Backup Documents 05/26/2009 Item #16C 4
ORIGINAL DOCUMENTS CHECKLIST & ROUTIN(j~e 4
TO ACCOMPANY ALL ORIGINAL DOCUMENTS SENT 'fO
THE BOARD OF COUNTY COMMISSIONERS OFFICE FOR SIGNATURE
Print on pink paper. Attach to original document. Original dowments should be hand delivered to the Board Office. The completed routing slip and original
documents are to be forwarded to the Board Office only after the Board has taken action on the item.)
ROUTING SLIP
Complete routing lines # I through #4 as appropriate for additional signatures, dates, and/or infonnation needed, If the document is already complete with the
exceDtion of the Chainnan's signature, draw a line through routing lines #1 through #4, comDlete the checklist, and forward to Sue Filson (line #5).
Route to Addressee(s) Office Initials Date
(List in routing order)
1. Tony Russo PUPPMD 111 '1U/o1'
2.
3.
4.
5. Sue Filson, Executive Manager Board of County Commissioners
6. Minutes and Records Clerk of Court's Office
PRIMARY CONTACT INFORMATION
(The primary contact is the holder of the original document pending BCC approval. Normally the primary contact is the person who created/prepared the executive
summary. Primary contact infonnation is needed in the event one of the addressees above, including Sue Filson, need to contact staff for additional or missing
infonnation. All original documents needing the BCe Chainnan's signature are to be delivered to the Bee otlice only after the Bee has acted to approve the
item.)
Name of Primary Staff Peter Schalt, Senior Project Manager - Phone Number 239-252-5343
Contact Public Utilities Division
Agenda Date Item was May 26, 2009 Agenda Item Number 16 C4
Approved by the BCC
Type of Document Work Order Number of Original I
Attached Documents Attached
1.
INSTRUCTIONS & CHECKLIST
Initial the Yes column or mark 'IN/A" in the Not Applicable column, whichever is
a ro riate.
Original docwnent has been signed/initialed for legal sufficiency. (All documents to be
signed by the Chairman, with the exception of most letters, must be reviewed and signed
by the Office of the County Attorney. This includes signature pages from ordinances,
resolutions, etc, signed by the County Attorney's Office and signature pages from
contracts, agreements, etc. that have been fully executed by all parties except the BCC
Chairman and Clerk to the Board and ossibl State Officials.)
All handwritten strike-through and revisions have been initialed by the County Attorney's
Office and all other arties exce t the BCC Chairman and the Clerk to the Board
The Chairman's signature line date has been entered as the date ofBCC approval of the
document or the final ne otiated contract date whichever is a Iicable.
"Sign here" tabs are placed on the appropriate pages indicating where the Chainnan's
si nature and initials are re uired.
In most cases (some contracts are an exception), the original document and this routing slip
should be provided to Sue Filson in the BCC office within 24 hours of Bee approval.
Some documents are time sensitive and require forwarding to Tallahassee within a certain
time frame or the BCC's actions are nullified, Be aware of our deadlines!
The document was approved by the BCC on May 26, 2009 (enter date) and all
changes made during the meeting have been incorporated in the attached document.
The Count Attorne 's Office has reviewed the chan es, if a Iicable.
Yes
(Initial)
N/A (Not
A licable)
2.
3.
4.
5.
6.
ps
fs
f'S
pS
{'S-
f$:
I: Fonns/ County Fonns/ Bee Fonns/ Original Documents Routing Slip WWS Original 9.03.04, Revised 1.2605, Revised 2.24.05
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MEMORANDUM
Date: May 29, 2009
To: Peter Schalt, PMP, Project Manager
Public Utilities Engineering Department
From: Teresa Polaski, Deputy Clerk
Minutes & Records Department
Re: Work Order for Contract #06-8337
Agreement for Annual Contract for Well
Drilling & Maintenance
Enclosed please find one (1) copy of the document as
referenced above (Agenda Item #16C4), approved by the
Board of County Commissioners on Tuesday, May 26,
2009.
The original document is being kept at the Minutes &
Records Department as part of the Board's Official Record.
If you should have any questions, please contact me at 252-
8411.
Thank you.
Enclosures
WORK ORDER
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Agreement 1'01' Annual Contract fu;' Well Driilillg So; rYlaiuleuancc
Dilled Ajl!'il ; 1,2006 (Coatl"llet #{)6-3S!5i)
This Work Order is for prol'cssional services lor \HHK k:10\\ n a,<
(Title): NCRWTP OeeD Iniection Well Injection No.2 Tllbilll! l{clllaccmcu1
(Reason for Proicct): To restore compliance. rcliabilHv, and sustuinabilitv to the NCW:,', TV.
The \York is specified in the proposal datl;)d May 18, 2009 \\heh is attached hercto and ::c~.. '"
of this \Vork Order. In <lCCOrduilco,;; '.vit.h the Tl'.rms ;,1)jdCond :iJ.'<l:} uC ']e /\grl.:.;cmC!ll rC'r~r'..."',:;,,'d ~; ;.;
this Work Order is assiglCd to Youllgquis, l3rutl:e:'s. 1I:e.
Scope of Wo,'k:
Task under Category N,). 4 -- Professional services t.) repair \C 1< INTi' DiW NO.2 with r~ :lce ~
FRP tubillg~ J'vIlT testing. and updated O&M l!lanu~:ls ai] to :-intisf) FD~:P pcnnil conditions
Schedule of Wo.-J;.: Complele work \,Iilhin 90 uavs L'o:1' r,,:ccl[l or ,he: NOli<.:c :,'
authorizing start of \Ycrk.
l.. '_ 0.;. \.;"
COlllpensation: In ac<.:ordancc with ArtiCle Five or lhc Agrcement. ,ill' Coullty wiil <.:Gmp:n,,:(c
Finn in accl)rdance \'-vith thl;,;. negotiated IUlnp stun <l111011n1 indicated l1 :hc ::-;chcduJL: be 'x..t...lL!li.L
412-273512-763100
Task: TOla! Lump Sun; Amount or $9~O.()OO
Any change within monclary authority or
appro va! wii; be cO:1Sidcred ,dl additiona
Agreement.
this w"ork ()rd~r n:21u:..' sL;b,sl,;ljuellt lO rin~:l
sc:"yice ~l:ld Chtrgcl. ~:cc~~;.llillg to SGh~du!J
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PREPARED BY: _~~blCi{+-_____
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Signature
S i g :1...:~; ;-c
?ri [j t Name
Prinl Name
~&~.i?~I. t
...., CoaDt)' AU.....)'
Youngquist Brothers, Inc.
15465 I>ine Ridge Rond
Fort M)'crs, Florida 33908
(239)-489-4444
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Peter Schalt, PMP
Senior Project Manager
Collier County Public Utlities Division
Planning and Project Management Dcpt.
3301 Tamiami Trail East
Bldg H, 3rd Floor
Naples, Florida 34112
May 18, 2009
Re: Collier NCR WTF, Deep Injection Well No.2, Liner Replacement Proposal
Dear Mr. Schalt,
We are providing this proposal as requested. It is based on the scope of work and
services delineated in the April 7, 2006, FDEP Permit Modification Application, (copy
attached). Youngquist Brothers, Inc., ("YBI") will provide all labor, equipment and
materials necessary to perform the referenced tasks for stipulated price / lump sum
amount of$980,000.00. This proposal is based on the conditions outlined below.
Conditions:
1. 10 days notice to mobilize equipment.
2. 90 contract days to perform tasks.
3. The FRP is eunently in stock in Houston TX, it is subjected to prior sale, if sold we
will need an additional 45 contract days to have it manufactured and shipped.
4. YBI can not guarantee the current condition of this injection well.
5. This proposal is based on completing the tasks outlined in the FDEP pennit
modification application; YBI cannot guarantee that all possible items are included
nor can we accept responsibility/liability for unforeseen and pre-existing conditions
the injection well resulting from pelfomling these tasks, we will merely perfOlm the
tasks requested.
Please call if you have any questions or need any additional information.
Respectfully,
;"~--1Jt[~~
Edward McCullers,
V ice President
Attachment:
Florida Contractors Licenses
Well Drilling 2172 & 1509,
CILB - CGCA54031, CFC057 1 63, CMC057 164, CUCA35775, EILB - EC0002556
Underground Fire, Class V # 45835300011999
~~llllCfi()QlIn gqu istbrpthers. com
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AP}')LICA'I'ION FOR WELL MODIFfCA TION
INJECTION WELL IW-2
COLLIER COUNTY NORTH COUNTY REGIONAL WATER TREATMENT PI,ANT
PERMIT 50581-311-UQ
This report provides information requested in Part I. Directions, Part II, General Information,
and under Engineering and Hydrologic Data Required for Support of Application AC. Class I
Well Operation Repermitling of the Florida Department of Environmental Protection
Application to Construct/Operate/ Abandon Class I, III, or V Injection Well Systems.
Part I. Directions, E.
Part of the 7.5 minute U.s. Geological Survey topographic map of the North County Regional
Water Treatment Plant (NCRWTP; Belle t'v1eade NW and Corkscrew SW quadrangles) is
provided as Figure 1. Injection wells IW-1 and IW-2 and the dual-zone monitor well are
located in the SW 1/4 of the SE '1/4 of Section 35, Township 48 SOlI th, Range 26 East. The
approximate latitude and longitude of injection welllW-2 is 2601t1"12" North, 81040'41" West.
Part II. Genernllnformation, Subpart B. GcncrallJrojcct Dcscription
Injection well lW-2 was consh'ucted between November 1995 and April 1996 to provide 100
percent redundant capacity for injection well IW-I, \vhich \vas completed in March 1993.
Injection well IW-2 has a permitted capacity of 6.3 million gallons per day (Mgd) of liquid
waste. The original waste flow disposed of in the injection well system was reject concentrate
'.vater from a m.embrane softening facility, The NCRWTP has subsequently been expanded to
include a reverse osmosis desalination facility. I~eject concentrate from the reverse osmosis
desalination facility is also disposed of in injection \.vclIs lW-1 and IW-2. Excess reclaimed water
from the North County Water Reclamation Facility (NCWRF) was also formerly disposed of in
the NCRWT'P injection well system. With [he construction of the NCWRF injection system, the
pipeline between the NCWRF and NCRW'fP has been disconnected.
The 16-inch diameter steel injection tubing in well IW-2 developed a leak and was replaced with
another steel injection tubing in 2002, Injection well lW -2 passed a mechanical integrity test in
February 2006. Although the injection well IW-2 tubing still has mechanical integrity, Collier
County seeks to permit the replacement of the injection tubing now, so that the replacement
could be performed expeditiously should a leak develop in the tubing in the future. The
replacement tubing will be a 15.8-inch diameter, 0.66-inch thick wall Red Box 1250 fiberglass,
as manufactured by Future Pipe Industries, or an approved equivalent. The annulus between the
injection casing and fiberglass injection tubing will be cemented.
>>FlIns\TOl"PfojtctsTo!litrCiJUllly\ Injection Wcns\~CR.WTP\JW-2\2.r\CRWTl) JW.2 Tubing RcpJ,'\J:cmcnt',.\TRWIlJ J\\'-2 ~hjor Mod ApJllicalicmdoc
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H. General Project Description
Proiect Swnmary
The project involves the replacement urthe injection tubing in the Collier County NCRWTP
injection well IW-2. The entire 16-inch diameter, steel injection tubing will be removed and
replaced v,rith a 15.S-inch diameter fiberglass tubing. The replacement process calls for reuse
of the existing YBI positive seal packer to support the fiberglass injection tubing during
cementing. A schematic diagram showing the existing well construction ancl proposed
altemate design is provided in Figure 2 and a diagram of the proposed annulus cement
packer assembly is provided in Figure 3. The annulus will be pressure grouted from the
bottom of the annulus upward in a single stage.
In the event that the existing Yl3I packer is unusable, the annulus will be cemented while the
fiberglass casing is hung from tbe top of the well surface.
Proiect Work Outline
The project shall consist of the following work elements:
1. Install foUt' (4) shallow pad monitor wells SPW-l tlU'ough SPW-4 adjacent to il~ection
well IW-2. Conduct background water quality sampling of shallow pad wells. Water
quality sampling will be conducted on a weekly basis until the well modification work is
completed. Sampling shall include specific conductance, pH, cbloride concentration,
temperature and water level.
2. Install containment wall around the well pad, and all equipment necessary to maintain a
zero discharge operation at all stages of the project.
3. Mobilize equipment to the project site and set-up the drill rig over tbe wellhead,
including all necessary dismantling of existing vvellhead and associated
piping/instrumentation equipment.
4. Remove the existing 16-incb diameter steel injection tubing. Haul tubing offsite to a
scrap dealer.
5, Perform video survey from land surt~lce to approximately 25 feet below the base 01'20-
inch diameter injection casing. Perform side-view inspection of YBI packer area.
6. Conduct pressure testing on 20-inch diameter injection casing.
7. Install1iberglass injection tubing to the approximate depth of 2,460 feet below land
surface. If still usable, the existing male YBI packer element will be welded to an
approximately 15 it piece of stccl tubing, which will be attached to the bottom of the
fiberglass casing with a threaded coupling, as shown in Figure 3. The tubing shall be
new, filament-wound fiberglass tubing, such as Red Box l250 I1berglass as manufactured
by the by Future Pipe Industries, or approved equivalent. Dimensional specifications and
2
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performance ratings of the tubing are included in the Appendix C oftbe Alternate Design
Report.
8, Conduct a video survcy of 15.8-incb diameter FRP tubing tl'om land surface to
approximately 25 feet below the base oftbe 20-ineh diameter casing set at 2,492 feet
(approximately 2,5 I 7 feet below land surl~lce).
9, Install bridge plug at approximately 2,460 feet bls (base of the injection tubing) using
cement basket. Cement in low volume stages to obtain bridge plug length of at least 10
feet. Allow bridge plug cement to set up a minimum of 36 hours before pressure
grouting FRP tubing.
10. Cement annulus between 20-inch diameter injection casing and 15.8-inch FRP injection
tubing to land surface. The cement stage shall be pressure grouted and emplaced in one
stage of cementing operations. A temperature log shall be run after cementing. A
blowout pre venter or other method shall be employed to prevent the well from t10wing
during cementing operations. The cement may have up to 12% bentonite gel. Any other
additives, such as cement dispersants, must be approved by the ENGINEER and FDEP
prior to cementing.
11. Allow cement to cure for at least 24-hours.
12, Perforn1 cement bond log.
13. Perf 01111 pressure test on 16-inehFRP tubing.
14, Trip in hole and drill out cement and bridge plug, and continue drilling to below base of
injection casing at 2,498 feet bls.
15. Reinstall wellhead (modified as necessary to incorporate the new tubing), associated
piping, and instrumentation.
16, Perfol1n video survey frol11 land surface to the base of the injection casing, after a
sufficient volume of clear water has been pumped down the \vell to allow acceptable well
video visibility conditions.
17. Return well to service.
18. Conduct final sampling of perimeter pad wells pending approval of FDEP staff.
19. Demobilize equipment ii'om site.
J
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A. CLASS I WELL OPERATION IU~PERMrl'TING
1. An updated map showing the location of the injection wells or wellticld area for
which a permit is sought and the applicablc arca of I'cview. Within the area of
review, the mup must show the number or names, and locations of all producing
wells, injection wells, abandoned wells, dry holes, surface bodies of water, springs,
public water systems, mines (surface and subsurface), quarries, water wells and
other pertinent features including rcsidcnces and roads. The map should show
faults, if lmown or suspected. Only information 01' public record and pertinent
information known to the apll]icllnt is required to be included on this map.
The historic ammal injected volumes in NCRWTP injection wells IW-l and IW-2 are
compiled in Table 1.
Table l:.BIi!~iic-A~~~J}l1i~cted VOIUlll~S (MG) ~t the NCRWTP
Iniection WellIW-l Iniection Well IW-2
Year Reclaimed Reclaimed
Concentrate Water Total Concentrate Water Total Total
...--...-- --...-.....--............... --.....
1993 3,689 0 3.689 0 0 0 3.689
-
1994 213.548 0 213.548 0 0 0 213.548
........-.-,.-- -.-----. -.--....---........-...--.-....-.....
1995 239.989 0 239.989 0 0 0 239.989
........ ..-.--
1996 170.141 0 170.141 177.337 0 170.141 340,282
.-..----.,--" ......._.._--_..~- -..
1997 56.098 0 56.098 248.965 0 248.965 305.063
-....-..----.. ..-...-.....----
1998 273.279 0 273.279 590.901 0 590.901 864.18
- --.-..
]999 330.261 0 330.261 328.cJ7] 0 328.071 658.332
.-
2000 286.163 0.000 286.163 523.258 2,066 525.324 811.487
.-"'.'-.-.'-.'-
2001 186.240 1.301 187.541 674.819 56.680 731.499 919.040
.-.....-.....-.....-........... --..-. --..
2002 486.261 62.571 548.832 478.750 220.062 698.812 1247.644
....".......-..-..---.
2003 1233.278 n.oon 1233.278 6.4t19 443.373 449.822 1683.100
.......--
2004 580.c131 0.000 580.031 484.853 '109.847 594.700 1174.731
. _. -.-....-- .----------.----...----....-.-. ..........
2005 379.308 0.000 379.308 511.547 0.000 511.547 890.855
.. ..."......--.... ---._--
Total 4438.286 63.872 4502,158 4024.950 832.028 4849.782 9351,940
......,,---.--.. -_.._^
The total historic injected volume in the NCRWTP injection well system is 9,352 MG
tlu-ough December 2005. The only anticipated expansion of the NCRWTP is the
addition of a high-pressure reverse osmosis (RO) skid, which at its design capacity
would generate 1 MGD of concentrate. The high-pressure RO system would be used
only to meet peaks in demand as it will be the most expensive water to produce, Future
annual injection well disposnl volumes will likely be comparable to current levels.
The projected future disposal volume, for the purpose of the determining the area of
review, is estimated as 11 times the maximum historic annual concentrate disposal
volume (1,240 in 2003) or 13,640 MG, which include the requested and next 5 year
operation period and an additional 1 year safely factor. The total historic and projected
4
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future injection vohllnc is 22,992 Me.
The thickness of the injectate-invaded zone in \.vell lW-1 and lW-2 is over 600 feet thick,
as documented in the completion reports for the injection wells. However, for the
purpose of establishing a conservative area of review, a 200 ft injection zone thickness
and a porosity of 20% are used, Using a cylindrical flow assumption, the "zone of
endangering influence" radius (1~) is calculated as follows using the above discussed
injected volume, injection zone thickness and porosity:
R2 = ((22,992 X 106 gal * 0.13,1 fP/ gal)/ (200 ft * 0.20 (I) * 3.14))
R2 = 24,529,680 ft2
R == 4,953 it or 0.94 miles
The l-m.ile radius area of review is thus appropriate for thl' NCRWTP injection well
system, as the calculations include m.any vcry conservative assumptions.
Detailed area of review studies for a one-mile radius area were submitted to the
Department with the well lW-1 and lW-2 construction permit, operation permit, and
operation permit renewal applications. The one-mile radius area is shown on a
topographic map in Figure 1. The \-vell inventories \.vere conducted using data from the
Collier County Pollution Control Division, Florida Geological Survey (oil and gas and
geologic investigations sections), U.s. Geological Survey, and the South Florida ~Water
Management District. The locations of all known intermediate and Floridan aquifer
system wells are shown on Figure 4. Available details on the intermediate and Floridan
aquifer system wells within the area of review arc provided in Table 2.
Over 200 Tamiami aquifer wells (total depths mostly < 110 ft) for residential and/ or
irrigation use have been installed in the area of review since the original area of review
investigation in 1991 for injection well lW-1. A listing of all post-1991 wells in the area
of review in the Collier County Pollution Control Division (CCPCD) database is
provided in Appendix A. All wells completed from 1991 to present would have had to
have been permitted through Collier County, so the CCPCD database includes all wells
present in the databases of other agencies.
The project site area has undergone extensive residential development since injection
well 1W-1 was constructed. Golf course lakes have been excavated on the adjoining
property to the north. These recently excavated lakes do not yet appear on local maps.
Review of the literature indicates that there arc no known faults in the area of review.
5
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--- __.__"____......_.___~_...____.. .n .._----
Table 2: Flol'ida~~_aquifer ~~_lls within area o(review
- ......_.
Map Owner Well type Final Cased Total Date
No. casing depth depth completed
u_ dia.(in.) (feet bIs) (feet bls)
.............- ----------- --
IW-l Collier Co. Injection 20 2497 3330 3/93
---- .._.,,-,.... - -- -------- ---- --
IW-2 Collier Co. Ini~ction 20 2498 3200 3/9.?_
---
DZMW-l Collier Co. Tvlonitor 65/8 1815 19"30 10/92
--------- ------------ .----- ...... n .__._____
5000 Collier Co_ Test 6 390 1201 * II / 94
---- ^--~-- --- --- -
5003 Collier Co. Tpst 12 398 5~~ :I_2/94
...____n ...__..--.-.~ ---.
5005 Collier Co. Test 6 700 808 1/95
..-..~-_.- --~-_._-- ___..u.....
5007 Collier Co. Test 4 700 815 3/95
__n .- .. -....-.... ...-.. ----..-.--... ----------- -."'.-"....-.-.-- ,.--.--
5025 Collier Co. Production 12 705 801 10/98
.-----.------ ..-.----."..".. -
5026 Collier Co. Production 12 734 780 6/98
m""'" ._-_.__._,~ u...n_..."
5027 Collier Co. Production 12 720 800 7/.92_
---"" ........->> -
5028 Collier Co. Production 12 744 891 6/98
....-..----...-.....-...- ....----......... ."...... ._.-
5029 Collier Co. Production 12 790 "1070 6/98
.-..- "....._...._,."~-.~,-
5030 Collier Co. Production 12 740 975 7/98
.-- -_.._._..,~------'" --.--...
CC-27007 Collier Co. Test - - 397 11 /2004
--- ---......
CC-27008 Collier Co. Test - - 498 12/2004
-- ..-... '"
Note: * well was backfilled with cement to 828 feet below land surface
2. A tabulation of data on all wells within the area of review which penetrate into the
injection zone, confining zone, and monitoring zone. Such data shall include a
description of each well type, consh'uction, date drilled, location, depth, record of
plugging and/or completion, and any additional information the Department may
require.
Information on the locations and construction of intermediate and FlOl'idan aquifer system
wells in the area of review is provided in Table 2. The constrllction of all of the "veIls listed
in Table 2 was supervised by CDM Missimer (then Missimer International) persOlmeI, with
the exception of NCRWTP IW-1 and DZl'vlW-1, whose construction was supervised by
ViroGroup, Inc, and test wells CC-27007 and CC-27008. Only two wells have been
constmeted (other than injection wells IW-1 and lW-2) that peneh'ated as deep as the upper
monitor zone of the dual zone monitor well, which is open between 900 and 995 ft bls. A 6.
inch diameter test well (MC-5000) ,vas drilled to a total depth 1201 ft bls. Well MC-SOOO was
subsequently backfilled with cement to 828 ft bls. A production well (MC-5029; RO-5) for
the NCRWTP reverse osmosis water treatment facility was drilled to a total depth of 1070
feet in May 1998. The open hole interval of well MC-5029 is 790 to 1070 ft bls. Well MC-5029
is still in use.
3. Maps and cross sections indicating the general vertical and lateral limits within the area
of review of all underground sources of drinking water, their position relative to the
injection formation and the direction of water movement, where known, in each
underground source of drinking water which may be affected by the injection.
6
1:!(OU{Cfcounfy/h*,tion \\'e1lslJH:r\\'I~l-j~\'l OI}Na.tion ~wnllit/nuwtp 1\\'-1 O~'l(>{.\liOIl pNl\lit tt'\t.\I4.-X
16C4
Detailed information 011 hydrogeology of the NCRWTP an~a ,.vas provided to the
Department in the completion reports for injection well IVY-I (submitted by ViroGroup, Inc.
in August 1993) and injection well IW..2 (submitted by Missimer International, Inc. in
August 1996). The base of the USDW is located at approximately 1190 feet bls at the
NCRWTP. The bottom of the well lW-1 and IW-2 injection casings are located at 2497 and
2498 ft bls, respectively. WaleI' quality information obtained during the drilling of injection
well IW-2 indicates that the top of the injectate invaded zone from ,.veIl IW-1 is located at
approximately 2406 ft bls. The base of the USDW was thus located approximately 1214 ft
above the injectate invaded (injection) zone.
A regional north-south hydrogeologic cross section was prepared from data in the injection
well completion reports. ,!'he locations of the injection wells and line of the cross-section are
shown on Figure 5 and the cross-section is included in Figure 6. The USDW is located above
the injection zone and a confining zone is present between the base of the USDvV and the top
of the injection zone throughout the iHea of review.
As shovm in Figure 6, there is an overall regional trend for the base of the USDW to occur at
progressively shallower deptiu) from nortil to south in western Lee and Collier Counties. In
the general vicinity of the NCRWTP, the base of the USDW appears to be relatively flat. The
base of the USDW occurs at approximately 1190 at the NCRWTP and at 1,198-1,231 ft bls
approximately 5.5 miles to the south at the CoIIier SCHWTP injection well I\'V-1. I;Ul'ther
south, the base of the USDW occurs at approximately 969 ft bls at the Collier SCWRF, which
is located approximately 12 miles from the NCRWTP.
The nearest injection well site to the east for which the base of the USDW has been located is
the Immokalee injection \velI, 'which is located approximately 19 miles norti1east of the
NCRWTP. The Immokalee injection well was completed in March 2002. According to
information contained in the injection well completion report, prepared by CH2M Hill, the
base of the USDW at the Immokalee injection well site is located at approximately 1,960 ft
bls, which is approximately 770 feet deeper than at the NCRWTP. The average gradient of
the base of the USDW between the Immokalee injection well site and the NCRWTP is
approximately 40.5 feet pel' mile (770 feet/ 19 miles). The top of the injection zone was
located at approximately 2,404 ft bls in NCRWTP injection well IW-2. Thus the base of ti,e
USDW does not intersect tile injection zone at least as far east as Immokalee.
The regional groundwater flow direction in the USDW aquifers in the NCI{W'rp vicinity is
to the southwest, toward tile Gulf of Mexico.
4. Maps and cross sections detailing the hydrology and geologic structures of the local area,
See response to item 5.
5. Generalized maps and CI'OS5 sections illustrating the regional geologic setting.
The available information on local and regional hydrology and geology was summarized in
tile injection well lW-1 and lW-2 completion reports and is summarized. in Figure 6. The
hydrogeology of the deep \.vell disposal at the NCRWTP site and southwest Florida in
7
Z:/l'olli('rt:oun1y/injectiul\ \\'vlls/nuwtp.iwl operdlion permltjnl"n\'tp 1\\'-1 OJwroltion permit lc:....t.doc
16C4
general was discussed in a paper in Hydrogeology Joul'llal (tvlaliva and Walker, 1988), which
was previously submitted to the Department.
6. Contingency plans to cope with all shut-ins or well failures, so as to protect the quality of
waters of the State as defined in Rule 62-3 and 62~520, F.A.C., including alternate or
emergency discharge provisions.
If injection well rW-2 could not be used because of either planned shut-ins or well failure,
the ,.vaste shocam from the NCRWTP would be sent to injection ,veil 1\^l-1. In the unlikely
event that neither of the 1\'1'0 \-"ells could be used, the water plant would be shut down,
terminating the on-site generation of liquid wastes.
7. For wells within the area of review which penetrate the injection zone but are not
properly completed or plugged, the corrective action proposed to be taken under rule 62-
527.300 (5), F.A.C.
There are no known wells in the area of revie'w that peneh'ate the injection zone other than
NCRWTP injection ,.vells lW-l and lW-2. No corrective actions are therefore required.
8. A certification that the applicant has ensured, through a performance bond or other
appropriate means, the resources necessary to dose, plug or abandon the well as required
by Rule 62-528.435 (9) F.A.C.
Certification of Financial Responsibility documentation was provided to Mr. Richard
Deuerling, FDEP-Tallahassee as part of the November 2003 renewal of the injection well lW-
2 operation permit. The cost estimates included conservative values for each activity,
plus a 20% contingency. The proposed well modification will result in a reduction of
plugging and abandonment costs, because the replacement tubing will not be removed
and the casing volume, and thus cement requirements will be less. The current financial
responsibility documentation is therefore still applicable, and does not require updating.
9. A report shall be submitted with each application fOl' repermitting of Class I Well
operation which shall include the following information:
(1) All available logging and testing program data and construction data on the well or
wellficld.
Copies of all available logging and testing program data and construction data for
injection well IW-2 were provided to the Department in the weekly construction reports
during the drilling of injection IW-2 and again in the injection ,,,ell completion report,
dated August 1996. No ne"" data has been obtained since the completion of the well
other than the MIT and monitoring data described below.
(2) A satisfactOlY demonstration of mechanical integrity for an wens pursuant to Rule 62~
528.300 (6), F.A.C.
Mechanical Integrity Test
8
l:!(olli(>r CQunlr/injNlion \"'I,,~lIs/ncrwlp.iwl operation PCI'l1\it/ni.:l'wlp 1\\'.1 over.-\tion pcrmil tL.'xl,d(1{'
16C4
A mechanical integrity test was last completed on injection well IW-2 in February 2006.
The results of the test indicated that injection well IW-2 has mechanical integrity.
Dual-zone monitor well water qualitv data
Water quality data for the shallow and deep monitor zones and concenh'ate are
compiled in Tables D-l through D-3 of Appendix D. Plots of the various water quality
parameters (conductivity, TDS, chloride, sodium, sulfate, and TKN) are plotted versus
time in Figures C-l through C-3 for the upper (shallow) monitor zone, Figures C-4
through C-6 for the lm",rer (deep) monitor zone, and Figures C-7 through C-9 for the
concentrate.
The monitoring 'vvell data has random variation, but there is no suggestion of any long
term h"ends of changes in salinity, such as would be expected to occur if upward
migration of injected fluids had occurred. If salinity were changing over lime, then the
same h'end would be evident in all the salinity parameters (specific conductance, total
dissolved solids, chloride, and sulfate). The increase in the salinity of the concentrate in
late 1999 reflects the reverse-osmosis desalination facility coming on line,
Monitor well pressure data
Average daily monitor well pressure (upper and lower zone) versus time is provided in
Figure D-l in Appendix D. There is no h'end of either increasing or decreasing pressure
(head) with time in either the upper or lower monitor zones.
Hydropneumat.ic system data
Data on annular pressure, hydropneumabc tank fluid level, and fluid and pressure
added have been submitted to the Department in the Monthly Operating Reports.
The monitoring data since the installation of the replacement tubing in October 2002
are summarized in Table 3.
Since the hlbing replacement, aImular pressure and fluid level in the
hydropneumatic tank have fluctuated clue to fluid expansion and conh'act:ion caused
by seasonal temperature changes, but there are no long term h'encls. It has never
been necessary to add fluid to the hyc1ropnematic system, and there has been no
need to add pressure since the June 2004. The historic monitoring data thus indicate
that the injection casing and tubing have mechanical integrity,
Table 3: Summar of well IW-2 h dro neul1latic syste11l1l1011itorill data
Month Annular PressureJpsi) _ ."__.""__~mllar Make-u
Max. Min, Average Fluid Total Pressure
Tal si
o 86
o 19
November 2002
December 2002
64
64
58
60
61.1
62.6
9
L:/(olliercounly/injffUon wt'Us/ncrwt]l-iwl olh~r.ltioH J~Nlll\t/I1(("'lP 1\\'.1 upcr.djQn permit it"I.(!O(
16C4
---........ .._,_.__......_..._-_._.._~.-"_.., ,.,_.._u.................. .... i'..................,"
January 2003 64 60 62.1 0 22
--...- --. -----...-
February 2003 65 61 62.7 0 0
- -.----_._.- -.---
March 2003 61 58 59.5 0 25
-~.._.._.. , __"______..m..__'_.u.._.__ ...-----
April 2003 64 61 62.2 0 6
May 2003 64 61 62.1 0 0
June 2003 62 59 60.3 0 5
JulV 2003 65 61 62.8 0 0
Au?;ust 2003 67 64 64.5 0 0
....--
September 2003 68 65 65.9 0 0
------ --- --
October 2003 67.5 63.5 65.2 0 0
November 2003 64 59 6-1.3 0 23
----- -."--'-.--- -~._....~_...---- ..'---_.-..__..~_._--....__..._-- --..--.------
December 2003 63 59 60.6 0 26
--..--.....---.-- --~._--~-_...,-_._......-_....
J anuarv 2004 62 57 59.4 () 36
-
.. Febru~1Y- 20Q_~___ 61 57 58.6 () 26
March 2004 61 56 58.7 () 42
April 2004 62 58 59.8 0 20
- ..--.-.--.........".-.....---......,.---
May 2004 61 56 58.1 0 23
June 2004 63 59 60.4 0 13
July 2004 63 59 60.2 0 0
August 2004 62 59 60.'1 0 0
September 2004 62 60 60.8 0 0
October 2004 62 57 59.2 0 ()
-
November 2004 58 55 56.6 0 0
December 2004 56 53 54.6 0 0
-- --
March 2005 55.1 52.1 53.5 0 0
April 2005 59.7 55.6 57.5 0 0
Mav 2005 63.1 59.7 61.1 0 0
...-....-- ......__.._n.__.__.. ---.
June 2005 62,5 59.7 60.8 0 0
July 2005 62.8 59.2 60.5 0 0
-- ---
August 2005 62.8 59.5 60.7 0 0
September 2005 64.4 60.8 62.1 0 0
October 2005 63.5 60.1 61.5 0 0
-~ ---.---- .....---.--- ----- ---- ---.----
November 2005 59.3 55.6 57.'1 0 0
--_._---_._~-~- _."--~, _ __."..~~'_M_'_'.._, . --_.-.._~-,._---~-
December 2005 59.4 54.5 57.2 0 0
January 2006 59.4 54.5 57.2 0 0
_._-----_._-
(c) The actual operating data, including injection prcssures versus pumping rates where
feasible, or the anticipated maximum pressure and flow rate at which the permittee
will operate, if approved by thc Department.
The monthly operating data are summarized in Table D-1 of Appendix D. The results
of specific injectivity tests performed over the past 5 years are summarized in Table D-2.
Plots of the average daily injection pressure and average daily injection flow rate versus
10
Z:/(olli..-T ((mnlY/inj('\~lion \\"C~Us/n'_r\..'tp.h,'1 opcfdtion pcrlllit
16C4
time and each other arc providl'd as Figures 0-2 and 0-3.
Average daily injection pressure data shows no evidence of an increase in injection
pressure over time, such as would occur if the transmissivity of the injection zone had
decreased over time due to clogging of pores. Average monthly injection pressures have
always been less than 40 psi and the maxinlllln injection pressure has been less than 75
psi. The calculated specific injectivity values have fluctuated considerably over the
monitoring period, but have consistently been over 200 gpmjpsi for the operation
history of the well, ,.vhich is acceptable for the design capacity and construction of the
,veIl.
Injection well IW-l will continue to be operated at a maximum rah~ of 6.3 MeD, which
corresponds to a velocity 8 ftj see. The anticipated injection pressUl'e are similar to
historic values (average daily pressure < 40 psi). 'I'he maximum permitted injection
pressure of 100 psi should not be exceeded,
(4) The actual injection procedure
The injection procedures at the NCRWTP are discussed in the "Injection Well IW-l and
IW-2 Operation and Maintenance ivlanual" which ,.vas submitted to the Department in
July 2005. No changes in the injection procedures are herein proposed.
(5) The compatibility of the injected waste with fluids in the injection zone and minerals
in both the injection zone and confining zone.
The major solute concenh'ations of the groundwater in the injection zone and lower
monitor zone are very similar to those of seawater. The solute concentration (salinity) of
the concentrate from the NCRWTP is substantially less than that of the \vaters in the
injection and confining zone. The relatively dilute injected waters would not be
expected to significantly impact either the injection zone or confining zone rock, which
consists predominantly of dolomite, Dolomite has both a low solubility and dissolution
and precipitation rates under the temperature, pressure, and pH conditions of the
injection zone.
(6) The status of corrective action on defective wells in the area of review
No defective wells that penetrate either the injection or confining zone are known to
exist within the area of review. No corrective actions arc therefore necessary.
(7) Record drawings, based upon inspections by thc cngineer or persons under his direct
supervision, with all deviations noted.
Record drawings of injection welllW-2 and the dU(l[-zone monitor well have previ011sly
been submitted to the Department.
(8) Certification of completion submitted by the engineer of record
11
l:/I,.'oUitor counly/injcdfon wells./ncrwtp-iwl Olk."rt\tlon )'('unit
16C4
A certification of completion fOt' injection '\vellIW-2 and the dual-zone monitor well
have previously been submitted to the Department.
(9) An updated operation manual including emergency procedures
The operation and maintenance procedures fOt' NCRWTP injection. wells IW-I and IW-2
were updated in July 2005 and submitted to the Deparhnent. Operations and
maintenance procedures have not been subsequently changed. The O&M manual was
therefore not updated. The O&tvf Manual will be updated afler the completion of the
major modification of injection well IW-2.
(10) Proposed revisions to the monitoring program or data to be submitted
No revisions to the monitoring program 01' data to be submitted arc proposed.
(11) Proposed plugging and abandonment plans pursuant to Rule 62-528.435 (2) F.A.C.
A plugging and abandonment plan \vith revised estimated costs for injection well lW-l
is provided in Appendix E.
References:
Maliva, R.G., and Walker, C.W., 1998, Hydrogeology of deep-well disposal of liquid wastes in
southwestern Florida, USA: Hydrogeology Journal, V. 6, p. 538-548.
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16C4
Figure 3
Collier NCRWTP Injection Well IW.2 Major Modification Application
Annulus Cement Packer Diagram