy efficiency.
Figure 2: Portfolio Manager's 2016 Energy Rating
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2.2 Portfolio Manager Energy Performance Explanation:
The City of Austin requires that the ECAD rating be calculated utilizing a 12-month range from
January – December of a given year. The rating has to be calculated yearly and communicated to
the City of Austin. The yearly energy ratings were calculated using the Department of Energy’s
ENERGY STAR Portfolio Manager.
The ENERGY STAR score is a measure of how well a property is performing from an energy
efficiency perspective relative to similar properties, when normalized for climate and operational
parameters.
The ENERGY STAR scores are based on data from national building energy consumption surveys.
This allows Portfolio Manager to control for key variables affecting a building’s energy
performance, including climate, hours of operation, and building size. What this means is that
buildings from around the country, with different operating parameters and subject to different
weather patterns, can be compared side-by-side in order to see how they stack up in terms of energy
performance.
The 1-100 scale is set so that 1 represents the worst performing buildings and 100 represents the
best performing buildings. A score of 50 indicates that a building is performing at the national
median, taking into account its size, location, and operating parameters. A score of 75 indicates
that at a property is performing in the 75th percentile and may be eligible to earn ENERGY STAR
certification.
PM measures the Energy Use Intensity (EUI) per square foot. Intuitively, this can be thought of
as the aggregated energy used per square foot converted to British Thermal Units (Btu)i PM uses
kBtu, which is 1,000 Btu. In addition, PM distinguishes between “Site” and “Source” energy. A
simplified explanation is that “Site” energy is the energy consumed at the “Site” and “Source”
energy represents the total amount of raw fuel that is required to operate the building. It
incorporates all transmission, delivery, and production losses, thereby enabling a complete
assessment of energy efficiency in a building.
Austin Energy states the following regarding the ECAD rating on their website:
The energy evaluation online tool will give you a rating number, a single number between 1 and 100
which indicates the overall energy use of your building compared to similar buildings. Factors such
as weather and operating hours are part of the calculation.
The Austin City Council has set the following voluntary goals to help you interpret your rating:
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3. Historical Energy Consumption Analysis
In most commercial buildings, the second largest operational expense after property taxes is energy
cost. Unlike property taxes, building management can effectively mitigate this operational expense
by running a building as efficiently as possible.
The City of Austin’s ECAD ordinance does not require a detailed analysis of historical energy
usage or cost developments. Blue Ocean includes this analysis as part of our compliance work, as
we deem that the understanding of the energy profile of a building is the first step in operating the
building efficiently and thereby mitigating energy costs.
Blue Ocean believes that you cannot manage what you do not measure.
3.1 Onsite Energy Sources
6222 N. Lamar has one Austin Energy (AE) electricity meter serving the facility, located on-site.
3.2 Austin Energy Electricity Charges
The analysis done in this section is completed utilizing gross energy as invoiced by Austin Energy.
For this report, Blue Ocean Energy utilized electricity data from 2013 - 2016. These 48 months
make up the base period.
As can be observed in Figure 3, below, the trendline for electricity consumption has increased
slightly over time. During the 48 months of data used for this report, 6222 N. Lamar used 707,760
kWh of electricity at a cost of $83,251.
Figure 3: kWh Consumed in 2013 – 2016
In Table 1, below, the base period’s electricity consumption (kWh), costs, demand usage (kW),
and demand cost are summarized.
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Table 1: Energy Consumption (kWh), Demand (kW) Usage and Costs 2013 - 2016
More important, perhaps, than consumption, is the actual cost of the electricity and the breakdown
in cost between kWh and demand charges. 6222 N. Lamar has incurred a total of $83,251 in Austin
Energy charges during the base period. As shown in Figure 4, below, the monthly electricity costs
for 6222 N. Lamar are increasing.
Figure 4: Monthly Cost of Electricity 2013– 2016
During the base period, the average monthly electricity cost was $1,734.
During 2016, Austin Energy had three different rate changes. The table below shows the current
rates and not the rates that were in effect in 2016.
6222 N. Lamar is currently on the Austin Energy fixed rate called “SECONDARY VOLTAGE
>10kW <300 kW.” This rate structure has five major components. The five components, as well
as the current rate, can be observed in Table 2, below.
Table 2: Current Electric Utility rates
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The unit cost ($/kWh) for electricity is a function of the relationship between peak demand (Load
Factor) and energy prices for a particular billing period.
One variable that will change the unit cost is the peak demand (kW) in a particular billing period.
If a particular billing period has an increase in the peak demand but a reduction in kWh
consumption, the kWh unit cost will increase, as there would be fewer kWh to “absorb” the
demand charges.
Figure 5: Unit Cost ($/kWh) in 2013 – 2016
The unit cost (see Figure 5, above) is the total invoice divided by kilowatt hours. The average unit
price for the 48-month base period is $.118 /kWh.
4. Electricity “Demand” (kW) Analysis
4.1 Austin Energy Demand Charges
Austin Energy, like all other utilities in the U.S., charges peak demand (kW) fees. In fact, Austin Energy
has some of the highest peak demand rates in the state of Texas. The reason why Austin Energy has
implemented this rate strategy is to financially incentivize commercial customers to manage their peak
demand.
Demand charges are billed by Austin Energy to its customers based on the numerically largest average
power demand in 1000 Watts (kW) during any 15-minute period within a given billing period. The
following hypothetical example explains the demand charge pricing structure:
• Case 1: Given a 10kW motor and a 15kW motor, if both units were operated for 1 hour at the
same time, the demand meter will record 25 kW for the purposes of calculating the demand
charge. If the two motors were the only two electricity-consuming operations measured by the
account meter, then the demand charge portion of the monthly invoice would be based on 25
kW.
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• Case 2: Given the same 10kW motor and 15kW motor, if the units could be operated
alternately, operating each for 1 hour, but the 15kW only when the 10kW unit is off, then the
kW demand would only be 15kW.
Austin Energy implemented its last rate change in January 2017 and no longer has seasonal charges for
peak demand. Currently Austin Energy is charging $12.44/kW for the rate plan >10kW<300kW.
Calculating cost of the two cases utilizing AE’s rate for peak demand ($12.44/kW) and $0.02421/kWh,
the cost would be as seen in Table 3:
kWh kW Cost
Simultaneously (Case 1) 25 25 $311.00
Alternately (Case 2) 25 15 $186.60 Table 3: Demand Cost Example
This is sometimes referred to as “load shifting.” The key point is that in the example above, the same
amount of kWh was used but a 60% savings was achieved ($311.00/186.60) by simply “shifting”
operations of the units.
4.2 Demand Charges
Over the base period, 6222 N. Lamar had an aggregated total of 2,109 kW in peak demand equaling
charges of $31,313, representing 38% of total electric costs.
Over the 48-month base period, the monthly demand average for 6222 N. Lamar has been 44 kW,
with a corresponding average monthly demand charge of $652. The trendline for demand charges
for the base period is increasing, as can be seen in Figure 6, below.
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Figure 6: Peak Demand (kW) Cost for 2013 – 2016
The split between the demand charge (kW) and electricity charges (the “fuel” and “energy” charges
discussed above) can be seen in Figure 7, below.
Figure 7: Demand and Electricity Charges from 2013 -2016
6222 N. Lamar incurred a total of $51,939 in electricity costs (non-demand charges) from 2013
through 2016. As can be observed in Figure 7, above, $31,313 or 38% of total electricity cost is
attributable to the demand charges over the last two years.
To think of the demand charge another way, a series of 15 minute peaks of electricity each month
over the period have determined 38% of the total electricity cost.
5. Load Factor
Load Factor (LF) is a parameter which compares average consumption of electricity against peak
demand. Load Factor is indexed on a scale from “0 to 1,” with a Load Factor of “1” being the
maximum, as it implies that the consumer’s demand is constanti. The lower the Load Factor the
greater the difference is between average consumption and peak demand. Utilities prefer even or
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constant demand as it is easier to plan for power production and supply. This is why utilities place
a premium on demand charges (kW).
LF = [(Total kWh) / (# Days in Bill Cycle x 24 hrs/day)] x [Peak kW Demand]
A simpler, more intuitive way of looking at Load Factor is to think of it as the relationship between
the average load and the peak load.
If the LF is low, one should look for ways to level the electrical usage (i.e., shift energy intensive
processes to periods of otherwise low usage). By increasing LF, the impact of monthly demand
(kW) charges will be reduced. Peak demand (kW) in a billing period is what Austin Energy
utilizes in its demand charge calculations discussed earlier in this section.
If a Load Factor of “1” is achieved, it does not mean that demand charges will not be incurred or
that a building is operating efficiently from an energy point of view. For example, if all lights and
HVAC systems in a building were left running all the time, a very high LF would be observed.
The theoretical ideal Load Factor is a LF close to “1” with the fewest kWh possible consumed.
Load Factor for the base period can be observed in Figure 8, below.
Figure 8: Load Factor for 6222 N. Lamar 2013 – 2016
Over the 48-month base period, 6222 N. Lamar averaged a Load Factor of 0.45. The Load Factor
for this property is rather low indicating Peak Demand is high.
6. Power Factor
Power Factor (PF) is another measurement of how efficiently electricity is used in a building.
Austin Energy, along with many other utilities, are applying additional utility charges if the PF is
below a certain threshold.
In general, utilities are moving to a pricing structure that intends to financially “punish” clients
with poor or below average Power Factor and Load Factor (demand) measurements. Austin
Energy currently imposes additional charges when the Power Factor is below “.9.”
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If any such power factor charges are incurred, they will appear as a separate line item on the AE
bill (Power Factor Adjustment Below 90%).
Figure 9: Power Factor 2013 – 2016
In Figure 9, above, the PF readings as reported by Austin Energy for 6222 N. Lamar are shown.
This property obtained PF charges in 41 months out of the 48-month base period. Although the
cost was only $1,351 during this time period, PF charges should be monitored moving forward to
ensure that total electricity costs are minimized.
7. Climatic Variation
The climate plays a significant role in the consumption of electricity in buildings, especially
heating, ventilating, and air conditioning (HVAC). The weather-related impacts on energy
consumption make it difficult to evaluate energy efficiencies. However, one method for
normalizing for temperature variations is the use of published degree days.
Degree days are either Heating Degree Days [HDD] or Cooling Degree Days [CDD]ii. When
rationing kWh of energy used by the number of degree days for a period, the impact of temperature
variation on energy consumption is normalized so that a truer picture of energy efficiency can be
visualized.
As can be seen in Figure 10, below, the proportions of HDDs to CDDs vary significantly from
year to year. In general, during the past 16 years, there has been an upward trend in CDDs, whereas
HDDs have remained flat.
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Figure 10: Degree days, 2001 - 2016
Specifically, for 2016, it can be stated that it was a fairly typical climatic year from a CDD point
of view, whereas the very mild winter of 2016 meant fewer HDDs. The implication of the 2016
degree days is that all commercial buildings using strip heat should have seen reductions in energy
consumed (kWh) and cost.
In the benchmarking table, we offer a simplified climatic normalization by converting kWh/degree
day.
8. Electricity Price Forecasting
In a regulated market like Austin, customers do not have the option to contract with competitive
energy suppliers or use different types of priced energy contracts. Austin Energy is the only choice
for electricity.
Based on criticism from commercial and industrial customers, Austin Energy has initiated a new
rate structure. In the fall of 2016, Austin Energy announced new rate structures for residential,
commercial and industrial customers. The various rate and rate class changes were implemented
in Q4 of 2016, resulting in most commercial customers in Austin experiencing a slight decrease in
energy costs.
Historically, Austin Energy has imposed high demand (kW) charges, which often make up 40%
to 50% of commercial customers’ bills. Paradoxically, some of our customers have reduced
electricity consumption (kWh) significantly, only to see their electricity “all-in unit” ($/kWh)
increase due to peak demand (kW) remaining the same. We anticipate similar confounding factors
to be part of future rate plans, leading to increasing energy costs for customers who do not
strategically manage the components of their electricity bills such as peak demand, power factor
and load factor.
In 2016, natural gas prices have increased slightly from historic lows. As the percent of electricity
generation that comes from natural gas is increasing, natural gas impact on fuel charges are also
increasing. In spite of the slightly increasing natural gas prices in 2016, AE twice reduced the fuel
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charges. It is our anticipation that later in 2017, AE will be forced to increase the fuel charges
again.
As a result of these multiple factors, each affecting future electricity costs in different ways, Blue
Ocean assumes a modest 2% per year increase in electricity costs, as well as a less likely aggressive
3.5% annual increase in electricity costs for our price forecasting exercise.
If we model current electricity costs for this facility over the next decade, assuming a constant
occupancy rate and no energy efficiency improvements, the following forecast can be observed:
Figure 11: 6222 N. Lamar Yearly Projected Cost of Electricity Only
If we assume this price increase to occur evenly over the next 10 years, we can calculate the
additional cost for 6222 N. Lamar over the period using 2016 as the reference year and the $20,859
paid for electricity in 2016 as the base cost. The cost for electricity would reach $25,428 /year by
2026 in the best-case scenario and $29,424 /year in the worst scenario.
This corresponds to an additional $24,379 to $44,681 in cumulative projected electricity costs over
the 10-year period attributable to the price increase as can been seen in Figure 12, below.
Figure 12: Projected Cumulative Increase in Energy Costs
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9. Greenhouse Gas Emissions
Portfolio Manager produces a defensible Greenhouse Gas (GHG) number. The methodology
employed is used by all GHG registers and is a standard that is sanctioned by the federal
government. The GHG calculated in the table below is considering the actual energy consumption
of this particular building and the electricity generation fuel mix of Austin Energy.
GHG can be viewed as a measurement of waste. If GHG emissions are reduced, holding all other
parameters constant, it will mean a more efficient utilization of energy and lower energy cost.
Table 4: GHG Emission Table from Portfolio Manager
As can be seen in Table 4, above, the total Greenhouse Gas (GHG) emissions for 2016 was 94.7
Metric Tons of Carbon Dioxide equivalent (MT CO2e).
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Footnotes
i A Btu is defined as amount of heat required to raise the temperature of one 1 pound (0.454 kg) of liquid water by 1 °F (0.556 °C)
at a constant pressure of one atmosphere. As is the case with the calorie, several different definitions of the Btu exist, which are
based on different water temperatures and therefore vary by up to 0.5%: A Btu can be approximated as the heat produced by burning
a single wooden match[2] or as the amount of energy it would take to lift a one-pound weight to a height of 778 feet (237 m)
ii Heating degree days,” or “HDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was lower than a specific “base temperature” (or “balance point”). They are used for calculations relating to the energy consumption
required to heat buildings.
“Cooling degree days,” or “CDD,” are a measure of how much (in degrees), and for how long (in days), outside air temperature
was higher than a specific base temperature. They are used for calculations relating to the energy consumption required to cool
buildings.
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Page 1 of 2
DATA REQUEST RESPONSE RECEIPT
Data Request Name: Data Request:Austin ECAD Commercial Report 2017
Response sent: 04/01/2017 03:45 PM EDT
Response includes: 1 property
Response sent to: ECAD Commercial Report 2017City of Austin811 Barton Springs RoadSuite 300Austin, TX 78704
Response sent by: Bo PetersenBlue Ocean Energy2313 Lake Austin Blvd.Suite 108Austin, TX 78703
I __________________ (print name) verify that the properties enumerated below were submitted on the abovedate to this data request.
Signature: ___________________________________________ Date: _________________________
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Page 2 of 2
Properties included in this Response (1)*
PortfolioManagerProperty ID
Property Name & Address Other Property IDs
5835175 1165 Airport1165 Airport Blvd.Austin Texas 78702
TCAD: 198924_001Austin Property ID: 198924
*Note: ECAD Commercial Report 2017 will only receive a single record for each property. If a property listedon this receipt was also included in another response, then ECAD Commercial Report 2017 will only see the dataassociated with the last (i.e. most current) response sent. That is, if another person submits data on these propertiesat a later data, your record will be over-written.
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Page 1 of 2
DATA REQUEST RESPONSE RECEIPT
Data Request Name: Data Request:Austin ECAD Commercial Report 2017
Response sent: 04/01/2017 03:10 PM EDT
Response includes: 1 property
Response sent to: ECAD Commercial Report 2017City of Austin811 Barton Springs RoadSuite 300Austin, TX 78704
Response sent by: Bo PetersenBlue Ocean Energy2313 Lake Austin Blvd.Suite 108Austin, TX 78703
I __________________ (print name) verify that the properties enumerated below were submitted on the abovedate to this data request.
Signature: ___________________________________________ Date: _________________________
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Page 2 of 2
Properties included in this Response (1)*
PortfolioManagerProperty ID
Property Name & Address Other Property IDs
4096868 1430 Collier1430 CollierAustin Texas 78704
TCAD: 100321_001Austin Property ID: 100321
*Note: ECAD Commercial Report 2017 will only receive a single record for each property. If a property listedon this receipt was also included in another response, then ECAD Commercial Report 2017 will only see the dataassociated with the last (i.e. most current) response sent. That is, if another person submits data on these propertiesat a later data, your record will be over-written.
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Page 1 of 2
DATA REQUEST RESPONSE RECEIPT
Data Request Name: Data Request:Austin ECAD Commercial Report 2017
Response sent: 04/01/2017 03:26 PM EDT
Response includes: 1 property
Response sent to: ECAD Commercial Report 2017City of Austin811 Barton Springs RoadSuite 300Austin, TX 78704
Response sent by: Bo PetersenBlue Ocean Energy2313 Lake Austin Blvd.Suite 108Austin, TX 78703
I __________________ (print name) verify that the properties enumerated below were submitted on the abovedate to this data request.
Signature: ___________________________________________ Date: _________________________
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Page 2 of 2
Properties included in this Response (1)*
PortfolioManagerProperty ID
Property Name & Address Other Property IDs
4094890 5225 N. Lamar5225 N. LamarAustin Texas 78734
TCAD: 223217_001Austin Property ID: 223217
*Note: ECAD Commercial Report 2017 will only receive a single record for each property. If a property listedon this receipt was also included in another response, then ECAD Commercial Report 2017 will only see the dataassociated with the last (i.e. most current) response sent. That is, if another person submits data on these propertiesat a later data, your record will be over-written.
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Page 1 of 2
DATA REQUEST RESPONSE RECEIPT
Data Request Name: Data Request:Austin ECAD Commercial Report 2017
Response sent: 04/13/2017 01:21 PM EDT
Response includes: 1 property
Response sent to: ECAD Commercial Report 2017City of Austin811 Barton Springs RoadSuite 300Austin, TX 78704
Response sent by: Bo PetersenBlue Ocean Energy2313 Lake Austin Blvd.Suite 108Austin, TX 78703
I __________________ (print name) verify that the properties enumerated below were submitted on the abovedate to this data request.
Signature: ___________________________________________ Date: _________________________
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Page 2 of 2
Properties included in this Response (1)*
PortfolioManagerProperty ID
Property Name & Address Other Property IDs
4097234 6222 N. Lamar6222 N. LamarAustin Texas 78752
TCAD: 230016_001Austin Property ID: 230016
*Note: ECAD Commercial Report 2017 will only receive a single record for each property. If a property listedon this receipt was also included in another response, then ECAD Commercial Report 2017 will only see the dataassociated with the last (i.e. most current) response sent. That is, if another person submits data on these propertiesat a later data, your record will be over-written.
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VII. Announcements
Handout Pg. 139
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VIII. New Business
• Identify Consent/Non-Consent Agenda Items
Consent: Item III
Non-Consent: Item IV
Handout Pg. 140
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IX. Citizens’ Comments
Handout Pg. 141
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