HomeMy WebLinkAboutMITIGATION (16) TRIHYDRO
~=_ oorporation
Environmental Engineering & Consulting
Shell Oil Products US
II I
Fourth Quarter and Annual 2002
Groundwater Monitoring Report
Shell Bakersfield Refinery
Bakersfield, California 93302
2002
City of Bakersfield
· Required Environmental Clean-up Status as of
01/01/2003
Contact: Ralph E. Huey
Phone: (661) 326-3979
e-mail: rhuey @ ci.bakersfield.ca.us
1715 Chester Av. Bakersfield, CA 93301
Hazardous Waste Corrective Actions:
Ld Agency Site Name & Address Location Photo Environmental Status
RWQCB PG&E Kem Steam Plant Hexavalent Chrome was retested and detected
2401 Coffee Rd. at 3 ppb (drinking water standard is 50 ppb) in
~1the grOundwater near the cOOling tOwers'
Water supply wells are non-detect for chrome
elsewhere on site. 80 tons of soil containing
hazardous levels of heavy metals were
removed in Nov. '01 from a former
incinerator area.' Additional soil and
groundwater sampling for petroleum impacts
around fuel oil storage tanks to be conducted
in 2002.
RWQCB Sunland Refinery Free product removal, air sparging & vapor
2150 Coffee Rd. extraction in progress. A total of 4,520,047
~ lbs (821,827 gal) of petroleum have been
(MTBE in groundwater) removed from the soil and groundwater to
(Benzene in groundwater) date, and clean-up is estimated at only 50%
(Floating gas on water table) complete. MTBE detected in water under the
site up to 90,000 ug/L. Benzene at 16,000
ug/L. Contaminants have moved under
PG&E site & deeper water sampling is being
required by RWQCB. City's Water Agency
well # CBK-25-01, SW of Brimhall & Coffee,
is not in service due to contamination in the
area. '
RWQCB Shell Refinery ~. tt_~[ ~ ~~ I N°t in City, but within area °f c°ncem.
6451 Rosedale Hwy MTBE in groundwater resulting from
(Not in City Limits) previous spill events at the refinery. Aquifer
tests were performed in Oct. 2000 to assess
(MTBE in Groundwater) water table and water movement in the area.
Soil vapor extraction and air sparging.in
progress.
DTSC Former Tosco Refinery - DTSC has a clean-up order for Tosco to
6451 Rosedale Hwy-~ remove a petroleum coke pile which is on the
north side of the Kern River across· from
(Not in City Limits, but Tmxtun lakes. The deposition of waste
adjacent to Kern Riverbed) petroleum coke in this area was a former
practice of the refinery while under Tosco's
ownership, over 20 years ago.
RWQCB KL Aviation Pesticide contamination assessment still
2014 Union Ay. continuing as an open case from previous
Former Garriot Crop Dusters practice of rinsing crop duster tanks into a
i former sump. Additional monitoring well to
(Soil assessment req'd)~'' ~ be installed downgradient. Abandoned UST's
removed on 12/01/00. Gasoline detected in
soil between former tank and dispenser
locations and referred to RWQCB for
coordination with their existing investigation.
RWQCB Former CleanSoil Facility RWQCB requesting new owner to properly
903 E. White Ln. ~!:~! ?;'; abandon groundwater monitor wells 6n site.
(Note: adjacent SoilRem facility has been
'' :-i[- iP' ' ~- ~~?':9c:;~7%~:~'"~'~'.~d~'~ properly closed under the City of Bakersfield
' ,' ::: ::z:' Permit Consolidation Zone and its monitoring
t wells were properly abandoned).
DTSC Gibson Oil Refinery .1 Not in City, but within area of concern.
End of Commercial St.~ Corrective Action Branch of the Permitting
(Not in City Limits) Program (Berkeley Office) is handling the
clean-up oversight. All hazardous liquids &
(Waste liquids & tanks tanks have been removed. 'Soils currently
removed. Soils currently ~¢:~ ~ being classified and removed. Tony Netera,
being removed) : DTSC, is case agent at (510) 540-3951.
DTSC K&D Salvage DTSC has removed solid wastes from K&D
600 S. Union [-~.- ...... site, and has performed further assessment.
..... ' .... Final remedial action plan proposes to remove
710 cubic yards of soil impacted with
(Lead and PCBs on site)
leachable concentrations of lead and PCBs
~..~ and place an asphalt covering over part of the
site to prevent percolation of rainwater. Cost
of cleanup estimated to exceed $1,300,000.
USEPA Double D Recycling USEPA repaired fence & returned April 25,
Former Benham-Johnson '. ~ 2002 to conduct further assessment. Double
340 Daniels Ln. D has shown high levels (19 ppm) of DDT in
(located behind 600 Union) soil (hazardous threshold=lppm). All
hazardous waste removed from the surface.
(Junk removed by City Code No sample results yet from the latest soil
Enforcement in cooperation ',~ assessment in May 2002.
with EPA soil sampling
activities)
Underground Petroleum Storage Tank Release Corrective Actions:
Ld Age~'c¥ Site Name " Location Photo Status
BFD Freeway Liquors MTBE (295 ug/l), Benzene (95 ug/l), &
2030 E. Brundage Ln gasoline (2,049 ug/l) detected in groundwater
:~ (126') beneath site. No water supply wells are
(MTBE in groundwater) ..... within one mile. Vapor extraction in
(Benzene in groundwater) ~ ~ operation since Nov. '02. 140 gallons of
Wlllll product have been removed from the soil and
groundwater so far. Latest groundwater
monitoring shows low concentrations are
decreasing to non-detect last quarter.
BFD Elks Lodge Vapor extraction completed. A total of
1414 E. California Ay. ~~ ~ 26,207 lbs. (4,765 gal.) have been removed to
¢:; ~ date by soil vapor extraction. MTBE not
(MTBE not involved)~ involved since leak occurred in early 1980's
(Clean-up complete.pending before MTBE was added to gasoline.
closure report acceptance) Confirmation sampling now performed &
report still needs to be approved for closure.
BFD St. Vincent De Paul · Vapor extraction completed and confirmation
310 Baker St. sampling required for closure. A total of
8,169 lbs or 1,276 gallons of gasoline has
(No MTBE detected) been removed through vapor extraction.
(Clean-up complete pending Work plan for confirmation sampling has
confirmation) been approved. Sample drilling to occur
during January, 2003.
RWQCB Downtown Chevron At least 400 gallons of gas leaked through a
2317 L Street hole in an underground pipe before the leak
was confirmed. There is now detectable
(MTBE in groundwater) benzene (2400 ug/1), and MTBE (4,000,000
ug/1, or 4000 ppm) in the shallow groundwater
below the site. Soil vapor extraction has been
ordered by RWQCB to begin and is now
overdue to begin.
RWQCB Mr. Fast Gas Leak from former UST's stopped in 1995.
600 Brundage Ln. Vapor extraction system and add'l
groundwater monitoring wells have been
(Gasoline floating on installed and operating. On site cleanup is est.
groundwater table, no to be 70% complete. Second vapor extraction
MTBE detected lately) system to be installed on south side of
Bmndage Ln. during January '03.
RWQCB Beacon Truck Stop Vapor extraction started on Oct. 15, 1999 and
3225 Buck Owens Blvd. 4,462 lbs (822 gal) of gasoline removed to
date. MTBE has not been detected in the
(Clean-up was to be groundwater during the past two quarters.
completed, but diesel now Vapor extraction completed. However, very
appearing in groundwater) minor amounts of diesel (100 ppm) keeps
appearing in the groundwater and monitoring
& investigation is still continuing because of
this recent diesel detection.
RWQCB Former Mobil Station Max. MTBE of 16,000 ug/L in groundwater at
4456 California Av 36' beolw surface. Monitoring well to be
installed on south side of California Ave.
(MTBE groundwater site) Groundwater pumping & vapor extraction
pilot study approved for implementation and a
schedule for startup is required by 1/21/03.
This site has not been meeting regulatory
deadlines set by RWQCB & has been granted,
and exceeded, several extensions already.
RWQCB Minit Stop Market Gasoline detected in groundwater at 380 ug/l
2900 Union Ave. and MTBE detected at 1570 ug/1. Case has
been referred to RWQCB for further
(MTBE groundwater site) investigation. Approved for three additional
groundwater monitoring wells.
RWQCB 7-Eleven Small pipe leak discovered & repaired, but
525 W. Columbus I--i; ~~ I I shallow groundwater (15'below surface)
[::l i' [ I impacted by MTBE at max. concentration of
(MTBE groundwater site, I~-~ [] _ ~--,,,~ ~ / [ 2,600 ug/L. Vapor extraction pilot study now
and levels have increased ~li ~ ]lll~ ~ ~ [ required as MTBE has recentlyincreased'
since last quarter) ~' ~ ~ ~ ~ I Add'l monitoring well to be installed near
· · I [] ~]/1 I dispenser island to determine if dispensers are
· III II/l a source of the release.
RWQCB Former 7-Eleven [ Leakage from former UST's showed trace
1700 Brundage Ln. ~ '- -- '~ I MTBE in the soil at such depths (150 ft) that
| I RWQCB wanted to assess the groundwater
· (MTBE in soil only) ~1 [] ~ I quality even· though groundwater is
~ I ~li I approximately 250 below the surface. 7-
~ Il/ill I Eleven's consultants argued that groundwater
~ ~ I monitoring wasn't warranted & RWQCB
] agreed to shallow soil vapor extraction only.
RWQCB Car Wash of America / Unreported release in 1997 has not yet been
1701 Stine Rd. / fully defined, but max. MTBE of 2.8 mg/kg
/ detected in soil at 85' below surface (that's
(Suspected MTBE ~l . ' ~' · ~1 ] deep for max. MTBE). A monitoring well
groundwater site) ~ and vapor extraction system to be installed.
/ Former owner of Niagara Car Wash has taken
i~] over responsibility for clean-up.
RWQCB Apex Bulk Commodities ~' ~ Diesel impacted soil & G/W @ 17' BGS.
2111 Bricyn Ln. t ~ ' :7 / MTBE detected in soil at 0.58 mg/kg. Soil
[ I / excavation & removal on 8/17/00. Benzene
(Benzene in groundwater) I - --~.~ 'F I / originally detected in groundwater at 9.ug/L,
(MTBE in soil only) / but has been non-detect last two years. No
~ t ~ ] MTBE in water.' RWQCB will consider case
(Groundwater monitoring / closure upon review of next monitoring event
completed, closure pending) /
/
RWQCB Holden Truck Stop I | Gasoline & diesel detected in groundwater.
3775 Buck Owens Blvd ~~l~/ Property is in bankruptcy, but San Joaquin
' [ ~ ~ / Bank, as lien holder, has paid for all UST
(Trace gasoline & diesel in I [~-.a~.~ ~[~[~-[ / removals and is funding site assessment work.
groundwater, no MTBE) ~~, - ~ / Groundwater monitoring now in Progress. An
[ excavation work plan is due 1/15/03 to
~' '~ / remove petroleum impacted soil that was
I I ~ ;1 / allowed to be left on site by Kern County
I ' ? / dunng a prevmus UST removal ,n 1980 s.
KCEH KHSD Maint. Yard [ Over-excavation performed for remediation of
3100 Chester Ay. ] ~ I ~ [ Underground Injection Well. G/W
(No MTBE Detected) ~ll!l~ / /m°nit°ringn°winpr°gress'
IIi
.p · p. g
(No MTBE Detected) / [ '~ ~ I risk assessment prior to requesting closure.
/ ~~lll I Vapor extraction equipment has been
/ ~.~ ~;~-,,dtd I removed from site, but vapor wells and piping
KCEH
McKenny's Air Cond.
2323 R St.
(No MTBE Detected)
G/W monitoring in progress. Vapor
extraction equipment (owned by the State)
still on site but has not operated in two years.
Site Investigation Case Closures During the Last Quarter:
Ld Agency Site Name Location- Status
BFD Former World Oil Station 2101 Brundage Ln. Previously closed site which was re-evaluated
for change in property use to commercial
retail offices. No further action required.
Cases Currently Under Investigation Pending Clean-Up Determinations:
Ld Agency Site Name Location Status
BFD Golden Empire Transit 1830 Golden State Hwy Soil sampling performed under diesel fuel
dispenser, which had leaked. Case to be
(Case closure pending) closed after GET completes upgrade to
dispenser island. GET is currently out to bid
for the upgrade work.
BFD Excell Excavation Arrow & Brittan Sts. Illegal dumping of restricted soil from 7-
Eleven site assessments from No. Calif. Soil
sampling conducted and waiting for results.
BFD Former Texaco Station 2601 White Lane UST removal showed tank pit & dispenser
islands impacted with petroleum products.
(Soil assessment req'd) Work plan currently under review.
BFD ARCO AM/PM 900 Monterey St. Leakage detected under a former product line
which was removed in May, 2001. Requested
(Soil assessment req'd) work plan for further soil sampling.
BFD Union Pacific Railroad 700 Sumner St. Ruptured locomotive fuel tank leaked 1700
gallons onto the track area west of Baker St. at
depot. Extent of soil impact still to be
determined through soil sampling on 1/23/03.
BFD 34t~ Street ARCO 1102 34th St. UST lining inspection uncovered petroleum
impacted soil surrounding two of the three
UST turbine pump areas. UST's are emptied
and temporarily abandoned until
responsibility for repairs and clean-up is
adjudicated in pending law suit.
BFD Texaco Service Station 4050 Gosford Rd. 50 cu. yds. of impacted soil excavated &
removed during product piping upgrade.
(Soil assessment req'd) Detectible MTBE still present in soil. Further
soil sampling to be required. '
Key~
BFD =
DTSC =
KCEH =
RWQCB =
USEPA =
Bakersfield Fire Department (Office of Environmental Services)'
Department of Toxic Substances Control
Kern County Environmental Health
Regional Water Quality Control Board
United States Environmental Protection Agency
S :\CORRESPONDENCEL2003-01 \Cleanups 1-03.wpd
Overman, Steven D SOPUS
From:
Sent:
To:
Subject:
William D Prevatt [William. D.Prevatt@conocophillips.com]
March 18, 2003 1:30 PM
Overman, Steven D SOPUS
contacts
Steve,
The individual signing the agreement will be Bob Staab. His contact info.
is as follows:
Bob:Staab
ConOcoPhillips Company
1500 N Priest Dr
Tempe, AZ 85281
phone: 602-728-7058
fax: ~ 602-728-5245
email: Robert. F.Staab@conocophillips.com
The :ConocoPhillips attorney who will have to sign off on the agreement
before Bob will sign it is Derrick Vallance. His contact info is:
Derrick Vallance
ConOcoPhillips Company
600 'N Dairy Ashford Rd
Houston, TX 77079
phone: 281-293-2247
fax:: 281-293-4255
email: Derrick. D.Vallance@conocophillips.com
I am your contact for this and I am the person within ConocoPhillips that
is reSponsible for shepherding this project. Therefore, it is probably
besti if draft documents flow thru me so that I can make sure that they are
attended to properly
William D Prevatt, PhD
Site Manager
Con0coPhillips
Risk', Management and Remediation
1218 PB
Bartlesville, OK 74004
918-661-3616 (bus)
918-661-5664 (fax)
918-~261-6447 (cell)
William. D.Prevatt@conocophillips.com
<<gO not to the wise for advice, for they will say both yes and no>>
®
Steven D. Overman Shell Oil Products US
Supervisor, Environmental Environmental Department
Bakersfield Refinery 6451 Rosedale H ghway, Bakersfield, CA 93308
P.O. Box 1476, Bakersfield, CA 93302
Tel +1 661 3264351
Fax +1 661 326 4255
Pager +1 661 398 7801
Mobile +I 661 201 2515
Email sdoverman@shellOPUS com
Gene Freed
Venture Manager
Shell Oil Products US
Health, Safely & Environment
6451 Rosedale Hwy.
Bakersfield, California 93308
Tel +1 661 326 4412
Mobile + 1 661 496 6272
Email eefreed@shellopus.com .
- : -; : , ~ -SHELL OIE PRODUCTS u.S: .: : ......
.... ~ ........ . :, :. : RAKI=RRF-iFi.D
~- - - , _. _._.._..___, CALIFORNIA
' - - February 12, 2003 ._
. _ ___ .- : -- . _. _ . ~ __ . ~.,,...,~re,-,~,r",~_~.,..,.. _ -
..... : ..-. .:-:, --' - Shell Oil Products U.S.
"- - - : - 6451._. ___.Rose:d~le Highway. ' ~ -
.... ': --.- Bakersfield, CA 93308
-~ . Prepared by:
.... -- - i- i : _::. ._ TriHydr0 CorpOration -- --
'- -: --~ 920 Sheridan Street _ - -
. - : .:i_ ' -.'._Laramie, WY 82070 -.
Hydro C po atio
idan '
.~...., . :~ - .: ......
- ~ :: :-'_L_aramie, Wy_om qg-82070 - FA_Xi (30?)
'CERTIFICATION
FOURTH QUARTER AND ANNUAL 2002
GROUNDWATER MONITORING REPORT
SHELL OIL PRODUCTS U.S..
BAKERSFIELD, CALIFORNIA
I certify that I have reviewed this document. To the best of my knowledge, the data contained herein
are true and accurate and the work was performed in accordance with appropriate and customary
professional standards.
J. Kirk Hardy Date
California Registered Geologist #5273
California Certified Engineering Geologist #1679
Licenses Expire March 31, 2003
H:~Projects~SH ELL~}akersfield~Final~77-O30~ReportO1~RPT01 .doc
SHELL OIL PRODUCTS U.S.
FOURTH QUARTER AND ANNUAL 2002
GROUNDWATER MONITORING REPORT
February 12, 2003
Facility Location:
Facility Contact:
Primary Consultant/Contact Person
Lead Regulatory Agency
Lead Regulatory Agency Contact:
6451 Rosedale Highway, Bakersfield, Ca 93308
Steve Overman (661) 326-4351
TriHydro Corporation / Ms. Linda Barnes (307) 745-7474
Regional Water Quality Control Board - Central Valley Region, Fresno
Office
Mr. Anthony Medrano (559) 488-4395
SECTION 1.0
ANNUAL GROUNDWATER MONITORING SUMMARY- 2002
Current Project Phase:
Depth to Groundwater Range in 2002:
Groundwater Gradient:
MTBE Concentration Range:
Well with Highest MTBE Concentration: ·
Benzene Concentration Range:
Well with Highest Benzene Concentration
TPHG Concentration Range:
Well with Highest TPHG Concentration:
Separate Phase Hydrocarbon Thickness Range:
Water Supply Wells within 2,000 feet of the Site:
Surface Water within 2,000 feet of the Site:
Remediation Techniques:
Separate Phase Hydrocarbons recovered in
2002:
Agency Directives:
Groundwater Investigation, Interim Remediation,
Ongoing Remediation (Refinery VES/Air Sparge
Systems), Groundwater Monitoring
51.51' - 110.9' bgs (Water table declining at approximately
1.7 feet per quarter)
0.0064 - 0.0071 ff/ft westerly to southwesterly in the
<110'bgs zone
0.0065 - 0.0074 ftJft westerly to southwesterly in the 110' -
140' bgs zone
0.0078 - 0.0083 ft/ft westerly to southwesterly in the >140'
bgs zone
<1 - 74,000 ug/L
B-159
<0.5- 17,000 ug/L
B-159
<100 - 600,000 ug/L
B-159
0.13 - 1.56 ft
D-l, D-2, D-3, D-4, D-5, D-6, D-7, I-1, I-2, I-3, I-4, I-5, I-6, I-
7, I-8, I-9, 1-10, 1-11, 1-12, 1-13, 1-14, 1-15, 1-16, P-31
Calloway Canal (dry) 500' northwest of Area 1 Refinery,
1,500' northwest of Area 2 Refinery
Soil Vapor Extraction, Groundwater Extraction and
Treatment, and Air Sparging
790 barrels (33,180 gallons) from the refinery SVE system
None
H:\Projects\SHELL~Bakersfieid~Final\077-030\Report01~RPT01 .doc
1-1
SECTION 2.0
DATA SUBMITTAL (ATTACHED)
Fi.qures
· 2
· 3
· 4
· 5
· 6
7
8'
9
10
11
12
13
14
site Vicinity Map
Site Plan
Potentiometric Map for Groundwater <110' bgs, November-December 2002
Potentiometric Map for Groundwater 110'- 140' bgs, November-December 2002
Potentiometric Map for Groundwater >140' bgs, November 2002
MTBE Plume Contours for Groundwater <110' bgs, November-December 2002
MTBE Plume Contours for Groundwater 110'- 140' bgs, November-December 2002
MTBE Plume Contours for Groundwater >140' bgs, November 2002
MTBE Results for Nearby Water Supply Wells, November 2002
Benzene Plume Contours for Groundwater < 110' bgs, November-December 2002
Benzene Plume Contours for Groundwater 110' - 140' bgs, November-December 2002
Benzene Plume Contours for Groundwater >140' bgs, November 2002
Benzene Results for Nearby Water Supply Wells, November 2002
Air Sparging Well Locations
Tables
1
2a
2b
3
4th Quarter- Groundwater Levels, Shell Oil Products U.S.
4th Quarter- Monitoring Well Analytical Results, Shell Oil Products U.S.
4th Quarter - Water Supply Well Analytical Results, Shell Oil Products U.S.
4th Quarter - Quality Assurance Results, Shell Oil Products U.S.
Appendices
· A
· B
Field Data Sheets
Laboratory Analytical Reports
H:~Projects~SHELL~Bakersfleld~Final\077-030~Report0 I\RPT01 .doc
2-1
SECTION 3.0
FACILITY DESCRIPTION
Shell Oil Products U.S. (SOPUS) has owned and operated the facility now known as the Shell
Bakersfield Refinery (SBR) since October 2001. The Shell Bakersfield Refinery consists of three
interconnected operating areas known as Areas 1, 2, and 3. Area 1 was built in 1932 by the Mohawk
Oil Company (1932 to 1970) and was subsequently owned by Reserve Oil and Gas Company (1970
through 1980), Getty Oil Company (1980 through 1984), Texaco (1984 through 1998), and Equilon
Enterprises LLC (1998 through 2001). The adjacent Area 2 was built by the US Government in 1942
and was subsequently owned by Lion Oil Company, Tosco Oil Company, Texaco (1986 through
1998), and Equilon Enterprises LLC (1998 through 2001). SBR Areas I and 2 encompass
approximately 599 acres of land located in the city of Bakersfield, Kern County, California (the Site,
Figure 1). Area 3 was built and operated by the Independent Valley Energy Company (1978 to 1987)
and was subsequently owned by Texaco (1987 to 1998) and Equilon Enterprises LLC (1998 to 2001).
Area 3 is located approximately 1.5 miles northeast of Area 1 and encompasses approximately 357
additional acres of land. The Shell Bakersfield Refinery currently processes about 70,000 barrels of
crude oil per day.into products such as automotive gasoline, diesel fuel, petroleum coke, fuel oils,
liquefied petroleum gas, asphalt, and sulfur. A site plan showing the Site and adjacent properties is
included as Figure 2.
H:~Projects~SHELL\Bakersfietd~Final\077-030\Report01~J~PT01 .doc
3-1
SECTION 4.0
GEOLOGIC AND HYDROGEOLOGIC SETTING
The Site is located at an elevation of approximately 390 feet above mean sea level (msl) and is
underlain by approximately 200 feet of late Pleistocene and Recent alluvial sands and gravel
(deposited primarily by the Kern River). The Kern River alluvial fan is a large wedge of sand and
gravel on the east side of the valleY that forms where the Kern River exits the Sierra Nevada foothills.
Alluvial fan deposition is the geologic response to the change in slope and to the transition from
confined to unconfined flow (Dale, 1966).
Water runoff from the Sierras flows from the northeast to the southwest down the bed of the Kern
River onto the alluvial fan, where water slowly seeps from the river bottom into the distant margins of
the fan. Elk Hills, which represents the surface expression of a subsurface anticline, then diverts the
subsurface flow southward towards Buena Vista Lake (Dale, 1966).
The near-surface aquifer is made up of Pleistocene to Recent sands and gravel. These sediments
cut into older alluvial fan and lacustrine sediments of the Plio-Pleistocene Tulare Formation. An
angular unconformity then separates the continental sediments from underlying marine deposits of the
Pliocene San Joaquin Formation (Bertoldi, 1991).
Studies of the Site and surrounding area indicate that the upper' 100 feet of sediments consist
primarily of interbedded sands and silts (with minor clay) deposited as the outwash plain of the Kern
River. Because of the nature of braided stream deposition, correlation of distinct stratigraphic
horizons is difficult and may vary across the Site and vicinity.
For monitoring purposes, the site stratigraphy has been divided into three distinct horizons~.
Depth of less than 110 feet below ground surface (bgs) (Shallow Zone);
Depth of 110 feet to 140 feet bgs (Intermediate Zone); and
Depth of greater than 140 feet bgs (Deep Zone).
The aquitards that separate these horizons are pervasive and relatively uniform across the Site.
Although there may be two or more coarse-grained strata present within any of these horizons, each
individual monitoring well is typically screened across only one stratum.
The shallowest groundwater in the site vicinity is generally unconfined, with confined conditions
occurring locally. The water table elevation has fluctuated by tens of feet per year in response to
changes in regional groundwater recharge and pumping conditions. There was approximately 100
feet of water table rise between 1993 and 1999. Since 1999, the water table has been decreasing in
elevation and dropped by more than one foot per month during 2001, with an average elevation
decrease of approximately 0.57 foot per month in 2002. The current average depth to water is
approximately 80 feet bgs.
Groundwater flow directions have remained consistently to the south/southwest in 2002, with some
local, transient groundwater mounding occurring along the northern portion of the site in the first and
fourth quarter monitoring events. The groundwater mounding is likely due to recharge from the
H:~Projects~SH ELL~Bakersfield~FinaR077-030~Report0 I~RPT01 .doc
4-1
Calloway Canal in the first and fourth quarter gauging events. Groundwater extraction activities along
the northern portion of the site tended to depress groundwater elevations in groundwater monitoring
wells located within the extraction wells' radii of influence. Groundwater gradients have remained
relatively stable throughOut 2002, ranging from 0.0064 to 0.0071 foot per foot in the Shallow Zone,
0.0065 to 0.0074 foot per foot in the Intermediate Zone, and 0.0078 to 0.0083 foot per foot in the.
Deep Zone. Fourth quarter 2002 groundwater levels are summarized in Table 1. Field data sheets for
the fourth quarter 2002 groundwater sampling event are included in Appendix A. Po. tentiometric maps
for groundwater less than 110 feet bgs, between 110 and 140 feet bgs, and deeper than 140 feet bgs,
are included as Figures 3 through 5, respectively.
H:~Projects~SH ELL~Bakersfi eid~Final~077-O30~Report0 I~PT01 .doc
4-2
SECTION 5.0
DISTRIBUTION OF PETROLEUM CONSTITUENTS
Identification of Source Areas
Two source areas for methyl tert-butyl ether (MTBE)-affected groundwater have been identified at the
Site. One source area is located at the Sales Terminal (hereinafter referred to as the "Terminal"),
along the southwest corner of Fruitvale Avenue and Rosedale Highway. The second source area
(Blending Area) is located near the eastern property line within the Refinery, near the railcar-loading
area in Area 1.
A release of petroleum hydrocarbons containing MTBE first occurred from the Terminal's underground
product lines in March 1999. Subsequent releases occurred in December 2000 and April 2001..A soil
vapor extraction (SVE) system was installed and is currently operating within the Terminal's source
area. Several groundwater extraction wells were installed in the central and down-gradient portions of
the Terminal's MTBE plume to provide down-gradient and vertical hydraulic containment of the
dissolved-phase MTBE plume. Two IRM treatment systems, IRM-1 and IRM-2, are utilized to treat
the extracted groundwater prior to its discharge into the Calloway Canal.
An air sparging system has been in operation down-gradient of the Blending Area's MTBE source
since 1995. The SVE system was expanded into the Blending Area's MTBE source area (near
monitoring well B-116) and is anticipated to be in operation by the second quarter of 2003.
A reformate release, in the vicinity of the Area 2 Refinery's hydrocracker, is currently being
remediated using a system of four vapor extraction wells and six air sparge wells. Details regarding
operation of the air sparging, groundwater extraction, and SVE systems are included in Section 6.0.
MTBE Plume Distribution In Groundwater
Extensive subsurface investigation has delineated the Terminal's dissolved-phase MTBE plume as
being a maximum of 3,300 feet long and up to 800 feet wide in the Shallow Zone (<110 feet bgs), and
2,100 feet long and up to 400 feet wide in the Intermediate Zone (110 to 140 feet bgs) in the 2002.
groundwater sampling events. MTBE was not detected above laboratory method detection limits of 1
microgram per liter (ug/L) in the Terminal plume's Deep Zone groundwater monitoring wells (>140 feet
bgs) during the 2002 quarterly sampling events,, with the exception of first quarter 2002 samples
collected from wells B-126L (3.9 ug/L) and B-176L (1.1 ug/L).
Subsurface investigation activities have delineated the Blending Area's dissolved-phase MTBE plume
as being a maximum of 3,400 feet long and up to 900 feet wide in the Shallow Zone, 2,600 feet long
and up to 1,000 feet wide in the Intermediate Zone, and 3,600 feet long and up to 500 feet wide in the
Deep Zone during the 2002 quarterly groundwater sampling events.
Both the Terminal and Blending Area's dissolved-phase MTBE plumes trend in an east to west
direction, following the local groundwater gradient (accentuated by groundwater extraction in the case
H:\Projects~SHELL\Bakersfi eld~Final\077-O30~'RePort01\RPT01 .doc
5-1
of the Terminal plume), with limited north-south expansion over time. No appreciable eastward
migration (upgradient) of the dissolved-phase MTBE plumes has been observed.
Concentrations of MTBE in wells located in the vicinity of the Terminal source area have dropped
significantly between the February and November 2002 quarterly sampling events. Concentrations of
MTBE in Terminal source area wells have decreased from 570,000 to 220 ug/L in T-9A, 63,000 ug/L
to ND (at a-detection limit of 1.0 ug/L) in T-10A, and 7,700 to 30 ug/L in WIP-W4A. MTBE
concentrations in groundwater in the vicinity of the Simpson Property and Blending Area have shown
a similar drop in concentrations in 2002, decreasing from 540 to 38 ug/L in B-178U, 270 ug/L to ND
(at a detection limit of 1.0 ug/L) in B-187U, 180 ug/L to ND (at a detection limit of 1.0 ug/L) in B-188U,
370 to 64 ug/L in B-195U, and 81 to 11 ug/L in B-098M.
Fourth quarter 2002 MTBE plume isoconcentration contour maps for groundwater less than 110 feet
bgs, between 110 and 140 feet bgs, and greater than 140 feet bgs, are included as Figures 6 through
8. Fourth quarter 2002 MTBE analytical results for nearby water supply wells are shown on Figure 9.
Benzene Plume Distribution in Groundwater
DisSolved-phase benzene plumes are located in the Blending Area and the northwestern portions of
the Area 2 Refinery. During 2002, the Blending Area dissolved-phase benzene plume was a
maximum of 2,200 feet long and up to 800 feet wide in the Shallow Zone, 1,600 feet long and up to
400 feet wide in the Intermediate Zone, and 1;800 feet long and up to 700 feet wide' in the Deep Zone.
During 2002, the Area 2 Refinery's dissolved-phase benzene plume was a maximum of 3,000 feet
long and up to 2,000 feet wide in the Shallow Zone, 3,000 feet long and up to 1,200 feet wide in the
Intermediate ZOne, and 3,200 feet long and up to 1,200 feet wide in the Deep Zone.
Both the Blending and Refinery 2 Area's dissolved-Phase benzene plumes trend in an east to west
· direction. The down-gradient portion of the Refinery 2 Area's Shallow Zone plume exhibits some
lateral (north and south) migration of dissolved-phase benzene. No appreciable eastward migration
(upgradient) of the dissolved-phase benzene plumes has been observed.
Concentrations of benzene in wells located in the vicinity of the Blending Area have decreased or
remained stable between the February and November 2002 quarterly sampling events. Benzene
concentrations in groundwater in the Refinery 2 Area plume have dropped in 2002, decreasing from
1,700 to 280 ug/L in R6B, 840 to 280 ug/L in RS-6A, 4,800 to 1,200 ug/L in D2, and 20 ug/L to ·ND (at
a detection limit of 0.5 ug/L) in MS2.5A.
Fourth quarter 2002 benzene plume isoconcentration contour maps for groundwater less than 110
feet bgs, between 110 and 140 feet bgs, and greater than 140 feet bgs, are included as Figures 10
through 12. Fourth quarter 2002 benzene analytical results for nearby water supply wells are shown
on Figure 13.
Monitoring well and water supply well groundwater analytical results for the fourth quarter 2002
groundwater sampling event are summarized in Tables 2a and 2b, respectively. Laboratory reports
and chain-of-custody documentation are included in Appendix B.
H:\Projects\SHELL\Bakersfield~Final\077-O30~Report0 I\RPT01 .doc
5-2
SECTION 6.0
CONCEPTUAL PLAN FOR GROUNDWATER REMEDY
The first stage of the groundwater remedy was to identify and eliminate all receptor pathways. Five
off-site water supply wells were identified as potential future receptors due to their proximity to the
dissolved MTBE plume. Four of the wells (EPC, Gaslight, Simpson,. and IP) have been destroyed.
The remaining supply well GD, on the Caza Drilling property is not operating. Other off-site supply
wells in the site vicinity are north of the Calloway Canal. The dominant groundwater flow direction is
west-southwest, parallel to the Calloway Canal, and sampling results indicate that dissolved MTBE
above 1.0 ug/L does not extend north of the canal. Four on-site supply wells provide water to the
refinery for both potable and non-potable uses. All wells are screened at depths greater than 500 feet
and are separated from the strata of M'l'BE-affected groundwater by a regional aquitard that begins at
a depth of approximately 250 feet bgs. The refinery's four on-site water production wells are utilized
as a source of process water. The use of two of the wells as a source of potable water for the refinery
was discontinued on June 22, 2002, when the potable water distribution systems for Areas 1 and 2 of
the refinery were connected to a municipal water supply. Area 3 of the refinery utilizes municipal
water for process and potable uses.
The MTBE plume originating at the Terminal is contained through operation of a groundwater
extraction system. The effectiveness of the hydraulic containment system is provided through the
following: 1) extraction from the leading (down-gradient) edge of the plume, 2) extraction from
additional wells as necessary to provide capture of the full width of the dissolved plume, 3) extraction
from enough locations along the. length of the plume to ensure hydraulic containment under conditions
of shifting groundwater flow, and 4) extraction from sufficient depth to capture the vertical extent of the
dissolved plume.
The hydraulic containment system has been designed with enough flexibility to accommodate the
anticipated fluctuations in water table elevation. In anticipation of dropping water levels, groundwater
extraction wells have been completed in both the Shallow Zone, at a depth of approximately 80 to 110
feet (currently the primary interval containing dissolved-phase MTBE), and the Intermediate Zone, at a
depth of approximately 110 to 140 feet. Extraction from the Intermediate Zone will be a precaution
against MTBE bypassing the containment system as the water table drops. Shallow extraction wells
that go dry will be temporarily capped and preserved for possible later use in the event that the water
table rises in future years.
IRM-1 consists of seven extraction wells (EW-3, 4, 5, 6, 7, 12, and 13) located 50 to 200 feet south of
the Calloway Canal, approximately 450 feet west of the Charity Avenue cul-de-sac. IRM-1 was
constructed to provide hydraulic containment at the down-gradient, leading edge of the Terminal
dissolved-phase MTBE plume. Treated water from IRM-1 currently discharges to Calloway Canal.
During 2002, the average discharge rate was 139 gallons per minute (gpm) or approximately 200,522
gallons per day (gpd). Influent MTBE concentrations for IRM-1 extraction wells ranged from less than
1.0 ug/L to 4,100 ug/L during 2002.
· IRM-2 consists of one extraction well (EW-8) north of Charity Avenue and four extraction wells (EW-9,
10, 11, and B-149) south of Charity Avenue. Treated water from IRM-2 also discharges to the
Calloway Canal. During 2002, the average discharge rate was 105 gpm or approximately 151,113
gpd. Influent MTBE concentrations for IRM-2 extraction wells ranged from less than 1.0 ug/L to
59,000 ug/L during 2002.
H:\Projects\SH ELL\Bakersfi eld~'inal\077-030~Report0 I~RPT01 .doc
6-1
The groundwater treatment technology is a biologically augmented, granulated active carbon system
(BioGAC). The BioGAC system utilizes a standard carbon treatment system inoculated with a
naturally occurring, MTBE-degrading bacteria that has been isolated and patented by Shell Global
Solutions. The BioGAC treatment technology is currently utilized for both the IRM-1 and IRM-2
extraction systems. As a precaution, the process streams from the treatment plants are run through a
standard GAC unit before being discharged.
Petroleum hydrocarbon-affected soil vapor is currentlY being removed from the source area at the
Terminal by means of an SVE system. The SVE well extraction and operating system is being
modified to increase mass removal rates and to take advantage of the dropping water levels,
addressing residual and free-phase product from progressively deeper strata as the water table
continues to drop. The existing SVE treatment system has sufficient capacity to accommodate
increased extraction rates in the vicinity of the Terminal.
Significant effort has been expended at the Terminal to prevent future releases of product to the
subsurface. A series of five underground, pressurized product lines that lead from the Refinery to the
Terminal have been replaced with aboveground lines. This modification should minimize the potential
for future releases of the type contributing to the Terminal source area.
The Blending Area MTBE plume is being contained by enhanced bioremediation through the use of
the air sparge system. Historical MTBE concentrations show that the Blending Area MTBE plume is
stable and will not affect offsite receptors. In addition, the refinery has installed a vapor extraction well
in the Blending Area. The well should be online and operational by the second quarter 2003.
In areas of favorable geochemical conditions, aerobic microbial populations are capable of degrading
MTBE. Preliminary studies conducted by Shell's Westhollow Technology Center indicate indigenous
MTBE-degraders are present at the site, however the rate of biodegradation is relatively slow. In
areas within and down-gradient of a product release, groundwater is typically depleted of oxygen.
The addition of oxygen to the groundwater system (e.g. through air sparging) is expected to stimulate
microbial growth and associated MTBE biodegradation. Air sparging well locations are shown on
Figure 14.
H:~Projects~SHELL~Bakersfleld~Final\077-O30~Report01\RPTO 1 .doc
6-2
sECTION 7.0
TREATMENT SYSTEM OPERATION SUMMARY - 2002
Soil Vapor Extraction System Operation Summary
The SVE system recorded an online operational time of 66.4% during 2002 and recovered
approximately 790 barrels (33,180 gallons) of product. The SVE system's down time resulted primarily
from the following:
1. Inadequate steam supply from the refinery (14.2% of the available operational time).
A planned shutdown to replace the original GAC in all six primary and secondary
carbon vessels (5.3% of the available operational 'time).
The failure and replacement of the natural gas supply regulator to the oily water
separator (4.9% of the available operational time). The length of the shutdown period
associated with the regulator failure was exacerbated by a lack of suitable replacement
parts within a reasonable timeframe.
Not including "scheduled plant shutdown" and refinery-related downtimes (i.e. steam issues), the SVE
system recorded a run time of 90.8% of the available operational time.
During the scheduled shutdown for. carbon change out, Shell replaced the temporary B-inch HDPE
piping from the SVE to the Terminal area with permanent 8- and 10-inch carbon steel piping and
installed four knockout pots to remoVe condensate from the system. Frequent interruPtion of the
steam supply to the carbon adsorbers was corrected by replacing a faulty 150-pound pressure
regulator. Other routine maintenance included:
Ten control valves were replaced at the inlet, dilution air, and recycle line of the B, C, and D
blowers;
Rebuilt the 24-inch vapor inlet valve;
Replaced oil pressur;e switches on the B, C, and D blowers;
The cooling tower was refurbished during shutdown;
Terminal wellhead fittings were upgraded;
The Mohawk Area tie-ins were completed;
The oily water separator was washed out; and
A shed was installed for the OVM meter.
These modifications are expected to increase the overall efficiency of the SVE unit.
H:~Projects\SH ELL\Bakersfi eld~Final\077-O30~°.eport0 I\RPT01 .doc
7-1
IRM Operation Summary
The average efflUent flows from the IRM units were 139 gpm for IRM-1 and 105 gpm for IRM-2. Flow
from the individual wells was adjusted based on changing groundwater elevations. Two new
extraction wells (EW-12 and EW-13) were brought online for the IRM-1 unit. The pump in EW-3 was
malfunctioning and was replaced during the third quarter 2002. The discharge flow from both .of the
IRM units was switched out of the Calloway Canal and redirected .to the refinery storage retention
pond on September 24, 2002. The North Kern Water District requested this change in order to dry the
Calloway Canal for weed removal. Shell notified the California Regional Water Quality Control Board
(CRWQCB) of this temporary change, as required by permit. On November 11, 2002, the effluent flow
was returned to the Calloway Canal.
Air Spar.qin.q Summary
The refinery's air sparge system was 100% operational during 2002. The original system consisted of
36 air sparge wells. Ten air sparge wells were installed and added to the system in 2002. Air supply
pressure was maintained at 40 psig during the year. Shell redeveloped all of the original air sparge
wells to remove accumulated sediments and improve flow in 2002.
H :'~Projects\SH ELL~Bakemfield~Final\O77-O30'~eportO I'~.PTO 1 ,doc
7-2
SECTION 8.O
GROUNDWATER MONITORING SUMMARY - 4TM QUARTER 2002
Current Project .Phase:
Frequency of Monitoring/Sampling:
Depth to Groundwater Range:
Groundwater Gradient:
Groundwater Gradient Consistent with Previous
Quarter:
MTBE Concentration Range:
Well with Highest MTBE Concentration:
Benzene Concentration Range:
Well with Highest Benzene Concentration:
TPHG Concentration Range:
Well with Highest TPHG Concentration:
Separate Phase Hydrocarbon Thickness Range:
Water Supply Wells within 2,000 feet of the site:
Surface Water within 2,000 feet of the Site:
Current Remediation Techniques:
Separate Phase Hydrocarbons recovered this year:
Agency Directives:
Groundwater Investigation, Interim Remediation,
Ongoing Remediation (Refinery VES/Air Sparge
Systems), Groundwater Monitoring
Quarterly (240 wells)
68.74' - 110.58' bgs
(Water table 'declining at approximately 1.7
feet/quarter)
0.0071 ft/ft westerly to southwesterly in the <110' bgs
zone
0.0070 ft/ft westerly to southwesterly in the 110' - 140'
bgs zone
0.0082 ft#t Westerly to southwesterly in the >140' bgs
zone
Gradient slightly steeper, but direction unchanged
Local, transient mounding occurred due to recharge
from Calloway Canal
<1.0 - 84,000 ug/L
WIP-W3A
<0.5 - 4,800 ug/L
B-118L
<100 - 50,000 ug/L
B-118L
0.11 - 1.37 ft
D-l, D-2, D-3, D-4, D-5, D-6, D-7, I-1, I-2, I-3, I-4, I-5,
I-6, I-7, I-8, I-9, 1-10, 1-11, 1-12, 1-13, 1-14, 1-15, 1-16, P-
31
Calloway Canal (dry) 500' northwest of Terminal,
1,500' northwest of Area 2 Refinery
Soil Vapor Extraction, Groundwater Extraction and
Treatment, and Air Sparging
160.26 barrels from the refinery SYE system
None
H:~Projects\SHELL~Bakersfleld~Final\077-030~Report0 I\RPT01 .doc
8-1
SECTION 9.0
DATA QUALITY. REVIEW (FOURTH QUARTER 2002)
Seventeen equipment blanks were analyzed in the fourth quarter 2002 groundwater sampling
event. One sample (MS2.5A) contained gasoline range total petroleum hydrocarbons at a
concentration of 460 ug/L. Benzene, toluene, ethylbenzene, xylene isomers, and MTBE were
not detected above analytical method detection limits.
No trip blanks were analYzed in the fourth quarter 2002 groundwater sampling event.
MS/MSD results for all compounds were generally within control parameters. Ten percent of
the results for TBA were out of control parameters due to matrix interference, but, in all cases,
the corresponding LCS/LCSD results were within control parameters.
LCS/LCSD results for all compounds were generally within control parameters.
Fourth quarter 2002 groundwater quality assurance results are summarized in Table 3. Laboratory
analytical results and chain-of-custody documentation for groundwater quality assurance samples are
included in Appendix B.
H:~Projects~SHELL~Bakersfield~Final\077-O30~Report01~RPT01 .doc
9-1
SECTION 10.0
TREATMENT SYSTEM OPERATION SUMMARY
The SVE System recorded an online operating time of approximately 79.4%, 39.6%, and
86.4% for the months of October, November, and December 2002, respectively. A substantial
amount of downtime for the month of November resulted from the failure of one of the natural
gas regulators at the inlet of the OWS unit. The SVE system removed approximately 160.26
barrels of product during the fourth quarter of 2002.
The refinery-wide air sparge system operated continuously during the fourth quarter of 2002.
The refinery-wide system now consists of 46 well clusters. For the fourth quarter of 2002, all
of the sparge well clusters in Area 1 (north of the railroad tracks) were online. In Area 2 (south
of the railroad tracks), 28 air sparge wells were online.
Both IRM-1 and IRM-2 were fully operational during the fourth quarter of 2002 and operated in
accordance with the guidelines provided by Westhollow personnel.
H:~Projects\SH ELL~Bakersflelo'~Final\077-O30~,eportO I\RPT01 .doc
10-1
SECTION 11.0
WORK PERFORMED THIS QUARTER (FOURTH QUARTER 2002)
Operated and 'maintained the air sparge, SVE, and IRM systems at the Site;
Submittal of "3"d Quarter 2002 Groundwater Monitoring Report", prepared by GeoSyntec
Consultants;
Submittal of the Sales Terminal's "Environmental Indicators Vapor Sampling Report", dated
November 11, 2002, prepared by GeoSyntec Consultants;
Installed, developed, and sampled groundwater monitoring wells B-201, B-202U, and B-202L
in the Westside Industrial Complex. These wells were installed to provide additional sampling
points as depth to groundwater continues to increase across the site;
Installed and developed groundwater monitoring wells A3-01 through A3-04 in Area 3 of the
refinery. Information detailing these well installations will be provided to the CRWQCB under
separate cover; and
Completed the installation of extraction wells EW-12 and EW-13 in the IRM-1 area to increase
groundwater production for the remediation systems. The IRM-1 system was modified in the
fourth quarter 2002 to connect these new extraction wells to the system.
H:~Projects~SH ELL'~Bakersfield~Final\077-030~Report0 I~RPT01 .doc
11-1
SECTION 12.0
WORK PROPOSED FOR NEXT QUARTER (FIRST QUARTER 2003):
A technical report will be completed for the installation of B-201, B-202L, B-202U, and A3-01
through A3-04 in the first quarter of 2003;
Perform first quarter 2003 groundwater gauging and sampling event;
Manifold the Blending Area SVE well to the SVE system; and
Submittal of the Fourth Quarter 2002 NPDES Monitoring Report.
H:~Projects~SHELL\Bakersfield~'inal\077-030~Report0 I~RPT01 .doc
12-1
SECTION 13.0
REFERENCES
Dale, R.H., French, J.J., and Gordon, G.V., 1966, Ground-water Geology and Hydrology of the Kern
RiverAIluviaI-Fan Area, California: United States Geological Survey.
Bertoldi, G.L., Johnston, R.H., and Evenson, K.D., 1991, Ground Water in the Central Valley,
California- A Summary Report: United States Geological Survey, Professional Paper 1401-A.
H:\Projects\SHELL'~lakersfield~Final\077-030~Report0 I\RPT01 .doc
13-1
TABLES
H:\Projects~HELL\Bakersfi eld~Final\077-030'~Report0 I\RPT01 .doc
Table 1.
Well ID
4th Quarterl- Groundwater Levels, Shell Oil Products U, S,
Elevation of
Measurementi Measuring Point Depth to Product Depth to Water
Date ~ Time Elevation Product Thickness Groundwater Surface
, (ft-msl) (ft-bmp) (ft) (ft-bmp) (ft-msl)
Depth to Top
of Screen
(ff-bgs)
Depth to
Bottom of
Screen
(ft-bgs)
B-001L 11/11/02 , 14:10
B-001M 11/11/02 ' 14:13
B-001U 11/11/02 ', 14:15
B-003 11/11/02 , 13:46
B-O07 11/11/02 i 10:32
B-008 11/11/02 ! 14:59
B~009 11/11/02 ' 14:35
B-010 11/11/02 i 10:17
B*011 11/11/02 * 14:30
B-012 11/12/02 I 11:48
B-013 11/11/02 14:22
B-014 11/11/02 ' 10:59
B-017 11/11/02 ' 10:36
B-023 11/12/02 , 10:10
B-024L 11/11/02 ; 14:35
B-024U 11/11/02 , 14:38
B-030L 11/11/02 ' 15:04
B-030M 11/11/02 , 15:05
B-030U 11/11/02; 15:08
B-041L 11/11/02 15:15
B-041M 11/11/02 ' 15:17
B-041U 11/11/02! 15:18
B-042 11/11/02 : 11:58
B-043 11/12/02 11:27
B-044L 11/12/02 ' t1:40
B-044M 11/12/02 , 11:42
B-044U 11/12/02 , 11:44
B-050L 11/11/02 : 13:51
B-O50M 11/11/02 ! 13:54
B-050U 11/11/02 : 13:56
B-052L 11/11/02 , 11:38
B-052M 11/11/02 ; 11:42
B-052U 11/11/02 ', 11:46
B-075L 11/11/02 ; 13:40
B-075M 11/11/02 13:42
B-075U 11/11/02 '~ 13:44
B-098L 11/12/02 i 11:51
B-098M 11/12/02 ' 11:53
B-098U 11/12/02 i 11:55
B-099L 11/11/02 ~ 11:15
B-099M 11/11/02 , 11:18
B-099U 11/11/02 ! 11:22
B-100L 11/11/02 10:49
B-100M 11/11/02: ·10:52
B-100U 11/11/02 ! 10:55
B-103L 11/11/02 , 10:39
B-103M 11/11/02 ' 10:42
B-103U 11/11/02 10:45
B-104L 11/11/02 ' 10:22
B-104M 11/11/02: 10:24
B-104U 11/11/02 i 10:26
B-105L 11/11/02· i 11:27
B-105M 11/11/02 '~ 11:29
B-106L 11/11/02 '~ 11:19
B-106M 11/11/02 11:21
ACCESS - Table 1_Groundwater Quarterly
388.35
390.40
390,38
388,74
383.60
388,27
380,77
383.10
387.53
388.47
386.34
385,21
383,53
383.08
384,45
384.45
388.08
388,08
388,08
382.37
382,37
382,37
389,86
390,79
388,40
388,40
388.40
390.62
390,37
390,98.
388,00
388.00
388.00
384.35 ·
384,35
384,35
384,79
384,79
384.79
385.35
385,35
385,35
354,91
384,91
384,91
383,73
383,73
383.73
385,26
385,26
385,26
387,58
387,58
386,23
386,23
ND None 95,21
ND None 90.03
ND None 89,78
ND None 91.76
ND None 107,52
N D None 100.85
ND None 99.65
ND None '110.58
ND None 105,29
88,99 1,56 90,55
ND None 106,39
ND None 98,93
ND None 108.37
ND None 88,04
ND None 109,19
ND None 89,19
ND None 96.97
ND None 94,51
ND None 94.83
ND None 87,97
ND None 85.82
ND None 85,99
ND None 81.7
ND None 93,5
ND None 89,02
ND None 89,73
ND None Dry
ND None 84.98
ND None 84,79
ND None Dry
ND None 99,84
ND None 97.42
ND None 97,93
ND None 76,63
ND None 80.94
ND None 80.62
ND None 79,99
ND None 78,55
ND None 78,69
ND None 96,94
ND None 96.08
ND None Dry
ND None 94.61
ND None 94.74
ND None Dry
ND None 94.39
ND None 94.42
ND None Dry
ND None 93,07
ND None 93,04
ND None 82,3
ND None 74.18
ND None 73.83
ND None 71,59
ND None 70.68
293.14
300.37
300.60
296.98
276.08
287.42
281.12
272.52
282.24
297.92
279.95
286.28
275.16
295.04
275.26
295.26
291.11
293.57
293.25
294.40
296.55
296.38
· 308.16
297.29
299.38
298.67
Dry
305.64
305.58
Dry
288.16
290.58
290.07
307.72
303.41
303.73
304.80
306.24
306.10
288.41
289.27
Dry
290.30
290.17
Dry
289.34
289.31
Dry
292.19
292.22
302.96
313.40
313.75
314.64
315.55
145,00
100.00
30,00
140.00
140,00
143.00
143.00
150,00
155,00
144,36
174.00
140,00
180,00
136.00
162,70
120.00
129,50
101,50
74,50
129.61
101,73
73,82
114,56
130,00
115.00
88.00
63,00
114,00
86,00
61,00
135,00
108.00
83.00
131.00
105,00
78.00
109,81
79,82
49,83
110,00
80.25
50,00
110,00
80,25
50,00
110,00
80,25
50,00
110,00
80,25
50.00
95,00
65,00
110.00
80.00
200,00
140.00
90,00
180.00
180,00
183.00
183.00
190.00
195,00
184.36
194.00
180.00
200.00
176.00
182.70
150.00
160.00
122.00
95.00
149.61
121.73
93.82
154.56
170.00
135.00
108.00
83.00
134.00
106.00
81.00
175.00
128.00
103.00
150.00
125.00
100.00
140.00
109.82
79.83
140.00
110.25
80.00
140.00
110.25
80.00
140.00
110.25
80,00
140,00
110,25
80,00
125,00
95,00
140,00
110.00
Page 1 of 5
Table 1.
Well ID
4th Quarter- Groundwater Levels, Shell Oil Products U. S.
Measurement Measuring Point Depth to
Date Time Elevation Product
(ft-msl) (ft-bmp)
Product
Thickness
(ft)
Depth to
Groundwater
(ft-bmp)
Elevation of
Water
Surface
(ff-msl)
Depth to Top
of Screen
(ft-bgs)
Depth to
Bottom of
Screen
(ft-bgs)
B-107L 11/12/02 10:20 390.51 ND
B-107M 11/12/02 10:22 390.51 ND
B-108L 11/11/02 11:35 388,61 ND
B-108M 11/11/02 11:37 388.61 ND
B-10gL 11/12/02 11:56 389,11 76.25
B-109M 11/12/02 11:58 389.11 74.33
B-110L 11/12/02 10:30 392.49 ND
B-11 OM 11/1 2/02 10:32 392,47 ND
B-111L 11/11/02 14:22 381.34 ND
B-111M 11/11/02 14:24 381,34 ND
B-114L 11/11/02 11:04 387.19 ND
B-114M 11/11/02 11:07 387.19 ND
B-114U 11/11/02 11:11 387,19 ND
B-115L 11/11/02 11:27 387,38 ND
B-115M 11/11/02 11:30 387,38 ND
B-115U 11/11/02 11:33 387.38 ND
B-116L 11/12/02 10:58 389.46 ND
B-116M 11/12/02 11:00 389,49 ND
B-117L 11/12/02 10:52 393.32 ND
B-117M 11/12/02 10:53 393.34 ND
B-118L 11/12/02 10:48 393.06 ND
B-118M 11/12/02 10:49 392.99 ND
B-119L 11/11/02 10:39 389,46 ND
B-119M 11/11/02 10:41 389,56 ND
B-120L 11/11/02 10:32 388.74 ND
B-120M 11/11/02 10:34 388.76 ND
B-121M 11/11/02 10:24 390,88 ND
B-124L 11/11/02 14:50 390.20 ND
B-124M 11/11/02 · 14:53 390.16 ND
B-124U 11/11/02 14:55 389.96 ND
B-125L 11/11/02 11:18 391,32 ND
B-125M 11/11/02 11:20 391.36 ND
B-125U 11/11/02 11:22 391.47 ND
B-125L 11/11/02 15:33 389.16, ND
B-126M 11/11/02 15:37 389.33 ND
B-126U 11/11/02 15:35 389.47 ND
B-127L 11/11/02 11:25 392.55 ND
B-127M 11/11/02 11:27 392.61 ND
B-127U 11/11/02 11:29 392,62 ND
B-128L 11/11/02 14:30 395.85 ND
B-128M 11/11/02 14:32 395.90 ND
B-128U 11/11/02 14:34 395.96 ND
B-129L1 11/11/02 10:58 391.50 ND
B-129L2 11/11/02 10:56 391.31 ND
B-129M 11/11/02 11:03 391.67 ND
B-129U 11/11/02 11:06 391.85 ND
B-130L1 11/11/02 10:34 392,04 ND
B-130L2 11/11/02 10:30 392,29 ND
B-130M 11/11/02 10:32 391,91 ND
B-130U 11/11/02 10:41 391,86 ND
B-131L1 11/11/02 10:45 391.17 ND
B-131L2 11/11/02 10:44 391.13 ND
B-131M 11/11/02 10:48 391.32 ND
B-131U 11/11/02 10:49 391,31 ND
Bo132 11/11/02 10:57 390.63 ND
ACCESS - Table 1 _Groundwater Quarterly
None
None
None
None
0,31
0,16
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
74.24
73.41
75.6 '
73.51
76.56
74,49
74.16
73.93
81.59
81.29
96.12
96,35
81.85
96.98 ·
96,56
Dry
77.54
75.23
82,09
80.42
80.18
78.48
76,87
75.21
82.99
79.85
80.53
95.9
91.25
89,79
104.6
99.47
72.52
98.78
97,71
Dry
99.7
96.85
79.61
93.67
91.78
69.39
106.15
106.49
101,72
Dry
108.25
108.66
102.89
92.92
110.22
110.45
103.13
88,1
Dry
316.27
317.10
313.01
315.10
312.55
'314.62
318.33
318.54
299.75
300.05
291.07
290.84
305.34
290.40
290.82
Dry
311.92
314.26
311,23
312,92
312,88
314,51
312,59
314.35
305.75
308,91
310,35
294,30
298,91
300.17
286,72
291.89
318,95
290.38
291,62
Dry
292,85
295,76
313.01
302,18
304,12
. 326,57
285.35
284.82
289.95
Dry
283.79
283,63
289.02
298.94
280.95
280,68
288,19
303.21
Dry
110.00
80,00
110,00
80,00
110,00
78.00
110,00
80.00
100.00
70.00
120.00
85,00
40,00
120,00
85,00
40,00
165.00
100,00
165,00
100,00
165.00
100,00
163.00
100,00
165~0
100.00
100,00
160,00
120.00
30,00
160,00
125,00
30,00
160.00
110,00
30.00
160,00
115,00
30.00
162.00
110.00
30,00
180.00
235.00
120.00
30.00
180.00
235,00
125.00
30.00
190.00
243.00
120.00
30.00
30.00
140.00
110.00
140,00
110.00
140,00
108.00
140,00
110.00
130.00
100.00
150.00
115.00
80,00
150.00
115,00
80,00
175.00
110.00
175,00
110,00
175,00
1.10,00
173,00
110.00
175.00
110.00
135.00
200.00
140.00
90.00
185,00
150,00
70,00
180,00
140,00
80.00
185,00
140,00
80,00
182,00
140.00
70,00
200.00
245.00
145.00
90.00
200,00
245.00
145.00
90.00
210.00
253.00
145,00
85,00
90.00
Page 2 of 5
Table 1.
Well ID
4th Quarter - GroundWater Levels, Shell Oil Products U. S.
Measurement Measuring Point Depth to
Date Time Elevation Product
(ft-msl) (ft-bmp)
Product
Thickness
(ft)
Depth to
Groundwater
(ft-bmp)
Elevation of
· Water
Surface
(ft-msl)
Depth to Top
of Screen
(ff-bgs)
Depth to
Bottom of
Screen
(ft-bgs)
B-133 11/11/02 11:10
B-134 11/11/02 11:38
B-143 11/11/02 14:51
B-144 11/12/02 11:54
B-145 11/12/02 16:00
B-146 11/12/02 12:00
B-150M 11/11/02 14:05
B-153 11/12/02 10:07
B-154 11/12/02 10:23
B-156 11/1 2/02 12:08
B-157 11/12/02 13:14
B-159 11/1 2/02 13:25
B.161M 11/11/02 11:55
B-161U 11/11/02 11:58
B-162M 11/11/02 14:10
B-162U 11/11/02 14:12
B-163M 11/11/02 13:50
B-163U 11/11/02 13:48
B-164L 11/11/02 14:00
B-164M 11/11/02 14:02
B-164U 11/11/02 14:04
B-166L 11/11/02 11:10
B-166M 11/11/02 11:11
B-166U 11/11/02 11:13
B-167L 11/11/02 10:10
B-167M 11/11/02 10:12
B-167U 11/11/02 10:14
B-168L 11/11/02 11:05
B-168M 11/11/02 11:07
B-169L 11/11/02 11:12
B-169M 11/11/02 11:15
B-169U 11/11/02 11:17
B-170L 11/11/02 10:30
B-170M 11/11/02 10:32
B-170U 11/11/02 10:34
B-171L 11/11/02 14:22
'B-171M 11/11/02 14:24
B-171U 11/11/02 14:26
B-172L 11/11/02 15:10
B-172M 11/11/02 15:15
B-172U 11/11/02 15:20
B-173L 11/12/02 10:40
B-173M 11/12/02 10:42
B-173U 11/12/02 10:44
B-175L 11/12/02 11:08
B-175M 11/12/02 11:09
B-175U 11/12/02 11:11
B-176L 11/11/02 14:38
B-176M 11/11/02 14:40
B-176U 11/11/02 14:42
B-177L 11/12/02 15:04
B-177M 11/12/02 15:06
B-177U 11/12/02 15:08
B-178M 11/12/02 13:33
B-178U 11/1 2/02 13:35
393.06
392.87
389,27
390.30
391,69
393.21
388,94
391.07
391,76
390.91
392,42
390.31
393,08
392.95
398.25
398.37
398.07
398.01
398.71
398.81
398.96
390.04
390.11
390.30
391.59
391.67
391.75
389.77
389.78
391.41
391.47
391.56
389.75
389.86
369.95
392.87
392.95
392.96
382.96
383.01
383.07
385,79
385.85
385.88
388.00
388.07
388.24
391.14
391.27
391.29
383.25
383.32
383.43
385.25
385.49
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
Dry
Dry
75.06
75.08
74.87
74.47
87.81
74.62
74.41
74.6
74.31
74.83
95.3
84.17
97.63
97.61
100.18
87.76
98.94
98.37
84.25
105.23
101.56
Dry
106.94
104.95
102.56
103.25
99.48
101.44
98.87
98.45
98.23
96.92
96.87
102.3
100.38
96.14
82.51
84.13
82.1
86.88
85.85
85.58
87.16
85.11
91.67
91.01
89.26
79.48
78.72
78.15
84.65
83.64
Dry
Dry
314.21
315.22
316.82
318.74
301.13
316.45
317.35
316.31
318.11
315.48
297.78
308.78
300.62
300.76
297.89
310.25
299.77
300.44
314.71
284.81
288.55
Dry
284.65
286.72
289.19 .
286.52
290.30
289.97
292.60
293.11
291.52
292.94
293.08
290.57
292.57
296.82
300.45
298.88
300.97
298.91
300.00
300.30
300,84
302.96
303.40
299.47
300.26
302.03
303.77
304.60
305,28
300.60
301.85
30.00
30.00
40.00
40.00
40.00
40.00
90.00
35.00
35.00
35.00
35.00
35.00
110.00
75.00
115.00
80.00
116.00
68.00
114.00
89.50
170.00
120.00
70.00
160.00
120.00
70.00
160.00
118.00
150,00
120.00
90.00
125.00
108.00
92.00
154.00
120.00
80.00
235.00
176.00
148,00
225.00
190.00
150.00
210,00
172.00
140.00
175.00
145.00
115.00
222.00
172.00
144.00
115.00
90.00
90.00
90.00
75.00
75.00
75.00
75.00
110.00
75.00
75.00
75.00
75.00
75.00
120.00
85.00
125.00
100.00
126.00
88.00
134.00
104.00
64.00
185.00
140.00
95.00
1~0.0~
140.00
105.00
180.00
138.00
170.00
140.00
110.00
140.00
118.00
102.00
164.00
140.00
100.00
245.00
196.00
168.00
240.00
210.00
170.00
225.00
192.00
160.00
190.00
160.00
135.00
232.00
192.00
164.00
120.00
95.00
ACCESS - Table 1_Groundwater Quarteity Page 3 of 5
Table 1.
Well ID
4th Quarter - Groundwater Levels, Shell Oil Products U. S.
Measurement Measuring Point Depth to
Date Time Elevation Product
(ft-msl) (ft-bmp)
Product
Thickness
(ft)
Depth to
Groundwater
(ff-bmp)
Elevation of
Water
Surface
(ft-msq
Depth to Top
of Screen
(ft-bgs)
Depth to
Bottom of
Screen
(ft-bgs)
B-179M
B- 179U
B-180L
B-180M
B-180U
B-181L
B-181M
B-181U
B-182M
B-182U
B-185L
B-185M
B-185U
B-186L
· B-186M
B-186U
B-187L
B-187M
B-187U
B-188L
B-188M
B-188U
B-195L
B-195M
B-195U
B-196L
B-196M
B-196U
B-201
B-202L
B-202U
D2
D3
DP2
M14S
MN1Z
MN2AU
MS2.5A
PW-L23
PW-L26
PW-L28
PW-U4
R1
R3
R4
R6B
RS-6A
RS-BW4
RS-DP4
RS-DP5
RS-DP6
RS-DP7
RS-HC7
RS-HC8
11/13/02 g:00 383.03
11/13/02 9:02 383.10
11/11/02 12:00 390.06
11/11/02 12:02 390.18
11/11/02 12:04 390.30
11/11/02 11:48 391.23
11/11/02 11:49 391.30
11/12/02 15:21 391.23
11/12/02 10:50 385.47
11/12/02 10:52 385.54
11/11/02 15:22 391.57
11/11/02 15:24 · 391.69
11/11/02 15:26 391.79
11/11/02 15:13 392.32
11/11/02 15:15 392.43
11/11/02 15:17 392.56
11/11/02 14:50 389.33
11/11/02 14:55 389.60
11/1 2/02 13:29 389.80
11/11/02 14:59 388.57
11/11/02 13:20 388.72
11/12/02 13:22 389.12
11/11/02 15:24 389.67
11/11/02 15:26 389.44
11/11/02 15:28 389.36
11/12/02 15:00 388.42
11/12/02 15:02 388.51
11/12/02 15:03 388.66
12/30/02 9:38 394.16
12/30/02 9:46 388.62
12/30/02 9:43 388.64
11/11/02 11:17 388.29
11/11/02 14:32 378.44
11/1 2/02 11:10 386.07.
11/12/02 13:41 391.55
11/11/02 14:26 389.40
11/11/02 14:21 387.50
11/11/02 14:07 384.62
11/11/02 14:44 382.22
11/11/02 14:40 381.18
11/11/02 14:44 364.01
11/11/02 11:46 388.16
11/1 2/02 11:38 383.42
11/11/02 14:10 '387.20
11/11/02 14:04 388.70
11/12/02 10:29 390.04
11/12/02 16:00 383.41
11/12/02 11:23 379.99
11/11/02 10:28 385.30
11/11/02 13:57 386.27
11/11/02 14:17 381.07
11/11/02 14:56 387.07
11/11/02 14:12 385.77
11/12/02 10:16 381.43
11/11/02 15:26 385.60
ACCESS - Table 1_Groundwater Quarterly
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
80170
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
None
None
None
None
None
None
None
None
None
None,
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
0.13
None
None
None
None
None
None
None
None
None
None
None
None
80.25
79.16
97.21
95.16
95.01
95.3
93.98
89.66
82.68
81.89
101.03
101.11
97.69
102.31
102.29
98.16
95.50
90.12
89.94
88.81
89.46
97.47
94.31
91.46
104.04
97.08
95.24
89.70
83.70
85.26
90.56
79.75
96.48
88.79
97.41
Dry
88.09
73.77
77.67
75.80
77.12
80,83
83.80
82.58
85.25
82.99
79.47
94.77
98.42
83.60
96.08
92.97
81.66
77.30
302.78
303.94
292.85
295.02
295.29
295.93
297.32
301.57
302.79
303.65
290.54
290.58
294.10
290.01
290.14
294.40
293.83
299.48
299.86
293.73
299.91
299.66
292.20
295.13
297.90
284.38
291.43
293.42
304.46
304.92
303.38
297.73
298.69
289.59
302.76
291.99
Dry
296.53
308.45
303.51
308,21
311.04
302.59
303.40
306.12
304.79
300.42
300.52
290.53
287.85
297.47
290.99
292.80
299.77
308.30
113.00
76.00
150.00
125.00
95.00
150.00
125.00
90.00
120.00
85.00
190.00
165.00
126.00
182.00
165.00
125.00
160.00
125.00
70.00
160.00
110.00
70.00
165.00
122.00
BO.O0
160.00
125.00
75.00
75.00
114.00
97.00
54.00
40.00
92.00
70.00
14.00
20.00
18.00
100.00
90.00
70.00
100,00
12.00
12.00
12.00
12.00
18.00
88.90
105.00
125.00
98.00
129.25
100.00
74.00
74.00
133D0
106.00
170.00
140.00
115.00
165.00
140.00
110.00
135.00
105.00
205.00
180.00
146.00
202.00
175.00
145.00
180.00
145.00
100.00
180.00
140.00
95.00
180.00
152.00
180.00
145.00
105.00
95.00
134.00
105.00
114.00
100.00
105.00
90.00
104.00
80.00
108.00
144.50
138.75
143.00
140.00
105.00
117.00
117.00
117.00
98.00
148.90
134.00
150.00
138.00
149.25
130.00
134.00
134.00
Page 4 of 5
Table 1.
4th Quarter - Groundwater Levels, Shell Oil Products U. S.
Measurement
Well ID Date Time
Measuring Point Depth to Product Depth to
Elevation Product Thickness Groundwater
(ft-msl) (ft-bmp) (ft) (ft-bmp)
Elevation of
Water
Surface
(ff-msl)
Depth to Top
of Screen
(ff-bgs)
Depth to
Bottom of
Screen
(ft-bgs)
RS-MNIZ 11/11/02 14:02 387.54
RS-MN2B 11/11/02 14:06 385.36
RS-MS2.5 11/12/02 14:11 384.26
RS-MS3A 11/11/02 14:17 384.71
T10A 11/12/02 10:30 391.45
T16A 11/12/02 10:10 390.03
T3B 11/12/02 10:50 391.92
T8B 11/12J02 11:40 390.22
T9A 11/1 2/02 11:46 390.40
TR-2 11/12/02 11:08 390.73
U4 11/11/02 11:50 386.86
WI P-W1 11/11/02 11 .'35 387.39
WIP-W2 11/12/02 13:38 388.43
WIP-W2A 11/12/02 11:30 388.28
WIP-W3A 11/11/02 13:03 390.67
WIP-W4 11/12/02 14:20 389.52
WlP-W4A 11/11/02 12:02 389.61
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
ND
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
None
98.26
94.21
87.85
91.95
82.34
80.73
82.73
81.95
82.27
81.71
73.60
Dry
68.74
82.66
83.03
Dry
82.45
289.28
291:15
296.41
292.76
309.11
309.30
309.19
308.27
308.13
309.02
313.26
Dry
319.69
305.62
307.64
D~
307.16
125.00
105.50
100.00
100.00
73.00
20.00
59.00
70.00
70.00
42.00
35.00
50.00
50.00
20.00
20.00
50.00
19.00
150.00
150.50
149.00
130.00
95.00
50.00
89.00
90.00
90.00
82.00
95.00
70.00
70.00
50.00
50.00
70.00
49.00
ACCESS - Table 1_Groundwater Quarterly Page 5 of 5
Table 2a. 4th Quarter - Monitoring Well Analytical Results, Shell Oil Products, U.S.
Gasoline Range . Ethyl-
Sample Organics Benzene Toluene benzene
Sample ID Date (pglL) (pg/L) (pg/L) (l~g/L)
o-Xylene
(pg/L)
m,p-Xylene
(pg/L)
MTBE
(pg/L)
B-O01U
B-O01M
B-O03
B-O07
B-O08
B-009
B-010
B-011
B-013
B-014
B-017
B-023
B-O24U
B-O24L
B-O3OM
B-O30L
B-041U
B-041M
B..041L
B-042
B-043
B-O44M
B-O44L
B-O50M
B-OSOL
B-O52U
B-O52M
B-O52L
B-O75U
B-O75M
B-O98M
B-O98L
B-O99M
B-O99L
B-100M
B-100L
B-IO3M
B-IO3L
B-104M
B-104L
B-IOSM
B-108L
B-111M
B-111L
B-114M
B-114L
B-115M
B-115L
B-116M
B-116L'
B-117M
B-117L
B-118M
B-118L
B- 120M
B-120L
11/19/02 ND(lO0) ND(0.5) ND(l)
11/13/02 ND(lO0) ND(O.5) ND(l)
11/13/02 ND(lO0) ND(O.5) ND(l)
11/19/02 ND(lO0) ND(O.5) ND(l)
11/15/02 ND(1 00) ND(O.5) ND(1 )
11/15/02 ND(lO0) ND(0.5) ND(l)
11/14/02 ND(lO0) ND(0.5) ND(I)
11/19/02 560 23 ND(l)
11/19102 2700 77 140
11/14/02 ND(lo0) ND(0.5) ND(l)
11/14/02 ND(lO0) ND(O.5) ND(l)
11/18/02 ND(lO0) ND(O.5) ND(l)
11/14/02 ND(lO0) ND(O.5) ND(l)
11/14/02 ND(lO0) ND(0.5) ND(l)
11/15/02 2900 2.7 ND(l)
11/15/02 750 ND(0.5) ND(l)
11/18/02 180 ND(0.5) ND(l)
11/18/02 4000 7.8 N D(5)
11/18/02 850 ND(0.5) ND(l)
11/19/02 12000 120 ND(25)
11/20/02 32000 870 1800
11/18/02 ND(lO0) ND(0.5) ND(l)
11/19/02 ND(lO0) ND(0.5) ND(l)
11/12/02 ND(loo) ND(0.5) ND(I)
11/13/02 ND(lO0) ND(0.5) ND(l)
11/19/02 NO(lO0) ND(0.5) ND(l)
11/14/02 ND(lO0) ND(0.5) NO(l)
11/13/02 ND(lO0) ND(0.5) ND(l)
11/13/02 ND(lO0) 2.1 ND(l)
11/13/02 210 4.8 ND(1 )
11/20/02 ND(lO0) ND(0.5) ND(l)
11/19/02 ND(lO0) 0.52 ND(l)
11/13/02 ND(lO0) ND(O.5) ND(l)
11/14/02 ND(lO0) ND(O.5) ND(l)
11/14/02 ND(lO0) ND(0.5) ND(l)
11/14/02 ND(lO0) ND(O.5) ND(l)
11/12/02 ND(lO0) ND(O.5) ND(l)
11/12/02 ND(lO0) ND(0.5) ND(l)
11/13/02 ND(lo0) ND(O.5) ND(l)
11/13/02 ND(lO0) ND(O.5) ND(l)
11/19/02 430 440 ND(lO)
11/19/02 4000 7.2 N D(5)
.11/14/02 ND(lO0) 4.3 2.3
11/14/02 ND(100) 5 ND(1 )
11/12/02 ND(lO0) ND(0.5) ND(l)
11/12/02 ND(lO0) ND(0.5) ND(l)
11/12/02 ND(lO0) ND(0.5) ND(l)
11/12/02 ND(lO0) ND(0.5) ND(l)
11/20/02 17000 62 41
11/20/02 42000 280 3500
11/20102 19000 · 22 170
11/20/02 46000 820 3000 .
11120102 39000 620 6400
11/20/02 35000 4800 2000
11/14/02 ND(lO0) ND(O.5) ND(l)
11/14/02 ND(lO0) ND(O.5) ND(l)
ACCESS - ¢ptGroundwater Quarterly_Table 2a
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
NO(l)
140
NO(l)
ND(l)
ND(l)
ND(l)
ND(l).
1.6
ND(l)
ND(l)
14
ND(l)
230O
3100
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
1.2
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
18
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
2900
610
2200
1700
1800
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
190
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
1.9
ND(l) .
ND(l)
ND(5)
ND(l)
N0(25)
ND(l)
ND(l)
ND(l)
ND(t)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(lO)
ND(5)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
140
5200
2600
4500
3300
ND(l)
ND(l)
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
1
210
ND(l)
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
NO(5)
ND(l)
4500
93O0
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
1.7
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(t)
ND(l)
ND(l)
350
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
2800
12000
4900
9600
9300
71 O0
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l).
ND(l)
ND(l)
ND(l)
ND(l)
ND(2)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
NO(l)
NO(5)
ND(l)
ND(25)
ND(25)
ND(l)
1.5
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
5.1
9.8
11
42
NO(l)
NO(l)
NO(l)
ND(l)
ND(l)
ND(t)
ND(l)
ND(l)
ND(lO)
ND(5)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
93O
ND(25)
ND(50)
ND(50)
ND(SO)
ND(l)
ND(l)
Page 1 of 3
Table 28. 4th Quarter - Monitoring Well Analytical Results, Shell Oil Products, U.S.
Sample
ID
Gasoline Range Ethyl-
Sample Organics Benzene Toluene benzene
Date (pg/L) (pg/L) (pg/L). (pg/L)
o-Xylene
(pg/L)
m,p..Xylene
(pg/L)
MTBE
(pg/L)
B-121M
B-124L
Bo125M
B-125L
B-126M
B-126L
B-128M
B-128L
B-129M
B-129L1
B-130M
B-130L 1
B-130L2
B-131 L1
B-15OM
B-161M
B-152U
B-164M
B-1 56M
B-156L
B-167U
B-167M
B-167L
B-168M
B-168L
B-169U
B-170U
B-170M
B-170L
B-171 U
B-171M
B-171L
B-172U
B-172M
B-172L
B-173U
B-173M
B-173L
B-175U
B-175M
B-175L
B-176U
B~176M
B-176L
B-177U
B-177M
B-177L
B-178U
B- 178M
B-179U
B-179M
B-180U
B-180M
B-180L
B-181U
B-181M
11/14/02 ND(100) .ND(0,5)
11/13/02 ND(100) ND(0,5)
11/13/02 ND(100) ND(0,5)
11/13/02 ND(lO0) ND(0,5)
11/14/02 ND(lO0) ND(0.5)
11/14/02 ND(lO0) ND(0.5)
11/15/02 ND(lO0) ND(0.5)
11/15/02 ND(lO0) ND(O.5)
11/12/02 ND(lO0) ND(O.5)
11/12/02 ND(lO0) ND(O.5)
11/12/02 ND(lO0) ND(O.5)
11/12/02 ND(lO0) 1
11/12/02 ND(lO0) ND(O.5)
11/12/02 ND(100) ND(0.5)
11/13/02 ND(lO0) ND(0.5)
11/14/02 ND(lO0) ND(0.5)
11/18/02 ND(lO0) ND(O.5)
11/20/02 ND(lO0) ND(0.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(0.5)
11/13/02 ND(lO0) ND(O.5)
11/12/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) N D(O.5)
11/14/02 ND(lO0) ND(O.5)
11/18/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(0.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(0.5)
11/13/02 ND(lO0) ND(O.5)
11/14/02 N D(100) N D(O.5)
11/14/02 ND(lO0) ND(0.5)
11/1 4/02 ND(100) ND(0.5)
11/14/02 ND(lO0) ND(O.5)
11/14/02 ND(lO0) ND(0.5)
11/14/02 ND(lO0) N D(0.5)
11/19/02 23000 2400
11/19/02 3000 220
11/19/02 570 8
11/15/02 'ND(lO0) ND(0.5)
11/14/02 ND(lO0) ND(0.5)
11/14/02 ND(lO0) ND(O.5)
11/20/02 6300 · 160
11/18/02 9000 420
11/18/02 N D(100) 1.8
11/19/02 ND(lO0) ND(0.5)
11/19/02 N D(100) N D(0.5)
11/20/02 410 N D(1 )
11/20/02 ND(lO0) ND(O.5)
11/14/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(O.5)
11/13/02 ND(lO0) ND(0.5)
11/20/02 140 ND(lO0)
11/13/02 ND(lO0) ND(0.5)
ACCESS - ~ptGroundwater Quarterly_Table 28
ND(l) ND(l) ND(l) ND(I) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) 2.1
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(I')
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(I) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(I) ND(l) ND(l) ND(l) ND(I)
ND(l) ND(l) ND(l) ND(1) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(I) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(1) . ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(1) 16
ND(l) ND(l) ND(l) ND(l) 56'
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(I) 3.1
ND(l) ND(l) ND(l) ND(l) 1.6
ND(l) ND(I) ND(I) ND(l) ND(I)
7700 620 3200 6600 ND(50)
ND(5) 160 ND(5) 38 ND(5)
7.4 26 6.7 62 7.2
ND(l) ND(l) ND(l) ND(l) 4
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) . ND(l) ND(l).
ND(20) 1300 240 3300 ND(20)
59 1500 760 2600 ND(20)
ND(l) 6.7 4 12 ND(l)
ND(l) ND(l) ND(l) ND(l) 38
ND(l) ND(l) ND(l) ND(l) 170
ND(2) ND(2) 7.3 4 260
ND(l) ND(l) ND(l) ND(l) 81
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(l) ND(l) ND(l) ND(l) ND(l)
ND(200) ND(200) ND(200) ND(200) 9800
ND(l) ND(l) ND(l) ND(l) ND(l)
Page 2 of 3
Table 2a, 4th Quarter - Monitoring Well Analytical Results, Shell Oil Products, U,S.
Gasoline Range Ethyl-
Sample Organics Benzene Toluene benzene
Sample ID Date (pg/L) (pg/L) (pg/L) (l~g/L)
o-Xylene
(pg/L)
m,p-Xylene
(pg/L)
MTBE
(l~g/L)
B-181L 11/13/02 ND(lO0)
B-182U 11/18/02 ND(lO0)
B-182M 11/18/02 ND(lO0)
B-185U 11/15/02 N D(IO0)
B-185M 11/15/02 N D(100)
B-185L 11/1 5/02 ND(100)
B-187U 11/20/02 ND(lO0)
B-187M 11/13/02 ND(100)
B-187L 11/13/02 ND(100)
B-188U 11/19/02 ND(lO0)
B-188M 11/19/02 ND(100)
B-188L 11/13/02 ND(100)
B-195U 11/20/02 ND(lO0)
B-195M 11/20/02 ND(lO0)
B-195L 11/20/02 ND(lO0)
B-196U 11/13/02 N D(100)
B-196M 11/13/02 N D(100)
B-196L 11/13/02 ND(100)
B-201 12/30/02 N D(100)
B-202U 12/30/02 ND(100)
B-202L 12/30/02 ND(lO0)
D2 11/20/02 8800
D3 11/19/02 ND(lO0)
DP2 11/18/02 ND(100)
M14S 11/19/02 ND(100)
MN1Z 11/19/02 2700
MS2.5A 11/20/02 39000
PW-L23 11/14/02 N D(100)
PW-L26 11/1 4/02 3400
PW-L28 11/14/02 N D(100)
PW-U4 11/1 4/02 N D(100)
R2 11/18~02 970
R4 11/19/02 1000
R6B 11/20/02 20000
RS-6A 11/20/02 7600
RS-BW4 11/15/02 ND(lO0)
RS-DP4 11/15/02 ND(lO0)
RS-DP5 11/15/02 . ND(lO0)
RS-DP6 11/19/02 ND(lO0)
RS-DP7 11/18/02 ND(lO0)
RS-HC7 11/19/02 1700
RS-HC8 11/14/02 ND(lO0)
RS-MN1Z 11/18/02 220
RS-MN2B 11/15/02 ND(lO0)
RS-MS2.5C 11/14/02 ND(lO0)
RS-MS3A 11/15/02 ND(lO0)
T9A 11/20/02 1 40
TIOA 11/20/02 ND(lO0)
T16A 11/19/02 ND(lO0)
WIP-W2A 11/19/02 ND(lO0)
WIP-W3A 11/20/02 50000
WIP-W4A 11/20/02 ND(lO0)
Notes:
ND(0.5) ND(l) ND(l)
ND(l) ND(2) ND(2)
ND(0.5) ND(l) ND(l)
ND(O.5) ND(I) ND(l)
ND(0.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(1 ) ND(1 )
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(!)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(l) ND(2) ND(2)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(0.5) ND(1) ND(l)
280 6 590
ND(50) 280 5100
ND(0.5) ND(l) ND(l)
110 2300 160
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) 1.2
77 4.9 1.5
280 1 40 1700
280 56 540
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(0.5) 16 130
ND(0.5) ND(l) ND(l)
0.53 ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(O.5) ND(l) ND(l)
ND(2.5) 5.1 ND(S)
ND(O.5) ND(1) ND(l)
ND(O.5) ND(l) ND(l)
ND(0.5) ND(l) ND(l)
ND(lO0) ND(200) ND(200)
ND(0.5) 1.3 ND(l)
ND - Indicates Not Detected at the detection limit shown in parentheses.
ND(l)
ND(2)
ND(l)
ND(l)
· ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)'
ND(l)
ND(l)
ND(l)
ND(2)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
NO(l)
180
ND(l)
ND(l)
ND(I)
ND(5)
7900
ND(l)
360
ND(l)
ND(l)
ND(l)
3.6
190
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
87
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
5.7
ND(l)
ND(l)
ND(l)
ND(200)
ND(l)
ND(l)
ND(2)
1.5
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(2)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(I)
33
25000
ND(l)
ND(I)
ND(l)
1.8
10
1100
1600
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(1)
13
ND(l)
ND(l)
ND(l)
ND(200)
1.9
ND(l)
130
1,3
2.3
7.4
4.4
ND(l)
47
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(lO)
ND(l)
ND(l)
1.7
ND(5)
ND(lO0)
ND(l)
N0(25)
ND(l)
ND(l)
ND(l)
ND(l)
ND(25)
ND(20)
ND(l)
ND(l)
NO(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
ND(l)
84000
ACCESS - rptGroundwater Quarterly_Table 2a Page 3 of 3
Table 2b. 4th Quarter - Water Supply Well Analytical Results, Shell Oil Products, U.S.
Gasoline Range Ethyl-.
Sample Organics Benzene Toluene benzene
Sample ID Date (pg/L) (pg./L) (pg/L) (pg/L)
o-Xylene
(pg/L)
m,p-Xylene
(IJg/L)
MTBE
(pg/L)
0-3 11/14/02 ND(lO0) ND(O,5) ND(l) ND(l) ND(l) ND(l) ND(l)
D-6 11/14/02 ND(lO0) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
I-1 11/14/02 ND(lO0) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
I-2 11/14/02 ND(100) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
I-3 11/14/02 ND(100) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
I-6 11/14/02 ND(lO0) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
I-9 11/14/02 ND(100) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
1-12 11/14/02 ND(100) ND(0.5) ND(l) ND(l) ND(l) ND(l) ND(l)
Notes:
ND - Indicates Not Detected at the detection limit shown in parentheses.
ACCESS - rptGroundwater Quarterly_Table 2b Page 1 of I
Table 3
4th Quarter - Quality Assurance Results
Shell Oil Products U. $.
Well ID
B-001U
B-008
B-041L
B-044M
B-100L
B-103L
B-117M
B-130U
B-131L
B-! 62U
B-168L
B-175M
B-176U
B-181U
MS2.5A
PW-U4
RS-DP6
B-201
B-202L
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
MS
MS
MS
MS
MS
MS
Sample Type
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
EB
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCD
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
LCS
MS
MS
MS
MS
MS
MS
Sample Date
11/19/02
11/15/02
11/I 8/02
I 1/18/02
11/14/02
11/12/02
11/2O/02
11/13/02
11/12/02
11/18/02
1 !/12/02
11/19/02
11/15/02
11/20/02
11/20/02
11/14/02
11/19/02
12/30/2002
12/30/2002
11/17/02
11/18/02
11/19/02
11/20/02
11/21/02
11/22/02
1 !/24/02
11/25/02
11/26/02
11/27/02
11/30/02
12/01/02
12/02/02
11/17/02
11/18/02
i 1/19/02
11/20/02
11/21/02
11/22/02
1 !/24/02
11/25/02
11/26/02
11/27/02
11/30/02
12/01/02
12/02/02
11/17/02
11/I 8/02
11/19/02
11/20/02
11/21/02
11/22/02
Units
%REC
%REC
OAREC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
%REC
TPHG
<100
<I00
<100
<100
<100
<100
<100
<100
<100
<I00
<i00
<100
<100
<100
460
<100
<100
<100
<100
93
96
96
102
85
95
107
94
109
93
99
106
99
99
107
88
99
93
87
BENZENE TOLUENE
<0.5 <I
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <!
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0.5 <1
<0;5 <1
<0.5 <1
98 97
101 98
96 99
99 97
94 98
109 109
99 109
92 99
92 98
100 102
99 98
100 98
98 99
97 95
94 98
i12 111
93 109
99 98
93 99
100 101
90 88
95 94
98 95
99 96
96 88
ETHYL BENZENE o-XYLENE p/m-XYLENE MTBE
<i <1 <1 <1
<1 <1 <I <1
<1 <1 <1 <1
<l <l <l <l
<1 <1 <1 <I
<l <l <l <l
<1 <1 <1 <!
<l <l <l <l
<l <l <l <l
<! <l <l <l
<l <l <l <l
<l <l <l <l
<l <l <l <l
<l <l <l <l
<l <l <l <l·
<l <l <l <l
<l <l <l <l
<l <l <l <l
<l <l <l <l
_ -- -- 93
.... 95
.... 95
...... 96
.... 97
-- -- -- 99
_ -- -- 99
.... 97
..... 96
..... 102
.... 96
-- -- -- 94
..... 94
.... 95
..... 97
..... I00
.... 92
..... 98
.... 95
.... 99
..... 81
..... 85
..... 87
...... 84
.... 80
TAME
89
91
9O
92
97
102
102
94
93
100
90
89
89
92
95
104
91
95
92
97
78
81
82
82
91
ETBE
95
96
98
99
89
108
108
98
96
104
96
95
96
98
90
107
95
98
96
103
83
86
89
88
88
DIPE
93
97
97
104
87
118
95
94
102
96
97
98
103
87
119
94
96
94
101
83
89
92
93
90
TBA
94
97
81
84
76
91
91
95
103
97
98
89
82
82
96
103
96
74
87
'95
74
83
85
86
75(4)
Well ID Sample Type Sample Date Units
MS MS 11/24/02 %REC
MS MS 11/25/02 %REC
MS MS 11/26/02 %REC
MS MS 11/27/02 %REC
MS MS 11/30/02 %REC
MS MS 12/01/02 %REC
MS MS 12/02/02 %REC
MSD MSD 11/17/02 %REC
MSD MSD 11/18/02 %REC
MSD MSD 11/19/02 %REC
MsD MSD 11/20/02 %REC
MSD MSD 11/21/02 %REC
MSD MSD 11/22/02 %REC
MSD MSD 11/24/02 %REc
MSD MSD 11/25/02 %REC
MSD MSD 11/26/02 %REC
MSD MSD 11/27/02 %REC
M SD M SD 11/30/02 %REC
MSD MSD 12/01/02 %REC
· MSD MSD 12/02/02 %REC
Notes:
'--' = indicates not analyzed
'<' = indicates not detected above reporting detection limit
'*' = indicate multiple analytical results:
Maximum detected value used for detects.
Minimum reporting detection limit used for non-detects.
Maximum sample date used.
Qualifiers:
(3) MS/MSD compound out of control-marl'ix interference
(4) MS/MSD RPD out of control-maUix interference
Table 3
4th Quarter - Quality Assurance Results
Shell Oil Products U. S.
TPHG BENZENE
-- 113 112 ~
97 93 98 ~
86 94 99 ~
98 93 98 --
-- 100 101 --
108 -- -- ~
97 -- -- --
107 91 88 --
91 95 93 --
a_. 99 97 --
-- 93 98' --
-- 94 98 --
-- 112 111 --
100 93 99 --
86 93 98 --
80 92 99 --
-- 102 102 --
106 ....
99 -- -- --
TOLUENE ETHYL BENZENE o-XYLENE p/m-XYLENE
MTBE
99
96
109'
93
100
83
87
90
89
95
98
88
91
90
101
TAME
101
100
99
90
96
79
82
84
85
92
101
92
96
88
97
ETBE
108
107
111
95
102
84
88
91
92
86
108
97
99
92
104
DIPE
124
96
98
94
101
84
91
95
96
85
120
97
95
91
103
TBA
94
81.
121
97
101
74
85
91
85(4)
78
88
' 86
81
92
97
Page-I of I
FIGURES
H:\Projects\SHELL\Bakersfi eld\Final\077-030~Report0 I\RPTO 1 .doc
0 2000 ft.
SCALE
from U.S.G.S. 7.5 MIN. QUADRANGLE
GOSFORD, CA 194-9, PHOTOREVISED 1969
AND OILOALE, CA 1954. PHOTOREVlS£0 1968
~ FIGURE 1
SITE VICINITY MAP, SHELL BAKERSFIELD
~ REFINERY AND SALES TERMINAL, BAKERSFIELD,
TdHydro
Corporation CALIFORNIA
920 Sheddan Stme~
Laramie. Wyoming 820}'0
DrawnBy: BW l Checked By: JR I Scale: ASSHOVVN I Date: 01113/03 J Reference: 077USGSSlTE
L.__]
/i°
ROSEDALE HIGHWAY
CHARI'P( AVENU[%~tC-R'~UiTVAL£ ¢.XTiCNSiON)
AREA 94,
¸OO
oO,
AREA 91
STREET
._i)
EXPU4NA T/ON
.... PROPERTY BOUNDARY
AREA 92
o
o~
?.
AREA 95
(""1 OOO O 0
000
00000
00000
O O O oooo
90'
II
TriHydro
Corpo-r~tl~h
920 Sheridan Street
Laramie, Wyoming 82070
Drawn By: DS I Checked By: ,~R,11 Scale:
0 600 ft.
SCALE
FIGURE 2
SITE PLAN,
SHELL BAKERSFIELD REFINERY,
BAKERSFIELD, CALIFORNIA
1"= 600' I Date: 01/30/03 J Reference: 077SlTEPLAN
'x%xX --- (._ _. ', /' ..r~B-L15:7
L_ ~: ~ I~ , "% ~-~.~ ~ _~ Cd _ --~ ' - ~- B-'lr6'4'U ~-Bm+62~. ~. , -~ - ~
~ -~ .... --' ~ ~ ~ , L~ i--Pi ~' LJ ' ' .... ~' ~ ~2 - -: .... ~ ~ ,
2 ' ' ' ' .....,' i
. '~ [ a C: 16.45 ~ ~ ~] ia
310.35
I
~- I ~---- LINE OF EQUAL EL~ATION OF
"-- ~ ~" ~'~ (~ i i POTENTIOM~RIC SURFACE
;... , __, ,,,j~ . __ _ % --~ .. ~ doshed where inferred; hochures
: - .... -" ~' [,'/ -. .................... :~-.~ ..... ¢~ .~)~:~ ._j~ ~ delineete depressions in the
.~ ~ DIRECTION OF GROUNDWATER FLOW
~! bgs BELOW GROUND SURFACE
Il 290.82 ~ 290.07 ~; ~
, b~-n~ ~ J ~ '--
289 3~ ~ CB- 10~ ....... ~-'-/ ..........
I .~ ~'~'Y ~ ~ / ./
l
D~, ~ ~ / /' --'V
'/~:~/ I' %. I_Z:' ' -'" ;[:
B- 1 0 M ~. ' ~.~:::~*~: ~:~ ~ ~ r SCALE
, ~ PW-E28 ~' ~ ~ ~ ~ E'
' ¢ 292.22 I ' ~=
~ ~ .I ~ ,,,
I~ uu ~ C "~:::::-I ~' il~ ..... ~ ......... :~ ~::::~--¢: ~ ~ ,_
' ~ ,," ' " .............. =~ ...... - ....... ,- i FIGURE 3
i ' -' ....... ~'~/7. '
, , I . a , U,! ..... POTENTIOMETRIC MAP FOR GROUNDWATER
i I : ~ ,~,' ~; j~ L~ ~ '.~:.=~ ,.,- ~ Jj, _.~.~ ~<110'bgs, SHELL BAKERSFIELD REFINERY,'
' ~ ,~'. ', -=~+ ~.- ~ ......... ~'~' ' ..... ~" ._~ I Irl.y=ro
i I : -~' - . . ':-Z --. - - ~' ;: ~ ~ ' ~ Corporation ~1 BAKERSFIELD, CALIFQRNIA
(November
December
I
2002)
I- · ~-Ii i ~ i = ~ i.i ~ '-:~--; --~'- .... :~ , : I Laramie, Wyoming 82070 '}
B-1 6~M
\' 290.3
~- ....... ' _B- f~TM
286.72
/ eB- 1 3OM
/ 288.19
eB- 1 29M
289.95
I
I-
I-
I'
291.52'~'
ROSE,
126M
I
B-165M
297.89
' 300.l
/
128M
304.12
B-131M )M
288.19
B-196M
291.43
290.4
i290.58
eB-O99L RS-MN1Z,
288.4~ 289.28
]4L
LO7 :
! .3 ~ . -.~ ....
I
i 3A
' 6
. 296.41
!
RS-P6-~
290,99
AREA 92
/'
AREA/~'I
I OL
318.33
!
I
A~NI. IE
B- 1 28M
· 304.12
a, EW-09
-....--312-- '-"'
bgs
EXPLANA ?~ON
MONITORING WELL AND NAME
(showing potentiometric-surfoce
elevation in feet above mean
sea level)
EXTRACTION WELL AND NAME
LINE OF EQUAL ELEVATION OF
POTENTIOI~IETRIC SURFACE
(in feet above mean sea level;
dashed where inferred; hachures
delineate depressions in the
potentiometric surface)
DIRECTION OF GROUNDWATER FLOW
BELOW GROUND SURFACE
PROPERTY BOUNDARY
0 600 ft.
I i I
SCALE
FIGURE 4
P, OTENTIOMETRIC MAP FOR GROUNDWATER
~ 1110'- 140' bgs, SHELL BAKERSFIELD REFINERY,
TriHydro / BAKERSFIELD, CALIFORNIA
Corporation
920 Sheridan Street (November - December 2002)
Laramie, Wyoming 82070
By: BW I Checked By: KH Scale: AS SHOWN I Date: 01/29103,I Reference: 077PS1102M
Drawn
~ ' L' 1 D 29255 , - 'i ' ~ .......... (, ~ / ~ , (showing potentiometric-surface
elevation
feet
above
meon
/
/
j / /, _.7, j ". I i J ~'~29e'471ij .... J~J¢~ Z~ '-I z[ -,'-- ' ,EW-07 EXTRACTION WELL AND NAME
//
-(:~ i~0 POTENTIOMETRIC SURFACE
J .... i : --'; ~- potentiometric surface)
~ L2
: 284.38 j i ' L.._~ ~ 292 2 " " '"~ ~ ' -~,~',~'~"-
*' =OTENTIOMETRIC MAP FOR GROUNDWATER
>140' bgs, SHELL BAKERSFIELD REFINERY,
___ BAKERSFIELD, CALIEORNIA ............
....... (November 2002)
d y: KH Scale: AS SHOWN J Date: 01129103 J Reference: 077PS1102L
B-167U
B-1 71 U,
<1
B-1 TO,M:
EW-04 ~'~;
B- 1 g 6 U ·. l "' '~-= ........ =:=~"
t-180U·
,, B ~'1,8'.1U
11
B-170U
B-04¢M,
<1
B-187LJ.
~--~110 .,
<1
B-100M
· ·
B-105M
<1
DP2
I
,i
B-104M
1
AREA 92
MS2.5A
<100
4S B-050~t
i 1.7
<1
B-'150M
<1
~ AR~ 94
B-O01U
130
AVENUE
I
AREA 91
B-121M
<1
: ! I
I
B-116M
· 9~30
<11]
~,REA 90%
!
B-121M
.EW-08
MTBE
bgs
~g/L
£XPLANA T/ON
MONITORING WELL AND NAME
(showing MTBE concentration
in micrograms per liter)
EXTRACTION WELL AND NAME
LINE OF EQUAL METHYL TERT-
BUTYL ETHER (MTBE)
CONCENTRATION (in pc~/L;
doshed where inferred)
METHYL TERT-BUTYL ETHER
BELOW GROUND SURFACE
MICROGRAMS PER LITER
PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN jug/L.
<1
N
600 ft.
i I
SCALE
TrlHydro
- - Corporation
920 Sheridan Street
Laramie, Wyoming 82070
Drawn By: DS J Checked By:
FIGURE 6
MTBE PLUME CONTOURS
FOR GROUNDWATER <110' bgs,
SHELL BAKERSFIELD REFINERY,
--BAKERSFIELDr CAEIFORNIA ...........
(November - December 2002)
JL
~'0S£ D~L.~ HIC HWAY
.J
B-126M
®B~ 150M
B-129M*
B-lg6M
¢1
EXTENSION )
B-OSOL®
<1
B-178M
'11o
eB-115L
<1
<1
B-O99L
·
·
B-11¢L
<'1
RS-MN 1Z ®
<1
B- 100L
· ·
-~103L
I ·
~ RS-BW4
!
i~TIO4L·
!
!
!
'F
! RS-MN2B
~ RS-DP7
RS-MS3A
RS-DPt5
B-O24U
<1 ·
RS-MS2.5C®
<'1
;-DP6 /
<1 eT__ -~ 9.8
AREA 92
i
5~.oo I:M
AREA 91
-'i
<1
!
B- 108L
90
!
!
TrlHydro
920 Sheridan Street
Laramie, Wyoming 82070
Drawn By: DS J Checked By: JR
EXPLANA ?ION
B-IO8L
MONITORING WELL AND NAME
(showing MTBE concentrotion
in microgroms per liter)
AEW-O9 EXTRACTION WELL AND NAME
~!---- LINE OF EQUAL METHYL TERT-
BUTYL ETHER (MTBE)
CONCENTRATION (in pq/L;
dashed where inferred)
MTBE METHYL TERT-BUTYL ETHER
bgs BELOW GROUND SURFACE
flg/L MICROGRAMS PER LITER
PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN jug/L.
0 600 ft.
I ~ I
SCALE
FIGURE 7
MTBE PLUME CONTOURS
FOR GROUNDWATER 110' - 140' bgs,
SHELL BAKERSFIELD REFINERY,
__BAKERSEIELD,_CALIEORNIA ................
(November - December 2002)
Scale: 1" = 600' I Date: 01129/03 J Reference: 077MTBEll02M
-- ' ....... , EXPLANA T/ON
'r':. ?'.": ..... j.. _. :t..' -:' ;;i7' ;[, '7 : '-~'J :f "2:':' ' ] '- " ' -':':7~1' ,-12
., m O<1
:-¥'i ~-'~:T, : i ;: ._.f .. ..... :: ..... ].; .... -.. "-'] :- WATER SUPPLY WELL AND NAME
/ /'//~' : ~ ¢' :~ ~n .... "; o ~ ' ~ <' , ~~;I E .' i gMTBE METHYL TERT-BU~L ETHER
/J /.' : ~ ........... :->=,-:-. ..... u~ 8 ' '- ~~ ..... J:::L ........ I ~g/L ~ICROORA~S PER LITER
//-
....,: ,_, .... ....
CHCRI A~ ~E ._L~ i
'. ..... .- ~ ~ , t J , ___,, : ,. ~k~ ALL CONCENTRATIONS SHOWN IN ~g/L.
._j V , ' - k ~ ' '~ ..... · L, ~-~ · ~ a_ ~, ~-
,~- ....... k*-~] , ~-~4,%M~-~4 ~-~ m~b~-=~-- ~ v~q:=~ ~ ...... ~.~. · ,.,~-~. ~ , .~.,...~~..., , ~ ............. .... ~--I~
, .~3-------. .... ~- . <: ~ ~--- ~. ~J ,' ' i ·
I . ~~ ~F= ~-'F'-~ ~tE -- !1 .... ~ ,, ~ ;,~ .
I ' ~ " ~' JE~''~ ~ ".N ~--'"'~
J : ....... J~ ' ' t ,. , ;il, . ', ' ~2~ :. :~ '. : :: ~ .'" ~ '1-~ //..:'1 SCALE
I ' ~ ~ 'll '~ 'ii '~' bi - ~ .- ' ~,~ ~ '~ , f ! [ ' "I~1 ' S , '
' _ .......... ~ ~ ~: , FIGURE 9
~ ~ MTBE RESULTS FOR
, ~- ...... :-- ...... ~ xx ...... ,~ ~, ~.. . . ,~, ,. ~ .... ~ .i NEARBY WATER SUPPLY WELLS,
~ J ' : .... '~=<~ ~"i I TrlHydro SHELL BAKERSFIELD REFINERY,
..... ~ ............................. ~- - : ,,,,~. ,,, :,. ~,~,~ . ,', - !'l ....................... ~oratio.- - ~l~flfkOr~lkl~O~ll
, ' ; ~ '~ -:~.i *::,' ,..." , 920 s~.~., s~, (November 2002)
I
' :' - ..... '/ :/~ Drawn By: DS J Checked By: JR I S~le: 1" = 600' I Date: 01~9~3 I Reference: 077MTBEH1102
<0.5
B- 130L2 eB- 1 30L1
<0.5
· :eB-151L1
: <0.5
BiS 166L
· <0.5
ieB-O07
<0.5
B-017
<0.5
I eB_010
<0.5
B-O52L ·
<0.5
~ 23
RS-DP4
<0.5
<0.5
80Le-"], :'-~B-181L
<0.5 \ ~. _...'
CHARITY A'~'ENU~-~FRUFP4AI F EXTE~NSION)
B-171L
<0.s
<0.5
B_~75~u
<0.5
B-173L
<0.5
<0:5 '
AREA 92
<0.5
B-009
B-O24Le
<0.5
187L
<0.5
B-O03
<0.5
AREA 9~-
AREA 91
C STREET,
;q
77,, U";
16o
B-.~ 77M.
420 .~
B-;1771
B-023
17.5U
2,400
0<2~0
Be- 1.1 6L
AREA 90':'
!
RFFIN£RY A','~NU E ~
eB- 128L
<0.5
EXPLANA l/ON
MONITORING WELL AND NAME
(showing benzene concentration
in micrograms per liter)
AEW--07 EXTRACTION WELL AND NAME
~ 1---' LINE OF EQUAL BENZENE
CONCENTRATION (in p<~/L;
doshed where inferred)
bgs
~g/L
BELOW GROUND SURFACE
MICROGRAMS PER LITER
.... PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN t~g/L.
600 ft.
I I
SCALE
TrlHydro
----C~flO--~--
920 Sheridan S~eet
Laramie. Wyoming 82070
Drawn By: DS I Checked By: JR II Scale: 1" = 600'
FIGURE 12
BENZENE PLUME CONTOURS
FOR GROUNDWATER >140' bgs,
SHELL BAKERSFIELD REFINERY,
BAKERSFIEI-D;-GAI-IFORNIA-
(November 2002)
I Date: 01129/03 I Reference: 077BEN1102L
B-167U
B-171U,
<0.5
'\ 4S
ifa, B- 17OM, 1 ~ <o.5 B-05OM<o.5
<0.5 ~-u- B- 170U -'150M
EW-O¢ Ic <0.5 <0.5 ,= ;~ ..-
B-001U AR~ ~*
<0.5
'~,I 178U
' B-044M "
,,
B-187U,
<0.5
,- ...... ", T
<0.5 ~ ,. ....... F:~ B-195U·
~ ' ¢_-_-' oi <0.5
· B-115M e B-05:
<0,5 <0.5
<0,5
B-O99M~
·
I-114M
<0.5
7
<0.$
B- 100M
103M
DP2
I
<0.5 D3 .e
~, <0,5
B-030N '~R'6 ~1 d~ 77 ~ I'
AREA 92 o~ ~'~ "3 ,~
3-111M
4,3
AREA 91
B-121M
t C STREET,
~440
AREA 90'
AVENUE
TrlHydro
----Corporation- '
920 Sheridan Slreet
Laramie, Wyoming 82070
Drawn By: DS I Checked By: JR
EXPb~NA flOfl
eB-121M
<0,5
MONITORING WELL AND NAME
(showing benzene concentrotion
in microgroms per liter)
· EW-08 EXTRACTION WELL AND NAME
.-----1--' LINE OF EQUAL BENZENE
CONCENTRATION (in laC~/L;
deshed where inferred)
bgs BELOW GROUND SURFACE
pg/L MICROORAMS PER LITER
PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN ~ug/L.
600 ft.
i I
SCALE
FIGURE 10
BENZENE PLUME CONTOURS
FOR GROUNDWATER <110' bgs,
SHELL BAKERSFIELD REFINERY,
BAKERSFIELD,-CALIFORNIA
(November - December 2002)
B-167L ,~,
<1 B,.-=_ 1 66L
7-
B=1150L2 eB ~-11 50L1
B-1 29L1 ·
<1
B-131L1
<1
B-196Le
<1
".LIB_-_ 128L
:1
, B-176M
LJ
B-126L ~, ',
CHAR~¥¢ AVEt, IUE'"(¥RuITVALE EX.'~Nfi~ON)
B-171L
<1 ~!175U
:3.1
B-173M ~
1.6
B- 175L
B- 124L <1
<1
B-188L
<1
B-003
<1
AREA
AREA
c STREDr
· <,50
<1
· <1
AREA 92
<5¸
1,,16L
'i
AREA 90'
!
EXPLANA T/ON
· B~128L MONITORING WELL AND NAME
(showing MTBE concentration
in micrograms per liter)
.EW-O7 EXTRACTION WELL AND NAME
~I---' LINE OF EQUAL METHYL TERT-
BUTYL ETHER (MTBE)
CONCENTRATION (in pg./L;
doshed where inferred)
MTBE METHYL TERT-BUTYL ETHER
bgs BELOW OROUNB SURFACE
/Jg/L MICROGRAMS PER LITER
.... PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN pg/L.
B-O52L ·,
i
m: '~ B-O1 1
I
RS-DP4 & <1
: B-014·
, ,TOO7
i · } .... ';-- · -
I
B-O1 7 ~
i <1 ,
. ',,"
J
- B-O24L· j
.J '%T
-j
AREA 93
<1
B-O09
|mmmmmm mmmm. mm
,?
!
TrlHydro
--Corporation--
920 Sheridan Street
Laramie, Wyoming 82070
Drawn By: DS 1 Checked By: JR
0 600 ft.
SCALE
FIGURE 8
MTBE PLUME CONTOURS
FOR GROUNDWATER >140' bgs,
SHELL BAKERSFIELD REFINERY,
BAKERSEIELD,_CALIEORNIA
(November 2002)
LScale: 1"=600' ~129103 iReference: 077MTBEll02L
<0.5
Bi~166M
EW-03* ·
· B- 130M <0.5
<0.5
B- 126M
<0.5 ~
B- 1 29 M·
<0,$
B-196M
<O.S
B-171M
"='~ <0.5
:'" <0,5
B- <o.5125M 8ti <0.5
" ~'i B- 187M
! j~ <0.5
· 1,~._ ~-:: ~ B-195M
.. L ~-~ <0.5 i <0,$
B-050Le
<0.5
B - 0 0 I:M AR~ ~a
<0.$ 94.
,B-178M <0.5
i-DP6 '
'~ RS-MN 1Z .4/
0,53
AREA 92
-- r 5RD AVENUE ~J
· B-1 15L ·E
:<0.5
<O.S ~
B-099Lj
·
oB-1 1¢L ~
<O,S ;
<O.S ! <0,5
I/
'0
AREA 91
!
STREET
<0.5
Fq
R E'FINE~' A~NUE ~
TrlHydro
- --cifloh---
920 Sheddan S~t
Laramie. W~min9 ~?0
Drawn By: DS I Checked By: JR
EXP/_,4N,,4 T/ON
B-108L
i 7.2
MONITORING WELL AND NAME
(showing benzene concentrotion
in microgroms per Ii[er)
~EW-09 EXTRACTION WELL AND NAME
LINE OF EQUAL BENZENE
CONCENTRATION (in /Jq/L;
deshed where inferred}
bgs BELOW GROUND SURFACE
lag/L MICROGRAMS PER LITER
.... PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN pg/L.
600 ft.
I I
SCALE
FIGURE 11
BENZENE PLUME CONTOURS
FOR GROUNDWATER 110' - 140' bgs,
SHELL BAKERSFIELD REFINERY,
BAKERSFIELDFCAUFORNIA
(November - December 2002)
, S~le: 1"= 600' i Date: 01~9~3 I Re~mn~:
0~BENll02M
,,/
RO S ED,~,LE HICNWA¥
I-6:q ,: ,i_,/1'_-9
-Z<°'5,
,,<tl._~ ' '~
CHARITy AvENu~¢(FR. UrtVALE £XF~NSION)
! ~ ? ~- <, .....0 <0.5
,,. <0.5 --"
I--2
AREA
AREA 92
AREA 93
AREA 91
TriHydro
--Corporation--
920 Sheridan Street
Laramie. Wyoming 82070
Drawn By: DS [ Checked By: JR
EXPLANA 1-ION
1-12
0 <0.5
WATER SUPPLY WELL AND NAME
(showing benzene concentration
in microgroms per liter)
jug/L MICROGRAMS PER LITER
.... PROPERTY BOUNDARY
NOTE:
ALL CONCENTRATIONS SHOWN IN pg/L.
0 600 ft.
I 1 I
SCALE
FIGURE 13
BENZENE RESULTS FOR
NEARBY WATER SUPPLY WELLS,
SHELL BAKERSFIELD REFINERY,
BAKERSFIELD,-CALIFORNIA
(November 2002)
Scale: 1" = 600' I Date: 01129/03 I Reference: 077BENH1102
/
_J
i
HIGHWAY
C ~Rli'r' AVENU~FRUITVALE EX'I'~NS ON)
B-198L
B- 197L/M
.B-049 L/ivi/U i0 0
o00
IB"=-048L/M/U E~
AREA 94
mB-O47L/M/U ~. ~
· m B-074L/
AR-----------------CA 91
C ~TREET
._[1
o8
,,~- ~ g ~L/M/U.,
· B- 193L/bl/U
mB- 192L/M/U
mB- 191L/M/U
· B- ~ 90L/M/!.
· B- 189L/M, ~<
O-078L/M/U m
AR~ 92
B-01
AREA 93
· '{3
B-039L/bl/U
AV~.NUE 0 j
000 O O
000
00000
00000
0 0 0 ooooo
~ B-O9¢L
:,. ..... , u?' ':--- '
90
1
TriHydro
--Corporation ....
920 Sheridan Slmet
Laramie. Wyoming 82070
Drawn By: DS I Checked By: JR
E,,,vpL~N,4 Z/ON
mB-°97L/u/u AIR SPARCING WELL AND NAME
.... PROPER'FY BOUNDARY
0 600 ft.
I I I
SCALE
FIGURE 14
AIR SPARGING WELL LOCATIONS,
SHELL BAKERSFIELD REFINERY,
BAKERSFIEL-D;-C-AL-IFORNIA
Scale: 1' = 600' I Date: 01/30/03 I Reference: 077ASWI=I I $