United States
Environmental
Protection
Agency
Office of Water Office of Solid Waste EPA
Regulations and and Emergency 530-SW-87-005C
Standards (WH-552) Response
Washington, D.C. "jJfQ'J?9*011' D'C> V
20460 20460 Y
. I
&EPA
TECHNICAL REPORT: APPENDIX C
ft
EXPLORATION, DEVELOPMENT, AND PRODUCTION
CRUDE OIL A
TURAL GAS
USEnvifonmentatPfOtectiorv Agency
Region 5. Library (Pl-I2J)
77 West Jackson Boulevard, ion
Chicago, IL 60604-3590
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APPENDIX C
SAMPLING REPORTS
VOLUME 1
U.S. Environmental Protection Agency
Region 5, Library (PL-12J)
77 West Jackson Boulevard, 12th Floor
Chicago, It 60604-3590
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TABLE OF CONTENTS - VOLUME 1
Paqe
INTRODUCTION '. 1
ALABAMA 5
Investigation of Separation and Filtration Enterprises
(SAFE), Incorporated, June 12 and 13, 1986, Mobile . . 7
ALASKA 41
Investigation of Standard Alaska Production Company's
Gathering Center 2 (GC2), August 1, 1986, Prudhoe Bay . 43
Investigation of Standard Alaska Production Company's
Drill Pad G, Well No. G-30, August 2, 1986, Prudhoe Bay 57
Investigation of ARCO Alaska, Inc.'s Drill Site 3N,
August 3, 1986, North Slope 73
Investigation of Marathon Oil Company's Trading Bay
Production Facility, August 7, 1986, Cook Inlet .... 107
Investigation of Union Oil Company's Kenai Gas Field
Production Site 41-7, August 8, 1986, Kenai 133
CALIFORNIA 183
Investigation of Sun Exploration and Production
Company's Oxnard Oil Handling Facility, July 14, 1986,
Oxnard 185
Investigation of Shell California Production, Inc.'s
Central Water Treating System, July 15, 1986, Ventura 203
Investigation of Shell California Production, Inc.'s
River Bottom Unit Gosnell Well No. 51, July 15, 1986,
Ventura 225
Investigation of McFarland Energy, Inc.'s Section 24
Production Facility Midway Sunset Oil Field, July 16,
1986, Kern County 247
Investigation of Shell California Production, Inc.'s
Gore C Lease Oil Well No. 50-3P Midway Sunset Oil
Field, July 16, 1986, Kern County 265
COLORADO 295
Investigation of E-Vap, Limited, July 11, 1986, Greeley 297
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TABLE OF CONTENTS - VOLUME 1 (Continued)
Page
KANSAS 313
Investigation of Cindy Van Dyke's Gentry Lease Well
No. 2A, July 1, 1986, Montgomery County 315
Investigation of American Energies Corporation's
Munsell F Well No. 1, July 7, 1986, Pendennis 333
Investigation of DaMar Resources, Incorporated's 9067
Randa Well No. 1, July 7, 1986, Hays 351
Investigation of Ritchie Exploration, Inc. and Cross
Wind Petroleum, Inc.'s Keith Garrett Well No. 1,
July 8, 1986, Wakeeney 365
Investigation of Oil Producers, Inc. of Kansas' Ott
Well No. 2, July 9, 1986, Wakeeney 381
KENTUCKY 411
Investigation of Maverick Production, Inc.'s Glassco
Lease Well No. 1, August 21, 1986, Henderson County . . 413
Investigation of Ecus Corporation's Gamblin Lease
Production Facility, August 22, 1986, Hopkins County . 435
LOUISIANA 453
Investigation of FMP Operating Company's S/L 195 No. 2
Oil Well, June 14, 1986, Plaquemines Parish 455
Investigation of Sun Exploration and Production
Company's Sweetbay and Bateman Lake Tank Battery No. 2,
June 16, 1986, St. Mary Parish 493
Investigation of Mobil Oil's Bayou Blue Production
Facility, Jun 17, 1986, Iberville Parish 517
Investigation of Westland Oil Development Corporation's
Joseph Earl Bajoie No. 1 Oil Well, June 17, 1986,
Pointe Coupee Parish 535
MICHIGAN 557
Investigation of Wolverine Gas and Oil Company, Inc.'s
Hanover 7 Central Production Facility, July 29, 1986,
Jackson County 559
Investigation of Sun Exploration and Production
Company's Cameron Lease Well No. 1-10, July 30, 1986,
Gladwin County 579
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TABLE OF CONTENTS - VOLUME 1 (Continued)
Investigation of Powell Production, Inc.'s Savarino and
Stoll Well No. 6-21, July 31, 1986, Hillsdale County . 619
TABLE OF CONTENTS - VOLUME 2
NEW MEXICO 637
Investigation of Basin Disposal, Inc., Jun 25, 1986,
Bloomfield 639
Investigation of Amoco Production Company's USG
Section 18 Well No. 43, Jun 26, 1986, San Juan County . 715
Investigation of Cities Service Oil and Gas Corpora-
tion's State E Lease, June 27, 1986, Lea County .... 745
OKLAHOMA 761
Investigation of Ward Petroleum Corporation's Rowe
Lease Well No. 1-20, June 26, 1986, Grady County . . . 763
Investigation of George Kahn Operating Company's Mary
Allen Tank Battery, Jun 27, 1986, Oil Center 793
Investigation of Royce Kelly's Centralized Disposal
Pit, June 29, 1986, McClain County 309
PENNSYLVANIA 827
Investigation of Franklin Brine Treatment Corporation,
September 3, 1986, Franklin 829
Investigation of Mark Resources Corporation's Hazlett
Well No. 1, September 4, 1986, Venango County 855
TEXAS 867
Investigation of Exxon Company, USA's Hawkins Field
Unit Well No. 1210, June 19, 1986, Wood County .... 869
Investigation of Mobil's C. W. Belcher Lease Production
Facility, Jun 20, 1986, Talco 886
Investigation of Murexco Petroleum, Inc.'s Frye Lease
Oil Well No. 1-29, June 23, 1986, Wheeler County . . . 925
Investigation of Chevron USA, Inc.'s W. V. Lister No. 1
Gas Well Production Facility, June 24, 1986, Wheeler
County 999
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TABLE OF CONTENTS - VOLUME 2 (Continued)
Page
UTAH 1015
Investigation of Meridian Oil Company's Navajo-Federal
Well No. 23-4, June 29, 1986, San Juan County 1017
Investigation of Marathon Oil Company's Tin Cup Mesa
Well No. 1-25, Jun 30, 1986, San Juan County 1031
Investigation of Wexpro Company's Island Unit No. 27,
July 2, 1986, Uintah County 1077
WEST VIRGINIA 1099
Investigation of Scott Oil Company's Garvin Lease Well
No. S-614, August 19, 1986, Jane Lew 1101
WYOMING 1123
Investigation of Diamond Shamrock Exploration Company's
Myers State Well No. 41-16, July 13, 1986, Gillette . . 1125
Investigation of Amoco Production Company's LACT No. 4,
July 14, 1986, Midwest 1147
Investigation of Waste, Incorporated1s Lawrence Brown
Disposal Lagoon, July 15, 1986, Uinta County 1173
Investigation of Sun Exploration and Production
Company's Luckey Ditch Fed B Well No. 4, July 16, 1986,
Uinta County 1189
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INTRODUCTION
This appendix is comprised of Sampling Reports for each site
visited during the field sampling portion of this Project. There
are 46 reports, including 44 Sampling Reports and 2
Reconnaissance Reports.
The reports in this appendix are grouped together by state, and
are arranged chronologically within each state. The states are
arranged in alphabetical order.
Three sites were visited that are not among the Sampling Reports
in this appendix. These sites were sampled by a team from EPA's
Office of Research and Development Environmental Research
Laboratory (ERL) in Gulf Breeze, Florida, in cooperation with the
Louisiana Department of Environmental Quality. The ERL
performed the sampling at these sites in a cooperative effort
designed to provide both ERL and this Project with needed data.
The ERL is testing the applicability of existing aquatic
toxicological test procedures, using produced water as the test
medium. Therefore, all the sites visited by the ERL team were
specifically selected production facilities. Sampling was
conducted according to the protocols described in the Sampling
Plan and Sampling Quality Assurance/Quality Control Plan in
Appendix G. Sampling Reports are not included for these sites
because, at this time, the operators have not reviewed the
information to be included in the reports.
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All reports in this appendix include the following topics: SITE
SELECTION, SITE LOCATION, ATTENDEES, SITE DESCRIPTION, DISPOSAL
PRACTICES, and PERMITS. Sampling Reports include the following
additional sections: SAMPLING INFORMATION, SAMPLE POINT
LOCATION, and SAMPLING METHODS AND EQUIPMENT. Attachments to the
reports include photo documentation of sampling activities,
copies of drilling or operating permits, and miscellaneous
information provided by the site operators and state officials
regarding the sample site.
Draft copies of these Sampling Reports were sent to each of the
site operators for their review and clarification of specific
details within the reports. The reports in this appendix reflect
the comments returned by the operators.
Finally, the following notes are included to clarify .the contents
of the Sampling Reports:
o Most information regarding sample site characteristics
was provided by the site operators. Exceptions to this
include measurements made by the sample teams, such as
pit dimensions and liquid and sludge depths. Unless
otherwise noted, all remaining quantities are estimates
provided by the operators.
02
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o Terms such as "brine tank", "slop tank", and "free
water knockout" are used in the Sampling Reports as
they were used by the site operators and state
officials. Use of the word "brine", for example, does
not indicate that the produced water at a particular
site was chemically classified as a brine. The words
"brine," "produced fluid," and "produced water" are
used interchangeably in the Sampling Reports because of
the manner in which operators and state representatives
used these terms in the field.
o Documents provided by state officials and site
operators, such as permits and laboratory reports, were
often provided in the form of photocopies. The clarity
of such documents reproduced in the Sampling Reports is
typically poor.
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ALABAMA
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Sampling Report
Investigation of Separation and Filtration
Enterprises (SAFE), Incorporated
Mobile, Alabama
June 12 and 13, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). The selection was based on personal
communication with the Alabama Department of Environmental
Management. At the request of EPA, the Department of
Environmental Management identified four facilities treating oil
and gas wastes in Alabama. Of the four sites, Separation and
Filtration Enterprises, Incorporated was the only site actively
treating wastes available during the sampling time frame. Thus,
it was selected.
Site Location
SAFE, Inc.'s centralized waste treatment facility is located on
the southwest end of Pinto Island at the mouth of the Mobile
River as it empties into Mobile Bay. Figure 1 is a map
indicating the plant site. The mailing address for SAFE, Inc.
is:
Separation and Filtration Enterprises, Inc.
P.O. Box 1691
Mobile, Alabama 36633
205-428-4028 or Baton Rouge, LA 504-293-7107
The property is leased from Alabama Dry Dock and Shipbuilding
Company (ADDSCO).
Attendees
Sampling at the SAFE, Inc. facility was performed by CENTEC
Corporation personnel on June 12 and 13, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
EPA Representative: Susan de Nagy, Office" of Water,
Project Officer
State Representative: Edgar Hughes, Alabama
Department of Environmental
Management, Industrial
Branch, Water Division
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Operator Representatives: Jay Simon, Vice President SAFE,
Inc.
Doug Staub, Operations Manager
Site Description
SAFE, Inc. is located in a suburban, coastal area where the depth
to groundwater is between 0 and 25 feet, and the nearest surface
water is at the boundary of the property. The soil in this area
is mostly sand. The climate at this site location is net
precipitation.
The site consists of a 400-foot pier, 4.4 acres of land, a
warehouse, and a concreted process area. Figure 2 is a plot plan
of the SAFE, Inc. facility, showing the waste treatment area in
relation to the adjacent barge slip and pier. At the time of
sampling, the area northwest of Pier X (right of Pier X in Figure
2) was occupied by a semisubmersible drilling rig that was docked
for repairs. This rig appears in photographs taken at the time
of sampling, located in Attachment A.
One of SAFE, Inc.'s storage barges was in the slip, as shown in
Figure 2 and Photos 2, 3, and 4. This barge was full of drilling
waste and was therefore sampled. The other storage barge was
moored to Pier X, and was not in use at the time of sampling.
The operations manager's office is located in the warehouse,
north of the waste treatment area, and is visible in the
background of Photo 3.
Process Description
The following process description is also illustrated in a
simplified process flow diagram, Figure 3. Both the description
and the diagram were provided by SAFE, Inc.
"Material can be received by barge or by truck.
Holding tanks and barges supply the surge capacity
needed for fast turnaround. The customer barge will be
secured along the 400-foot dock. The content will be
circulated as much as possible using a submersible
pump. The material will then be pumped to the process
or to a permanently moored (10,000 bbl) barge. If
additional storage capacity is needed, a second barge
will be utilized. Dock space will not be a problem
since the dock is 400-feet long with access to both
sides.
"From the holding barge, the mud is pumped through
shaker screens for cuttings removal and into a 450
barrel mud tank. To allow continuous feed to the mud
tank, batches are fed to the clarifier for pH control
and flocculation.
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Figure 2. Schematic of Treatment Facility
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_" PLOT PLAU
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LAUD FILL
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SEUUER
Figure 3. Flow Diagram of Treatment Process
JUG.
LE, AL^.
JAkJ. 2i , ' 985
PROCESS FLOLU
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"The solids from the clarifier are pumped to a
separator feed tank, which are continuously fed to the
system. Conditioning of sludge takes place prior to
the separator to ensure maximum de-watering. A
bladeable solid is conveyed from the discharge of the
unit to a solids holding area.
"The liquid streams from the clarifier and the
separator are pumped to a process tank which feeds the
final filter. The final filter is set up to
continuously filter liquid while adding material to
prevent blinding. The filter capacity is in excess of
300 gpm which far exceeds the anticipated flow rate.
The oversize filter will also allow for low-solids
material to bypass the separator and efficiently
increase the capacity of the plant.
"The water is then pumped to the city sewer for final
treatment. Solids are trucked off to the municipal
landfill for disposal."
The facility is designed to operate 24 hours per day, 365 days
per year, although the market has not demanded such operation as
yet. The daily capacity of the facility is 1,500 to 4,000
barrels of waste, depending on the properties of the mud
(particularly its density).
The State of Alabama does not permit the discharge of any wastes
from drilling rigs located in State waters. The wastes must be
hauled to shore for treatment and disposal. Therefore, the
proximity of SAFE, Inc.'s clientele is within a 50-mile radius.
In addition, SAFE, Inc. accepts only water-based drilling muds
and associated drilling wastes.
The price schedule for waste treatment at SAFE, Inc. is based on
the density of the incoming material. The draft of the barge is
used to calculate the weight of the material. The material's
volume is measured from each compartment of the barge before
pumping starts. The weight and volume measurements are then used
to derive the overall density of the material. The density is
then used to determine the price per barrel of material
processed.
Permits
Permits and approvals obtained by SAFE, Inc. to properly operate
the waste treatment facility include the following:
o Alabama Department of Environmental Management (ADEM)
State Indirect Discharge (SID) Permit allowing
operation of the facility and discharge into the City
sewer, issued April 1, 1985.
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o The Board of Water and Sewer Commissioners of the City
of Mobile approval to discharge into the sewer system,
dated March 4, 1985.
o The Certificate of Need from the Mobile County
Commission authorizing the handing of the solids, dated
March 11, 1985.
o City of Mobile, Alabama Department of Flood Plain
Management Construction, and Engineering Services
building application for facility construction, dated
March 20, 1985.
o ADEM Solid Waste Section, Land Division approval to
utilize any of four local landfills, dated April 15 and
June 4, 1985.
Copies of these documents are located in Attachment B.
The ADEM State Indirect Discharge permit sets discharge
limitations and monitoring requirements for the water leaving the
facility. A copy of the discharge limitations and monitoring
requirements as presented in the SID permit is located in
Attachment C.
The ADEM approval to utilize local landfills for disposal of
solid waste includes the following four conditions:
"1. An analysis (E.P. Toxicity) of the mud from each
Company must be submitted to this office prior to
disposal.
"2. A certification from the generator that the mud is
non-hazardous must be submitted to this office prior
to disposal.
"3. The mud must be dewatered/solidified to a bladeable
consistency.
"4. Trucks hauling the mud shall be secured to prevent
spillage en route to the disposal site."
To fulfill the analysis requirements for disposal of solid waste,
SAFE, Inc. samples and tests each incoming barge for E.P.
Toxicity and other analytes. Figure 4 is a laboratory report
listing the results of tests performed on barge samples, as
ordered by SAFE, Inc.
A copy of the waste shipping control ticket used by SAFE, Inc. at
the points of transfer of solid waste between generator,
transporter, and disposer is located in Attachment D.
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I Lu I h. J. h.
-r •::•: P •.<:
PHON.B
MARCM 13, 19t?o
SAFE. I PC. -
MOBILE, ALABAMA
SAMPLES COLLECTED & TRANSPORTED B'/ EA^E, INC.
SAMPLE I.D.: BARGE # WGH 73
SAFE SAMPLE tf WGH 7C-9
VOLUME HANDLED: 5,509 k?L3,
AET PROJECT NO.: 10012
ANALYTICAL
PARAMETER RESULT
PHYSICAL CHARACTARISTICS
COLOr' (DESCRIPTIVE) GREY
FLASH POINT > 145 F
ODOR (DESCRIPTIVE) KEROSENE FUZ_
pH 10.1 £TL '.'I'-:
PHYSICAL STATE @ 70F LIC1UTD SL'.'l - '
SPECIFIC GRAVITY i . 1 c
CHEMICAL ANALYSIS sr.z. i T
AMMONIA 12.C
BOD 101
COD 11,. : :.
CHLORIDE 116';
Ci'ANIDE
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EAFE, ir-C.
MOBILE, .'.LA'dArVi
AET
PC.
PARAMETER
ANAL/TICAI-
RES ULT
EP TOXICITY ANALYSIS
ARSENT C
BARIL',1
CADMIUM
CHROMIUM
CHROMIUM-HEXAVALENT
LEAD
MEPCL1' /
SELEN:MM
SILVER
mg/1
<0.05
8.97
0. 01
0. 33
<0. 05
0.12
O. O03
••"0.05
0. 05
IhE
DATE
1 <~ '
!-!
hi'j; •
RDH
^'DM
PDH
KPH
r •.:•'•-,
I-.L:
^_(
10
9
12
4
3
1 1
S
9
O U D 'Tl
30 c-in
10 an-!
15 p m
00 pm
15 p m
30 am
** ^-
*• w.' - ,Ti
25 am
Oi /30
'.^ *_ / ^ J -'
02/<..3
01 / "3
02 / 1 1
01/31
0 1 / 0 7
01/31
02/03
ALL OF THE ABOVE TESTS WERE PERFCRr-ZD AS CuTi.I[.;£!• IN THE U.S. E.P.A
"METHODS FOR CHEMICAL ANALYSIS OF t-'ATER A. IL> k'iTjTES," 1~33, AND
"STANDARD METHODS FOR THE EXAMINATION OF W.-'-TEK ,-."D t-.-^TEl-'ATER. " 1985.
CERTIFICATION:
H. f -.li LE',1/
CSIEF IMEM 1ST
Figure 4. Laboratory Report on Barge
Samples (Continued)
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SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At SAFE, Inc., the influent liquid sample was defined as the
combined supernatant and solid contents of the waste material in
the holding barge. The effluent liquid sample was defined as the
stream discharging to the Mobile Publicly-Owned Treatment Works.
The point at which this stream was accessible to sampling was the
flow to a storage tank located upstream from the metered effluent
line. The sludge sample was obtained from the dry mud area (see
Figure 2) where mud collects in a concreted holding area prior to
removal by truck.
Figure 5 indicates the measured sample points as well as the
actual sample points from which the barge sample was composited.
The northeast end of the barge was covered with sheet metal that
made it possible to sample very near the measured sample points
at that end (Photos 2 and 3). Note that sampling shown in Photo
3 is done through a 6-inch gap in the cover. The southwest end
of the barge was accessible only from the side, so that the
actual sample points are closer to the sides than to the measured
quadrant centers.
Figure 6 indicates the measured and actual sample points in the
dry mud area from which the sludge sample was composited. The
differences between measured and actual sample points were also
the result of limited accessibility. Both Figure 6 and Photo 5
show the retaining wall that was used to obtain samples from the
northeast end of the area. The southwest end was accessed by
standing on wood planks placed on the solids pile and reaching as
close to the desired sample points as safely possible.
Sampling Methods and Equipment
The first sample to be collected was the effluent liquid. To
obtain this sample, a one-gallon glass container was held under
the flow from the input pipe to a water storage tank. In
Photo 1, the input pipe is shown slanted down from left to right
into the storage tank. Also shown in Photo 1 is the sample being
poured from the 1-gallon container to the 5-gallon compositing
carboy.
The next sample to be collected was the barge contents, which was
in distinct liquid and solid phases. After measuring the barge,
the covered end was sampled first with the thief, then with the
coring device. A 6-inch opening in the barge cover made it
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Figure 5. Measured vs. Actual Sample Points
Holding Barge
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KEV
o : M«
Figure 6. Measured vs. Actual Sample Points:
Dry Mud Area
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possible to lower the sampling equipment to the barge contents.
The surface of the liquid was approximately 10 feet below the
cover. The uncovered end of the barge was sampled in the same
manner as the covered end, except that the samplers stood on the
edge of the barge and reached in to get samples (Photo 4). The
liquid and sludge were composited in the steel bucket.
The last sample collected was the sludge from the dry mud area
(Photo 5). The average depth of the mud was 2 feet. The coring
device was used with a 5-foot extension rod attached. The
sampler stood on the retaining wall at the northeast end of the
area and on wood planks at the southwest end. The mud was thick
enough that a core catcher in the end of the glass core sleeve
was not necessary. The mud was composited in the steel bucket.
The first two samples were collected on June 12, 1986. The last
sample was collected the following day, June 13, 1986 because
sampling on June 12 was not completed before 7:00 PM.
The liquid and sludge samples were tested onsite for pH after
sampling was completed. The pH was 8 for all samples.
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
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Photo 1. Pouring liquid sample composite
Photo 2. Holding barge
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Photo 3. Sampling through cover over NE end of barge
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ATTACHMENT B: PERMITS
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ALABAMA DEPARTMENT OF EJA'IRON^ENTAL MANAGEME!I7
STATE INDIRECT DISCHARGE PEP.M1T
Ir. accordance with the provisions of the Alaba-a Water Pollution
Control A.ct, as amended, (Code of Alahana 1975, £§22-22-1 to 22-22-U; the
"State Act") and the Alabaca Environmental Management Act (Code of Alabama
1975 $$22-22A-l to 22-22A-13; the "State Act") and rules and regulations
adopted thereunder;
f.AFE, Inc.
, Alabama
(hereinafter, ."the permittee") is hereby authorized to discharge industrial
wastes resulting from treatment of drilling] waste.
to waters of the State through Publicly Owned Treatment Works (hereinafter,
"POTV") located at McDuffie Island
in accordance with the monitoring requirements and other terms and conditions
set forth herein.
This permit and the authorization to discharge shall expire at midnight
on March 31, 1990.
Issued this 1st day of April, 1985.
By:
a-.a7 Department of Environmental Management
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The Board of Vrater and Sswer Commissioners
cJ tit
City of Mobile
P. O. BOX 236S
MOBILE. ALABAMA 36652
March 4, 1985
Kr. G. P.
Safe, Inc .
P. 0. Box
Theodore,
Dear Mr. Stu.*rdi:
36590
ye jare writing you in regard to you and your
engineers' r"e
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C- REVcWUE
FRAK'CHISL TAX DIVISION
MONTGOMERY. AL 36130
FOR THE YEAR ENDING DECEMBER 31. 19E5
CORPORATION PERMF
This is 1o certify that Ihe corporation shown has caicJ tns
Alabama Department o? Revenue as reouired. by Tide 4D-14-21
or 40-U-22 CoOe cl Aiifcama 1975. This permit is therefore
issued a-'tnorijmp the aomp of business in the State ot Ala-
bama by sard corporation tor Ins eoove year and is subject
to trie terms and conditions ol said code.
TOM
JAMISC.U-H1TE, SR.
Coaoittioner
FK 1*2196
SEPARATION' C FILTRATION ENTERPRISES, INC.
10*: ST. JOSEPH ST., STE. 325
KOBILC, AL
36602
II a check has been accepted in payment of this permit and such check is not paid. THIS PERMIT IS VOID.
MOBILE COUNTY COMMISSIONERS
MOBILE COUNTY, ALABAMA
P.O. Box 1443
Mobile, Ala. 36633
CERTIFICATE OF NEED
FOR
Hauling
CERTIFICATE
NO.
97
(Type ol Operation)
This certifies that.
SAFE. Inc.
(Name ol Company)
Owned or operated hy Separation Systems, Inc. John R. Dyas & G. TR. Stuardi
100 St. Joseph Street, Mobile, AL 36602
at
has submitted the information
as required under Act #81-450, and the County Commissioners of Mobile County has found such
documents to conform with the laws and regulations as provided for in this Act. It is further declared
that the services to be performed do not violate the requirements of this Act.
this llth day ot _ March 1 9 _8.5
Certificate expires
March 1JD 19 86
Cooniy
ol Mobile Cour-.ty/Alatama
C/29
This ;'s not a Permit To Opersle This Service
, Chairman
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err; or ,"02114:-, AL.'IBAKA
Di?>.r.Trj::iT or •-• \ .
FLOOD PLAK> <"""J ACE.KEN7, CONSTRUCTION
AND L^CINEEKING SERVICES
/rr, I CATION FOR
LAI"' »,,slti»ans.
Applicant's
Telephone Number
Authorized Representative
Telephone Number
Street Address
Site Location
City
State
Zip Coe
Application Approved By:
SignaFure^7
City Engineer
Permit above applied for (will)(will not) comply with the Mobile Zoning
Regulations.
By:
Zoning Examiner
Refer to construction plans on file in City Engineer's Office and in
Inspection Services prepared /°r compliance with Ordinance 65-045 and
accompanying standards. It is required that-a licensed Professional
Engineer certify to Inspection Services that this project has been
completed in conformance with plans approved by the City Engineer prior
to receiving a Certificate of Occupancy.
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ALABAMA
DEPARTMENT OF ENVIRONMENTAL MANAGEMENT
April 15, 1985
p Addrrsi:
Capital
Montgomery. AL
3613C
20S/53*-1303
F.cld Oflicei
P. 0 Box 9i3
Dccalui. AL
3SC.02
Unit 806. Building 8
225 Oimoor Circle .
Birmingham, AL
35709
20S/9<2-6168
4358 Midmost Drive
Mobile, AL '
- *9
43-7841
Mr. Jay A. Simon, V.P.
SAFE, Inc.
P. 0. Box 15203
Baton Rouge, LA 70895
Dear Mr. Simon:
We have reviewed your request to dispose of drilling mud
at the Chunchula and Dirt, Inc. landfills in Mobile County and
the Magnolia landfill in Baldwin County. We have also discussed
your request with Ms. Sonja Massey of the Water Division of ADEM.
We are approving the disposal of drilling mud by SAFE, Inc.
at the above landfills under the following conditions:-.-
1. An analysis (E. P. Toxicity) of the mud must be submitted
to this office prior to disposal.
2. A certification from the generator that the mud is non-hazardous
must be submitted to this office prior to disposal.
3. The mud must be dewatered/solidified to a bladable consistency.
4. Trucks hauling the mud shall be secured to prevent spillage
enroute to the disposal site.
We want to point out that it is the responsibility of SAFE,
Inc. to insure that only non-hazardous mud is hauled to any of
these sites. You should also contact the Baldwin and Mobile County
Commissions concerning disposal at the Magnolia and Chunchula
sites. Mr. Lamar Harrison of Dirt, Inc. should be contacted concerning
disposal at his landfill in Theodore.
If you have any questions or if we can be of further assistance,
please contact us.
Sincerely,
(Jack" Horfeycut^., Chief
Solid Waste Section
Land Division
JH:sl
cc: Honorable Clarence Pishop, Chairman-Baldwin County Commission
Kr . Gurnpy Owens, Kobife" Bounty
"r . !.a:r.ar Harrison, Dirt, Inc.
1 C ^O
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; i. v.
June 4, 1985
OF I^
'Vi... ' .v
' Dt
203 3J3-1713
Unit £C6. Ei-!a.:ig 8
225 Oxnio-jr Circle
Birmmghf.i. AL
35209
205 3'.2-6168
4353 Midmost Drive
"obile, AL
09
—,5,'343-7841
Mr. Jay Simon
SAFE, Inc.
P. 0. Box 15203
Baton Rouge, LA 70895
Dear Mr. Simon:
This office recently revised Mr. Lee Jackson's Landfill Permit
No. 49-]7R thereby authorizing him to accept drilling mud for
disposal. The landfill is located-on Lott Road in Mobile County.
Pursuant to your telephone request, wetwill approve the disposal
of drilling mud by SAFE, Inc. from Exxon, :Shell and Mobile Oil
Companies at the Lee Jacksonrlandfill under the following conditions:
1. An analysis (E.P. Toxicity.). of the mud from each Company
must be submitted to this Office prior to disposal.
2. A.certification from the generator that the mud is non-hazardous
must be submitted to this office prior to disposal.
3. The mud must be dewatered/solidified to a bladable consistency.
4. Trucks hauling the mud shall be secured to prevent spillage
enroute to the disposal site.
I want to again point out to you that it is the responsibility
of SAFE, Inc. to ensure that only non-hazardous mud is hauled
to the Lee Jackson or any other landfill within the State.
You should contact Mr. Lee Jackson concerning delivery schedules,
fees, etc.
If you have any questions, please contact us.
Sincerely,
Jack Honeycutt, Chief
Solid Waste Section
Land Division
JH:sl
cc: Mr. Lee Jarkson
Mr. Gurney Owens
Mr. Jamos Fibbo
\ 0 8 1335
C-3 2
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ATTACHMENT C: DISCHARGE LIMITATIONS PRESCRIBED
BY SID PERMIT
C-33
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i
U)
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IMschar Serial Number: 001 - Total Facility Discharp-
Discharge Limitations
Ibs/day inP»/l (except as noted)
Monitoring RCCJU I rements
l-'low
Total Suspended
Solids
Arsenic, total
Cadmium, total
Chromium, total
Chromium, hexavalun
Lead, total
Copper, total
Nickel, total
011 and Crease
Cyanide, total
lonthly Avg. Dally Max.** ^Monthly AVR. Dally Max.''*
80,000 GPD
150
1.0
0.2
— — — 1.0
ten -- — — 0.2
-7 — — 0.2
1.0
1.0
100
1.0
Frequency
Dally
2/week
2/week
2/week
2/week
2/week
2/week
2/week
2/week
2/week
2/week
Sample Type
Meter or Recorder
Grab
Crab
Crab
Crab
Crab
Crab
Crab
Crab
Crab
Crab
n Uncontdininated stormwater and non-contact cooling water shall not be discharged to the POTW.
t_n
The pH ^hall not be less than 6.0 i-i-Jnrc! units nor nore than 9.5 standard units and shall be ran! cored
-.--.i : -..: ,ttl. -_y grab sa:-,;.le.
Samp Jl up, locution for discharge: After final treatment but prior to mixing with the contents of the s .1 \\ i t.. ry
sewer or any other wastewater.
"The arithmetic average of all sample results from a given calendar month monitoring perloi!.
A-:The ma:;lmum value ohtalncd for any single sample.
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ATTACHMENT D: WASTE SHIPPING CONTROL TICKET
C-37
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WASTE SHIPPING CONTROL TICKET
Part I: TO BE COMPLETED BY GENERATOR
Company Name
Business Address __J^^^~~~"^^^~~~^^^~~~~~~~~~~~~~"~~~~~~
Telephone Number "^^^^^^~~~~~~~~
Originator of Was"telArea: Well;
OProduction Facility O Drilling Operations
Description of Waste:
Quantity of Waste:
DESTINATION:
Disposer's Name
Business Address
CERTIFICATION: The waste described above was consigned to the
carrier named below. I certify that the foregoing is true and
correct to the best of my knowledge.
Signature of Generator's Authorized Agent Date & Time of Shipment
Part II: TO BE COMPLETED BY TRANSPORTER (NOTE:To be completed in presence of
Generator, before removing Generator's copy)
Transporter's Name
Business Address
Telephone Number
License Plate of Truck
License Plate of Trailer
If Transported by Barge, Barge and Tug Identification
CERTIFICATION: I certify that the waste in the quantity above and the
description in Part I was received by me for proper disposal.
Signature of Transporter's Agent Date & Time Received
Part III: TO BE COMPLETED BY DISPOSER
Disposer's Name
Disposal Site Address
Telephone Number
License Plate of Truck
License Plate of Trailer
If received by Barge, Barge and Tug Identification
Quantity of Waste Received:
CERTIFICATION: I certify that the waste in the quantity above and the
description in Part I was received by me for proper disposal.
Signature of Disposer's Agent Date & Time Received
DISTRIBUTION: Original: Disposer's Copy for Report to Permit Agency
Green: Generator's 2nd. Copy
Yellow: Disposer
Pink: Transporter 3^
Golden Rod: Generator's 1st.Copy
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ALASKA
C-41
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C-42
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Sampling Report
Investigation of Standard Alaska Production Company's
Gathering Center 2 (GC2)
Prudhoe Bay, Alaska
August 1, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical-
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of North Slope Basin production sites developed by EPA
Region X Alaska .Operations Office at the request of EPA. The
list was transmitted via telephone to the EPA contractor on July
22, 1986. Site selection from this list took place during the
telephone conversation.
EPA Region X Alaska Operations Office preferred to list the
possible sample sites as shown below. The EPA contractor had no
interest in the manner the particular sites were listed (by site
name, location, operator, permit number, API number, etc.) as
long as the site could be identified in detail upon selection.
Thus, the EPA contractor had minimal information which kept to a
minimum the amount of bias. No other information was known about
the sites on the list at the time of selection. Detailed
information was obtained only after selection of primary and
back-up sites. The list consisted of three North Slope Basin
production sites:
1. CPF 1
2. CPF 2
3. GC 2
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 3 on the above list (GC 2) was selected as the primary sample
site. No. 2 on the above list (CPF 2) was selected as a back-up
site should sampling at the primary site prove inaccessible or
inappropriate. A second back-up site was selected by default as
a precautionary measure.
Sampling of GC 2 (Gathering Center 2) was scheduled on August 2,
1986. Due to difficulties arising from the attempted sampling of
Pad F (see "Site Selection" of the trip report of Standard
Alaska's Drill Pad G) and at the request of Standard Alaska, the
sampling of GC2 was rescheduled on August 1, 1986. The back-up
sites were not required.
C-43
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Site Location
Gathering Center 2 is located 15 miles northwest of Deadhorse,
AK. Figure 1 is a map locating the production site.
The site is operated by Standard Alaska Production Company, whose
mailing address and telephone number are:
PO Box 196612
900 East Benson Boulevard
Anchorage, AK 99519-6612
907-659-4362
Contact Name: Dale Calven
Attendees
Sampling of Gathering Center 2 was performed by CENTEC
Corporation personnel on August 1, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (Sample Team):
EPA Representatives:
Operator Representatives:
American Petroleum
Institute Representatives:
Site Description
Bruce Hoskins, Team Leader
Susan de Nagy, Office of Water,
Project Officer
Ted Rockwell, Region X, Alaska
Operations Office
Randy Hammack, Operations
Supervisor
Lynn Billington, Standard
Alaska Production Co.
Jim Collins, Observer
Arden Ahnell, Observer
Bob Zahray, Contracted Sample
Team Member
Gathering Center 2 is located within the North Slope Basin in an
area characterized as rural coastal tundra. The depth to
groundwater is approximately 1,800 feet, and the nearest surface
water is less than 1/2-mile away. There are no drinking water
wells within a 25-mile radius of this site.
This site consists of actively producing oil and gas wells with
an average total production of 300,000 bbl/day oil and 350
million SCF/day gas. Water production at this site is 65,000
bbl/day. Production at this site is sweet. There are 56
individual flow lines entering the facility. The average well
depth is 12,000 feet. The site is producing using primary and
secondary techniques. Primary production is accomplished with
C-44
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WEST DOCK
PRUDHOE B A '
UK DEAD ARM C\
(TRACTION ARE*
Figure 1. Location of Gathering Center 2, North
Slope, Alaska
C- 45
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both natural and artificial drive. Water and gas flooding is
also used as secondary production.
Figure 2 is a schematic diagram of the production facility. The
flow lines feed into a -dehydration chamber and then into a series
of settlers and a slug catcher. At the slug catcher, emulsi-
fiers, corrosion inhibitors, scale inhibitors, and antifoamants
are added. The water line from the slug catcher combines with
the water removed from the dehydration chamber and is fed into a
skimmer; here, biocide X-cide 105 is added.
Disposal Practices
From the skimmer, the water goes to booster pumps and is then
sent to injection pumps. The water is injected as its final
disposal.
Permits
No facility permit was available to the sample team at the time
of sampling. It is unknown whether a permit is required for this
facility.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Gathering Center 2 consisted of two
liquid samples, one before oil separation and one after
separation. The samples were collected at valves in the process
flow lines designated for grab sample collection.
Sampling Methods and Equipment
The sample bottles were filled directly from the valve at the
direction of the EPA Project Manager. There was no photo
documentation for this site as the facility was indoors and
facility representatives did not allow the taking of photographs
with a flash.
Both liquid samples were tested onsite for pH and free chlorine
content after completion of sampling. For both liquid samples,
pH was 8 and free chlorine was less than the lowest detectable
level of 0.2 ppm.
C-46
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n
I/VHIBITOR
3
CATCHERS*
5ETTLBKS
\HK-T £"R
A
Figure 2. Flow Diagram, Gathering Center 2
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The samples were shipped the day of collection. Sample shipment
from the North Slope required the use of air cargo. A.S a result,
a greater time elapsed between shipment and laboratory receipt
than if overnight mail service had been available. The samples
were shipped to two laboratories: S-Cubed in California and CAS
in Virginia. The shipment to California arrived 4 days after
collection. The shipment to Virginia arrived 11 days after
collection.
C- 48
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-49
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C-50
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No photodocumentation specific to the
operation of this site is available.
C-51
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C-52
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ATTSCHM2NT B: PERMITS
C-53
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No permit specific to the operation
of this site is available.
C- 55
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Sampling Report
Investigation of Standard Alaska Production Company's
Drill Pad G, Well No. G-30
Prudhoe Bay, Alaska
August 2, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active North Slope Basin drill sites developed by EPA
Region X Alaska Operations Office at the request of EPA. The
list was transmitted via telephone to the EPA contractor on July
22, 1986. Randomization and site selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
EPA Region X Alaska Operations Office with input from Alaska
Department of Environmental Conservation, ARCO, Standard Alaska,
and Amerada-Hess listed the possible sample sites by location.
The list consisted of fifteen sites:
1. Drill Site 1
2. Endicotte SDI
3. Endicotte MDI
4. Drill Site 16
5. Drill Site 11
6. Pad F
7. Pad J
8. Pad X
9. Pad B
10. Pad R
11. Drill Site 18
12. Drill Site 3N
13. Drill Site 31
14. Drill Site 1C
15. Pad C
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
C-57
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table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 2 on the above list
(Endicotte SDI). No. 7 on the above list (Pad J) was selected as
a back-up site in the event the primary site was inaccessible or
inappropriate.
A public meeting was held in Anchorage, AK on July 29, 1986,
during which the site selections for the North Slope were
announced by EPA. At the meeting, Standard Alaska voiced
concerns over the selection of Endicotte SDI for sampling because
it is a permitted offshore island. Because of these concerns,
the primary site was deemed inappropriate for sampling by EPA.
On August 1, 1986, the day of scheduled sampling at the back-up
site (Pad J), a meeting was held between Standard Alaska, ARCO,
EPA, EPA Region X, and the EPA contractor. Standard Alaska and
ARCO raised issues regarding the qualifications of the back-up
site as described in the May 5, 1986, draft sampling strategy
document (see Appendix B of the EPA Technical Report [EPA
530-SW-87-005]). At that time, EPA negotiated with ARCO and
Standard Alaska to develop a new list of appropriate sites.
The second list of sites was:
1. Pad F
2. Pad G
3. Pad C
4. Drill Site 11
A second set of primary and back-up sites was selected from this
list. The randomly-selected primary site was No. 2 on the above
list (Pad G) No. 3 on the above list (Pad C) was selected as a
back-up site in the event the primary site was inaccessible or
inappropriate.
Further inquiry identified the primary sample site as the well
No. G-30 of Drill Pad G operated by Standard Alaska. Sampling
was arranged for August 2, 1986.
Site Location
Drill Pad G is located about 12 miles northwest of Deadhorse, AK.
Figure 1 is a map indicating the drilling site.
The site is operated by Standard Alaska Production Company, whose
mailing address and telephone number are:
900 East Benson Blvd.
PO Box 196612
Anchorage, AK 99519-6612
(907) 561-5111
C-58
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. FUTURI
BULL I»L»KO
PRUDHOE BAY
K DEAD ARM <\. ( ^
TDACTION ARE*
Figure 1. Location of Drill Pad G, North Slope, Alaska
C-59
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Attendees
Sampling of Drill Pad G, Well No. G-30 was performed by CENTEC
Corporation personnel on August 2, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team)
EPA Representatives:
Operator Representatives:
Bruce Hoskins, Team Leader
Susan de Nagy, Office of Water,
Project Officer
Ted Rockwell, Region X, Alaska
Operations Office
Jerry Haberthur, Standard Alaska
Production Co. Drilling
Foreman
Lynn Billington, Standard Alaska
Production Co.
Donny Fields, Alaska United
Drilling Co.
Dean Bryan, Mud Engineer,
Macgobar
American Petroleum
Institute Representatives: Jim Collins, Observer
Arden Ahnell, Observer
Bob Zahray, Contracted Sample
Team Member
Site Description
Drill Pad G is located within the North Slope Basin in a rural
area of coastal tundra. The depth to groundwater is
approximately 1,800 feet, and the nearest surface water is less
than 1/2 mile away. There are no drinking water wells within a
25-mile radius of the site. The soil in this area is tundra.
The climate at this site is net evaporation.
This site was a developmental oil drilling site. Well drilling
began on July 23, 1986 with a completion date of August 7, 1986.
On the day of -sampling, the well was at a depth of 9,500 feet.
The final completion depth was 9,772 feet. Drilling was
accomplished with low-solid, lightly dispersed mud. This mud
consisted of bentonite (Magcogel), caustic, carboxy methyl
cellulose, ferrous chrome lignosulfonate (spersene), and sodium
bicarbonate. Chloride concentration in the mud was 400 ppm. Mud
pH was 11.
Figure 2 is a schematic diagram of the drilling site. One large
pit was constructed for the site. The pit was 1,000 feet long
and 300 feet wide. The purpose of the pit was long-term storage.
The pit was unlined and had no special preparation prior to use.
The pit received drilling muds, rig wash-down water, completion
C- 60
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LOCATION MAP
Figure 2. Schematic Diagram of Pad G
06]
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fluids, spent acids, stimulation fluids, produced effluent, and
snow melt. Well G-30 was the fifteenth well drilled at this pad
since May, 1975. It was estimated that the reserve pit consisted
of 80 percent drilling fluids, 19 percent snow melt, and 1
percent associated wastes. The pit area was not fenced. The pit
construction was above grade. Photos 1-6 (in Attachment A) show
the pit and the drilling rig. The facility oil and gas lines
were constructed above the pit surface to ensure that they are
out of the way of the drilling rig during its operations. Figure
3 shows the reserve pit with the flow lines. These pipes have
not leaked any fluids into the reserve pit.
About 30 percent of the drilling muds were disposed by annular
injection; the remaining fluids were piped into the pit. The
liquid depth in the pit was 2-3 feet. The total volume of
drilling fluids for Well G-30 was estimated at 8,000 bbl.
A total of 520 bbl of diesel oil were stored in tanks at this
facility. It was unknown how much waste diesel oil would be
generated. The waste oil would be taken to a recycling facility.
Disposal Practices
The pit was designed for long-term storage of drilling effluents
and eventual disposal of drilling solids. The pit was
constructed during 1974 and 1975. There was no testing of pit
contents, nor was there treatment of pit contents. The pit was
not to be closed at the end of current drilling activities; it
would be closed at the end of the field life (beyond the year
2000).
Permits
No permit was available to the sample team at the time of
sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Drill Pad G Well No. G-30 consisted of
one drilling mud, one supernatant, and one sludge sample. A
partial field duplicate was also taken. Figure 3 shows the
sampled pit and the location of the sample points. Four
C-62
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o
CViTTIMG-S LIA/E
•* i
U
RESERVE ?\T
PIPES
-l--
?0\NT
1000'
Figure 3. Reserve Pit - Drill Pad G
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quadrants were established for supernatant sampling. Sample
points were accessed by boat. There were no discrepancies
between designated and actual sample points.
Sampling Methods and Equipment
The supernatant was sampled from the boat with a sampling thief.
The sludge was collected from the boat with the dredge. Photos
7-9 show the sample collection in the pit from the boat. The
drilling mud sample was collected at the rig. The mud sample
represented fresh mud collected from the current drilling
operation.
The pit supernatant was tested onsite for pH and free chlorine
content after completion of sampling. The pH value was 8 and the
free chlorine content was less than the lowest detectable level
of 0.2 ppm.
The samples were shipped the day of collection. Sample shipment
from the North Slope required the use of air cargo. As a result,
a greater time elapsed between shipment and laboratory receipt
than if overnight mail service had been available. The samples
were shipped to two laboratories: S-Cubed in California and CAS
in Virginia. The shipment to California arrived 2 days after
collection. The shipment to Virginia arrived 3 days after
collection.
C- 64
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-65
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C-66
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f
*-r' "*' V^-'"!''-'-^-?
**£&]]
e*«%3*-*»«.5y*."it1>;« ,ii.« -i*--
fe^«^ifcfS-fj-->—-. •-
•&*f&£&yjxfrC-ii-?-.- .;
***V.v?^ -* T -•**-4
:^i^ ^^Tj^SSSJCW^fc-SSSerr*-/,^ ;* f
^ ; ^
Photos 1,2,3. Drill Pad 6 drilling rig and reserve pit
CTl
Photos 4,5,6.
Drill Pad G reserve p it
-------
Photo 7. Sample collection from reserve pit
O
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en
oo
Photo 8. Sample collection from reserve pit
Photo 9. Sample collection from reserve pit
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ATTACHMENT B: PERMITS
C-69
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No permit specific to the operation
of this site is available.
C-71
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CM
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Sampling Report
Investigation of ARCO Alaska, Inc.'s Drill Site 3N
North Slope, Alaska
August 3, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active North Slope Basin drill sites developed by EPA
Region X Alaska Operations Office at the request of EPA. The
list was transmitted via telephone to the EPA contractor on July
22, 1986. Randomization and site selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
EPA Region X Alaska Operations Office with input from Alaska
Department of Environmental Conservation, ARCO, Standard Alaska,
and Amerada-Hess listed the possible sample sites by location.
The list consisted of fifteen sites:
1. Drill Site 1
2. Endicotte SDI
3. Endicotte MDI
4. Drill Site 16
5. Drill Site 11
6. Pad F
7. Pad J
8. Pad X
9. Pad B
10. Pad R
11. Drill Site 18
12. Drill Site 3N
13. Drill Site 31
14. Drill Site 1C
15. Pad C
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 8 on the above list
C-73
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(Pad X). No. 11 on the above list (Drill Site 18) was selected
as a back-up site in the event the primary site was inaccessible
or inappropriate.
A public meeting was held in Anchorage, AK on July 29, 1986,
during which the site selections for the North Slope were
announced by EPA.
On August 1, 1986, two days before scheduled sampling at Pad X, a
meeting was held between Standard Alaska, ARCO, EPA, EPA Region
X, and the EPA contractor. Standard Alaska and ARCO raised
issues regarding the qualifications of the primary and back-up
sites as described in the May 5, 1986, draft sampling strategy
document (see Appendix B of the EPA Technical Report [EPA
530-SW-87-005]). At that time, EPA negotiated with ARCO and
Standard Alaska to develop a new list of appropriate sites.
The second list of sites was:
1. Pad F
2. Pad G
3. Pad C
4. Drill Site 11
A second set of primary and back-up sites was selected from this
list. The randomly-selected primary site was No. 1 on the above
list (Pad F). No. 4 on the above list (Drill Site 11) was
selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
On August 2, 1986, the EPA sampling team conducted a
reconnaissance of Pad F. Upon arrival onsite, EPA was told that
no sampling of the site would be allowed (see letter from
Standard Alaska in Attachment C).
The EPA sampling team successfully conducted reconnaissance of
Drill Site 11 on August 2, 1986, one day prior to scheduled
sampling. However, on August 3, 1986, the sampling team was
unable to obtain access to the drill site. The rig was being
dismantled (see letter from ARCO Alaska, Inc. in Attachment D).
Given the history of problems associated with locating and
conducting sampling at appropriate North Slope drill sites, the
Agency opted to specifically select a site rather than to attempt
sampling the second back-up site. ARCO Alaska, Incorporated's
Drill Site 3N was selected. Sampling was arranged to be
conducted the same day.
Site Location
Drill Site 3N is located about 50 miles west of Deadhorse, AK.
Figure 1 is a map indicating the drilling site.
C-74
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3 —
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North
C-75
-------
The site is operated by ARCO Alaska, Incorporated, whose mailing
address and telephone number are:
Kuparuk Operations
PO'BOX 6105
Anchorage, AK 99502
(907) 659-2821
Attendees
Sampling of Drill Site 3N was performed by CENTEC Corporation
personnel on August 3, 1986. The following is a list of people
present at the time of sampling:
CENTEC Corp. (sample team)
EPA Representatives:
Operator Representatives:
American Petroleum
Institute Representatives:
Bruce Hoskins, Team Leader
Susan de Nagy, Office of Water,
Project Officer
Ted Rockwell, EPA Region X,
Alaska Operations Office
Charlie Dixon, ARCO Drilling
Supervisor
Al Schuyler, ARCO
Jay Turner, Mud Engineer,
NL Benoid
Jim Collins, Observer
Bob Zahray, Contracted Sample
Team Member
Arden Ahnell, Contracted Sample
Team Member
Site Description
Drill Site 3N is located in rural coastal tundra; the depth to
groundwater is over 100 feet, and the nearest surface water is
less than 1/2 mile away. There are no drinking water wells
within a 1-mile radius of the site. The soil in this area is
tundra. The climate at this site is net evaporation.
This site was a developmental oil drilling site. Nine different
wells (Well Nos. 10-18) were drilled from late March-May, 1986.
Wastes from drilling activities at these wells were placed in the
pit chosen for sampling. The following information was available
for the nine individual wells:
Well 3N-10 was drilled from March 29-April 5, 1986. Well depth
was 9,394 feet. Total drilling costs were [confidential]. Mud
costs were [confidential]. Drilling was accomplished with a
C-76
-------
low-solids, nondispersed polymer mud with the following
components: gel, caustic, quick gel, SAPP, benex, barite,
dextrid, Q-broxin, drespac, and aquagel.
Well 3N-11 was drilled from April 6-14, 1986. Well depth was
8,691 feet. Total drilling costs were [confidential]. Mud costs
were [confidential]. Drilling was accomplished with a
low-solids, nondispersed polymer mud with the following
components: aquagel, benex, caustic, quick gel, gel, soda ash,
barite, SAPP, cellex, drespac, and dextrid. Completion fluids
composed of sodium chloride and sodium bromide were used.
Well 3N-12 was drilled from April 12-22, 1986. Well depth was
8,100 feet. Total drilling costs were [confidential]. Mud costs
were [confidential]. Drilling was accomplished with a low
solids, nondispersed polymer mud with the following components:
gel, benex, caustic, quick gel, aquagel, drespac, SAPP, cellex,
dextrid, thermathin, and condet. Chloride content in the mud was
450-500 ppm. A 400 ppm sodium chloride solution was used as
completion fluid.
/
Well 3N-13 was drilled from April 22-28, 1986. Well depth was
7,792 feet. Total drilling costs were [confidential]. Mud costs
were [confidential]. Drilling was accomplished with a low
solids, nondispersed polymer mud with the following components:
aquagel, benex, caustic, quick gel, soda ash, barite, gel,
cellex,lime, and drespac. Chloride content in the mud was
500-700 ppm.
Well 3N-14 was drilled from April 28-May 6, 1986. Well depth was
7,460 feet. Total drilling costs were [confidential]. Mud costs
were [confidential]. Drilling was accomplished with a low
solids, nondispersed polymer mud with the following components:
gel, benex, caustic, quick gel, aquagel, barite, cellex, dextrid,
drespac, baroid, and thermathin. Chloride content in the mud was
500-550 ppm.
Well 3N-15 was drilled from May 6-12, 1986. Well depth was 8,508
feet. Total drilling costs were [confidential]. Mud costs were
[confidential]. Drilling was accomplished with a low solids,
nondispersed polymer mud with the following components: aquagel,
barite, benex, caustic, quick gel, dextrid, drespac, and cellex.
Well 3N-16 was drilled from May 12-20, 1986. Well depth was
9,189 feet. Total drilling costs and mud costs were not
available. Drilling was accomplished with a low solids,
nondispersed polymer mud with the following components: aquagel,
x-tend, caustic, quick gel, barite, gel, baroid, thermathin, EP
mud lube, lime, defoamant, dextrid, drespac, and Q-broxin.
Well 3N-17 was drilled from May 20-26, 1986. Well depth was
9,005 feet. Total drilling costs were [confidential]. Mud costs
were [confidential]. Drilling was accomplished with a low
C-77
-------
solids, nondispersed polymer mud with the following components:
aquagel, x-tend, caustic, quick gel, barite, gel, baroid,
thermathin, EP mud lube, lime, defoamant, dextrid, drespac, and
Q-broxin.
Well 3N-18 was drilled on May 26-June 4, 1986. Well depth was
10,630 feet. Total drilling costs were [confidential]. Mud
costs were [confidential]. Drilling was accomplished with a low
solids, nondispersed polymer mud with the following components:
aquagel, x-tend, caustic, quick gel, barite, gel, baroid,
thermathin, EP mud lube, lime, defoamant, dextrid, drespac, and
Q-broxin. Chloride content in the mud was 600 ppm.
.Figure 2 is a schematic diagram of the drilling site. Two large
pits were constructed for the site. The purpose of the pits was
for long-term storage. The pits were unlined and had no special
preparation prior to use. The pits received drilling cuttings.
The pit area was not fenced. The pit construction was above
grade. The facility oil and gas lines were constructed above the
pit surface to ensure that if any of these lines leaked, the
leakage would fall into one of the pits.
This rig operated as a nearly alosed system. The drilling muds
were disposed by direct annular injection. The cuttings were
piped into the pits. There was no .discrete liquid surface over a
major portion of the pits. The sludge depth in the sampled pit
was 2-3 feet. The total volume of drilling fluids was estimated
to be less than 2,500 bbl.
A total of 1,500 bbl of diesel oil was stored in tanks at this
facility. Waste oil totaling 589 bbl was generated. The waste
oil was disposed by injection.
Disposal Practices
The pits were designed for long-term storage. There was no
testing of pit contents. There was no treatment of pit contents.
The pits were not to be closed at the end of current drilling
activities. It was unknown when the pits would be closed. The
following injection information was available for Wells 10-18:
Well 3N-10 injected 1,355 bbl mud.
Well 3N-11 injected 3,467 bbl mud, 1,300 bbl water, and 16 bbl
diesel oil.
Well 3N-12 injected 2,743 bbl mud, 300 bbl water, and 26 bbl
diesel oil.
Well 3N-13 injected 4,834 bbl mud, 300 bbl water, and 20 bbl
diesel oil.
Well 3N-14 injected 4,184 bbl mud, 300 bbl water, and 106 bbl
diesel oil.
C-78
-------
O\L£<;A
-------
Well 3N-15 injected 3,979 bbl mud, 300 bbl water, and 28 bbl
diesel oil.
Well 3N-16 injected 9,931 bbl mud, 300 bbl water, and 287 bbl
diesel oil.
Well 3N-17 injected 3,464 bbl mud, 300 bbl water, and 76 bbl
diesel oil.
Well 3N-18 injected 978 bbl mud, 455 bbl water, and 40 bbl diesal
oil.
Permits
Permit applications for Wells 3N-10 to 3N-18 are shown in Attach-
ment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at Drill Site 3N consisted of one pit sludge
sample taken from the eastern reserve pit. Figure 2 shows the
sampled pit and the location of the sample points. Four
quadrants were established for sludge sampling.
Sampling Methods and Equipment
The pit contained a supernatant on only one-half of the pit in
which two of the four quadrants were located. In these
quadrants, the coring tube was not used, since the sludge was too
liquid to remain in the tube. The sludge was collected from the
boat with the stainless steel spoon and bucket in two quadrants.
In the other two quadrants, the sample was collected using the
coring tube lined with Teflon. Photos 1-4 (see Attachment A)
show the sample collection in the pit from the boat. Photos 5
and 6 show the sample collection with the coring tube.
The samples were shipped on the day of collection. Sample
shipment from the North Slope required the use of air cargo. As
a result, a greater time elapsed between shipment and laboratory
receipt than when overnight mail service was utilized. The
samples were shipped to two laboratories: S-Cubed in California,
and CAS in Virginia. The shipment to California arrived 3 days
after collection. The shipment to Virginia arrived 4 days after
collection.
C-80
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-81
-------
C-82
-------
en
01
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-------
Photo 5. Sample collection with coring tube
Photo 6. Sample collection with coring tube
-------
ATTACHMENT B: PERMITS
C-85
-------
o
I
oo
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work Drill Redrill Z,
Re-Entry"Z Deepen C
1b. Type of well. Exploratory _ Stratjgrapnic Test _ Development Oil
Service Z Developement Gas _ Single Zone % Multiple Zone
2. Name of Operator
ARCO Alaska, Inc.
3. Address
'.0. Box 100360 Anchorage, AK
99510
5. Datum Elevation (OF or KB)
RKS 63', PAD 3» '
6. Property Designation
AOL 2SS20 ALK 2556
10. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
4. Location of well at surface
1561'FSL, 105'FEL, Sec.29, T13N, R9E, UM
At top of productive interval
1358'FNL, 1817'FWL, Sec.28, T13N, R9E, UM
At total depth
178'FNL, 196»'FWL. Sec.28. T13N, R9E, UM
7. Unit or property Name
Kuparuk River Unit
8. Well number
3N-13
9. Approximate spud date
0*721/86
11. Type Bond (s»« 20 AAC 250251
Statewi de
Number
*8088-26-27
Amount
$500.000
12. Distance to nearest
property line
105' (8 surf aca_
feet
13. Distance to nearest well
14. Number of acres in property
15. Proposed depth IMO and
7850'MO
'Tun i
feet
16. To be completed for deviated wells
Kickoff depth 23 i»i feet Maximum hole angle ,
17. Anticipated pressure OM 20 AAC 21035 («m>
Maximum surface 2915 ^"^ ** tot1' ^*°tn ^0) 3 3 1* 2
18. Casing program
size
Specifications
Setting Depth
Top
Bottom
Quantity of cement
Hole Casing
Weight Grade Coupling Length
MO
TVD
MO
TVD
(include stage data)
fl V,
I -US
7 fll fi '
HF-ERW
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth:
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
measured
true vertical
Length
feet
feet
Junk (measured)
Size
Cemented
Measured depth
True Vertical deotn
measured
true vertical
20. Attachments Filing fee £ Property plat % BOP Sketch J& Diverter Sketch .S_ Drilling program^
Drilling fluid program ^ Time vs depth plot S3 Refraction analysis Z Seabed report _ 20 AAC 25.050 requirements _
21. I hereby caflify trat the foreggitfg is tfue and correct to the best of my knowledge
Signec
Title
Regional Drilling Engineer
Commission Use Only
(LWK) PO/P0252
Permit Nu*ber
' 86-81
API number
50- 029-21584
Approval date
04/18/86
See cover letter
for other requirements
Conditions of approval Samples required _ Yes XNo Mu<* '°9 required _. Yes
Hydrogen sulfide measures Z Yes Z No Directional survey required X Yes Z No'
Required workingowssureJor^SOP^i—Z2M< If 3M; 1. 5M; Z 10M; Z 15M
Approved by \^ , f, \ iZ&iwktifSt) C-87 Commissioner the commission
Form 10-401 Rev. 12-1-85
triplicate
-------
GENERAL DRILLING PROCEDURE
KUPARUK RIVER FIELD
DEVELOPMENT WELLS
1. Move in rig.
2. Install Tankco diverter system.
3. Drill 12V hole to 9-5/8" surface casing point according to directional
plan.
A. Run and cement 9-5/8" casing.
5. Install and test blow out preventer. Test casing to 2000 psig.
6. Drill out cement and 10' new hole. Perform leakoff test.
7. Drill 8V' hole to logging point according to directional plan.
8. Run open hole logs.
9. Continue drilling 8*5" hole to provide 100' between plug back total depth
and bottom of Kuparuk sands.
10. Run and cement 7" casing. Pressure test to 3500 psig.
11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus.
12. Nipple down blow out preventer and install temporary Xmas tree.
13. Secure well and release rig.
14. Run cased hole logs.
15. Move in workover rig. Nipple up blow out preventer.
16. Pick up 7" casing scraper and tubing, trip in hole to plug back total
depth. Circulate hole with clean brine and trip out of hole standing
tubing back.
17. Perforate and run completion assembly.
18. Nipple down blow out preventer and install Xmas tree.
19. Change over to diesel and set packer.
20. Flow well to tanks. Shut in. .
21. Secure well and release rig.
22. Fracture stimulate.
LWK4/ih
sysrcm
C-88
-------
Spud to
DRILLING FLUID PROGRAM
Drill out
Density
PV
YP
Viscosity
Initial Gel
10 Minute Gel
Filtrate API
pH
Z Solids
9-5/8" Surface Casing
9.6-9.8
15-30
20-40
50-100
5-15
15-30
20
9-10
104
to Weight Up
8.7-9.2
5-15
8-12
35-40
2-4
4-8
10-20
9.5-10.5
4-7
Weight Up to TD
10.3
9-13
8-12
35-45
3-5
5-12
6
9.5-10.5
9-12
Drilling Fluid System;
Triple Tandem Shale Shaker
2 -Mud Cleaners
Centrifuge
Degasser
Pit Level Indicator (Visual & Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Notes:
Drilling fluid practices will be in accordance with the
appropriate regulations stated in 20 AAC 25.033.
Maximum anticipated surface pressure is calculated with
an unexpanded gas bubble at surface, including temperature
effects.
LWK5/ih
C-89
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMto.^SION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request Abandon _ Suspend I Operation Shutdown N Re-enter suspended well I Alter casing I
Time extension I. Change approved program ~ Plugging ~ Stimulate ^ Pull tubing Z Amend order ~ Perforate % Other
^ '
2. Name of Operator
ARCO Alaska, Inc
5. Datum elevation (OF or KB)
68 ' RKB feet
3. Address
P. 0. Box 1QQ360 Anchorage, AK
6. Unit or Property name
4. Location of well at surface
1561'FSL, 179'FEl, Sec.29, T13N, R9E, UM
At top of productive Interval
1381'FSL, 1825'FWL, Sec.33, TUN, R9E, UM (approx.)
At effective depth
1496'FSL, 1874'FWL, Sec.33, T13N, R9E, UM (approx.)
At total depth
1191'FSL, 1996'FWL, Sec.33, T13N, R9E, UM (approx.)
7. Well number
3N-i n
8. Permit number
86-72
9. API number
50—029-21576
10. Pool
Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 9 3 9 if <
true vertical 57291
Effective depth: measured
true vertical
Length
80'
4535'
9271 '
6440'
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
Nona
None
Size
16"
9-5/8"
Casing
Conductor
Surface
Producti on 9365 '
(iZ'cUxwc i
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
Cemented
Measured depth
Conductor report 115'
not available.
1400 sx AS III & 4572 '
315 sx Class C
300 sx Class G &
175 sx AS I
9353
True Vertical depth
115'
3567'
6702'
l2.Attachments Description summary of proposal _
Well History
Detailed operations program _ BOP sketch C
13. Estimated date for commencing operation
May, 1986
14. if proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed df, /7O uMxA^Title Associate Engineer
Date 5-I-8L*
Commission Use Only
(DAM) SA/012
Conditions of approval Notify commission so representative may witness
~ Plug integrity 3 BOP Test Z Location clearance
Approved by
Approval No.
Commissioner
by order of <
the commission Date •
Form 10-403 Rev 12-1-85
C-90
Submit in triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _ Operation Shutdown Re-enter suspended well _ Alter casing ~
Time extension Z Change approved program ~ Plugging Z Stimulate ~ Pull tubing ~ Amend oraer ~ Perforate ' Otner
2. Name of Operator
ARCO Alaska, Inc.
5. Datum elevation (OF or KB)
68' RKB «eet
3. Address
P. 0. Box 100360 Anchorage. AK 99510
6. Unit or Property name
Kuoaruk River U n < t
4. Location of well at surface
1561'FSL, 155'FEL, Sec.29, T13N, R9E, UM
At top of productive interval
1267'FSL, 785'FEL, Sec.20, T13N, R9E, UM (approx.)
At effective depth
1441'FSL, 915'FEL, Sec.20, T13N, R9E, UM (approx.)
At total depth
7. Well number
3N-1 1
8. Permit number
86-77
9. API number
50—029-21580
otal depth
509'FSl, 931'FEL, Sec.20, T13N, R9E, UM (approx.)
10. Pool
Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 8790
true vertical 6648
Effective depth: measured g691
true vertical 65?8
feet
feet
feet
feet
Plugs (measured) None
Junk (measured)
Casing
Conductor
Surface
Production
Length
.80'
4523'
8786'
Size
16"
9-5/8"
7"
Cemented Measured depth
Conductor report 115'MO
not available.
1300 sx AS III & 4558'MD
350 sx Class G
300 sx Class C & 8777'MO
175 sx AS I
True Vertical depth
115'TVO
3643'TVO
6639'TVO
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth)
None
G Detailed operations program i_i SOP sketch ~
13. Estimated date for commencing operation
June, 1986
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed iQmU Axku Title *»•«"". Engineer
Date 5-12-Sb
Commission Use Only
(DAM) SA/028
Conditions of approval
Approved by
Form 10-403 Rev 12-1-85
Notify commission so representative may witness
Z! Plug integrity C BOP Test Z Location clearance
Commissioner
Approval No.
by order of
the commission Date
Submit m triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon I Suspend I Operation Shutdown ^ Re-enter suspended well _ Alter casing .
Time extension ~ Change approved program I Plugging ~ Stimulate I Pull tubing I Amend order : Perforate " Other
2. Name of Operator
ARCO Alaska, Inc.
5. Datum elevation (OF or KB)
68' RKB 'eet
3. Address
0, Box 10(nfifl Anchor-ape. AK 9,*}
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend Z Operation Shutdown J? Re-enter suspended well _ Alter casing ~
Time extension Z Change approved program Z Plugging ~ Stimulate Z Pull tubing Z Amend order Z Perforate ~ Otner
2. Name of Operator
ARCO Alaska^ Inc.
5. Datum elevation (OF or KB)
68* RK8 feet
3. Address
P. 0. Box 100360 Anchorage. AK
6. Unit or Property name
Kuoaruk RfV(,r Unit-
4. location of well at surface
1561'FSL, 105'FEL, Sec.29, T13M, R9E, UM
At top of productive interval
1358'FNL, 1817'FVHL, Sec.28, T13N, R9E, UM (approx.)
At effective depth
1213'FNL, 1960'FWL, Sec.28, T13N, R9E, UM (approx.)
At total depth
1169'FNL, 1990'FWL, Sec.28, T13N, R9E, UM {approx.)
7. Well number
3N-13
8. Permit number
86-81
9. API number
50—029-21580
10. Pool
Kuparuk River 011 Pool
11. Present well condition summary
Total depth: measured 7875
true vertical 6667
Effective depth: measured
true vertical
7792
Casing
Conductor
Surface
Productlon
6604
Length Size
80' 16"
3737' 9-5/8"
7882' 7"
(91 above rotary)
feet
feet
feet
feet
Plugs (measured) None
Junk (measured) ..
None
Cemented Measured depth
Conductor report 115'MO
not available.
1100 sx AS III & 377VMD
300 sx Class G
320 sx Class G 7873 'MO
True Vertical depth
115'TVIT
3631 'TVO
6665'TVD
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
- a C.l i •- - " •••
• . — -3
12.A1
story
Description summary of proposal G Detailed operations program G BOP sketch _
13. Estimated date for commencing operation
July, 1986
14. if proposal was verbally approved
Name of approver ua
certify that the foregoing is true and correct to the best of my knowledge
1 " LA , — Associate Engineer
Date approved
15. I hereby
Signed
Tltte
Date 5-fc.Qu
Commission Use Only
(DAM) SA/039
Conditions of approval
Notify commission 30 representative may witness
G Plug integrity C BOP Test G Location clearance
Approval No.
Approved by
Commissioner
by order of •—
the commission Date 3 -
Form 10-403 Rev 12-1-85
C-93
Submit in triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend 2 Operation Shutdown x Re-enter suspended well Z Alter casing I
Time extension ~ Change approved program Z Plugging ~ Stimulate ~ Pull tubing ~ Amend order I Perforate ~ Other ~
2. Name of Operator
ARCO Al aska, Inc.
5. Datum elevation (OF or KB)
68' RK8 feet
3. Address
P. 0. Box 1QQ360
6. Unit or Property name
A K
4. Location of well at surface
1561'FSL, 79'FEL, Sec.29, T13N, R9E, UM
At top of productive interval
1327'FSL, 1792'FWL, Sec.28, T13N, R9E, UM (approx.)
At effective depth
1327'FSL, 1958'FWL, Sec.28, T13N, R9E, UM (approx.)
At total depth
1318'FSL, 2030'FVrL, Sec.28, T13N, R9E, UM (approx.)
7. Well number
8. Permit number
86-86
9. API number
50-029-21589
10. Pool
Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 7lf60
true vertical 6687
Effective depth: measured
feet Plugs (measured) None
feet
true vertical
7356
6612
feet
feet
Junk (measured)
None
Casing
Conductor
Surface
Product i on
Length
80'
2542'
71*40'
Size
16"
Cemented
238 sx CS II
Measured depth
110'MO
10-3/4" 1150 sx AS III & 2579'MD
150 sx Class C
Top job w/100 sx AS I
7"
660 sx Class C
7440'MO
True Vertical depth
110'TVO
2579'TVD
6673'TVO
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
12-Attachments
Well History
Description summary of proposal G Detailed operations program ~ BOP sketch ~
13. Estimated date for commencing operation
July, 1986
14. if proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
do (}fmj Ajud)4^ Title Associate Engineer
Date
Commission Use Only (0AM) SA/042
Conditions of approval Notify commission so representative may witness
G Plug integrity G BOP Test G Location clearance
Approval No.
Approved by
Commissioner
by order of
the commission Date
- 2- 1~
Form 10-403 Rev 12-1-85
C-94
Submit m triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Aoandon _ Suspend _ Operation Shutdown Re-enter suspended well 1 Alter casing I
Time extension ~ Change approved program Z Plugging ~ Stimulate Z Pull tubing I Amend order ~ Perforate I Other 3
2. Name of Operator
ARCO Alaska , Inc.
5. Datum elevation (OF or KB)
68' RK8 feet
3. Address
P. 0. Box 100.330 Anrhnraq.., AK
6. Unit or Property name
tf up j r,.L P {
4. Location of well at surface
1561'FSL, 54'FEL, Sec.29, T13N, R9E, UM
At top of productive interval
1323'FSL, 844'FEL, Sec.28, T13N, R9E, UM (approx)
At effective depth
1402'FSL, 755'FEL, Sec.28, T13N, RT9E, UM (approx)
At total depth
1415'FSL, 694'FWL, Sec.28, T13N, R9E, UM (approx)
7. Well number
3N-15
8. Permit number
86-90
9. API number
50-029-21592
10. Pool
Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 8508
true vertical 6700
feet Plugs (measured) N0ne
feet
Effective depth: measured
true vertical
8409
Casing
Conductor
Surface
Product!on
6623
Length Size
80' 16"
feet
feet
Junk (measured)
None
Cemented
255 sx CS II
Measured depth
115'MO
4284 •
8496'
9-5/8"
7"
1250 sx AS III & 4321'MO
350 sx Class C
325 sx Class C 8496'MO
True Vertical depth
115'TVO
3639'TVD
6690'TVD
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
12.Attachments
Well History
Description summary of proposal _ Detailed operations program _ BOP sketch _
13. Estimated date for commencing operation
July, 1986
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed J-, %i/R^ ^UJfXXJ Title Associate Engineer
Date
J
Commission Use Only (DAM) SA/043
Conditions of approval Notify commission so representative may witness
2 Plug integrity Z BOP Test ~ Location clearance
Approval No.
Approved by
Commissioner
by order of
the commission Date £ • H ~*l:
Form 10-403 Rev 12-1-85
C-95
Submit in triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMM, ,iON
APPLICATION FOR SUNDRY APPROVALS
1 Type Of Request: AQanaon : Suspend _ Operation Shutdown/^ He-enter suspended well ~ Alter casing
Time extension .1 Change approved program 1 Plugging ~ Stimulate 7 Pull tuGmg ~ Amend order Perforate " Otner
2. Name of Operator
ARCO Alaska, 1 no
3. Address
p n R*r innicn an^hn...^ si/ aaein
4. Location of well at surface
1561' PSL, 29' PEL, Sec. 23, H3N, S9E,
At top of productive interval
1289' PNL, 840' PEL, Sec. 33, T13N, R9E,
At effective depth
1288' PNL, 561' PEL, Sec. 33, T13N, R9E,
At total depth
1320' FNL, 487' PEL, Sec. 33, T13N, R9E,
11. Present well condition summary
Total depth: measured 9235' feet
true vertical 6950. feet
Effective depth: measured feet
true vertical 91°2' feet
6744'
Casing Length Size
Conductor 80' 16"
Surface 4760' 9-5/8"
Production 9189' 7"
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
l2.Attachments Description summary of proposal
Well History
5. Datum elevation (OF or KB)
68' RKS 'eet
6. Unit or Property name
7. Well number
U.M ™-lfi
8. Permit number
UM (approx) 86-91
9. API number
UM (approx) 50— 029-21593
10. Pool
UM (approx) Kuparuk River OH Pool
Plugs (measured) None
Junk (measured)
None
Cemented Measured depth True Vertical depth
249 sx CS I I 1 1 5 ' MO 1 1 5 ' 1 VD
1350 sx AS 1II& 350 sx Class C 4797'MO 2598' 1VD
300 sx Class C 9189'MO 6813' 1VO
, i -
~ Detailed operations program ~ BOP sketch Z
13. Estimated date for commencing operation
July, 1986
u. if proposal was verbally approved
Name of approver
Date aporoved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed d '!/V)O xJ't
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _, Operation Shutdown £ Re-enter suspended well _ Alter casing ~
Time extension ~ Change approved program ~ Plugging ~ Stimulate 1 Pull tubing ~ Amend order 1 Perforate Z Other ~
2. Name of Operator
ARCO Alaska, Inc.
5. Datum elevation (OF or KB)
68' RKB feet
3. Address
P. 0. Box 100360 Anchorage. AK 99510
6. Unit or Property name
Kuoarulc River U ni 1-
4. Location of well at surface
1561'FSL, VFEL, Sec.29, T13N, R9E, UM
At top of productive interval
850'FNL, 838'FEL, Sec.28, T13N, R9E, UM (approx.)
At effective depth
710'FNL, 651'FEL, Sec.28, T13N, R9E, UM (approx.)
'FEL, Sec.28, T13N, R9E, UM (approx.)
7. Well number
3N-17
8. Permit number
86-92
9. API number
50—029-2159'*
10. Pool
K u'p a r u k River Oil Pool
11. Present well condition summary
Total depth: measured 9005
true vertical 5727
Effective depth: measured
Casing
Conductor
Surface
Production
true vertical
Length
80'
8912
6658
feet
feet
feet
feet
Plugs (measured) None
Junk (measured)
Size
16"
9-5/8"
8997'
None
Cemented Measured depth
250 sx CS I I 115 'MO
1 350 sx AS I II & 1*606 'MO
350 sx Class C
Top job H/AS I cmt.
300 sx Class C 4 8997'MO
175 sx AS I
True Vertical depth
1 15 'TVO
3625'TVD
6721'TVO
Perforation depth: measured None
true vertical None
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) None
JUMl > 1386
-'asxa C
l2.Ayachme.pts
story
Description summary of proposal u Detailed operations program _ BOP sketch _
13. Estimated date for commencing operation
July, 1986
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed Jv'/,/^U *!/'/v'w.V^ Title Associate Engineer
Date
Commission Use Only
(DAM) SA/055
Conditions of approval
Approved by
Notify commission so representative may witness
~ Plug integrity "I BOP Test Z Location clearance
Commissioner
Approval No.
by order of
the commission Date srl V
Form 10-403 Rev 12-1-85
C-97
Submit in triplicate
-------
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Aoandon _ Suspend Z Operation Shutdown X Re-enter suspended well ~ Alter casing Z
Time extension Z Change approved program C Plugging Z Stimulate ~ Pull tubing Z Amend order I Perforate ~ Other I
2. Name of Operator
ARCO Alaska, Inc.
5. Datum elevation (OF or KB)
68' RK8 feet
3. Address
P. 0. Box 100360 Anchorage. AK 99510
6. Unit or Property name
Kuo
aru
4. Location of well at surface
1561'FSL, 21'FWL, Sec. 28, T13N, R9E, UM
At top of productive interval
1479'FSL, 920'FEL, Sec. 33, T13N, R9E, UM (approx.)
At effective depth
99g'FSL, 566'FEL, Sec. 33, T13N, R9E,
' 510'FEL, Sec. 33, T13N, R9E, UM {approx. )
7. Well number
3N-18
8. Permit number
86-93
UM (approx.)
9. API number
50—029-21595
10. Pool
Kuparuk River Oil Pool
11. Present well condition summary
Total depth: measured 10630
true vertical 5339
Effective depth:
Casing
Conductor
Surface
Product!on
measured
true vertical
Length
80'
5107'
10599'
10517
6765
feet
feet
feet
feet
Plugs (measured) None
Junk (measured)
None
Size
16"
9-5/8'
7"
Cemented Measured depth
2*2 sx CS I I 115'MO
1500 sx AS I I I & 51*4 'MO
~ <-
Form 10-403 Rev 12-1-85
("••—o i
\. ^ o
Submit m tnpiicat
-------
ATTACHMENT C:
LETTER FROM STANDARD ALASKA PRODUCTION
C-99
-------
n
i
o
o
-------
Standard Alatfca
Production Company
900 Eon Benson Boulevard
PO Bo. 196612
Anchorage. Alaska 99519-6612
(907, 561-5111
STANDARD
ALASKA PRODUCTION
August 8, 1986
Ms. Suzan DeNagy
Industrial Technology Division
U.S. Environmental Protection Agency
Waterside Mall
401 M Street SW
Washington D.C. 20460
Dear Ms. DeNagy:
As you requested, Standard's decision requiring that the drilling mud pit at
Standard's Prudhoe Bay Unit F Pad not be sampled on August 2nd is documented
herein. During August 1st and 2nd the drilling rig was recovering damaged
casing, a dual string of pipe, and cutting the pipe with an open flame as it
was retrieved on the rig floor, "his operation made it unsafe for personnel
to be on site sampling the drilling mud pit. Since safety of all personnel
entering our operating area is a primary concern of Standard, we appreciated
your cooperation in selecting another available site that met your
criteria.
I hope this documentation is sufficient for your records. Please let me
know if further information is necessary.
P. Lucid'o
Manager Environment/Regihia^ory Affairs
JPL:LMB/6284V
cc: L. Billington, SAPC
T. Rockwell, EPA-Anchorage
J. Collins, Ar co-Da lias
A. Ahnell, Standard
O" Co^po™*
« I87C p_ 101
-------
C-102
-------
ATTACHMENT D:
LETTER FROM ARCO ALASKA
C-103
-------
C-104
-------
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
August 4, 1986
Ms. Suzan DeNagy
Industrial Technology Division
U.S. Environmental Protection Agency
Waterside Mall
401 M Stret SW
Wasington, DC 20*60
Dear Ms. DeNagy:
As you requested, I am documenting ARCO's decison that sampling the
drilling mud pit at ARCO's Prudhoe Bay Unit Drill Site 11 would not be safe
on Sunday, August 3, 1986 because the drilling rig adjacent to the pit testing
area was rigging down and moving that day. It was also stated by ARCO
representatives that the pit could be tested Monday, August
-------
C-106
-------
Sampling Report
Investigation of Marathon Oil Company 's
Trading Bay Production Facility
Cook Inlet, Alaska
August 7, 1986
SITE INFORMATION
Site Selection
EPA specifically selected the Trading Bay Production Facility to
obtain technical information and analytical data regarding the
practice of using centralized facilities to treat and dispose of
wastes from multiple oil and gas sources in Alaska. The Agency
is interested in the developing information about the
constituents of the wastes, and about the effectiveness of the
treatment processes. A more detailed discussion of the rationale
for selection of centralized treatment facilities is contained in
Appendix B of the EPA Technical Report (EPA 530-SW-87-005).
No problems were encountered arranging for sampling to be
conducted on August 7, 1986.
Site Location
Trading Bay Facility is located on the west coast of Cook Inlet,
across from the city of Kanai and south of Tyonek. Figure 1 is a
map indicating the facility.
The site is operated by Marathon Oil Company, whose mailing
address and telephone number are:
3201 C Street
Anchorage, AK 99503
907-564-6337
Contact Name: Tom Brooks
Attendees
Sampling of Trading Bay Facility was performed by CENTEC
Corporation personnel on August 7, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
EPA Representative: Susan de Nagy, Office of Water,
Project Officer
State Representative: John Catlin, Environmental
Scientist, Bureau of Land
Management, Anchorage
District Office
C-107
-------
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Figure I. Location of Trading Bay Facility, Cook
Inlet, Alaska
0108
-------
Operator Representatives: Tony Swan, Production Foreman
Keith Woods, No. 1 Operator
Jack Shan, Operator
American Petroleum
Institute Representatives: Tom Brooks, Contracted Observer
Bob Zahray, Contracted Sample
Team Member
Site Description
Trading Bay Facility is located in the Cook Inlet Basin in a
rural coastal area; the depth to groundwater is 25-50 feet, and
the nearest surface water is less than 1/2 mile away. There are
three drinking water wells within a 1/4-mile radius of the site.
The climate at this site is net precipitation.
This site is a centralized treatment facility. Figure 2 is a
schematic diagram of the facility. The facility operates as a
continuous process as final treatment prior to discharge. Annual
operation hours are 8760. The facility accepts process fluids
(oil, gas, and water) from drilling rigs in Cook Inlet. The
facility receives 97,000 bbl/day oil-water emulsion. Seventy-
five thousand bbl/day water is discharged while 22,000 bbl/day
oil is recovered as well as 9-10 million SCF/day gas. The
facility uses no system to account for all influent.
Unprocessed oil, gas, and water enter the facility and are passed
through a pig trap building. Here the gas is separated and
proceeds to gas compressors and then to a liquid extraction
plant. The oil and water proceed through a series of free water
knockout tanks and heater treaters. The separated oil is placed
in storage tanks. The water goes into one of three skim tanks.
Any solids removed are placed in another tank prior to being
incinerated. The water flows into one of two retention pits
prior to discharge into Cook Inlet. The facility is required to
test for oil and grease in the effluent every 3 hours.
The facility also operates a landfill onsite to hold all solid
waste from process operations including oil spills, pig wax, tank
bottoms, residue from the sludge incinerator, and untreatable
emulsions. This pit is shown in Figure 3. The pit dimensions
are 100 ft x 80 ft. The pit is 17.5 feet deep and is lined with
plastic. Attachment C is the facility landfill waste deposit
record. This record shows the dates on which waste was placed in
the landfill, along with amounts and waste sources, from August
17, 1985 to August 1, 1936. Attachment D is a report dated May,
1985 which details the dates of all tank cleaning and maintenance
since 1978.
C-109
-------
_[_
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I
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-5A/1PLE
LOCATION
Figure 2. -Schematic Diagran, Trading Bav Facility
-------
n
i
SAM PLe
Figure 3. Sampling Locations in Facility Landfill
-------
Permits
The landfill operates under Permit No. SG-26-77 issued by the
Alaska Dept. of Environmental Conservation. A copy of this
permit is shown in Attachment B. The facility operaton permit
was not available to the sample team at the time of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The following samples were collected at the Trading Bay facility:
Influent after oil separation
Final effluent
Landfill sludge
Incinerated sludge
Landfill supernatant
Pig wax
The latter three samples were taken at the direction of the EPA
Project Officer. Figure 2 shows the sampling locations
throughout the facility. Figure 3 shows the sampling locations
within the landfill pit.
Sampling Methods and Equipment
The influent sample was collected from a sample valve in the pipe
prior to entering Skim Tank 2, as shown in Photos 1 and 2. The
sample bottles were filled directly from the valve at the
direction of the EPA Project Officer. The effluent sample was
collected at a pumping station between the water retention pits
and the discharge point. The bottles were filled directly from a
sampling line. Photos 3 and 4 show the sampling of the landfill
pit. The pit had no discrete liquid surface. There were a few
very shallow liquid pools from which the supernatant sample was
collected. The supernatant was collected with a glass cup. Four
quadrants were established for sludge sampling of the landfill.
The sample was collected using the Teflon lined coring tube and a
stainless steel spoon. The incinerated sludge sample was
collected at Building 18, as shown in Photos 5 and 6. The sample
bottles were filled directly from a valve. Photos 7 and 8 show
sampling of the pig wax. The wax from the pig trap building was
placed in metal drums and stored by the pig cooker next to Skim
Tank 1.
C-112
-------
The influent and final effluent were tested onsite for pH and
free chlorine content after the completion of sampling. For both
influent and effluent, pH value was 6 and free chlorine was less
than the lowest detectable level of 0.2 ppm.
Sample shipment required 2 days in travel time from the site to
the laboratories.
C-113
-------
C-1 14
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-1 15
-------
C-116
-------
^ Photo t. Skim tank f2, Influent sample collection point
'•".<**->'- '.'r'^*' . V>: ' "" *-•*' " ••""",' • • ~
~—^-^ ^.~u_/. .•«. .«* J?*.-_i.>*^,; . — -*-••' 's _1- • r-
Photo 3. Sample collection In landfill
\ mm. •. • "T •
A \m- - - n
^, '..:V«i"^-/'i
Photo 2. Influent sample collection point
Photo 4. Sample collection In landfill
-------
Photo 5. BuiIdlng 18
or
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,», ,.,r,: -,'i •; » . r* f
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o. - J. . T 01-
Photo 6. Building IB, sludge collection point
-------
ATTACHMENT B: PERMITS
C-119
-------
C-120
-------
STATE OF ALASKA
DEPARTMENT OF ENVIRONMENTAL CONSERVATION
POUCH O
JUNEAU, ALASKA 99811
WASTE DISPOSAL PERMIT
(SOLID WASTE MANAGEMENT PERMIT)
Permit No. SC-26-77 Date "OV 2 9 1977
This Waste Disposal Permit is issued to Marathon Oil Company, 3201 - C Street,
Anchorage, Alaska 99503 for the construction, operation and maintenance of
an oil'y waste disposal facility to be
located in the NW 1/4, Sec. 6, T8N, R14W, Seward Meridian, Trading Bay,
Alaska.
and is subject to the conditions and stipulations in sections A.I through
D.9, of this permit and the applicable State laws and regulations.
This permit is issued under provisions of Alaska Statutes, AS 46.03.100-110,
Water, Air, and Environmental Conservation, Alaska Administrative Code as
amended or revised, and other applicable State laws and regulations.
This permit is effective upon issuance and expires _ December 31, 1980
it may be terminated or modified in accordance with AS 46.03.120.
This permit is not valid until signed by the Commissioner of the Department
of Environmental Conservation.
ner
t of Environmental Conservation
C-121
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o
I
to
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ATTACHMENT C:
LANDFILL DEPOSIT RECORD
C-123
-------
C-124
-------
TBPF LANDFILL
OILY WASTE DEPOSIT RECORD
CELL NO.
OILY WASTE
DEPOSITED CYD3}
DATE
BLENDED
c,
DATE
O>!PACTED
LAYER THICKNESS
SOURCE
le
I*
t,
Is
//-*-*r
(c
TES:am
C-125
-------
TBPF LANDFILL
OILY WASTE DEPOSIT RECORD
CELT, NO.
OILY WASTE
DEPOSITED (YD3-)
DATE
BLENDED
DATE
OT4PACTED
APPROXIMATE
LAYER THICKNESS
SOURCE
c
1 yo
SAlt
b
df» '•
TES:a;n
C-126
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ATTACHMENT D:
TANK CLEANING AND MAINTENANCE SCHEDULE
0127
-------
C-128
-------
MARATHON OIL COMPANY
ENGINEERING DEPARTMENT
SUBJECT-
DATE_
BY
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A. S
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C ('/
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-------
Sampling Report
Investigation of Union Oil Company's
Kenai Gas Field Production Site 41-7
Kenai, Alaska
August 8, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix 3 of the EPA Technical
Report (EPA 530-SW-87-005). The gas field was selected randomly
from a list of Kenai Peninsula, Cook Inlet Basin production
fields developed by the Anchorage District Bureau of Land
Management at the request of EPA. The list was transmitted via
telephone to the EPA contractor on July 22, 1986. Field
selection from this list took place during the telephone
conversation. A random number table was used to select the Kenai
Gas Field for sampling to be conducted August 8, 1986.
On August 8, Union Oil Company, in the presence of EPA, the
Anchorage District Bureau of Land Management Office, and the EPA
contractor, developed a list of Kenai Gas Field production sites
for random selection of the specific site to be sampled.
Possible sample sites were listed as shown below. The EPA
contractor had no interest in the manner the particular sites
were listed (by site name, location, operator, permit number, API
number, etc.) as long as the site could be identified in detail
upon selection. Thus, the EPA contractor had minimal information
which kept to a minimum the amount of bias. No other information
was known about the sites on the list at the time of selection.
Detailed information was obtained only after selection of primary
and back-up sites. The list consisted of 6 Cook Inlet Basin -
Kenai Gas Field production sites:
1. Site 33-30
2. Site 43-32
3. Site 34-31
4. Site 14-6
5. Site 41-18
6. Site 41-7
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
No. 6 on the above list (Site 41-7) was selected as the primary
sample site. No. 1 on the above list (Site 33-30) was selected
as a back-up site should sampling at the primary site prove
inaccessible or inappropriate.
No problems were encountered in arranging sampling of Site 41-7
on August 8, 1986. The back-up site was not required.
C-133
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Site Location
Kenai Gas Field Production Site 41-7 is located 10 miles south of
Kenai, along Kasilof Road. Figure 1 is a map locating the
production site.
The site is operated by Union Oil Company of California, whose
mailing address and telephone number are:
PO Box 190247
Anchorage, AK 99519-0247
907-276-7600
Contact Name: Roy Roberts
Attendees
Sampling of Kenai Gas Field Site 41-7 was performed by CENTEC
Corporation personnel on August 8, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representative:
State Representative:
Operator Representative:
American Petroleum
Institute Representatives:
Site Description
Bruce Hoskins, Team Leader
Susan de Nagy, Office of Water,
Project Officer
John Catlin, Environmental
Scientist, Bureau of Land
Management, Anchorage
District Office
Bob Smith, Production Foreman
Tom Brooks, Marathon Oil
Bob Zahray, Contracted Sample
Team Member
Kenai Gas Field is located in a. rural coastal area; the depth to
groundwater is 30 feet and the nearest surface water is less than
1/2 mile away. There is one drinking water well within a 1/4-
mile radius of this site. The climate at this site location is
net precipitation.
This site consists of actively producing gas wells with an
average total production of 172 mmcf/day. Production at Site
41-7 on the day of sampling was 117 mmcf. Water production at
this site is 9 bbl/day. Production at this site is sweet. There
are 18 active gas wells at Site 41-7. The average well depth is
4,500 feet. The site is producing using natural drive. Figure 2
is a schematic diagram of the production facility. The facility
collects the wastewater from the gas field and has its own water
C-134
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GULF OF ALASKA
PROJECT LOCATION MAP
ITE ci:u-i
CANNERY LOOP UNIT
KENAI GAS FIELD
S1TE"33-30
SITE 43-32
SITE 14-6
SITE LOCATION
• SITE 41-18
Figure 1. Location of Kenai Gas Field Production
Site #41-7, Kenai, Alaska
C-135
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TYPICAL SITEFLOW PAGAM
' \i" GAS
i 3" WASTE V.'AlfR |//
pun
LiiiiJ
I
PROCESS FACILITIES O SITE 34-31
KENAI GAS Flf:LO
J
Figure 2. Kenai Gas Field Waste Water
Gathering System Flow Diagram
-------
separation system. The typical site flow diagram in Figure 2
illustrates the system used at Site 41-7. Triethylene glycol is
used for separation. No waste glycol is generated, since it is
filtered and recycled.
Disposal Practices
The water is sent to a central battery where it is combined with
produced water from the Beaver Creek gas field. The water is
disposed by reinjection. Included in Attachment C are monthly
injection well monitoring reports for January-July, 1986. In
this period, a total of 2,144,436 gallons of water were injected.
February had the largest injection volume of 517,272 gallons,
while May had the lowest volume at 165,396 gallons.
Permits
The facility has been reinjecting water under UIC Permit No. AK-
2D0217-E and Alaska Dept. of Environmental Conservation Permit
No. 8423-DB015. Copies of these permits are shown in Attachment
B. The UIC permit requires the monitoring of total dissolved
solids, suspended solids, and pH at no greater than 1-year
intervals. The AK DEC permit requires in addition the monitoring
of sodium, potassium, magnesium, iron, calcium, chloride,
carbonate, bicarbonate, and sulfate on an annual basis. There
are no other produced wastes unless a spill occurs. The facility
is currently storing a maximum of 200 cubic yards of spilled oily
waste.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The sample collected at Kenai Gas Field Site 41-7 consisted of
one liquid sample. The sample collection point was at a valve at
the bottom of the free water knockout tank.
Sampling Methods and Equipment
The liquid sample was collected at the base of the free water
knockout tank. At the direction of the EPA Project Officer, the
sample bottles were filled directly from a valve at the base of
the tank.
C-137
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The liquid sample was tested onsite for pH and free chlorine
content at the completion of sampling. The value of pH was 6.
The free chlorine content was less than the lowest detectable
level of 0.2 ppm.
The samples were shipped the day of collection. Two days of
travel time were required from shipment point to laboratory
receipt.
C-138
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-139
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C-140
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No photodocumentation specific to the
operation of this site is available.
C-141
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C-142
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ATTACHMENT B: PERMITS
0143
-------
C-144
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:N\NRON,
U.S. ENVIRONMENTAL PROTECTION* AGENCY
REGION X " A- Gn-'N
1200 SIXTH AVEN U E ' . |
i SEATTLE, WASHINGTON 98101
OCT b
REPIYTO M/c ..,, OCT 10198?
ATTN OF: M/S 437 iJOJ
C.JV;.. LOCKWQOI
Gerry A. Graham
District Operations Manager
Union Oil Company of California
P.O. Box 6247
Anchorage, Alaska 99502
RE: Kenai Gas Field Class II Emergency Underground Injection Control
(UIC) Permit
Dear Mr. Graham:
Enclosed is the emergency UIC permit for injection well KU WD-1 . This
permit is issued in accordance with 40 CFR 144.34. The permit is based on
Union's permit application of June 24, 1985, as supplemented and modified
August 12, 1985.
The emergency permit will remain in effect until either final EPA
action is taken on the permit application, the state of Alaska is granted
primary responsibility for the UIC program and has taken final action on the
state permit application, or the permits have been otherwise modified,
revoked and reissued, or terminated in accordance with 40 CFR 144.39-144.41.
Sincerely,
Rbbert S. Burd
Director, Water Division
Enclosure
cc: C. V. Chatterton, AOGCC
Bill Lamoreaux, ADEC
DECEIVED
OCT 0 9 1985
C-145
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Permit No. AK-2D0217-E
AUTHORIZATION TO INJECT UNDER THE
UNDERGROUND INJECTION CONTROL PROGRAM
In compliance with the provisions of the Safe Drinking Water Act, as amended
(42 U.S.C. 300f et seq).
Union Oil Company of California
Anchorage, Alaska
is authorized to inject into the Sterling Formation through injection well
Number KU WD-1 at the Alaska Kenai Gas Field (location of well: Section 31,
T.5N, R.11W, Section 31, 1/4 Section SE, 606 feet from south line and 2297
feet from east line), in accordance with conditions set forth herein.
This permit shall become effective on October 3, 1985.
Signed this 3rd of October 1985.
Robert S. Burd
Director, Water Division
Environmental Protection Agency
Region 10
0146
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Permit No. AK-2D0217-E
Page 2 of 12
TABLE OF CONTENTS
Cover Sheet - Issuance Date and Signature Page
A. Effect of Permit 3
B. Construction, Operating and Monitoring Requirements 3
C. Reporting and Record Keeping Requirements 4
D. Plugging and Abandonment 6
E. Financial Responsibility 7
F. Mechanical Integrity 7
G. General Requirements 8
1. Duty to Comply 8
2. Duty to Provide Information 8
3. Need to Halt or Reduce Not a Defense 8
4. Signatory Requirements 8
5. Proper Operation and Maintenance 9
6. Duty to Mitigate 9
7. Inspection and Entry 9
8. Prohibition of Injection of Hazardous Waste 10
9. Penalties 10
10. Permit Actions 10
11. Transfers 10
12. Confidentiality of Information 11
13. State Laws 1 ]
14. Property Rights 11
15. Severability 11
Attachment 1 - Plugging and Abandonment Plan 12
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Permit No. AK-2D0217-E
Page 3 of 12
A. EFFECT OF PERMIT
The permittee is authorized to engage in underground injection in
accordance with the conditions of this permit. The underground injection
shall not allow the movement of fluids into or between underground
sources of drinking water. Compliance with the terms of this permit does
not constitute a defense to any action brought under Section 1431 of the
Safe Drinking Water Act or any other law governing protection of public
health or the environment for any imminent and substantial endangerment
to human health, or the environment.
This permit is an emergency permit as provided for in 40 CFR 144.34. The
permit shall be effective until final action is taken on the permit
application or the permit is otherwise modified, revoked and reissued, or
terminated in accordance with Section G.10. of this permit.
This permit is based on the permit application dated June 12, 1985, and
supplemental information dated August 12, 1985. The permit application
requests an emergency permit for an existing Class II produced water well
operated by the Union Oil Company of California at its Kenai Gas Field.
Any underground injection which violates any authorization by permit is
subject to appropriate enforcement action.
B. CONSTRUCTION. OPERATING AND MONITORING REQUIREMENTS
1. Construction Requirements
a. The permittee shall case and cement the well to prevent the
movement of fluids into or between underground sources of
drinking water.
b. The casing and cement used in the construction of the well
shall be designed for the life expectancy of the well.
c. Casing and cement shall be placed in accordance with general
construction details as shown in Attachment M of the permit
application.
d. Tubing and packer shall be located at 2,150 feet. A revised
Attachment M shall be submitted to the Regional Administrator
no later than November 15, 1985.
e. Injection interval shall be between 3,030-3,250 feet.
2. Operating Requirements
a. The maximum injection pressure, measured at the wellhead, shall
not exceed 900 pounds per square inch absolute (psia).
b. The maximum injection pressure may be increased to 1,500 psia
once the Regional Administrator approves the permittee's
demonstration that the increased pressure will not fracture the
confining zone (2,820-2,915 feet).
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Permit No. AK-2D0217-E
Page 4 of 12
c. The Regional Administrator will notify the permittee of the
acceptability of the demonstration within 15 days of receipt of
the data. If the Regional Administrator does not respond
within 15 days, injection at 1,500 psia may commence.
3. Monitoring Requirements
a. Observation and recording of injection pressure, injection
rate, cumulative volume and annulus pressure shall be made at
intervals no greater than seven (7) days, beginning on the
effective date of this permit.
b. Monitoring of the injected fluid shall be made at intervals no
greater than 12 months, beginning on the effective date of this
permit. The following tests shall be conducted:
(i) Total dissolved solids
(ii) pH
(iii) Suspended solids
c. Samples and measurements taken for the purpose of monitoring
shall be representative of the monitored activity.
d. Monitoring must be conducted according to test procedures
approved under 40 CFR 136.3, unless otherwise approved by the
Regional Administrator.
C. REPORTING AND RECORD KEEPING REQUIREMENTS
All reporting and notification required by this permit shall be signed
and certified in accordance with the requirements of Section G.4., and
submitted to the Regional Administrator at the following address:
United States Environmental Protection Agency
Region 10
Attn: Mail Stop 409
1200 Sixth Avenue
Seattle, Washington 98101
A copy of all reports shall be submitted to the State at the following
address:
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
1. Monitoring results, as specified in Section B. 3., shall be reported
each month on EPA Form 7520-8. Reports shall be postmarked by the
20th day of the month following the reporting period.
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Permit No. AK-2D0217-E
Page 5 of 12
2. Monitoring results as specified in 40 CFR 146.23(b) for the period
June 25, 1985, through September 30, 1985, shall be reported on EPA
Form 7520-8 no later than October 20, 1985.
3. The permittee shall retain records of all monitoring information,
including the following:
a. Original strip chart recordings for continuous monitoring
instrumentation, copies of all reports required by this permit,
and records of the data or methods used to complete the
application for this permit, for a period of at least 3 years
from the date of the sample, measurement, report, or
application. This period may be extended by the Regional
Administrator at any time; and
b. The nature and composition of all injected fluids until 3 years
after the completion of any plugging and abandonment procedures
specified by this permit. The permittee shall continue to
retain the records after the 3 year retention period unless he
delivers the records to the Regional Administrator or obtains
written approval from the Regional Administrator to discard the
records.
c. Records of monitoring information shall include:
(i) The date, exact place, and time of sampling or
measurements;
(ii> The name(s) of the individual(s) who performed the
sampling or measurements;
(iii) The date(s) analyses were performed;
(iv) The name(s) of the indi vidua.l (s) who performed the
analyses;
(v) The analytical techniques or methods used; and
(vi) The results of such analyses.
d. Dates of most recent calibration or maintenance of gauges and
meters used for monitoring required by this permit shall be
noted on the gauge or meter.
4. The permittee shall give notice to the Regional Administrator as
soon as possible of any planned physical alterations or additions to
the permitted facility which may cause the movement of fluids into
an underground source of drinking water.
5. The permittee shall give advance notice to the Regional
Administrator of any planned changes in the permitted facility or
activity which may result in noncompliance with permit requirements.
0150
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Permit No. AK-2D0217-E
Page 6 of 12
6. The permittee shall report any noncompliance which may endanger
human health or the environment, including;
a. Any monitoring or other information which indicates that any
contaminant may cause an endangerment to an underground source
of drinking water; or
b. Any noncompliance with a permit condition or malfunction of the
injection system which may cause fluid migration into or
between underground sources of drinking water.
Any information shall be provided orally (Phone number:
(206) 442-1846 or (206) 442-1225) within 24 hours from the time the
permittee becomes aware of the circumstances. A written report
shall also be provided within 5 days of the time the permittee
becomes aware of the circumstances. The written report shall
contain a description of the noncompliance and its cause, the period
of noncompliance, including exact dates and times, and if the
noncompliance has not been corrected, the anticipated time it is
expected to continue; and steps taken or planned to reduce,
eliminate, and prevent recurrence of the noncompliance.
7. The permittee shall report all instances of noncompliance not
reported under paragraph 5. of this section, at the time monitoring
reports are submitted. The reports shall contain the information
listed in paragraph 5. of this section.
8. Where the permittee becomes aware that it failed to submit any
relevant facts in a permit application, or submitted incorrect
information in a permit application or in any report to the Regional
Administrator, it shall promptly submit such facts or information.
9. The permittee shall notify the Regional, Administrator upon
completion of conversion or construction of the well, and prior to
commencing injection.
10. The permittee shall notify the Regional Administrator no later than
30 days after conversion of the well to other than an injection well.
D. PLUGGING AND ABANDONMENT
1. Plugging and abandonment shall be conducted in accordance with
Attachment 1 of this permit, unless an alternative method of
pl.ugging and abandonment is approved in advance by the Regional
Administrator.
2. Plugging and abandonment shall be conducted such that movement of
fluids will not be allowed into an underground source of drinking
water nor will one underground source of drinking water be allowed
to move into another.
3. The permittee shall notify the Regional Administrator 30 days prior
to the plugging and abandonment of the well.
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Permit No. AK-2D0217-E
Page 7 of 12
4. Within 60 days after plugging the well, the permittee shall submit a
report to the Regional Administrator which shall consist of either:
a. A statement that the well was plugged in accordance with
Attachment 1 of this permit; or
b. Where actual plugging differed from Attachment 1 of this
permit, an updated version of the plan, on the form supplied by
the Regional Administrator, specifying the different procedures
used.
The report shall be certified as accurate by the person who
performed the plugging operation.
E. FINANCIAL RESPONSIBILITY
The permittee shall maintain financial responsibility and resources to
close, plug, and abandon the well. The Regional Administrator may
require the permittee to submit a revised demonstration of financial
responsibility if the Regional Administrator has reason to believe that
the original demonstration is no longer adequate to cover the cost of
closing, plugging and abandoning the well.
F. MECHANICAL INTEGRITY
1. Standards
The injection well must have and maintain mechanical integrity
pursuant to 40 CFR 146.8.
2. Prohibition Without Demonstration
Injection operations are prohibited 45 days after the effective date
of this permit unless the permittee has, submitted data to detect
leaks in the casing, tubing, or packer. The casing-tubing annulus
must be completely filled with a corrosion inhibited liquid and
pressure tested to 1,500 pounds per square inch absolute (psia) for
thirty minutes. Pressure loss may not exceed 150 psia at the end of
the thirty minute test.
3. Terms and Reporting
a. Mechanical integrity tests identified in F.2. shall be
submitted within 45 days of the effective date of this permit.
b. Mechanical integrity shall also be demonstrated by the pressure
test in F.2. any time the tubing is removed from the well, or
if a loss of mechanical integrity becomes evident during
operation. The permittee shall report the results of such
tests within 45 days of completion of the tests.
c. The permittee shall notify the Regional Administrator of his
intent to demonstrate mechanical integrity at least 30 days, or
as soon as possible, prior to such demonstration.
C-152
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Permit No. AK-2D0217-E
Page 8 of 12
d.. The Regional Administrator will notify the permittee of the
acceptability of the mechanical integrity demonstration within
15 days of receipt of the results of the mechanical integrity
tests. If the Regional Administrator does not respond within
15 days, injection may continue.
G. GENERAL REQUIREMENTS
1 . Duty to Comply
The permittee must comply with all conditions of this permit. Any
permit noncompliance constitutes a violation of the Safe Drinking
Water Act and is grounds for enforcement action; for permit
termination, revocation and reissuance, or modification; or for
denial of a permit renewal application.
2. Duty to Provide Information
a. The permittee shall furnish to the Regional Administrator,
within a time specified, any information which the Regional
Administrator may request to determine whether cause exists for
modifying, revoking and reissuing, or terminating this permit,
or to determine compliance with this permit. The permittee
shall also furnish to the Regional Administrator, upon request,
copies of records required to be kept by this permit.
b. When the permittee becomes aware that it failed to submit any
relevant facts in a permit application, or submitted incorrect
information in a permit application or any report to the
Regional Administrator, it shall promptly submit such facts or
i nformation.
3. Need to Halt or Reduce Not a Defense
It shall not be a defense for a permittee in an enforcement action
that it would have been necessary to halt or reduce the permitted
activity in order to maintain compliance with the conditions of this
permit.
4. Signatory Requirements
a. All permit applications, reports required by this permit and
other information requested by the Regional Administrator shall
be signed by a principal executive officer of at least the
level of vice-president, or by a duly authorized representative
of that person. A person is a duly authorized representative
only if:
(i) The authorization is made in writing by a principal
executive of at least the level of vice-president.
(ii) The authorization specifies either an individual or a
position having responsibility for the overall operation
of the regulated facility or activity, such as the
C-153
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Permit No. AK-2D0217-E
Page 9 of 12
position of plant manager, operator of a well or a well
field, superintendent, or position of equivalent
responsibility. A duly authorized representative may
thus be either a named individual or any individual
occupying a named position.
(iii) The written authorization is submitted to the Regional
Admini strator.
b. If an authorization under paragraph a. of this section is no
longer accurate because a different individual or position has
responsibility for the overall operation of the facility, a new
authorization satisfying the requirements of paragraph a. of
this section must be submitted to the Regional Administrator
prior to or together with any reports, information or
applications to be signed by an authorized representative.
c. Any person signing a document under paragraph a. of this
section shall make the following certification:
"I certify under the penalty of law that I have
personally examined and am familiar with the information
submitted in this document and all attachments and that,
based on my inquiry of those individuals immediately
responsible for obtaining the information, I believe that
the information is true, accurate, and complete. I am
aware that there are significant penalties for submitting
false information, including the possibility of fine and
impri sonment."
5. Proper Operation and Maintenance
The permittee shall at all times properly operate and maintain all
facilities and systems of treatment and control (and related
appurtenances) which are installed or used by the permittee to
achieve compliance with the conditions of this permit. Proper
operation and maintenance include effective performance, adequate
funding, adequate operator staffing and training, and adequate
laboratory and process controls, including appropriate quality
assurance procedures. This provision requires the operation of
back-up or auxiliary facilities or similar systems only when
necessary to achieve compliance with the conditions of the permit.
6. Duty to Mitigate
The permittee shall take all reasonable steps to minimize or correct
any adverse impact on human health or the environment resulting from
noncompliance with this permit.
7. Inspection and Entry
The permittee shall allow the Regional Administrator, or an
authorized representative, at reasonable times, upon the
presentation of credentials and other documents as may be required
by law to:
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Permit No. AK-2D0217-E
Page 10 of 12
a.. Enter upon the permittee's premises where a regulated facility
or activity is located or conducted, or where records must be
kept under the conditions of this permit.
b. Have access to and copy any records that must be kept under the
conditions of this permit.
c. Inspect any facilities, equipment (including monitoring and
control equipment), practices, or operations regulated or
required under this permit.
d. Sample or monitor for the purposes of assuring permit
compliance or as otherwise authorized by the Safe Drinking
Water Act, any substances or parameters at any location.
8. Prohibition of Injection of Hazardous Waste
Injection of hazardous waste as defined in 40 CFR Part 261 is
prohi bi ted.
9. Penalties
The Safe Drinking Water Act provides that any person who violates
any requirement of an applicable underground injection control
program is subject to a civil penalty of not more than $5,000 for
each day of violation, or, if such a violation is willful, such
person may, in lieu of the civil penalty, be fined not more than
$10,000 for each day of such violation.
10. Permit Actions
a. This permit may be modified, revoked and reissued, or
terminated in accordance with the provisions of 40 CFR 144.39 -
144.41.
b. This permit will be terminated when final EPA action has been
taken on the permit application, or when the State of Alaska is
granted primary enforcement responsibility for the underground
injection control program pursuant to the Safe Drinking Water
Act, applicable to the injection activity regulated by this
permit, and the State has taken final action on the State
permi t application.
c. The filing of a request by the permittee for a permit
modification, revocation .and reissuance, or termination, or a
notification of planned changes or anticipated noncompllance,
does not stay any permit conditions.
11. Transfers
This permit is not transferable to any person except after notice to
the Regional Administrator on EPA Form 7520-7 and in accordance with
40 CFR 144.38. The Regional Administrator may require modification
or revocation and reissuance of the permit to change the name of the
permittee and incorporate such other requirements as may be
necessary under the Safe Drinking Water Act.
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Permit No. AK-2D0217-E
Page 11 of 12
12. Confidentiality of Information
a. In accordance with 40 CFR Part 2 (Public Information), any
Information submitted to the Regional Administrator pursuant to
this permit may be claimed as confidential. Any such claim
must be asserted at the time of submission by stamping the word
"confidential" on each page containing such information. If no
claim is made at the time of submission, EPA may make the
information available to the public without further notice. If
a claim is asserted, the information will be treated in
accordance with the procedures in 40 CFR Part 2 (Public
Information).
b. Claims of confidentiality for the following information will be
denied:
(i) The name and address of any permit applicant or permittee.
(ii) Information which deals with the existence, absence, or
level of contaminants in drinking water.
13. State Laws
Nothing in this permit shall be construed to preclude the
institution of any legal action or relieve the permittee from any
responsibilities, liabilities, or penalties established pursuant to
any applicable State law or regulation.
14. Property Rights
This permit does not convey any property rights of any sort, or any
exclusive privileges, nor does it authorize any injury to private
property or any invasion of personal rights, nor any infringement of
Federal, State, or local laws or regulations.
15. Severabi1i ty
The provisions of this permit are severable, and if any provision of
this permit, or the application of any provision of this permit to
any circumstance, is held invalid, the application of such provision
to other circumstances, and the remainder of this permit shall not
be affected thereby.
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ATTACHMENT 1
form
Permit No. AK-2D0217-E
Page 12 of 12
QMS Ha 2U40 OO4
UNITED
wEPA
TATES ENVIRONMENTAL PROTECTION AQENC\
WASHINGTON. OC 2046O
PLUGGING AND ABANDONMENT PLAN
NAME AND ADDRESS OF FACIL.TY
Kenai Gas Field, Kalifonsky Beach Road
near Kenai, Alaska •
NAME ANO AOORESS OF OWNER/OPERATOR
Union Oil Company of California
P.O. Box 6247, 909 W. 9th, Anchorage, AK 99502
LOCATE WELL ANO OUTLINE UNIT ON
SECTION PLAT — S4O ACRES
I T
I I
I I I
STATE
AK
COUNTY
Kenai Borouah
PERMIT NUMBER
samole
SURFACE LOCATION DESCRIPTION
SW '/.OF SW ViOF SE
v. SECTION
31
TOWNSHIP
5N
aiNGE
12W
LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION ANO DRILLING UNIT
sun-ace 605 S
Location —— ft. from IN/SI __
. Una of quanar saction
,n<,343
W
TYPE OF AUTHORIZATION
53 Individual Permit
Q Area Permit
QRul.
Number of Wells _1
Lease Nam. A-028055
WELL ACTIVITY
Q CLASS I
% CLASS II
£ Snne Disposal
C Enhanced Recovery
C Hydrocarfion Storage
C CLASS III
Well Number KU VD-1
CASING ANO TUBING RECORD AFTER PLUGGING
SIZE
7"
WTILB/FTl TrOSEPUTlNWELLlFTl
TOaELEFTINWELLlFTI
47
29
118
3276
118
3276
HOLE SIZE
Drive pipe
8/2
METHOD OF EMPLACEMENT OF CEMENT PLUGS
G3 The Balance Method
Q The Dump Sailer Method
D The Two-Plug Method
D Other
CEMENTING TO PLUG ANO ABANDON DATA
PLUG »^ I PLUG »2 I PLUG '3 I PLUG '* I PLUG »S
PLUG •
Sue of Hot« or Ptpg m wntcn Plug Will fl« Ptactd oncnesi
I
Daoin to Bonom of Tubing or OnH P'o« tft)
2980
2980
I of C«fn«m To 8« Us»o it ten plug)
18
50 I
Slurry
To 9e Pumo*d ./G»I I
15.8
15.8
Type Cam«nt or Otnar Ma tan at (Class HI)
Class G
:iass G i
UST ALL OPEN HOLE ANO/OR PERFORATED INTERVALS AND INTERVALS WHERE CASING WILL as VARIED »/,»«»/
From
To
From
To
iiad Cost 10 Plug Walls
$250,000
CERTIFICATION
/ certify under the penalty of law that I have personally examined and am familiar with the information
submitted in this document and all attachments and that, based on my inquiry of those individuals
immediately responsible for obtaining the information. I believe that the information is true, accurate.
and complete. I am aware that there are significant penalties for submitting false information, including
the possibility of fine and imprisonment. (Ref. 40 CFR 144.32)
NAME ANO OFFICIAL TTTU lfl»itt run or primi
Gerry A. Graham
District Cceraticns Manaoer - Alaska
SIGNATURE
DATE SIGNED
EPA Form 7520-14 (3-84)
C-157
-------
r c
Unlon Q\\ Company
Union Oil Compan\ jf California
In Reply Give
February 17, 1986
TO: J. T. Beitia
J. R. Callender
C. H. Case
FROM: Candy Lockwood
Permit Requirements
W.D. No. 1, Kenai Gas Field
Attached for your information are the permit requirements for Kenai Gas Field,
W.D. No. 1. Please ask your field personnel to provide the requested data to
the Environmental Department for further handling with the agencies involved.
For those so inclined, I have attached a copy of the complete W.D. No. 1
permit to answer any questions that may arise. You will note that all
up-to-date changes have been noted on the permit. However, if you need
further assistance please feel free to contact the Environmental Department.
cwl
cc: G.A. Graham
R.D. Roberts
R.R. Culver
B. Smith
L. Abeuiathy
C-158
FORW 1.0C03 REV ».7I) niNTto'lN u.l.A.
-------
r
00260
•k STATE OF ALASKA
ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION
WD#1 PERMIT NO. 8A23-DB015
REPORTING REQUIREMENTS
Report due within 30 days of sampling.
1. DRILLING FLUIDS - Test fluid from each new well and workover to be
injected down WD#1 for the following:
Sodium x Carbonate " Arsenic ^
Potassium ' Bicarbonate/ Barium ^
Magnesium / pH - Cadmium ^
Iron — Sulfate x Chromium -
Calcium / Total Dissolved SolidsX^ Cyanide'"
Chloride x Lead
2. PRODUCED WATER
Representative Sample due annually by January 31.)
Sample must be tested for the following:
Sodium x Carbonate ^
Potassium ^ Bicarbonate/
Magnesium ^ pH ^
Iron •' Sulfate'
Calcium ' Total Dissolved Solids x
Chloride
Analysis must be performed in accordance with Standard Methods for the
Examination of Water and Wastewater.
3. INJECTION LOG - (must be available for inspection at site)
Report due annually, by January 31
Log must contain:
1. Date-of receipt and source of waste received.
2. Volume from each source.
3. Composition of the waste.
4. Type of monitoring performed and the results.
5. Date of injection
6. Level of injection
7. Surface pressures at beginning and end of each injection activity or
daily, whichever occurs first.
8. Maintenance activities
9. Record of any unusual complications.
C-
-------
• r r
STATE OF ALASKA
ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION
WD #1 PERMIT NO. 8A23-OB015 *
GENERAL REQUIREMENTS
1. Discharge shall be contained between 2710-3250 below surface of the
ground.
2. Discharge shall not exceed 5,000 barrels per day (210,000 gal/day)
and 150,000 barrels per year (6.3 million gal/year).
3. Maximum wellhead pressure is limited to 1,100 psi.
4. Only produced waters, drill fluids dilution water and equipment
washwater associated with drilling and production activities are
approved for injection.
PERMIT EXPIRES JANUARY 1, 1990
C-160
-------
BUREAU OF LAND MANAGEMENT
W.D. NO. 1
PERMIT REQUIREMENTS
The following items must be reported on a monthly basis:
1. Volume of produced water, drilling fluid, and dilution water
injected.
2. The range and average tubing and casing pressures.
3. An analysis of pH, chlorides, and total solids from each well,
4. Temperature logs are to be run within 30 days of continuous
injection, then after 6 months and then yearly.
C-161
-------
• r c
U.S. ENVIRONMENTAL PROTECTION AGENCY
KENAI GAS FIELD W.D. NO. 1
PERMIT REQUIREMENTS
1. Surface injection pressure of 1,100 psi.
2. Injection depth approved at 2710'.
REPORTING REQUIREMENTS
Due monthly
Form 7520-8 - Injection well monitoring report. 146.23 (b)(2)(i)
Due annually,
Annual report containing the following:
Summary of 146.23 (b)(2)(i) to include monthly records of injected fluids,
and any major changes in characteristics or sources of injected fluid.
May include previously submitted information by reference.
Additionally, a demonstration of mechanical integrity pursuant to 146.08
at least once every five years during the life of the injection well.
cwl/00260
C-162
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STATE OF ALASKA
DEPARTMENT OF ENVIRONMENTAL CONSERVATION
SOUTHCENTRAL REGIONAL OFFICE
437 "E" Street, Suite 200
ANCHORAGE, ALASKA 99501
Mr. Larry Cutting
Union Oil Company of California
P.O. Box 6247
Anchorage, Alaska 99502
PERMIT NO. 8423-DB015 DATE ISSUED: June 7, 1985
This permit is issued to Union Oil Company of California for the injection of
/ a. maximum of 5,000 barrels/day (210,000 gal/day) and 150,000 barrels/year
/V (6.3 million gal/year) of wastewater associated with the production of natural
gas located at Waste Disposal Well #1, Kenai Gas Field, off the Kalifonsky Beach
Road, 606'N and 2297'W of S.E. Cor., Sec. 31, T5N, R11W, Seward Meridian.
This permit is subject to the conditions contained in Appendices A and B, which
are incorporated herein by reference.
This permit is issued under provisions of Alaska Statutes 46.03, the Alaska
Administrative Code as amended or revised, and other applicable State laws and
regulations.
This permit is effective on issuance and expires January 1, 1990. This permit
may be modified or terminated before that time should the classification of the
waste change. It may be terminated or modified in accordance with AS 46.03.120.
Bill H/Tjamoreaux
Regional Supervisor
C-163
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PERMIT NO. 8423-DB015 Page 1 of 4
APPENDIX A
SPECIFIC CONDITIONS
A. Application Compliance
The Permittee shall comply with all parts of their permit application
dated November 30, 1984, except as specified otherwise in this permit.
Additional modifications may be requested, but must be authorized by
a permit amendment signed by the Regional Supervisor to be effective.
B. Site Operation
--' " - - 3 ~*3 C
1. The discharge shall be contained between 3030•'- 3250—feet below
the surface of the ground, unless authorized by a permit modifica-
tion issued by the Regional Supervisor of the Alaska Department
of Environmental Conservation.
2. The discharge shall not exceed 5,000 barrels per day (210,000
gal/day) and 150,000 barrels per year(6.3 million gal/year).
i i *-/ r>
'**U^J »I.A n. .*
3. The maximum pressure -at—the—reservoirs is limited to 1,500 psi.
4. The discharge shall b^limited to those wastes directly related
to drilling • activities7u""'"1This -includes, produced water.; drill
fluids and dilution water." '^Ofher—\vastej—-including—equipment
washwater—is~not-authorized"~tar*be -discharged.
5. The injection of hazardous waste is prohibited. Hazardous wastes
are defined according to Title 40, Part 261 of the Code of Federal
Regulations.
6. Should the monitoring required in Section C of this permit indicate
leaks in the casing, or the waste entering areas other than what is
authorized by this permit, the permittee shall cease injection
ijmmediately and take the necessary remedial steps to step this
violation. Injection will not begin until adequate repairs are
complete and the Department authorizes start-up in writing.
7. The waste shall be collected and injected without loss or spillage
onto the surface of the ground.
C-164
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PERMIT NO. 8423-DB015 Page 2 of 4
C. Monitoring and Reporting
1. Hazardous Wastes
The Permittee shall test all materials that are suspected of being
hazardous and exclude them from injection under Sec. B.5.
2. Produced Water
The permittee shall conduct a representative chemical analysis of
produced water to be injected as required by the BLM. The follow-
ing chemical analysis are required:
Sodium Carbonate
Potassium Bicarbonate
Magnesium pH
Iron Sulfate
Calcium Total Dissolved Solids
Chloride
This analysis shall be conducted annually and the results shall be
submitted to the Department's Southcentral Regional Office and the
Kenai District Office by January 31 of each year during the term
of this permit.
3. Drilling Fluids
The Permittee shall conduct a composite, representative chemical
analysis of the drilling fluids to be injected from each new well
and workover. The following chemical analysis are required:
Sodium Carbonate Arsenic
Potassium Bicarbonate Barium
Magnesium .pH Cadmium
Iron Sulfate Chromium
Calcium Total Dissolved Solids Cyanide
Chloride Lead
This analysis shall be submitted to the Department's Southcentral
Regional Office and the Kenai District Office within 30 days of
sampling during the term of this permit. Following a review of
two of these reports, the Department may modify this requirement.
4. The analysis required in Sec. 1. 2. and 3., shall be performed in
accordance with Standard Methods for the Examination of Water and
Wastewater. (American .PUDIIC Heaitn ASSOC.;~
C-165
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PERMIT NO. 8423-DB015
Page 3 of 4
5. Injection Log
The Permittee shall maintain a log which will contain the date
of receipt and source of waste received, volume frcra each
source, composition of the waste, type of monitoring performed
and the results. This log shall also include the dates of
injection, the level of injection, surface pressures at the
beginning and end of each injection activity or daily, which-
ever occurs first, maintenance activities, and any unusual
complications. A copy of this log will be submitted to the
Department's Southcentral Regional Office and the Kenai Dis-
trict Office on an annual basis. The log shall be submitted
by January 31 of each year during the term of this permit.
The log must be available for inspection at the site.
6. Temperature Monitoring
A temperature log run in accordance with your monitoring plan
filed for the BLM Permit to Drill shall be submitted to the
Southcentral Regional Office and the Kenai District Office
upon completion.
7. Injection Level
Any changes in injection levels other than as authorized in
this permit, requires the written approval in the form of a
permit modification from the Southcentral Regional Supervisor.
8. Noncompliance Notification
If for any reason the Permittee does not comply with or will be
unable to comply with any limitation specified in this appendix,
the Permittee shall report the noncompliance to the Kenai Dis-
trict Office within 24 hours, by telephone, telegraph, or in
the absence of both, by mail. This notification does not
relieve the permittee of any civil or criminal penalties for
noncompliance.
For purposes of this permit, non-compliance is defined as:
a. Discharging waste other than authorized.
b. Operating the injection well with a leak in the casing, as
identified by pressure monitoring.
c. Causing discharges to surface waters and lands, and to fresh
' water aquifers.
d. Injection into a formation and level other than as author-
ized in this permit, or as may be amended by the Regional
Supervisor.
e. Violating any conditions of this permit.
C-166
-------
PERMIT NO. 8423-DB015 Page 4 of 4
9. Reporting
All reporting required in this section shall be submitted to:
Alaska Department of Environmental Conservation
Kenai District Office
P.O. Box 1207
Soldotna, AK 99669
Phone (907) 262-5210
Alaska Department of Environmental Conservation
Southcentral Regional Office
427 E Street, Suite 200
Anchorage, Alaska 99501
Phone (907) 274-2533
C-167
-------
PERMIT NO. 8423-DB015 Page 1 of 2
APPENDIX B
GENERAL CONDITIONS '
A. Access and Inspection
The Department's representatives shall be allowed access to the Permittee's
facilities to conduct scheduled or unscheduled inspections or tests to
determine compliance with this permit and State laws and regulations.
B. Availability of Records
Except for information relating to secret processes or methods of manu-
facture, all records and reports submitted in accordance with the terms of
this permit shall be available for public inspection at the Southcentral
Regional Office of the Alaska Department of Environmental Conservation at
437 "E" Street, Suite 200, Anchorage, Alaska.
C. Civil and Criminal Liability
Nothing in this permit shall be construed to relieve the Permittee from
civil or criminal penalties for nonccmpliance, whether or not such nonccm-
pliance is due to factors beyond his control, including but not limited to
accidents, equipment breakdowns, or labor disputes.
D. Property Rights
The issuance of this permit does not convey any property rights in either
real or personal property, or any other privileges; nor does it authorize
any damage to private property or any invasion of personal rights, nor any
infringements of federal, State, or local laws and regulations.
E. Severability
The provisions of this permit are severable and, if any provision of this
permit or the application of any provision of this permit to any circum-
stances is held invalid, the application of such provision to other
circumstances and the remainder of this permit shall not be affected
thereby. .Notwithstanding the above, in the event such invalidation
materially alters the scope or conditions of this permit, the Department
shall have the right, at its sole option, to terminate the permit.
C-168
-------
PERMIT NO. 8423-DB015 Page 2 of 2
F. State Laws
Nothing in this permit shall be construed to preclude the institution
of any legal action or relieve the Permittee from any responsibilities,
liabilities, or penalties established pursuant to any applicabble State
law or regulation.
G. Adverse Impacts
The Permittee shall take all necessary means to minimize any adverse
impact to the receiving waters or lands resulting frcra noncoropliance
with any limitations specified in this permit, including such additional
monitoring as necessary to determine the nature and impact of the
noncomplying discharge. The Permittee is required to undertake cleanup
activities in the event of any adverse impact resulting from nonccm-
pliance.
H. Modifications or Changes
Anticipated facility expansion, production increases or process modifi-
cation resulting in changes to operation will be reported to the Depart-
ment, at least 30 days prior to the implementation of such changes.
I. Permit Availability
The Permittee shall retain a copy of this permit at the disposal facility.
J. Transfers
Should operation of the facility be contracted or a change in contractors
be made, the new contractor shall be notified of the existence of the
permit and its conditions. A copy of the written notification shall be
forwarded to the Regional Supervisor of the Department's Southcentral
Regional Office, 437 "E" Street, Suite 200, Anchorage, Alaska 99501
(274-2533).
C-169
-------
CSG-
L :'J; ;n>:i_ ^.'".. ' BILL SHEFFIELD, GOVERNOR
DEPT. OF ENVIRONMENTAL CONSERVATION
SOUTHCENTRAL REGIONAL OFFICE
437 E STREET, SUITE 200
ANCHORAGE, ALASKA 99501 274-2533
July 3, 1985 _ __
\\\\ '
:!••! 031363
v W -^
Mr. Larry Cutting ^ Erw'ro
Union Oil Company of California
PO Box 6247
Anchorage, Alaska 99510
Dear Mr. Cutting:
RE: WD #1
8423-DB015
The Department has reviewed your June 20, 1985 letter regarding
the referenced permit. It appears that some confusion in termi-
nology and permit wording is the basis for all but the last item
covered by your letter. In response to these issues, we hereby
grant the following permit modifications:
-Permit Cover, first paragraph, shall be changed to read:
This permit is issued to Union Oil Company of California
for the injection of a maximum of 5,000 barrels/day
(210,000 gal/day) and 150,000 barrels/year (6.3 million
gal/year) of wastewater associated with the drilling and
production of oil and natural gas. The wastewater will be
injected at Waste Disposal Well #1, Kenai Gas Field, off
Kalifonsky Beach Road, 606' N and 2297' W of S.E. Cor., Sec.
31, TSN, Rll W., S.M.
-Appendix A, Part B.3, shall be changed to read: The maximum
well head pressure is limited to 1500 psi.
-Appendix A, Part B.4, shall be changed to read: The dis-
charge shall be limited to those wastes directly related
to drilling and production activities. This includes
produced waters, drill fluids and dilution water. Other
waste, including equipment washwater is not authorized to
be discharged.
In regards to your comments concerning Appendix A. Part B and C,
as it relates to well safety, the Department believes that the
requested data is appropriate to establish that all concerns of
our Department are being reviewed and addressed, whether by this
C-170
-------
• r r r
Mr. Larry Cutting 2 July 3, 1985
Union Oil Company
Department or other governmental authorities and that these re-
quirements are fixed for the term of the permit. We will consult
with the BLM and AOGCC where safety issues and environmental pro-
tection are of joint concern. It is our position that the requested
information represent data critical to evaluating characteristics
of discharged materials and the assurance that this discharge is
only into the authorized injection zone.
Department of Environmental Conservation regulations provide
that any person (s) who disagrees with any portion of this deci-
sion may request an adjudicatory hearing in accordance with 18
AAC 15.200-315. The request should be mailed to the Commissioner
of the Alaska Department of Environmental Conservation, Pouch 0,
Juneau, Alaska 99811, or delivered to his office at 3220 Hospital
Drive, Juneau. Failure to submit a hearing request within thirty
(30) days of receipt of this letter shall constitute a waiver of
that person's right to judicial review of this decision.
Sincerely
Bill H. Lamoreaux
Regional Supervisor
BHL/JH/pkk
cc: Kenai District Office
Mary Core, Alaska Center for the Environment
Jerry Opatz, EPA, Seattle
C-171
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C-172
-------
ATTACHMENT C: MONTHLY WELL
INJECTION REPORTS, JANUARY-JULY, 1986
KENAI GAS FIELD
C-173
-------
C-174
-------
* t^TED STATES ENVIRONMENTAL PROTECTION AGS^f
A •— -« a '^ WASHINGTON. DC 20460 '^J
^E PA INJECTION WELL MONITORING REPORT
YEAR 1986
Injection Pressure (PSI)
1. Minimum
2. Average
Injection Rate (Gal/Mm)
1. Minimum
2. Average
3. Maximum
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
1. Monthly Total
2. Yearly Cumulative
Temperature (F°)
1 Minimum
2. Average
3 Maximum
pH
1 . Minimum
2. Average
Other
MONTH
Jan .
55D
7PR
qnn
n fl
5.5
10.2
o
n
n
344.73?
!U4.?3?
MONTH
Name and Address of Perm.nee Union Oil Company of California (Unocal)
P.O. Box 190247, Anchorage, AK. 99519-0247
Name and Official Title /Please type or print/
Roy D Roberts
Environmental Specialist
Signature
T^f-. Oa£~'7\£k''
-------
IjgBED STATES ENVIRONMENTAL PROTECTION AGE|g|^
ft _ — * - ^F WASHINGTON. DC 20460 WW
^C PA INJECTION WELL MONITORING REPORT
YEAR 1986
Injection Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Rate (Gal/Min)
1. Minimum
2. Average
3. Maximum
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
1 . Monthly Total
2. Yearly Cumulative
Temperature (F°)
1. Minimum
2. Average
3. Maximum
pH
1. Minimum
2. Average
3. Maximum
Other
Water from Beaver Creek
Water from Well KBU 33-7
Water from Kenai Gas Field
• MONTH
Feb.
700
800
900
1.3
5.1
8.8
0
0
0
517.272
861,504
162,918
264.264
90,090
MONTH
Name ana Address of Permittee Union Oil Company Of CalifOmdi (UHOCal)
P.O. Box 190247, Anchorage, AK. 99519-0247
Name and Official Title iPleasa type or print)
Roy D. Roberts
Environmental Engineer
Signature f
&& 0 f\i£c''*£
'i
Form Approved
OMB No. 200O-O042
Approval expires 9-30-86
MONTH
-
—
-•
Permit Numoer
AK-2D217-E
Date Signed
02/04/86
EPA Form 7520-8 (2-84)
C-176
-------
UNITfelpttATES ENVIRONMENTAL PROTECTION AGENCY tegl
fl _ _ _ ^^ WASHINGTON. DC 20460
^E PA INJECTION WELL MONITORING REPORT
YEAR
Injection Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Rate (Gal/Mm)
1. Minimum
2. Average
3. Maximum
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
1 . Monthly Total
2. Yearly Cumulative
Temperature (F°)
1. Minimum
2. Average
3. Maximum
pH
1. Minimum
2. Average
3. Maximum
Other
Water from Beaver Creek
Water from well 33-7
Water from KGF
MARCH MONTH
790
Q4R
1100
1 n
5 Q
9.0
0
0
0
480,396
1,341,900
183,120
202, 6bU
94,416
MONTH
Name and Address of Permittee
Union Oil Co. of Calif, P.O. Box 190247, Anch, Ak. 99519-0247
Name ^93 Official 1jyfl-/£0?f3? 'W* or prim)
Environmental Engineer
Signature
/|02;>,£/ T^Qht^L^fy
Form Approved
OMB No. 2000-00*2
Approval expires 9-30-86
MONTH
—
'ermit Number
AK 2D217 E
Date Signed
4/3/86
-------
U^BO STATES ENVIRONMENTAL PROTECTION AGENgj^
A jp—jrtA ^^ WASHINGTON, DC 20460 H*^
^E PA INJECTION WELL MONITORING REPORT
YEAR
Injection Pressure (PSI)
1. Minimum • •
iV '
2. Average --*'
3. Maximum
Injection Rate (Gal/Mm)
1. Minimum
2. Average
3. Maximum
Annular Pressure (PSI) ^
\
V
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
1 . Monthly Total
2. Yearly Cumulative
Temperature (F°)
1. Minimum
2. Average
3. Maximum
pH
1. Minimum
2. Average
3. Maximum
Other
Water from Beaver Creek
Water from Well 33-7
Water from Kenai Gas Field
MONTH
APRIL
805
900
995
0.7
5.1
9.5
0
0
0
291,900
1,633,800
189,966
26,880
75,054
MONTH
CX *--f.
-
Name and Address of Permittee
Unocal , P.O. Box 190247, Anchorage, Ak. 99519-0247
Name and Official Title (Please type or print)
Roy D. Roberts
Environmental Engineer
Signature
Form Approved
OMB No. 20OO-0042
Approval expires 9-30-86
MONTH
-
—
, ^ /<. c 7^ : . '-'.•-'-• i *•<-.
s
Permit Number
AK-2D0217-E
Date Signed
5/5/86
EPA Form 7520-8 (2-84)
C-178
-------
JJ^D STATES ENVIRONMENTAL PROTECTION AGEi^9
Ar-mA WASHINGTON. OC 20460 ^^
^81 PA INJECTION WELL MONITORING REPORT
YEAH 1QSfi
Injection Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Rate (Gal/Min)
1. Minimum
2. Average
3. Maximum
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
I. Monthly Total
2. Yearly Cumulative
Temperature (F°)
1. Minimum
2. Average
3. Maximum
pH
1. Minimum
2. Average
3. Maximum
Other
Water from Beaver Creek
Water from Kenai Gas Field
MONTH
MAY
700
800
900
0.7
3.9
7.1
-0-
-0-
-0-
165,396
1,799,196
^
83,370
82,026
MONTH
r r
Name and Address of Permittee
Unocal, P.O. Box 190247, Anchorage, Ak. 99519-0247
N^e an- Of
-------
STATES ENVIRONMENTAL PROTECTION
WASHINGTON. DC 20460
INJECTION WELL MONITORING REPORT
form Approved
OMB No. 2000-0042
Approval expires 9-30-86
X" YEAR
Injection Pressure (PSD
1. Minimum
2. Average
3. Maximum
Injection Rate (Gal/Min)
1. Minimum
2. Average
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Volume (Gal)
1. Monthly Total
Temperature (F°)
1. Minimum
2. Average
3 Maximum
pH
1. Minimum
2. Average
Other
Water from Beaver Creek
Water from Kenai Gas Field
MONTH
JUNE
700
800
900
0.7
3.9
7.1
-0-
-0-
-0-
167.95R
• r-
104.454
63,504
MONTH
Name and Address of Permittee
Unocal. P.O. Box 190247, Anchorage, Ak. 99519-0247
Name and Official Title (Please type or print)
Roy D Roberts
Environmental Enaineer
Signature
MONTH
—
AK 2D0217-E
Date Signed
7/11/86
EPA Form 7S20-8 (2-84)
C-180
-------
Uiq§pb STATES ENVIRONMENTAL PROTECTION AGENTS
^^ _____ WASHINGTON. DC 20460
^E PA INJECTION WELL MONITORING REPORT
YEAR
Injection Pressure (PSI)
1. Minimum
2. Average
3. Maximum
Injection Rate (Gal/Min)
J. Minimum
2. Average
3. Maximum
Annular Pressure (PSI)
1. Minimum
2. Average
3. Maximum
injection Volume (Gal)
f
1. Monthly Total
2. Yearly Cumulative
Temperature (F°)
1. Minimum
2. Average
3. Maximum
pH
1. Minimum
2. Average
3. Maximum
Other
Water from Beaver Creek
Water from Kenai Gas Field
MONTH
JULY
700
800
900
0.7
4.1
7.1
-n-
-0-
-0-
177,282
2,144,436
s
1 1 9 , 784
57,498
MONTH
Name and Address of Permittee
Unocal P.O. Box 190247, Anchorage, Ak. 99519-0247
Name and Official Title ff tease type or print/
Roy D Roberts
Environmental Engineer
Signature
faa/fct**
form Approved
OMB No. 2000-0042
Approval expires 9-30-3S
MONTH
—
'ermit Number
AK 2D0217-E
Date Signed
8/5/86
EPA Form 7520-8 (2-84)
-------
C-182
-------
CALIFORNIA
C-183
-------
C-184
-------
Sampling Report
Investigation of Sun Exploration and Production Company's
Oxnard Oil Handling Facility
Oxnard, California
July 14, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Santa Maria or Ventura Basin production sites
developed by the California Department of Conservation at the
request of EPA. The list was transmitted via telephone to the
EPA contractor on July 8, 1986. Randomization and site selection
took place during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Conservation listed the possible sample sites
by operator and general location. For simplicity of selection,
the list was transmitted as shown below. The list consisted of
five production sites:
1. Santa Fe Energy - Sespe Field
2. Arco - Ojai
3. Sun Oil - Oxnard
4. Sun Oil - Ojai
5. Conoco - San Miguelito
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 3 on the above list
(Sun Oil - Oxnard).
Further inquiry identified the primary sample site as Sun
Exploration and Production Company's Oxnard Oil Handling Facility
in Oxnard, California. No problems were encountered in arranging
sampling for July 14, 1986. No back-up site was required.
C-185
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Site Location
The Oxnard Oil Handling facility is located approximately 2 miles
south of Highway 101 via Rice Road and East Fifth Street in
Camarillo, CA. Figure 1 is a map indicating the production
facility site. The full name and mailing address for Sun is:
Sun Exploration and Production Company
25322 West Rye Canyon Road
Valencia, California 91355-0560
Main Office Ph.: 805-257-6228
Main Office Contact: B.J. Atkins
Environmental Coordinator
Attendees
Sampling at the Sun production site was performed by CENTEC
Corporation personnel on July 14, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (sample team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representative: Mike Stettner, California
Department of Conservation,
Division of Oil and Gas
Operator Representatives: B.J. Atkins, Environmental
Coordinator
Diana Visser, Segment
Production Engineer
Jim Wilson, Lease Operator
Lloyd Hill, Segment Foreman
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
Site Description
The Sun production facility is located in a rural, flatland area
in the Oxnard Flood Plain. The climate at this site location is
net precipitation. The soil consists largely of sand and clay.
Wells serviced by this facility are completed in the Vacca Tar
Sand formation of the Ventura Basin.
The depth to the groundwater in the area is between 0 and 25
feet. The nearest surface water is the Santa Clara River,
located approximately 3 miles west of the site. There are fresh
water wells within a 1/2- to 1-mile radius of the site, but these
C-186
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O X NV R D AIR FORCE BASE
• 9
FE LOCATION . .
V
\ I
1 !.OilW«H
>
Figure 1. Location of Sun Exploration and Production
Company's Oxnard Oil Handling Facility,
Oxnard, California
C-187
-------
are not drinking water wells. Their main use is for irrigation
and watering cattle.
The site was being tested as a pilot operation by Sun, to assess
the productivity of the facility and its associated wells. If
the site proved to be productive, Sun expected to upgrade all _the
equipment. Otherwise, Sun would consider selling the property.
For this reason, Sun representative B.J. Atkins requested that he
direct CENTEC's photo documentation, intending to avoid
documenting poor quality equipment that was out of use or soon to
be removed. The CENTEC team complied with his request.
At the time of sampling, the site consisted of one 2,500-barrel
steam heated oil and water separating tank called a "wash tank,"
two 3,000-barrel crude storage tanks, an 80-barrel skim tank, a
500-barrel diluent tank, a waste sump, and one injection well.
Figure 2 is a diagram of the site, dated 1984, as provided by
Sun. Several vessels on the site had been taken out of service
since Sun purchased the site from the previous owner. Well
No. 1 was in use as an injection well at the time of sampling.
The oil from wells in this area has an average API gravity
between 3 and 6 (water has an API gravity of 10). This means
that the oil is very thick and difficult to move. In order to
pump the oil, a diluent is introduced down-hole to thin and
lighten the oil. The diluent Sun used was KD-40, a kerosene
distillate. In addition, the wells are stimulated using a cyclic
steam recovery method referred to as "huff and puff."
Seven wells were serviced by this production facility at the time
of sampling. These were the W.R. Livingston Well No. 2, the C.V.
Lenox Well No.s 77 and 82, and the E.E. Lenox Well No.s 49, 60,
64, and 69. The average depth of these wells is 2,200 feet.
Each of the seven producing wells generated a daily average of 15
to 20 barrels of oil. Total oil production was approximately 120
barrels per day, and total water production was 150 barrels per
day. In addition to oil and water, production included small
amounts of natural gas containing
Oil enters the production area from the seven producing wells.
Referring to Figure 2, the wash tank receives the oil, where it
is heated by steam through coils in order to separate the oil and
produced water. The oil layer goes to the stock tanks and the
produced water goes to the skim tank where it is held for
disposal (this water is essentially oil-free) . From here, the
water goes to the injection well. Prior to injection, the water
goes through a spun-fiber filter to remove any remaining solids.
The injection well head and filter are shown in Photos 4 and 5.
The crude oil is piped across East Fifth Street to the Chase
Oxnard Refinery where the diluent used in Sun's wells is
separated out and returned to the Sun facility.
C-188
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o
oo
vr
HOTf: $U*P » HT TMK
TO K cuumaeo.
»4»CK MEM.EY 2 • «t »S ^^*»
I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I
• JACK HCRttY «
I/
, CHASf PRODUCTION CO
II
." ." *'°
Figure 2. Schematic Diagram of Production Site
-------
Other chemicals in use at the time of sampling included a
demulsifier, used continuously at a rate of 1-pint per day; a
corrosion inhibitor, used continuously at a rate of 0.5 gallons
per day; and a scale inhibitor, added every two days at a rate of
0.1 gallon per day.
All tanks in use at the facility are cleaned as needed. The
western crude storage tank had been cleaned 1 week prior to the
time of sampling.
Disposal Practices
Produced water is disposed of in an injection well located within
the production area. This is the E.E. Lenox Well No. 1, as
shown in Figure 2.
Permits
Annual inspections of the Oxnard Oil Handling Facility are
conducted by the California Department of Conservation Division
of Oil and Gas, the Ventura County Air Pollution Control
District, and the Ventura County Environmental Health Department.
A copy of the Report on Operations for the E.E. Lenox Well No. 1
is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At Sun's Oxnard Oil Handing Facility, the sample was defined as
the fluid entering the injection well, E.E. Lenox Well No. 1.
Figure 2 indicates the sample point from which the fluid sample
was composited.
Attempts were also made to collect a tank bottoms sample from the
wash tank. The tank was found to have no collectable solids at
the time of sampling.
Sampling Methods and Equipment
The produced fluid sample was obtained through a tap in the line
between the injection well head and the solids filter. Photos 4
and 5 show the well head to the left of the sign, and the solids
filter, vertically oriented to the right of the sign.
C-190
-------
The sample was collected in a clean 1-gallon glass jar, and
composited in a 5-gallon glass carboy (Photo 5). Immediately
after the CENTEC team was through collecting their sample, the
API sample team collected their samples from the same tap.
Photo 6 shows operator representative, Lloyd Hill, at the top of
the wash tank attempting the collect a tank bottoms sample.
CENTEC samplers were not permitted to climb the tank because of
the presence of natural gas containing I^S. Anyone entering the
stairs to the wash tank is required by Sun to wear an air supply
and respiratory mask for which the wearer has been trained.
Only the coring device could be used to sample the wash tank
because the opening at the top was too small for the dredge. Sun
representatives, Wilson and Hill, first attempted to obtain a
sample using the coring device connected to 20 feet of steel
extension rods. The rods were found to be too heavy and
inflexible to manage at the top of the tank. The rods were
replaced with plastic tubing, shown in Photo 8. The coring
device came up empty each time it was inspected. Finally, a rope
was attached to the device, but proved to be no more productive
than the tubing. Thus, it was concluded that there were not
enough bottoms in the tank to be collected.
C-191
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C-192
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-193
-------
C-194
-------
o
Ul
HfplflptSVufln^Vl I HpjqA^UMMKMm^^^^H^^^H^HHp i*^ *p"»*r • * **
•"'ij«^:^"ar- .- /_ * .!JLW^?i^-"-*£*j* KViT
; -,»- 'i""i;Ms*'-j—. »**• •-•jXiMsa?'^'1'* '• ^ ^5.^1
m--^?:-*+ni/*y&.f!;*0>ixt >yy«*^""gB;^j..-v ,»>r<..>?':
- -Rvf.-.«'. . r^--'^%-*V'tl^.^M*t^^*ffliP*'**f^>
t-«c.:-r-:i4s-.-.-- r-.„- -• \• t^S^sSfii^i'vy
Photo I . Wash tank
Photo 2. Skim tank
Photo 3. Skim tank
-------
Photo 4. Well head and filter
Photo 5. Pouring liquid composite
-------
O
I
«a
vo
-vj
Photo 6. Lloyd Hill accessing wash tank
Photo 7. CENTEC sample team examining empty coring device
Photo 8. Accessing wash tank
-------
C-198
-------
ATTACHMENT B: PERMITS
C-199
-------
C-200
-------
c.
c
MHOURCM AOINCT or CALirOKMIA
OEPAHTMCNT OF CONSERVATION
DIVISION OF OIL AND GAS
Report on Operations
T 284-52
Stanley W. Blossom. Agent
Eyeter Oil Company, Ltd.
P. 0. Box 55060
Valencia. CA
Santa Paula
March 20,
Calif.
, API No.
Your operations at w»n "Lenox" 1 p API
S^. 6 T T.1N, R.21W S.B.B.A M. Oxnard Field, in
were witnessed ™» VL4/84 H. Fulco ~
die supervisor,was present from 1200 to —
MeCulloch
111-OlOy?
V«?ntura
.County,
, representative of
There were also pr»«»n» Geor.Te Johns
' Present condition of well: 11 V*»" cem.
; 8 5 /P." com. 257^'. e.n. 112?': 6 5/3" Id.
2529-288?'. perf. 2585-2883'. T.D. 23?5'.
The operations were performed for the purpose of demonstrating that the injected fluid is
f*r\m -Ci WAS-) ±t* *»^*••*+•-* V««n ^M.t OCXC I
confined to strata below 2585*
DECISION:
THE OPERATIONS ARE APPROVED AS INDICATI?JG THAT ALL OF THE INJECTION FLUID IS CONFINED TO
THE FORMATIONS BELOW 2585' AT THIS TIME.
00109 (9/S3/CSR1/1SM)
C-201
Murray W. Dosch
-------
C-202
-------
Sampling Report
Investigation of Shell California Production, Inc.'s
Central Water Treating System
Ventura, California
July 15, 1986
SITE INFORMATION
Site Selection
This site was specifically selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected from active
Santa Maria or Ventura Basin production sites in the vicinity of
sampling already underway near Ventura, California. Planned tank
bottom sampling at another production site in the area could not
be achieved because the tanks contained no collectable solids.
Thus, an alternate site (near the original production site) was
selected. The California Department of Conservation was integral
in the identification and selection of this site.
Site Location
Shell CPI Central Water Treating System is located west on
Highway 33, and approximately 5 miles north of the intersection
of Highways 33 and 101 in Ventura, CA. Figure 1 is a map
indicating the treatment site. The full name and mailing address
for Shell is:
Shell California Production, Inc.
P.O. Box 11164
Bakersfield, California 93309
Main Office Ph.: 805-326-5000
Main Office Contact: D. L. Oreolt, Manager
Environmental Conservation
West Coast Production Division
Attendees
Sampling at the Shell CPI Central Water Treating System was
performed by CENTEC Corporation personnel on July 15, 1986.
Following is a list of people present at the time of sampling:
CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
EPA Representative: William Telliard, Chief, Energy
and Mining Industries Branch,
Industrial Technology Div.,
Office of Water
State Representative: Mike Stettner, California
Department of Conservation,
Division of Oil and Gas
C-203
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Figure 1. Location of Shell Production's Central Water Treating
System, Ventura, California
C-204
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Operator Representatives: Carl Brown, Production Operator
for Central Water Treating
System
Tod Stallings, Field
Surveillance Technician
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
Site Description
The Central Water Treating System is located in suburban
piedmont. The climate at this site location is net precipi-
tation. The soil is described as sand over rock and clay. The
area is a dried-up river bed.
The depth to the groundwater in the area is approximately 10
feet. The nearest surface water is the Ventura River, less than
1/2 mile west of the site. The nearest drinking water well is
estimated to be greater than 10 miles from the site.
At the time of sampling, the site consisted of two "slop" tanks,
one "production wash tank," two Wemco flotation cells, two stock
tanks, and one sump pit that receives bottoms from three free
water knock out (FWKO) tanks. The sump pit was sampled for tank
bottoms. Figure 2 is an approximate schematic diagram of the
site, indicating the directions in which photos were taken. This
figure is based on a diagram provided by the operator, and
therefore does not include all the tankage discussed in this
report.
At the time of sampling, each well serviced by this facility
produced a daily average of 45 to 50 barrels of oil. The average
depth of these wells is 6,813 feet, and range in depth from 4,000
to 15,000 feet. Primary production techniques include both
natural and artificial drives. Produced water from these wells
is reinjected for waterflooding the producing wells in the area.
Oil enters the production area from approximately 250 producing
wells located on the Taylor and RBU (River Bottom Unit) leases.
Photos 6 through 9 show the major elements of the production
system. In particular, Photo 7 shows the three FWKOs that dump
bottoms to the sump pit every 8 hours. Photo 8 shows the sump
pit viewed from between the two slop tanks.
The sump pit functions as a skim tank for any oil that is not
separated from the produced water in the FWKOs, and as a settling
tank for solids. The pit receives mainly sand and produced water
that has a chlorides content of 12,000 parts per million. The
C-205
-------
O
I
to
O
11
II
O.
photo
1
\
1
0
0
0
0
1 1
.0 WAS 111**, k-
L- O.la^W^
O
O
O
O
\
1 1
•*s " — '•— '
N
Figure 2. Schematic Diagram of Central Water Treating System
-------
pit is constructed with 6-inch-thick concrete walls, and has an
automatic level controller that keeps no more than 8 feet of
contents in it at all times. A cover over the pit can be raised
automatically for access to the pit, as shown in Photos 2 and 3.
Actual construction requirements are not known because the pit is
20 years old, and records from that time are not available.
The treatment chemicals which are used as part of the production
process are:
Emulsion Breakers: Tretolite RP 4005
Scale Inhibitor: Baker Chemical Calnox 214 R
Coagulating Agent: Baker Chemical Magna Clear W 107
In regard to the question of whether the contents of the sump pit
are ever analyzed, the operator submitted the following remarks:
Pit contents are not routinely tested. However,
enclosed is an analysis [see Attachment C] of tank
bottoms which would be expected to consist of similar
material to the pit. Possibly the only difference
would be that the pit contains coarser sand grains than
the tank bottoms because of the limited residence time
in the FWKO vessels compared to the tanks.
The pit is cleaned out once every 4 months, and was last cleaned
two weeks prior to EPA's sampling visit. The two slop tanks and
one wash tank at the site are cleaned once per year. The FWKOs
are cleaned three times per day, every 8 hours, and the stock
tanks are cleaned only as needed.
Disposal Practices
Produced water leaving the sump pit is pumped to a clarifier (not
shown in Figure 2), where the liquid polymer "Magna-Clear W-170"
is added to further separate solids from the water. The water is
sent from the clarifier to the wash tanks, then to an injection
well for enhanced recovery.
The solids from the pit are hauled to the Ventura Regional
Sanitation District Landfill in Santa Clara. Solids separated
from the produced water in the clarifier are also hauled to the
landfill after they have been dewatered. The company that hauls
the solids is Offshore Crane.
Permits
No operating permits were made available to the sample team at
the time of sampling.
C-207
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SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
The sample collected at this site was a tank bottoms sample, and
was defined as the sludge layer in the sump pit. Figure 2
indicates the points at which the samples were taken. The pit
was sampled from the sides, so that the centers of measured
quadrants were inaccessible. Actual sample points were directed
by EPA representative William Telliard.
Sampling Methods and Equipment
The sump pit was sampled by tossing the dredge from the side of
the pit. The coring device was not used due to time constraints.
Photos 10 and 11 show sampling in progress.
The sludge contained considerable sand and oil, and appeared
black in the sample bottles.
The pH of the sludge sample was measured onsite after sampling
was completed. The pH of this sample was 8.
C-208
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-209
-------
C-210
-------
o
. I
to
Photo 1. Cover rising from sump pit
Photo 2. Cover rising from sump pit
Photo 3. Cover rising from sump pit
Photo 4. Sump pit pump (lower right corner
-------
i,s>|ue + ao|s,,
-------
o
I
to
U>
Photo 9. "Wemco Flotation Cells" and oil stock tank
Photo 10. Sampling sump pit
Photo II. Sampling sump pit
-------
C-214
-------
ATTACHMENT B: PERMITS
C-215
-------
n
i
-------
No permit specific to the operation
of this site is available.
C-217
-------
o
I
10
CO
-------
ATTACHMENT C: LABORATORY REPORT ON
TANK BOTTOMS SAMPLE FROM A
STOCK TANK AT SHELL'S
CENTRAL WATER TREATING SYSTEM
C-21y
-------
C-220
-------
JACOBS LABORATORY
DIVISON OF CHEMCAL RESEARCH LABORATORIES
29 NORTH OLIVE. VENTURA. CALIFORNIA 93001
October 8, 1985
TELEPHONE (805) 648-2735
Shell California Production Inc.
P.O. Box 11164
Bakersfield, CA 93389
Attn: Ray Ouelette
8509131
CAM analysis of one sample received on Sept 30, 1985.
bottom.
Sample identified as tank
Respectfull^subrndrtte^,
Thomas K. Mikel
Laboratory Director
TKM/jm
C-221
-------
FORM i
' W.-*57E COMPONENT AND V.\S7£ EXTRACTION TEST SUMMARY
Laboratory Sample // _ 8509131
Type of Sample Tested tank bottom
1. Chemical Analyses and
Component
Inorganic Analysis:
Antimcnv
Arsenic
Scriurn
Bervlhum
Cadmium
Chromium (Hi)
Chromium (VI)
Cobalt
Coooer
Fluoride
Lead
Mercury
Molvbdenum
Nickel
Selenium
Silver
Thallium
Vanadium
Zinc
Extractions
STLC TTLC
LIMITS LIMITS CO;
L3 500 '•
5.0 500
-00 10000
0.75 75
i.i 100
5dv iJOO
o puu
60 iO'OO .
H 2500
loo iyuou
3.U iOUU
u.2 20
JOU JiOO
20 2000
1.0 100
5 500
7.0 /UO
24 Z'+UU
2iC JUUU
TOTAL CALIFORNIA
:.CE:-rrRATioN EXTRACTION TEST
(=g/kg) (mg/l)
60* 4.4
2.7
82 -
<0.2
1.2* <0.01
29.2
<1
8.6
185* 0.02
1.2
180* 0.4
1.3* <0.001
16
110* 0.5
<0.2
0.8
16* 0.2
32* <0.1
340* 2.16
Organic Analysis:
Chlorinated Pesticides
Polvchiorinated Biohenvls
Chlorophenoxy Acid
Pesticides
Nitroaromatics
Organophosphorus
Pesticides
Phenols
Polynuciear Aromatic
Hydrocarbons
Priority Pollutants
Volatile Orcanics
Carbamates
Other (Soecifv)
oH
Not Aoolicable
* Exceeds STLC
** Exceeds TTLC
- 7 -
C-222
-------
II. Sic&ssay-
Concentration (mg/1)
95-hr LC,, for Waste
333 mg/1
95% Confidence Interval
III. Head Specs Vapor Concentration
306 mg/1 ± v <. 582 mg/1
Weight of
component
Molecular in syringe
Component weigh : (mg)
Head
space vapor
concentration
(CA) =
(QA) (SO
(MW) (G)
where (QA) = quantity of component in head space vapor (mg)
(MW) = molecular weight (mg/mmole)
(R) = 2'4.5 ml/mmole
(G) = 2 x 10"6 M3
(CA) = Head space vapor concentration (ppm)
C-223
-------
FORM 3
cc-niicsivrrsr, FLAMMABILITY, REACTIVITY OF
Pzramsrsr
Experiment;:! data or ,
certification by chemist
Reference
Corrosivity
0% dilution
see item tb
' ^u JG-4 dil-:::cn , 7, , ,«<>„
- corrosion r^ta"* (rr.m/vr':
sec item *b
seo item tb
Flammability 0
- Flash ooint* (°O 36.0 C
see item &b
- Causes fire
- Fia.T.maole »as
- Fiam.TiabLe solid
- Oxidizer
Reactivity
- Unstable
- Reacts with H.O
- Forms potentially explosive
mixture with H,O
- Generates toxic~gases
with H.O
- Is a cyanide or suifide
between pH 2 and 12.5
which generates toxic
gases
Detonates or reacts at
standard temperature,
pressure
Detonates if heated under
confinement or with
initiating source
Forbidden or class B
exolosive
NOTES:
Fill in as follows:
Code
Y
N
X
if Optional
Certification
yes
no
not applicable
Supply experimental data
* comments or attachments
C-224
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Sampling Report
Investigation of Shell California Production, Inc.'s
River Bottom Unit Gosnell Well No. 51
Ventura, California
July 15, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Santa Maria or Ventura Basin drill sites
developed by the California Department of Conservation at the
request of EPA. The list was transmitted via telephone to the
EPA contractor on July 8, 1986. Randomization and site selection
took place during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Conservation listed the possible sample sites
by operator and operator representative. For simplicity of
selection, the list was transmitted as shown below. The list
consisted of four sites:
1. Conoco - Mr. Dave Dooley
2. Sun - Mr. Terry Carter
3. Santa Fe - [Contact kept private by Department of
Conservation.]
4. Shell - [Contact kept private by Department of
Conservation.]
Usually the EPA contractor assigned numbers to the members of the
list as they were transmitted and a random number table was used
to select the primary and back-up sample sites. In this case,
however, the Department of Conservation had already contacted the
proposed sample sites. Only site No. 4 (Shell) was amenable to
participation in the sampling program. The sampling time frame
would not allow pursuit of EPA's authority to sample a random
site at its discretion; thus, the Shell site was selected. It is
considered a random sample, however, because no bias was
introduced into its selection. It was selected from a random
list on the basis of availability. No information was available
C-225
-------
to indicate this site was a particularly "good" or
for sampling.
"poor" site
Further inquiry identified the primary sample site as Shell
California Production, Incorporated's River Bottom Unit Gosnell
Well No. 51, near Ventura, California. No problems were
encountered in arranging sampling for July 15, 1986. No back-up
site was required.
Site Location
The location of the River Bottom Unit (RBU) Gosnell Well No. 51
is approximately 1,500 feet east of Highway 33, and approximately
5 miles north of the intersection of Highways 33 and 101 in
Ventura, CA. Figure 1 is a map indicating the drilling site.
The full name and mailing address for Shell is:
Shell California Production, Inc.
P.O. Box 11164
Bakersfield, California 93309
Main Office Ph.: 805-326-5000
Main Office Contact: D. L. Oreolt, Manager
Environmental Conservation
West Coast Production Division
Attendees
Sampling at the RBU Gosnell site was performed by CENTEC
Corporation personnel on July 15, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (Sample Team)
EPA Representative:
State Representative:
Operator Representatives:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
William Telliard, Chief, Energy
and Mining Industries Branch,
Industrial Technology Div.,
Office of Water
Mike Stettner, California
Department of Conservation,
Division of Oil and Gas
Ron Cox, Environmental
Engineering Technician
D. L. LeVan, Operations
Foreman, Ventura Production
Unit, Coastal Production Div.
Tod Stallings, Field
Surveillance Technician
Wayne Kabrich, Drilling
Supervisor, WCO-Drilling
C-226
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Figure 1. Location of Shell Production's River Bottom Unit
Gosnell Well #51, Ventura, California
0227
-------
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
The drilling contractor for this well was Cal Pacific Drilling
Company.
Site Description
The RBU Gosnell site is located in a suburban, piedmont area.
The climate at this site location is net precipitation. The soil
is described as sand over rock and clay. The area is a dried-up
river bed. The well was completed in the C-Block formation of
the Ventura basin. Figure 2 is a map of the exact location of
the hole.
The depth to the groundwater in the area is approximately 10
feet. The nearest surface water is the Ventura River, less than
1/2 mile west of the site. The nearest drinking water well is
estimated to be greater than 10 miles from the site.
At the time of sampling, the site consisted of one oil well and
four sludge collection bins. Figure 3 is an approximate
schematic diagram of the site, indicating directions in which
photos were taken (Attachment A). The drilling rig for Well No.
51 is shown in the center of Photo 1. Figure 4 is a schematic
diagram of a typical Cal Pacific drilling rig, provided by
Operator Representative Wayne Kabrich. The rig layout has been
enhanced to show the sludge collection bins as they were situated
at Well No. 51;
This site was originally a developmental oil drilling site but
was changed to an injection well to be used for waterflooding
producing wells in the vicinity. Eight wells that were expected
to benefit from the waterflooding of Well No. 51 included the
following:
Edison 19
Citrus 1A
Gosnell 17, 39, 48, 49
Notten 7, 11
These wells are also indicated in Figure 2.
Well No. 51 was to be completed at 6,570 feet. The depth at the
time of sampling was 5,070 feet. Drilling began on July 7, 1986.
Drilling was accomplished with a saturated saltwater mud. The
chlorides content of the mud was estimated to be 12,000 parts per
million.
C-22B
-------
ENTURA
Figure 2.
Location of
by Water ?looing
Eiaht Wells Affected
C-229
-------
N
\
\
pkvcfo
Ken
Figure 3. Schematic Diagram of Drilling Site
C-230
-------
Cal Pacific Drilling Company, Inc.
RIG 4,5, & 6
TO CATWALK
-a' y-i
y-Cfca
tf-W
r4 01 A. X
22-0' DEEP
rRATHOLE
VcuLX B'-O'DEEP
MOUSE HOLE
(WELL .
ri
RATHOLE MOUSEHOLC
ANCLE ANGLE
TOWARD TOWARD
CATWALK CATWALK
**rHOLf/UOUS£HOLf
GfiOUHO
* OCPTH.
NOTE.LOCATION SIZE SHOULD ACCOMMODATE TRUCK ACCESS
MAX. TRUCK • TRAILER LENGTH M'-O? MAX. WIDTH I2*-0*
MAX TRUCK • TRAILER WIEGHT; »4,000 LSS
Na OF LOADS: • LEGAL LOADS AND • PERMIT LOADS
•) MAX. WELL CELLAR DIMENSIONS tt-0' DEEP BY
•'-0* * t'-O* SOUAME.ON ST $'-0' OAMETER
kl KELLY SUSMIH8MIEGHTFROM WOUND LEVEL ZS'-C*
c) LEFT HAND ««, MUD TANK ON OFF-DRILLERS SIDE
4) GROUND LEVEL TO IOTTOM OF ROTART BUMS St-ff
TYPICAL RIG LAYOUT
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Four plastic lined bins were located on the east side of the rig
to provide temporary storage of drill cuttings, residual drilling
muds from the circulation system, and water used to wash off the
equipment around the mud tank. The pit contents were dropped
from shale shakers at the mud tank, shown in Photos 5, 6, and 7.
One bin holds approximately 300 cubic feet (54 barrels) of
drilling waste. Figure 3 shows the dimensions of the bin that
was measured and sampled by the CENTEC team. The operator
estimated that 50 bins will be filled by completion date. That
is, an estimated 2,700 barrels of cuttings and drilling mud will
be generated from this well.
The depth of liquid in the bin chosen to be sampled was one to
two inches, and the depth of the sludge was between one-half and
three feet.
Disposal Practices
The contents of the disposal bins is vacuumed into trucks and
taken to a facility that treats the sludge to make it a solid
before it is landfilled. The name and address of the company is:
VenVirotek
1536 Eastman Avenue
Suite 6-A
Ventura, CA 93003
Phone: 805-654-1900
The VenVirotek treatment process turns the sludge into a
substance having a gel-like consistency that eventually hardens.
The final product can be used to cover landfills. VenVirotek
cannot accept sludge from drill sites with greater than 5 percent
oil content.
The final disposition of the drilling wastes is the Santa Clara
Landfill. The main office address for the landfill is:
Ventura Regional Sanitation District
1001 Partridge Drive
Suite 150
Ventura, CA 93003-5562
Permits
A copy of the drilling permit secured by Shell California
Production, Inc. for the RBU Gosnell Well No. 51 is located in
Attachment B. In addition, a copy of a Supplementary Notice,
stating that the designation of the well was changed from
"producer" to "injector," is also located in Attachment B.
C-232
-------
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the RBU Gosnell site, the samples were defined as the
supernatant and solid contents of the waste material in one of
four disposal bins in use at the time of sampling. The bin
immediately north of the southernmost bin was chosen to be
sampled because it had the most even distribution of liquid and
solid contents.
Sample points were identified based on measurements of bin
dimensions. Howeverr the small quantity of liquid on the surface
of the sludge did not allow for placing every sample point at the
center of measured quadrants, as with rectangular reserve pits.
In addition, the sludge was too shallow to be collected by the
coring device in particular places, so there is some discrepancy
between measured and actual sample points. Figure 3 indicates
the measured sample points as well as the actual sample points
from which the bin samples were composited.
Sampling Methods and Equipment
To collect samples from the disposal bin, measurements were made
to identify the four quadrants shown in Figure 3, and to locate
the center of each quadrant.
The first sample to be collected was the liquid composite. A
clean 1-quart glass jar was dipped into the supernatant liquid as
shown in Photo 9. The thief was not used because there was not
enough liquid to submerge it in. Liquid sample point locations
depended largely upon where the liquid could be safely reached.
The liquid from each sample point was composited in a
5-gallon carboy.
The reserve pit was then sampled for sludge. The coring device
was used with a 5-foot extension rod attached. The sludge was
deepest at the western end, directly under the shale shaker.
Three of the four gallons of sludge collected came from the two
sample points in the western end of the bin. Photo 11 shows
samplers emptying the coring device into the steel bucket used to
composite the sample.
Tests for the pH and free chlorine content of the samples were
performed onsite after sampling was completed. The pH of both
the liquid and sludge samples was 7. The free chlorine content
of the liquid sample was less than 0.2 ppm (the lowest detectable
level).
C-233
-------
C-234
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-235
-------
C-23*.
-------
^
<~> Photo 1. Dril I Ing r Ig
Photos
2,3,4. Northwester.y view of drill site (rig In Photo #2)
-------
Photo 5. Two waste bins at mud circulation tank
Photo 6.
Waste bin and two shale shakers
Waste bin and two shale shakers
Photo 8. Close-up of bin contents
-------
6F7-D
-------
eidu.es p|nb|| Bu|jnod '
6u| iduies e6pnis M I °4-°Md
I
CJ
-------
ATTACHMENT B: PERMITS
C-241
-------
C-242
-------
f
\
ll ACCNCY Or CJU.iro*M1A
DEPARTMENT Or CONSERVATION
GAS
DIVISION OF OIL AND GAS
Notice of Intention to Drill New Well
CE.Q.A. INFORMATION
EXEMPT Q
OASS
NEC. DEC rj
&.CM. NO
E-Ll. Q
S.CH. NO
DOCUMENT NOT
IEOUHED m
IY LOCAi. liJ
AHISDICDON
SM »r-»rvt SicU
"FOB OfVJSON USE ONLY
VENTURA. CAIiPpPKHA
MJkf
•MAP
«OOK
J2<_
In compliance with Section 3203, Division 3, Public Resources Code, notice is hereby given that it is our
intention to commence drilling well "RBU GosnelT'51 weD H™ Producer
23W SB
Legal description of mineral-right lease,
attached
.Field,
Ventura
(Asicacd by Divuioo)
.County.
n(
icres, is as
. Ple3Se ^66 map
(Attach mmp or
to icale)
Do mineral and surface leases coincide? Yes_JL
surface and mineral leases, and map or plat to scale.
.. If answer is no, attach legal description of both
Location of well
feet
(Direction)
along
(Crou out one)
and
feet
(Dinction)
at right angles to said line from the
.corner of
706' South and 879' West from R.C.L. Cornpr 11
(Cira oot on*)
or
Is this a critical well according to the definition on the reverse side of this form? Yes Q No
If well is to be directionally drilled, show proposed coordinates (from surface location) at total depth:
4££ feet tlarlb__and 521 feet West
(Direction) (Direction)
Elevation of ground above sea level 15fi feet.
All depth measurements taken from top of.
Kelly Bushing
(Dwaek Floor, Rotuy T«bk.or 1UB> Boifcia()
PROPOSED CASING PROGRAM
.that is.
22
.feet above ground.
•IZC Or CASING
INCHES API
13 3/8"
9 5/8"
7"
WEIGHT
54. 5#
36??
26#
CMAOC AND TYPE
K-55 STC
K-55 LTC
K-55 LTC
TOP
0
0
0
•OTTOM
fifin1
2800'
6600'
CEMENTING
DEPTH*
fifin1
2800'
6600'
CALCULATED FILL
BEHIND CASING
fifin1
2800'
6600'
(A complete drilling program is preferred and may be nibmitted in lieu of the above program.)
Intended zone(s) __ ._
of completion, C3/C4> 47001.
Hydrostatii
Estimated true vertical depth
(None, drptt.tnd exp»ct»d pranw*)
It is understood that if changes in this plan become necessary we are to notify you immediately.
Shell Cal
Addrca
P.O. Box
5 326-5684
ifornia Production Inc.
11164
N«m« of Penon FUmf Node*
S. Dormier - Agent P_9
Type of Orsaniza&an (Corporttxxx. Putnenhjp, Indfvidutl. etc.)
Corporation
City
Bakers^ield, CA^
A^^^y
93389-1164
Date
6/06/86
• ^ i ^ f^^t^rfi^J
"his notice and indemnity or cash bond »h.i!l b« filed, and approval given, before d>ffling begins. If
operations have not commenced
-------
RESOURCES AGENCY OF CALIFORNIA
DEPARTMENT OF CONSERVATION
DIVISION OF OIL AND GAS
No. P 286-193
814
PERMIT TO CONDUCT WELL OPERATIONS
S. F. Dormeir, Agent
Shell Calif. Prod. Inc.
P.O. Box 11164
Ventura
Bakersfield, CA 93339-1164
June 16,
(field code}
00
(area code)
00
(new pool code)
(old pool code)
, California
Your
A.P.I. No..
111-21415
, proposal to.
drill
Section
28
.well.
"RBU Gosnell" 51
., T. 3N
23W
Ventura
S-B- B. & M.,
Ventura
filed in this office.
. County, dated 6/6/86 - , received
. area,.
no breakdown
- pool,
been examined in conjunction with records
THE PROPOSAL IS APPROVED PROVIDED THAT:
1. Hole fluid of sufficient quality and quantity shall be maintained in the hole to
control any subsurface condition, and a reserve supply shall be on hand for emergencies
2. Blowout prevention equipment of at least DOG Class III 3M B shall be installed on the
13 3/8" casing and maintained in operating condition at all times.
3. Sufficient cement shall be used to fill the annular space to at least 500 feet above
oil and gas zones and anomalous pressure intervals, and to at least 100 feet above
the base of the freshwater zone.
4. This office shall be consulted before placing any plugs or sidetracking any hole.
5. The Division routinely monitors monthly well production data, and if anomalous water
production is indicated, remedial action will be ordered.
6. This office shall be consulted before initiating any changes or additions to this
proposed operation, or if operations are to be suspended.
7. THIS DIVISION SHALL BE NOTIFIED:
a. TO WITNESS a pressure test of the blowout prevention equipment before
drilling below 660'.
Blanket Bond
BW:Ijg
Engineer
Phone
Bill winkJer
(805) 654-4761
M. G. MEFFERD, State Oil and Gas Supervisor
6t
f deputy Supervisor
A copy of this permit and the proposal must be posted at the well site prior to commencing operations.
Records for work done under this permit are due within 60 days after the work has been completed
or the operations have been suspended.
C-244
-------
RESOURCES AGENCY OF CALIFORNIA
DEPARTMENT OF CONSERVATION
DIVISION OF OIL AND GAS
SUPPLEMENTARY NOTICE
DIVISION OF OIL AND GAS
Ventura
FOR DIVISION USE ONLY
ftOND
dft
fOKMS
114
*—
121
L-""
.Calif.
A notice to yon dated..
Drill
(Drill, rework, tbudon)
^ 28 T 3N p 23W
Ventura
June 6
W»TI Mrt "RBU GosnelT1 SI
S.B.R f, vr
County «hnnM fw> omAnd*"*
1986 stating
APT^n
Ventura
because of chai
111-21415
f,-»7rl
ieed conditions.
The present condition of the well is as follows:
Total depth
Complete casing record including plugs and perforations:
'f r-
'AS
We now propose to change well designation to injector. Please see attached
casing diagrams of all wells withing 1/4 mile radius.
It is understood that if changes in this plan become necessary we are to notify you immediately.
P.O. Box 11164 r£frglL Call fern la Production Inc.
(Street)
Bakersfield, CA
93389-1164
(City)
Telephone
(Sute)
(80S) 326-5684
(Zip)
(D»u)
Type of Organi2arion__^£!!P°E£i2£D
(Corpnndon, PiitDcnbip, lodividuil, etc.)
FO»K 123 IMCV. 1.71)
C-245
-------
RESOURCES AGENCY OF CALIFORNIA
DEPARTMENT OF CONSERVATION
DIVISION OF OIL AND GAS
p 286-224
814
PERMIT TO CONDUCT WELL OPERATIONS
WATERFLOOD
S. F. Dormier, Agent
Shell Calif. Prod. Inc.
P.O. Box 11164
Bakersfied, CA 93389-1164
Ventura
July 9, 1986
(liold code)
00
(area code)
40
(new pool code)
00
(old pool code)
, California
Your.
supplementary
A.P.I. No HI- 21415
\7onf TIT" a
, proposal to.
drill
.well.
'RBU Gosnell" 51
Section—
field, any
23-
., T
., B. 23W S.B. B. & M.,
area, C-3/C-4A(W) pool,
.County, dated—7/1/86 .received, 7/7/86 ha* been examined in conjunction with records
filed in this office.
THE PROPOSAL IS APPROVED PROVIDED THAT:
1. Injection shall cease if any evidence of damage is observed, or upon written notice
from the Division.
2. This office shall be consulted before initiating any changes or additions to this
proposed operation, or if operations are to be suspended.
3. THIS DIVISION SHALL BE NOT-IFIED:
a. TO WITNESS a survey to demonstrate that injected fluid is confined
below the highest perforated interval.
b. TO WITNESS a step rate test.
Blanket Bond
MS:ljg
Michael Stettner
Engineer
Phone _(805) 654-4761
M. G. MEFFERD. State Oil and Gas Supervisor
By
visor
Deputy'Supervi:
A copy of this permit and the proposal must be posted at the well site prior to commencing operations.
Records for work done under this permit are Qae&dthin 60 days after the work has been completed
or the operations have been suspended.
or.n, C~246
-------
Sampling Report
Investigation of McFarland Energy, Inc.
Section 24 Production Facility
Midway Sunset Oil Field
Kern County, California
July 16, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a computerized list of 335 active San Joaquin Basin production
sites developed by the California Bureau of Land Management at
the request of EPA. The list was transmitted via overnight
service to the EPA contractor on July 3, 1986. Randomization and
site selection took place immediately upon receipt.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The computerized listing showed the possible sample sites by
operator, type of operation, permit number, general location, and
disposal practice. For simplicity of selection, the sample site
was randomly selected based on the permit number. The list was
too extensive to include herein.
As indicated above, the EPA contractor used permit numbers for
randomization. A random number table was used to select the
primary and back-up sample sites. The randomly-selected primary
site was SAC 021030, McFarland.
Further inquiry identified the primary sample site as McFarland
Energy, Incorporated's Section 24 Production Facility in the
Midway Sunset Oil Field in Kern County, California. No problems
were encountered in arranging sampling for July 16, 1986.
In case the primary site was inaccessible or inappropriate, a
back-up site was also randomly selected. The back-up site was
McFarland SAC-065975. On investigation, it was discovered that
the back-up site was shut-in. However, the back-up site was not
needed.
C-247
-------
Site Location
The McFarland production facility is located approximately
1/2-mile east of Highway 33, 3 miles north of Fellows, CA in Kern
County. Figure 1 is a map indicating the production facility
site. The full name and mailing address for McFarland Energy is:
McFarland Energy, Inc.
P.O. Box 3608
10425 South Painter Avenue
Santa Fe Springs, California 90670
Main Office Ph.: 213-944-0181
Main Office Contact: Andrew McFarland
Vice President for Production
Attendees
Sampling at the McFarland production site was performed by CENTEC
Corporation personnel on July 16, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representative:
State Representatives:
Operator Representatives:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
William Telliard, Chief, Energy
and Mining Industries Branch,
Industrial Technology
Division, Office of Water
Ted Anderson, Physical
Scientist, U.S. Dept. of the
Interior Bureau of Land
Management, Bakersfield Dist.
Minerals Division
Hal Stoops, Supervisory
Petroleum Engineering
Technician, Bureau of Land
Management, Bakersfield
Dist. Minerals Division
Leroy Woods, Foreman, Midway
Sunset Field
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Shawn Hokanson, Contracted
Sample Team Member
C-248
-------
x\ \M,^4.V i: ^/rn^T^-^-rr'^,. J
Wi^arNt.a^s/feiJ.r-'V^-.!?' srh =uy
• \« ^^^^n / v ;'' P: ;;;^;-::., •'• '=;;y_ ~ —
Figure 1. Location of McFarland Eneray, Inc.'s Section 24
Production Facility, Kern County, California
C-249
-------
Site Description
The McFarland production facility is located in a rural flatland
area in the Midway Sunset Oil Field. The climate at this site
location is net evaporation. The soil consists largely of sand.
Wells serviced by this facility are completed in the Gusher
formation of the San Joaquin Basin.
The depth to the base of fresh groundwater in the area is between
1,400 and 1,500 feet. The nearest surface water is Buena Vista
Lake, located approximately 10 miles east of the site. The
nearest drinking water wells are located 10 to 15 miles from the
site.
Figure 2 is a map identifying the wells on U.S. Lease No.
SAC-021030, serviced by the McFarland facility. Wells 2, 4,
and 5 are still functional, but only No. 4 was operating the day
of sampling. Daily production for these wells averages 4 to 5
barrels of oil, and 30 barrels of produced water. The average
depth of the wells on this lease is 1,800 feet.
At the time of sampling, the site consisted of one 2,500-barrel
oil and water separating tank (referred to by the operator as a
"wash tank") and one oil skimming sump. Figure 3 is an
approximate schematic diagram of the site location, indicating
the directions in which photos were taken (Attachment A).
Produced water leaving the wash tank is shown in Photos 2 and 3.
The water flows from this outfall to the sump shown in Photos 4
and 5. Finally, the water is discharged to the surface, shown in
Photos 8 through 11. The reddish residue along the path of the
water suggested a high iron content.
A corrosion inhibitor made by Baker Chemical is added to the wash
tank at a rate of approximately 2 quarts per week.
The sump is cleaned once per year. The wash tank has been
cleaned only once in the 25 years it has been in use. It has
been 6 to 8 years since the wash tank was cleaned.
Disposal Practices
Produced water is discharged to the surface and is carried by
natural drainage to commercial disposal sumps operated by Valley
Waste Disposal. This facility has recently been using injection
wells for disposal, due to public concern about endangered
species in the area.
McFarland representative Leroy Woods stated that the produced
water leaving the production site generally evaporates or
percolates into the ground before it reaches the commercial
disposal site.
C-250
-------
13
• „ •. ,/»t • -,•••
^^Q
MIDWAY SUNSET
KERN CO CALIF
SCALE I" = i200'
Moren I, 1986
Figure 2. Locations of Wells and Production Facility
C-251
-------
Oil
0( 1
PWuttc/ ^^-^'
f« $)<;„..>.'•*. '
'iuv^Sb
V
Fiaure 3. Schematic Diaaran of Production Facility
C-252
-------
Permits
No operating permits were made available to the sample team at
the time of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the McFarland production facility, the sample was defined as
the fluid leaving the wash tank, shown in Photo 2. The produced
fluid sample was obtained at the end of the pipe leaving the wash
tank.
Sampling Methods and Equipment
Samplers at this site were U.S. EPA representative William
Telliard and CENTEC representative Bill Lane. At the direction
of Mr. Telliard, the sample was collected in individual sample
bottles by holding the bottles under the running stream shown in
Photo 2.
Tests for the pH and free chlorine content of the fluid sample
were conducted onsite after sampling was completed. The pH was
7, and the free chlorine content was less than 0.2 ppm (the
lowest detectable limit). \
C-253
-------
C-254
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-255
-------
C-256
-------
SF
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ifeb ^..- Jl
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C-258
-------
o
I
10
Ul
Photo 8. Discharge from wash tank flowing down hll
i—;- u-^Tir v. • ,-n s » ,•: ^>
i ^r *. .'fir'B jF/ I'-TS'"*'
r/*roifc$«s
Photo 9. Discharge from wash tank
fIowIng down hill
Photo 7. Samplers and observers
-------
O
I
NJ
Photo 10. Close-up of stream created by tank discharge
y**ii» •.
fc^^vr^Csa^^- •
".:- -i'^r^'.^v^^-*
t?K3??|^v,
Blii^ilfc-, • .v.^
Photo 11. Discharge flowing toward
dra I nage d i ten
-------
ATTACHMENT B: PERMITS
C-261
-------
C-262
-------
No permit specific to the operation
of this site is available.
C-263
-------
C-264
-------
Sampling Report
Investigation of Shell California Production, Inc.'s
Gore C Lease Oil Well No. 50-3P
Midway Sunset Oil Field
Kern County, California
July 16, 1986
SITE INFORMATION
Site Selection
This site was intended to be randomly selected by EPA as
described in the sampling strategy document in Appendix B of the
EPA Technical Report (EPA 530-SW-87-005), with the changes noted
below. This site was originally planned to be selected randomly
from a list of active San Jouquin Basin drill sites developed by
the California Bureau of Land Management at the request of EPA.
The list was to be developed immediately prior to July 17, 1986,
the scheduled sampling date. The short time frame was deemed
necessary because of the rapid nature of drilling in this basin.
It would be impossible to plan drill site sampling more than a
day or two in advance. Randomization and site selection were to
take place at BLM the day before sampling.
One day prior to the scheduled sampling time the Bureau of Land
Management was unable to locate a drill site at or near
completion for sampling. George Holliday, of Holliday
Environmental Services (formerly of Shell Oil Company, currently
representing the American Petroleum Institute), took the
initiative of calling his own industry contacts in the area.
Mr. Holliday was able to locate a drill site. The EPA contract
sampling team opted to obtain this sample rather than to depart
without sampling a drill site in the San Jouquin Basin. The site
is considered a random sample because it was the only site known
in the desired area during the necessary time frame.
The site was identified as Shell California Production
Incorporated's Gore C. Lease, Oil Well No. 50-3P, in the Midway
Sunset Oil Field in Kern County, California. Shell was amenable
to participating in the sampling program, but could not guarantee
that the drilling wastes would still be onsite on July 17, 1986.
The sampling team proceeded immediately to the site. Sampling
was conducted well into the evening.
Site Location
Gore C Lease Well No. 50-3P is located approximately 3 miles west
of Highway 33, and approximately 5 miles northwest of Fellows, CA
in Kern County. Figure 1 is a map indicating the well site. The
full name and mailing address for Shell is:
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Fiqure 1. Location of Shell Production's Gore C Lease Well
#50-3P, Midway Sunset Oil Field, Kern County, California
C-266
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Shell California Production, Inc.
P.O. Box 11164
Bakersfield, California 93309
Main Office Ph.: 805-326-5000
Main Office Contact: D. L. Oreolt, Manager
Environmental Conservation
West Coast Production Division
Attendees
Sampling at the Gore C Lease Well No. 50-3P was performed by
CENTEC Corporation personnel on July 16, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team):
State Representative:
Operator Representative:
Jamie Mclntyre, Sample Team
Leader
Bill Lane, Technician
None present (Ted Anderson of
the Bureau of Land Manage-
ment, Bakersfield District,
was asked but could not
attend)
Jim Simpson, Drilling Foreman
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Sample Team Member
Shawn Hokanson, Sample Team
Member
The contractor to drill at this site was the Golden State
Drilling Company.
Site Description
Figure 2 is a diagram, provided by Shell, of the exact location
of the Gore C Lease Well No. 50-3P. The well location is in
rural flatland, although the site was situated on a slight grade.
The climate at this site location is net evaporation. The soil
in the area is a mostly sand. The well was planned to be
completed in the Potter formation of the San Jouquin basin.
The depth to the base of fresh groundwater in the area is between
1400 and 1500 feet. The nearest surface water is Buena Vista
Lake, located approximately 10 miles east of the site. The
nearest drinking water wells are located 10 to 15 miles from the
site.
At the time of sampling, the site consisted of the Golden State
Drilling Rig No. 6 and one reserve pit. Figure 3 is an
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Figure 2. Grading Plan and Well Location
C-268
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Figure 3. Schematic Diagram of Drilling Site
C-269
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approximate schematic diagram of the site location, indicating
the directions in which photos were taken (Attachment A).
Although the site is not fenced in, the entire lease is fenced,
requiring access through a supervised gate.
This site was a developmental oil drilling site. The well was
planned to be completed at 1,287 feet, and was at a depth of
1,100 feet the day of sampling. Drilling began July 15, 1986 and
was estimated to be completed by July 20 or 21, 1986.
Drilling was accomplished first with a water base spud mud,
followed by a low-solids polyacrylic mud. The estimated total
volume of cuttings and drilling mud associated with drilling this
well was between 400 and 600 barrels.
The reserve pit at the site is shown in relation to the drilling
rig in Photos 2 and 3. The pit was designed for the temporary
storage of drill cuttings and residual drilling mud that left the
mud circulation system. Drill cuttings entered the pit from the
shale shaker, shown in a side view in Photo 4. Fluids from the
mud circulation tanks leaked from the rig and down the side of
the pit. Photo 5 shows a stream of fluid flowing into the pit
from an overhead view. Nothing was piped into the pit.
The only requirement regarding construction of the reserve pit is
that it must be large enough to contain 300 barrels of liquid and
solids. The operator stated that the size of reserve pits in
this area is arbitrary and site specific for the particular well
being drilled. The size is estimated by calculating the amount
of cuttings to be obtained and by estimating the amount of fluid
volume generated when changing from drilling mud to a completion
fluid system.
There, are no specific statewide requirements concerning the size
of reserve pits. However, each local agency may impose
restrictions if they choose. Kern County does not have any such
restriction on size.
The pit was constructed below grade, approximately as wide as a
bulldozer blade. Figure 3 shows the dimensions of the pit
measured by the sample team. Three sides of the pit were
vertical with an 8-foot drop to the surface of the liquid. The
fourth side was inclined enough to allow walking to the edge of
the liquid surface. Photo 6 views the pit from the top of the
inclined side. The depth of the liquid in the pit at the time of
sampling was 1 to 1-1/2 feet, and the sludge depth was 1 to 2
feet.
Approximately 1,500 gallons of diesel were being stored onsite in
tanks. An estimated volume of 2 gallons of waste oil from engine
oil leaks was expected to be generated onsite. This oil could
have possibly made its way into the reserve pit.
C-270
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In regard to analyzing the contents of the reserve pit, the
operator made the following remarks:
Because of the numerous wells that have been drilled in
the area, each and every pit is not routinely analyzed
during drilling or prior to disposal. However, the
drilling muds used are formulated according to the
Department of Health Services Approved List of
additives which will not render the mud hazardous when
used according to the manufacturer's recommended
practices. In addition, representative cuttings from
the field have been analyzed to determine whether any
formations are penetrated which might render the pit
contents hazardous.
A copy of the "Approved List" of drilling mud additives is
included in Attachment C. A copy of a laboratory report on well
cuttings from another well on the Gore C lease is included in
Attachment D.
Disposal Practices
The free liquid and sludge from the reserve pit would be removed
by a vacuum truck owned by B&L Vacuum Trucking Co., and hauled to
Petroleum Waste, Inc., a disposal facility in nearby
Buttonwillow, CA. The solid residue remaining in the pit would
be allowed to dry, and the pit would be backfilled and restored
to natural contours.
Permits
A copy of the drilling permit secured by Shell California
Production, Inc. to drill Well No. 50-3P on the Gore C Lease in
the Midway Sunset Oil Field is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Shell site, the samples were defined as the supernatant
and solid contents of the waste material in the reserve pit.
The sample points were obtained by standing on the sides of the
pit rather than from a boat within the pit for two reasons.
First, sampling began at approximately 5:00 p.m., and there was
concern about getting the samples shipped on time. Second, the
pit was considered small enough to obtain samples by accessing
the pit from the sides. Figure 3 indicates the measured sample
C-271
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points as well as the actual sample points from which the pit
samples were composited. Samples were not taken along the side
of the pit nearest the rig because it was unsafe to walk there.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked with
stakes to facilitate locating sample points.
The first sample to be collected was the liquid composite. The
thief was used by attaching the gaging tape to the thief and
lowering it to the liquid in the pit. Care was taken not
to allow oil floating on the surface of the liquid to enter the
thief. The liquid from each sample point was composited in a
5-gallon carboy.
The reserve pit was then sampled for sludge. The dredge was used
at this site because the sludge was too dense to enter the glass
core sleeve without breaking it. Sludge was collected at each
point where liquid was collected, as well as from the cuttings
pile. The sludge was composited in the steel bucket.
Tests for the pH and free chlorine content of the samples were
performed onsite after sampling was completed. The pH of both
the liquid and sludge samples was 6. The free chlorine content
of the liquid sample was less than 0.2 ppm (the lowest detectable
level).
The samples were held overnight under refrigeration before
shipment to the laboratories. This was necessary because
sampling activities extended past the time when shipping on the
day of sampling was possible.
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
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C-274
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Photo I . DrI I I Ing rig
Photo 2. Reserve pit and mud circulation tank
Photo 3. Reserve pit
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Photo 7. Reserve pit
Photo 6. Pump lines in reserve pit
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C-278
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ATTACHMENT B: PERMITS
C-279
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o
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Fora 3160-3 *"
(November 1983)
UNITED STATES
SUBMIT IN
(Oth*r Inatructloc
rererse side)
oved.
5ureau No. 1004-0136
Expires August 31, 1985
DEPARTMENT OF THE 1
BUREAU OF LAND MANAC
WTTDinF?
U < t.niWI\ 5. LEASE DESIGNATION AND SERIAL NO.
;EMENT . --- Sac. 021592
APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLIKTBACK 9 -»»*.. *«««.<>. «,...«.
la. TTPE or woaK
DRJLL ffl DEEPEN [
b. TTPE Or WELL
OIL rn °AS r~i
WELL LAI WELL 1 1 OTHER
2. NAME Or OPERATOR
Shell California Production Inc.
3. ADORERS Or OPERATOR
P. 0. Box 11164 Bakersfield, CA 93389
H PLUG BACK D 7- BhIT ««1*«1. uui v>.i 1JID aulvIT „, iM,
Section 21, T31S, R22E,
--M..D.B.&.M.
14. DISTANCE IN- MILES) AND DIRECTION- rioW NEAREST TOWN OR POST OWCE*— 12. COCNTT OR PARISH 13. STATE
See attached road map " "- -Kern Calif.
IS. DISTANCE raOM PROPOSED* Tjn 1 f-,.— £..,+.
LOCATION TO NEAREST 1 OU TrOITI t3St
PROPEETT OR LEAER LINE. n. •, - „ 1 ,' „ „
(Alto to nearest drlg. unit line. If any) 16856 1 1 06
13. DISTANCE FROM raorosED LOCATION* en i f>nm
TO NEAREST WELL. DRILLING. COMPLETED.-10 ' ' UUI
OR ATPUtD FOR. ON THIS LEAM. PT. W6 1 1 50" 3 I
21. ELEVATIONS (Show wb«th«r DF. RT. GR, »«
5--22-S6
X* 1 C "3S
OF APPRUVIL. IT ANT 1
C-281
*S<« Instructions Cn R
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C-282
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ATTACHMENT C: CALIFORNIA DEPARTMENT OF HEALTH SERVICES'
LIST OF DRILLING MUD ADDITIVES USED
IN NONHAZARDOUS MUDS AND FLUIDS
C-283
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C-284
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•MT Of CAUtt>«*«*-MtAlTM ANP Wnf AU AGENCY IDMUND C. MOWN
)EPARTMENT OF HEALTH SERVICES
4/744 P JTHETT
kCIAMSNTO. CA V3IU Q
32^-1789 0705 RPR*9 85
TO: EPS, WMS, WWTF July 9> l982
FROM: TOM COBNWELL
Still the current list per
Tracy. '
APR -04 1985
TO: Producers, Transporters, and Disposers of
Waste Drilling Muds and Fluids
FROM: Hazardous Waste Management Branch
714 P Street, Room 523
SUBJECT: Identification of Nonhazardous Waste Drilling Muds and Fluids
Waste drilling muds and fluids are listed in state hazardous waste regulations
(Section 66680, Chapter 30, Division A, Title 22, California Administrative
Code) as hazardous wastes if the muds or fluids contain hazardous materials.
That listing does not take into account the likely dilution of hazardous addi-
tives during drilling operations.
Since the time of the listing, the Department has obtained from laboratory test-
Ing and from manufacturers more information about the nature of drilling fluid
additives and their usage.
The Information has made possible the development of the enclosed list of chem-
ical and material drilling fluid additives which the Department has concluded
do not render the waste muds and fluids hazardous wastes. Note that some chem-
icals on the enclosure are listed In the regulations as hazardous wastes (e.g.,
phosphoric acid and sodium hydroxide). If these, and other additives, are di-
luted and used as recommended by the manufacturers, however, they will not cause
the waste muds and fluids to be considered hazardous wastes.
Accordingly, persons producing, transporting, and disposing of waste drilling
muds and fluids containing only the listed additives may manage them as non-
hazardous wastes, provided they do not contain substantial concentrations of
toxic substances from other sources (e.g., toxic metal from geological depos-
its encountered during drilling operations). Drilling muds that contain addi-
tives which are not included on the list will continue to be considered haz-
ardous waste. The Department will periodically revise the enclosed list as
more information Is obtained. If you wish to add a chemical or material to
the list, please send to the Department supporting data such as Material Safe-
ty Data Sheets, chemical compositions, toxic!ties, and concentrations used
(e.g., Ibs/bbl).
C-285
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-2-
Please note that all waste drilling muds and fluids, hazardous and nonhazardous,
must be disposed at sites approved by the Regional Water Quality Control Boards.
If you have any questions on this matter please contact the Chemical Support
Unit at
-------
CALIFORNIA DEPARTMENT OF HEALTH SERVICES
0 DRILLING MUD ADDfTIVES
USED IN NONHAZARDOUS DRILLING MUDS AND FLUIDS3
Hay 1982
1. Aluminum stearate (Aluminum tristearate)
2. Attapulglte clay
3. Bagasse (dried sugar cane)
4. -Barium sulfate
5. Bentonlte
6. Calcium carbonate
7. Causticized lignite (Sodium lignite)
8. Cellophane
9. Chrome free 1 ignosul fonate
10. Cottonseed pellets
11. Diamines and fatty acid amides
12. Detergents
.13. Ethylene oxide adducts of phenol and nonylphenol
14. Guar gum
15. Hydroxyethyl cellulose
16. Lecithin
17- Lignite
18. Magnesium oxide
19. Methanol
20. Mica .
21. Morpholine polyethoxyethanol
These additives will not a render a waste drilling mud or fluid hazardous when
used according to manufacturer's specifications and provided no other nonlisted
hazardous constituents are used. C-28t
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Drilling Mud Additives -2-
Q
22. Nut shells
23. Paraformaldehyde
24. Peptized bentonIte
25. Phosphoric acid
26. Polyacrylamide resin
27. Polyanionic cellulosle polymer
28. Polysaccharides
29. Potassium chloride
30. Potassium hydroxide (Caustic potash)
31. Potassium sulfate
32. Pregelatinized corn starch
33- Quartz or Cristobalite
34. Rice hulls
35. Sawdust
36. Shredded paper
37. Sodium acid pyrophosphate
38. Sodium bicarbonate (Bicarbonate of soda)
39- Sodium carbonate (Soda ash)
40. Sodium carboxy methyl cellulose
41. Sodium chloride
42. Sodium hexametaphosphate
43. Sodium hydroxide (Caustic soda)
44. Sodium montmorllloni te clay
45. Sodium polyacrylate
46. Sodium tetraphosphate
C-288
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Drilling Mud Additives -3-
Q
47. Starch
48. Tetrasodium pyrophosphate
49. Trlbutyl phosphate
50. Vegetable and polymer fibers, flakes, and granules
51. Vinyl acetate/Haleic anhydrie copolymer
52. Xanthan gum (XC polymer)
C-289
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C-290
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ATTACHMENT D: LABORATORY REPORT ON
WELL CUTTINGS FROM GORE C LEASE
C-291
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C-292
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•••II •••---•
[ ] 1 ZALCO LABURATORittD, IINIU.
/ L\ Analytical &. Consulting S
v_ ^
Shell California Production Inc.
P.O. Box 11164
Bakersfield, CA 93389-1164
Attention: Ray Ouelette
I}f=>n\/iof=»C3
Laboratory No: 4225-2
Date Received: 1-25-85
Date Reported: 2-28-85
til/, / J/
Sample Description: Midway Sunset Gore C7-5N Composite l/J^-/l O^jV/^^
Sample as received:
pH 7.74
~~
Moisture, wt. % 23.6
California Department of Health Services (CAM) revised 1-11-84
TTLC Total Cone.
mg/kg mg/kg
Cadmium, Cd 100 0.1
Chromium, Cr 2500/500 9.5
Cobalt, Co 8000 2.5
Copper, Cu 2500 7.5
Lead, Pb 1000 4.8
Nickel, Ni 2000 14.2
Silver, Ag 500 <0.3
Thallium, Tl 700 2.2
Zinc, Zn 5000 23
Barium, Ba 10,000 92 .
Beryllium, Be 75 0.2
Molybdenum-, Mo 3500 <2
Vanadium, V 2400 19
Antimony, Sb 500 <0.01
Arsenic, As 500 1.03
Mercury, Hg 20 <0.01
Selenium, Se 100 0.12
Fluoride, F 18,000 <10
TTLC - Total Threshold Limit Concentration
Extractable
STLC Concentration
mg/1 mg/1
1
560/5
80
25
5.0
20
5
7.0
250
100
0.75
350
24
15
5
0.2
1.0
180
STLC - Soluble Threshold Limit Concentration
WET - Waste Extraction Test. pH 5.0 Solution, 0.2 M Citrate Buffer.
All values are below the STLCs so that no
)
- RLP/sw
soluble testing is necessary.
Richard L. Penner
Chief Chemist
V zl^nQ Anmr-M in Av/«=n. 11= RsaL-oneafiealri Raliff-inoin <=?r^!^nH S
[805]
3539
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COLORADO
C-295
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C-296
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Sampling Report
Investigation of E-Vap, Limited
Greeley, Colorado
July 11, 1986
SITE INFORMATION
Site Selection
EPA specifically selected the E-Vap, Limited facility to obtain
technical information and analytical data regarding the regional
practice of using centralized pits for disposal of wastes from
multiple oil and/or gas sources. More detailed information about
the rationale for selection of centralized disposal pits is
contained in Appendix B of the EPA Technical Report (EPA 530-
SW-87-005).
EPA worked cooperatively with the Colorado Department of Health
to identify and select the E-Vap, Limited facility. No problems
were encountered arranging for sampling to be conducted on
July 11, 1986.
Site Location
E-Vap, Limited is located 7 miles southwest of Greeley, Colorado,
off County Road 54 connecting to State Route 257. Figure 1 is a
map indicating the disposal site.
The site is operated by Travelers Insurance Company in Denver,
CO. The contacting office has the following mailing address and
telephone number:
5404 24th Street
Greeley, CO 80634
303-339-0929
Contact Name: Robert Dragich
Attendees
Sampling of E-Vap, Limited was performed by CENTEC Corporation
personnel on July 11, 1986. The following is a list of people
present at the time of sampling:
CENTEC Corp. (sample team):
State Representatives:
Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
Scott Winters, Geologist, CO
Dept. of Health
Stephen Pott, Petroleum
Engineer, CO Oil & Gas
Conservation Commission
C-297
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Figure 1. Location of E-Vap, Limited, Greeley, Colorado
C-298
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Operator Representative: Robert Dragich, Operations
Manager
Kenneth Thrasher, Operator
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Earl Hinsley, Contracted
Sample Team Member
Site Description
E-Vap, Limited is located in rural flatland; the depth to
groundwater is 51-75 feet, and the nearest surface water is 1/2-2
miles away. There are no drinking water wells within a 1-mile
radius of the site. The soil in this area is clay. The climate
at this site is net evaporation.
This site is a commercial central pit facility for brine. Annual
operation hours are 8780. Proximity of clientele ranges in 0-50
mile radius from the facility. The facility utilizes an
evaporation system for produced waters. The facility accepts
produced water, completion fluids, and workover fluids trucked
from outside. Maximum daily capacity of the facility is 5000
bbl. Average daily influent is 2000 bbl. Fluids are unloaded at
a dumping station and proceed to sludge skimmers. The water then
flows through three consecutive oil-water separation tanks.
Saleable oil recovered is placed in oil storage tanks. The water
is then placed into one of four evaporation, aeration ponds.
Equipment needed at the facility for this operation includes two
tank batteries, an artificial well head, a five-state skim
system, heater treater system, oil washing facility, and aeration
system with air compressors. Capitol investment for this
equipment was $287,000. The facility has 12 acres of evaporation
ponds. The cost for pit construction was $450,000. The total
cost for constructing the facility was $900,000. Engineering and
consultant costs for pit treatment were $80,000. Operational
labor costs are $15,000 per month.
Figure 2 is a schematic diagram of the disposal site. Four
separate pits have been constructed for the site. All pits are
constructed above grade. The pits are lined with a 1.5-foot-
thick bentonite layer. The purpose of the pits is for
evaporation of produced fluids. Leak detection monitoring is
required. There is a peripheral drain system that requires
monitoring four times a year. The evaporation ponds are equipped
with a sprinkler system for aeration and to enhance fluid
evaporation. The pits are also chemically treated with borax,
calcium hypochlorite, and potassium permanganate. Monthly
chemical treatment costs are $3000. On the day of sampling, the
liquid depth of the pond selected for sampling was 2.5 feet. The
sludge depth was 2-3 inches. The liquid depths of the remaining
C-299
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Figure 2. Schematic Diagram, E-Vap,
Limited
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pits were no greater than 1 foot and sludge depths of less than
1/2 foot. The pits are constructed to be in operation for 15
years. The individual pits are not fenced; however, the entire
site is fenced. Photos 1 and 2 in Attachment A show the interior
of the truck dumping area. Photo 3 shows the exterior of the
dumping area and the sludge skim tanks. Photos 4-9 show the four
evaporation ponds as seen from the top of one of the oil-water
separation tanks.
The influent is tested for its physical and chemical properties
prior to treatment. The final disposition of the pit fluids is
evaporation. The solids from the skim tanks are collected and
placed in a designated pit. The final disposition of these
solids was unknown to site personnel.
Permits
A copy of the facility's permit was not available to the sample
team at the time of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at E-Vap, Limited consisted of one
supernatant sample and one sludge sample from the evaporation
pond closest to the dumping zone. Figure 3 shows the sampling
locations within the evaporation pit. This pit measured 395 feet
in length and 385 feet in width. This evaporation pit was
selected for sampling over the other three because it was the
most recently active pond. The other pits had not received
recent fluids and, as a result, had a substantially lower liquid
level due to evaporation. Analysis of samples from any of the
other three pits would show analytes in concentrated form. Prior
to sampling the pit and its contents had been treated. This
treatment included aeration, addition of fresh water, and
addition of calcium hypochlorite.
Sample points were accessed by boat. There were no discrepancies
between the actual and measured sample points caused by the
inaccessibility of the measured point.
C-301
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_ 315"
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185'
Figure 3. Sampled Evaporation Pond
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Sampling Methods and Equipment
To collect the samples, the pond was measured to identify the
four quadrants and to locate the center of each quadrant. Liquid
sampling was conducted with the liquid thief from the boat;
Sludge sampling was conducted from the boa't using a Ponar dredge.
The coring tube was not used because of concern that the tube
might penetrate the bentonite clay liner in the pit.
After sampling was completed, the pit supernatant was tested
onsite for pH and free chlorine content. The pH was found to be
8 and free chlorine was less than the lowest detectable limit of
0.2 ppm.
C-303
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C-304
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-305
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C-306
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Photo 1. Truck unloading zone
O
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o
Photo 2. Interior of truck unloading zone
Photo 3. Exterior of truck unloading zone and sludge
skim tanks
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E-Vap, Ltd. evaporation ponds
Ltd. evaporation ponds
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ATTACHMENT B: PERMITS
C-309
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C-310
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No permit specific to the operation
of this site is available.
C-311
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C-312
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KANSAS
C-313
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C-314
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Sampling Report
Investigation of Cindy Van Dyke's
Gentry Lease Well No. 2A
Montgomery County, Kansas
•July 2, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). In most cases, site selection could
be made from a list of appropriate sites several days in advance
of the sampling team's arrival. However, the Forest City Basin
in southeast Kansas is shallow, often requiring a single day for
drilling. This situation of very quick drilling and completion
made it impossible to develop a list of sites at or near
completion for the scheduled sampling date of July 1, 1986.
Thus, arrangements were made with the Kansas Department of Health
and Environment to select a site for sampling just prior to the
arrival of the sampling team.
On June 27, 1986, the Kansas Department of Health and Environment
notified the EPA contractor that they could not participate in
sampling on July 1, 1986. New plans were made to sample July 2,
1986, to accommodate their participation. State officials put
the EPA contractor in direct communication with a drilling agent
who was planning a well for that time period.
Since no list of sites was possible, the EPA contractor pursued
sampling arrangements with the drilling agent, Cindy Van Dyke,
for sampling July 2, 1986, at a site near Coffeyville, Kansas.
Site selection was considered random due to the nature of
southeastern Kansas drilling described above. The EPA contractor
had no prior knowledge of the drilling site prior to its proposal
by a Kansas state official.
Site Location
The Gentry Lease Well No. 2A is located approximately 8 miles
southeast of Independence, KS via Highway 160 and a county road
located 2 miles west of highway 169 in Montgomery County. Figure
1 is a map indicating the drilling site. The full name and
mailing address for Cindy Van Dyke is:
Cindy Van Dyke
Route 1
Coffeeville, KS 67337
Main Office Contact: Cindy Van Dyke
Phone: 316-948-6331
C-315
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oJr -1
•—4*-:.. '.t
• • -- ; *i^
I ; » ".r " pi-' "
-I-' • [ tt -
Figure 1. Location of Cindy Van Dyke's Gentry Lease Well #2A,
Montgomery County, Kansas
C-316
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Attendees
Sampling at the Gentry Lease site was performed by CENTEC
Corporation personnel on July 2, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (Sample Team):
State Representatives:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Steve Korf, Environmental
Geologist, Bureau of Oil
Field and Environmental
Geology, Kansas Corporation
Commission, Southeast
District Office
Bill Augustine, Environmental
Technician, Kansas
Corporation Commission
Operator Representatives: None Present
American Petroleum Institute
Representatives: George Holliday, Contracted
Observer
Alan Wilson, Contracted Sample
Team Member
Earl Hinsley, Contracted Sample
Team Member
Several unsuccessful attempts were made to contact the operator
the day of sampling. Steve Korf said he would continue to try to
contact the operator after the sampling was completed.
Information about drilling operations at this site was provided
by Steve Korf, and was largely based on local industry practices.
Site Description
The Gentry Lease site is located in a rural, piedmont area. The
climate at this site location is net precipitation. The soil is
described as clay with a layer of rich top soil. The site is
located over the Mississippian formation of the Forrest City
basin.
The depth to the groundwater in the area was estimated to be
100 feet, given that the depth to the bottom of "usable" water is
150 feet (see drilling permit, Attachment B). The nearest
surface water is the Verdigris River located one mile west of the
site. Information about drinking water wells located in the area
was not available.
At the time of sampling, the site consisted of one oil well and
two reserve pits. The drill rig had been removed from the site.
The well head consisted of a completion pipe rising approximately
C-317
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20 feet out of the hole (Photos 4, 6, and 7). This pipe was not
cemented in place. Gas could be heard and smelled coming from
the well. Figure 2 is an approximate schematic diagram of the
site, indicating the directions in which photos were taken
(Attachment A).
Also at the site was an array of cuttings samples taken from
various depths reached during drilling. These are shown in
Photos 9 and 10.
This site was an experimental oil or gas drilling site. The well
was completed at 1/400 feet. Drilling began on June 25, 1986 and
the well was completed June 27, 1986.
Drilling was accomplished using air rotary drilling, evidenced by
the cuttings pile located on the side of the pit farthest from
the well head (Photo 1 and Figure 2). It was suggested that this
drilling technique would have included the use of natural
drilling muds, as this is common local practice.
Two unlined pits were constructed onsite to provide temporary
storage of drill cuttings, residual drilling muds from the
circulation system, and waste oil. The pit contents were piped
from the drilling operation. The pits were in use between
June 25 and June 27, 1986, and could contain fluids for 120 days,
in accordance with State requirements.
The pits were constructed below grade, in approximately
rectangular shapes. The width of each pit was approximately the
width of a bulldozer blade. Figure 2 shows the measured
dimensions obtained at the time of sampling, based on the liquid
level in the pits at that time. A ditch connecting the two pits
allowed for mixing of the pit contents.
The purpose of the northern pit was to directly receive drill
cuttings from the rig. This was apparent from the piles of
cuttings indicated in Figure 2. The southern pit was used to
store drilling fluids, presumably drawn from the northern pit via
the small connecting ditch shown in Photos 2 and 5.
The depth of liquid in both pits was 1 foot, and the depth of the
sludge was 1/2 to 1 foot. Both pits had a 1-inch layer of oil on
the surface.
Pit contents included 2,500 barrels or less of cuttings, drilling
fluids and waste water generated from drilling operations, and 1
to 2 barrels of waste oil. Tank trucks storing diesel onsite
contained roughly 100 gallons prior to removal of the drilling
rig.
Disposal Practices
State representative Steve Korf suggested that the operator would
probably skim the oil layer off the surface of both pits and take
C-318
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d)
0
Figure 2. Schematic Diagram of Drillina Site
C-319
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it to a recycling facility/ possibly located in nearby
Coffeeville, KS. The remaining water would be hauled to an
injection well. The state allows for solids to dry in reserve
pits for one year, followed by backfilling and leveling the
surface to grade. Reseeding the area is usually left to the
discretion of the landowner.
Permits
A copy of the drilling permit secured by Cindy Van Dyke for the
Gentry Lease Well No. 2A is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Gentry Lease site, the samples were defined as the
supernatant and solid contents of the waste material in both
reserve pits. This was done because the connecting ditch between
the two pits allowed for mixing of pit contents.
Sample points were identified based on measurements of pit
dimensions. However, the asymmetry of the Gentry Lease pits did
not allow for placing sample points at the center of measured
quadrants, as with rectangular pits. Figure 2 indicates the
location of the sample points.
Sampling Methods and Equipment
To collect samples from the reserve pits, measurements were made
to identify four points evenly spaced within both pits. The
measured points were marked by placing stakes along the sides of
the pit to facilitate locating sample points.
The sample points were accessed by boat. The boat was pulled to
the measured sample points via one rope, and was anchored at that
point. One sample team member worked in the boat while the other
stood on shore to steady the boat.
The first sample to be collected was the liquid composite. The
thief was used to obtain this sample. Care was taken not to
allow oil floating on the surface of the liquid to enter the
thief.
C-320
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The reserve pits were then sampled for sludge. The dredge was
used to sample the sludge because the sludge was too liquid to be
retained by the coring device. Two full dredges were obtained at
each point, yielding a total volume of approximately 5 gallons.
The solids were composited in a steel bucket.
The samples were tested onsite for pH after sampling was
completed. The pH of both the liquid and sludge samples was 7.
C-321
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C-322
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-323
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C-324
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;Sp^iA:^
&&&3&s&m£
Photos 1,2,3. Easterly view of reserve pits
-------
Photo
Easterly view of pole extending from well
(pits In background)
Photo 5. Southerly view of ditch between pits
Photo 6. Westerly view of north pit
-------
o
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to
Photo 8. Northwesterly view of south pit
Photo 7. Westerly view of north pit
-------
o
u>
M
CD
Photo 9. Northeasterly v'ew of north pit -
(formation samples In foreground)
Photo 10. Formation samples
-------
ATTACHMENT B: PERMITS
0329
-------
C-330
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CARD MUST BE TYPED
6-25-86
Suiting Dale
OPERATOR: Urea** t 7.?.?.$.
Cl.ndy V
Route"!
Stale of Kansas
NOTICE OF INTENTION TO DRILL
(see rules on reverse side)
API Number 15—
';> '
CARD MUST BK SIGNED
yew
Cind
CONTRACTOR: Limu*
Nl-, Hok.a.t.
Ci,y/*l«...Tjr.r.O»...KS.....673.64 Domestic well
$W SW $W s_ 12
• ••«i •••** •*T«* din*•nn •
3.3Q
...4.9.5.0.
(Note: Local* well oa
Nearest lease or unit boundary^
County
Lease Nsme. .GW.tT.y Well # 2A
Ground surface elevation ... .1 /. A ferl MSL
X
. s. Rj...l.6...
FL fma South Lin* of SrdU>«
ft fnm EMI Line of Section
rr*cnr >idc)
3 U
within 330 feet:
SWD
Well Drilled For:
£_ Oil
1_ C- _ by
_ OWWO _ Espl
If OWWO: «U •«« !•(• ••
Operator
Well Class:
_ la/kU
__ Pool Esl.
JL WIMcat
Air
CaM*
.1.6...
.1.5.0.
—yes X no
l_ J
OMpUott OM Total Depth
I certify thai well will comply with KJ5.A. 55-101, et seq^, plus
Type Equipment: Municipal well within one mile:
Depth to bottom of fresh water..
Depth to bottom of usable water
Surface pipe by Alternate:
Surface pipe planned to be set.
f r r r
Conductor pipe required fu .3
Projected Total Depth IHQ.O feet
Formation M.i$.$.1S* J.PJJ.1
lally plugfiiw hole 14 KCC specifications.
lur M'JC Use:
C4Hidurlur Pipe Required f*tt; Minimum
Tbi» AulhuriialioB Expires
ace Pipe Required ..*..feet per
PLUGGING PROPOSAL IF ABOVE IS D le A
T5i» pluKKing proposal will be reviewed and approved or revised at the time the district office is called prior to setting surface casing (call 7 a.m. to
5 p.m. workdays).
In plug (a ..A.4. P.P. feet depth with ,
2nd plug (it feet depth with .
J.9.
s«s of ....
>x( of
C-331
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C-332
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Sampling Report
Investigation of American Energies Corporation's
Munsell F Well No. 1
Pendennis, Kansas
July 7, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA-530-SW-87-005). This site was selected randomly from
a list of Dodge City Embayment drill sites (at or near
completion) developed by the Department of Health and Environment
at the request of EPA. The list was transmitted via telephone to
the EPA contractor on June 27, 1986. Site selection toolc place
during the telephone conversation.
Kansas state officials preferred to list the possible sample
sites in the manner shown below. The EPA contractor had no
interest in the manner the particular sites were listed (by site
name, location, operator, permit number, API number, etc.) as
long as the site could be identified in detail upon selection.
Thus, the EPA contractor had minimal information which kept to a
minimum the amount of bias. No other information was known about
the sites on the list at the time of selection. Detailed
information was obtained only after selection of primary and
back-up sites. The list consisted of five drill sites:
1. Hutchinson Oil - 91712 - Barton Co.
Spud 6/25/86.
2. American Energy - 281527 - Gobe Co.
Spud 6/24/86.
3. Striling Ltd. - 211131 - Gobe Co.
Spud 6/24/86.
4. Pan Canadian Oil Co. - 12721 - Graham Co.
Spud 6/26/86.
5. CFA Oil Co. - 351031 - Thomas Co.
Spud 6/27/86.
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the sample site. No. 2 on the above
list (American Energy) was selected as the primary sample site.
Plans were made for sampling to be conducted July 7, 1986. No. 1
on the above list (Hutchinson Oil) was tentatively selected as a
back-up site. No back-up site was required.
C-333
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Site Location
Munsell F Well No. 1 is located 5.5 miles north of Pendennis,
Kansas. Figure 1 is a map indicating the well site.
The site is operated by American Energies Corporation, whose
mailing address and telephone number are:
575 Fourth Financial Center
Wichita, KS 67202
316-263-5785
Contact Name: Alan deGood
Attendees
Sampling of Munsell F Well No. 1 was performed by CENTEC
Corporation personnel on July 7, 1986. The following is a list
of people present at the time of sampling:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
State Representative: Don Butcher, Inspector in
Charge, Kansas Corporation
Commission
Operator Representative: L. W. Jackson, Production
Superintendent
American Petroleum
Institute Representative: George Holiday, Contracted
Observer
Site Description
Munsell F Well No. 1 is located within the Dodge City Embayment
in rural flatland; the depth to groundwater is 180 feet, and the
nearest surface water is over 2 miles away. There is one
drinking water well within a 1/2-mile to 1-mile radius of the
well. There are no drinking water wells within a 1/2-mile
radius. The soil in this area is mostly shale. The climate at
this site is net evaporation.
This site was an exploratory oil drilling site. The well reached
a final depth of 4,370 feet on June 30, 1986. The well was a dry
hole. Drilling was accomplished with fresh-water bentonite muds.
No biocides were used during drilling.
Figure 2 is a schematic diagram of the drilling site. Four
separate pits were constructed for the site: a reserve pit, a
fresh water pit, and two working pits. The fresh water and
working pits were constructed below grade. The reserve pit had
bermed sides. All pits were unlined except the fresh water pit,
which had a plastic liner. This was done to prevent the loss of
C-334
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Figure 1. Location of Munsell F Well #1, Pendennis, Kansas
C-335
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/
n
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00
en
Figure 2. Munsell F Well #1 Site Schematic Diagram
-------
fresh water in the pit due to percolation into the ground.
Liquids placed into the unlined pits would percolate into the
ground. The total cost of pit construction was unknown, but pit
costs at similar drilling sites are less than $1,000. Photos 1
and 2 (Attachment A) show the drilling rig platform and the
doghouse. Photos 3-7 show the working pits. Photos 8 and 9 show
the particular working pit that was sampled. Photo 10 shows the
dried reserve pit.
A mud recirculation system was used at this site. The reserve
pit was designed for a one-time use; all drilling cuttings were
to be piped into the reserve pit at the completion of drilling
operations. On the day of sampling, there was no supernatant in
the reserve pit. There was 1/2 foot of supernatant in the
working pit along with 2 feet of sludge. It was unknown what
quantity of drilling fluids the reserve pit received. The
reserve pit received only drilling fluids.
Fifteen hundred gallons of diesel oil were stored at this
facility in tanks. No waste diesel oil was generated.
Disposal Practices
At the completion of drilling, all cuttings were placed in the
reserve pit. There was no treatment or testing of pit contents.
The pit contents were not moved for final disposition. The
fluids were evaporated. The dried pit solids were buried. The
pit site would be reclaimed by the addition of new top soil, and
reseeded. According to site personnel, there are records
available regarding the final disposition.
Permits
No facility permit was available to the sample team at the time
of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).The following
is a description of site-specific sampling information and
activities.
Sample Point Locations
The samples collected at Munsell F Well No. 1 consisted of one
supernatant and one sludge sample. Originally, sampling was to
take place in the reserve pit. The reserve pit was dry on the
sampling day. Sampling took place in one of the working pits
that had a discrete liquid surface. This working pit also still
had drilling fluids in it according to s.ite personnel. Figure 3
C-337
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.\> X
v
-------
shows the sampled pit and the location of the sample points.
Pour quadrants were established for sludge sampling. The liquid
was not across the entire surface of the pit; therefore, liquid
sample points did not match sludge sample points.
Sample Methods and Equipment
The liquid was too shallow for thief sampling; the supernatant
was sampled from the boat with a stainless steel bucket. Sludge
was collected using a stainless steel spoon; the solids were too
fluid to use the coring tube. A sludge sample depth of 1 foot
below pit surface was achieved.
Due to time constraints, samples were held in refrigeration
overnight prior to laboratory shipment.
C-339
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C-340
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-341
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n
10
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Photo I. Drilling platform
Photo 2. Drilling platform and dog house
Photo 3. Work Ing pits
C-343
Photo 4. Working pits
-------
Photo
Working pit
Photo 7. Working pits
Photo
Sampled working pit
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-Ud eAjesey '0|
04.0114
-------
C-346
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Reconnaissance Report
Investigation of Ritchie Exploration, Inc. and
Crosswind Petroleum, Inc.'s Keith Garrett Well No.
Wakeeney, Kansas
July 8, 1986
SITE INFORMATION
Site Selection
EPA conducted a reconnaissance site visit to gain further
information on drilling practices in the state of Kansas. This
site was selected from active Dodge City Embayment drill sites
near Hayes, Kansas, that were accessible to the sampling team.
The Kansas Department of Health and Environment identified this
site at the request of EPA. Site identification was transmitted
directly to the EPA contractor on July 8, 1986.
No back-up site was selected. No problems were encountered
arranging for a site reconnaissance to be conducted July 9, 1986.
No back-up site was required.
Site Location
Keith Garrett Well No. 1 is located near Wakeeney, Kansas, 6
miles north on Route 283 from the junction of Route 283 and
Interstate 70, and 6.5 miles west on County Rd 422. Figure 1 is
a map indicating the well site.
The site is operated by Ritchie Exploration, Inc. & Crosswind
Petroleum, Inc.; the mailing address and telephone number are:
125 North Market
No. 1000
Wichita, KS 67202
316-267-4375
Also hired as contractor was Duke Drilling Co., Inc. from Great
Bend, KS.
Attendees
Reconnaissance of Keith Garrett Well No. 1 was performed by
CENTEC Corporation personnel on July 8, 1986. The following is a
list of people present at the time of reconnaissance:
CENTEC Corp. (sample team): Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
State Representative: Don Butcher, Inspector in
Charge, Kansas Corporation
Commission
C-365
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JJtfAK I MfcN 1 OK 1 Hb IIS I tKlUK
GEOLOGICAL SURVEY
07'30"
^~r\/
~.~ V:*.,- \ V,
'^' r 12 -'--- V
^'^tW^^ifc
Figure 1. Location of Keith Garrett Well No. 1,
Wakeeney, Kansas
0366
-------
Operator Representative: Jeff Christian, Geologist
American Petroleum
Institute Representative: George Holiday, Contracted
Observer
Site Description
Keith Garrett Well No. 1 is located within the Dodge City
Embayment in rural flatland; the depth to groundwater is over 100
feet, and the nearest surface water is less than 1/2 mile away.
The soil in this area is mostly sand and loam. The climate at
this site location is net evaporation.
This site was an exploratory oil drilling site. The well reached
a final depth of 3,970 feet on the day of the reconnaissance.
The well was a dry hole. Drilling was accomplished with
fresh-water muds. No biocides were used during drilling.
Figure 2 is a schematic diagram of the drilling site. Four
separate pits were constructed for the site: a reserve pit, a
fresh water pit, and two working pits connected by trenches. The
fresh water and working pits were constructed below grade. The
reserve pit had bermed sides. All pits were unlined except the
fresh water pit, which had a plastic liner. This was done to
prevent the loss of fresh water in the pit due to percolation
into the ground. Liquids placed in the unlined pits would
percolate into the ground. The total cost of pit construction
was $500. Photos 1-3 (in Attachment A) show the drilling rig and
the diesel oil storage tanks. Photos 4-6 show the working pits
and the trenches connecting them. Photos 7-11 are the reserve
pit and its contents. They show that a considerable amount of
trash was thrown into the reserve pit. Photos 12 and 13 show the
reserve pit and the adjacent fresh water pit. Photo 14 is a
closeup of the fresh water pit which was nearly completely dry.
A mud recirculation system was used at this site. There was no
liquid mud storage. The reserve pit received cuttings and
unrecirculated fluids once a day piped from the working pits. On
the day of the reconnaissance, there was a sludge depth of 1 foot
in the reserve pit. There was no supernatant in the reserve
pit. All remaining drilling fluids and cuttings were placed in
the reserve pit at the completion of drilling operations. The
reserve pit received less than 2,500 bbl of drilling fluids and
cuttings. The reserve pit also received trash. No waste diesel
oil was generated at this site.
Five hundred gallons of diesel oil were stored at this facility
in diesel storage tanks.
C-367
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3. j WORKING MOO ?tT
Figure 2. Keith Garrett Well #1 Site Schematic Diagram
0368
-------
Disposal Practices
At the completion of drilling, all drilling fluids and cuttings
were placed in the reserve pit. There was no planned treatment
of the pit contents. The reserve pit contents would not be moved
for final disposition. The fluids were evaporated. The dried
pit solids were buried. The pit site was to be reclaimed by the
addition of new top soil, and reseeded. According to site
personnel, there are records available regarding the final pit
disposition but were not available at the site.
Permits
The drilling of this well was authorized by the Kansas
Corporation Commission under API No. 15-195-21862. A copy of
this permit is in Attachment B.
C-369
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C-370
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-371
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C-372
-------
L.
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0.
C-373
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Photo 6. Working pit and reserve pit
Photo 8. Reserve pit
-------
li, Photo 9. Reserve pit
-4
ui
Photo 10. Reserve pit
Photo II. Reserve pit
Photo 12. Reserve and fresh water pits
-------
Photo 13. Reserve and fresh water pits
Photo 14. Fresh water pit
-------
ATTSCHMxiNT B: PERMITS
0377
-------
00
r-
m
I
U
-------
CARD MUST DF SIGNED
Stirring D»te
NOllvl <>l IMKN110N IODKII.I.
(•». i i tilt \ tui I <* MIU')
.fi/2.7/.'!.': .. \I-IN •-- r, ,
lUOHltl
,....4767.
1 ''.'.'I.-;. Mr I •>' ; .1.6.50 Kl. from South Un» of trttloo
Addf,
?ct role urn,... Inc.. j .",
i
...J.aif..Christ i,j'.
PbeM....3.16/.Z6.7.r.43.7rJ
CONTRACTOR: Licew. « !J91>')
NMM..Dukje..Djr.illiiKj. Cu.. ,. i i.. ,
cnr/suM...jGrjeii.L..BGndT...K:;.. . o ,'.> M
Well Drilled For: UVI] (.I..--. I M.. 1 .,,.,.„.. ,,i
V Oil SWD _ l.if.,1.1 '.. •>!.. i u..M,,
CM l«j I-.-.M.I \ »
owwo t»pi :•; w«u. .1 •••••
IfOWWO: »U veil infu .. (olt..v...
Operator
Ol.l'luul Ik-p
1 certify that well will comply *>iih K S. A. .'>"> IDl.ii-. .. ri..•.«%. niu-.ll\ plu^^nii; ).i|li in K('<^ \j>rrilii .ni
For KCC Uwt
Cooductor Pipe Required ..
Thu Aothoriulion Expirri.
(i<<. Mtttitiuiin ->.iit.MI* l*iiic Miiiniii'i
/-.-.'.. ,-'*{ ' -'•'<•.
.ree«PcrAI«.
\,T,..,.-.I lit <'...,.4,',.'. ,.'.•:.•.
/'i ' ' ' / ^ &
1 ( . . t !' '
, ..J.O «»P.J:s s. R». ..?.A..
Thi» plugjin|propoi»| wi
5 pja. worfcdajri).
lit ping® 1240.
iM.i'<:<;iN(. I'Koros.M. ii- \iu>\ i is i> .1 A HV^*-
rtl*»tli>|>|>i»\iu» 111 .cum); surface cuing (c«ll 7 t.m. lo
2nd plug @ Ifl H.O i,. i .
Srdpluggji 23.0 i.,,.
4«hplug@ AO I,, i .
Stbplug® I,,, ,
(2) JUrhole with ] U ,x.
•|.ih >• I'll
. Mill 1. l.ll
. i.o
' I I .) () ... Ft. from tut Un« i
(N.iir |JM nr Mftl IM. Sr. lii.it I'Ul an rever«« ttil*...l
t.t..nml MI.I.i. r rletji,..,! .. i.1:; t ... 23 25. feet MSL
I>..mi-kin uill uiilun '[.'III In-). ytt __no f
M.IIIU IJIA! urlt **tlmi **nr Itiilr yri no
!>• jilli I.. Imlli.iii of frr«h u^lrr L20.'.
I', fill III ln.llo.ll of U »!.!<• V.JIIT 1.00(1 .'
'.iiil.i. < JIIJH- In MlrniMlr*. I ?X—
S...I.I. r |.,|.i- pla it I,. IK- »••! 2QjO.'.
« <• • I'M" ' '«»
I'n.j. il. .1 I..I..I Dij.lh 3'1 40 feel
i-ori.,..i . ..U;.u;<;..ot"..Kansas.-Ci-ty
NOTE: Agrcrmrnl brlwrrn ..(«•. ji.., .,...1 ,|,M, ,. i .,if,,. ....,.! .: ,.t... »« m .m
In Addition: Call ili^irui uffur *lin >.i II M i nl.. i |.ln(v. .1 •.. | I"
i< .ill V . in )'. '. p in
Dutrict office u»c only.
Surface cuing of r,.,, ,,.( ,,,i|,
UlenUtC 1 or 2 mirfa.r |>.|M M.I-. OM-I|
IheruU 2 cementing wm» cuinpl«-i,-,| („
UU plugged |
-------
C-380
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Reconnaissance Report
Investigation of Oil Producers, Inc. of Kansas'
Ott Well No. 2
Wakeeney, Kansas
July 9, 1986
SITE INFORMATION
Site Selection
EPA conducted a reconnaissance site visit to gain further
information on drilling practices in the state of Kansas. This
site was selected from active Dodge City Embayment drill sites
near Hayes, Kansas, that were accessible to the sampling team.
The Kansas Department of Health and Environment identified this
site at the request of EPA. Site identification was transmitted
directly to the EPA contractor on July 8, 1986.
No back-up site was selected. No problems were encountered
arranging for a site reconnaissance to be conducted July 9, 1986.
No back-up site was required.
Site Location
Ott Well No. 2 is located near Wakeeney, Kansas, 6 miles north on
Route 283 from the junction of Route 283 and Interstate 70, and 6
miles west on County Road 422. Figure 1 is a map indicating the
well site.
The site is operated by Oil Producers, Inc. of Kansas, whose
mailing address and telephone number are:
PO Box 8647
Wichita, KS 67208
316-681-0231
Also hired as contractor is Western Kansas Drilling, from Hays,
KS.
Attendees
Reconnaissance of Ott Well No. 2 was performed by CENTEC
Corporation personnel on July 9, 1986. The following is a list
of people present at the time of reconnaissance:
CENTEC Corp. (sample team)
Operator Representatives:
Bruce Hoskins, Team Leader
Dewayne Buskey, Technician
John S. Weir, President, Oil
Producers, Inc. of Kansas
Bill Shepard, Geologist
Rick Hughes, Service Engineer,
Hughes Drilling Fluids
C-381
-------
DEPARTMENT OF THE INTERIOR
GEOLOGICAL SURVEY
100*00' <|«—£ «li
07'30"
•!»
•17 S7'30"
Owil OITY I I3SOOOI
Figure 1. Location of Ott Well #2, Wakeeney, Kansas
C-382
-------
American Petroleum
Institute Representative: George Holiday, Contracted
Observer
Site Description
Ott Well No. 2 is located within the Dodge City Embayment in
rural flatland; the depth to groundwater is over 100 feet, and
the nearest surface water is less than 1/2 mile away. The soil
in this area is mostly sand and loam. The climate at this site
location is net evaporation.
This site was a developmental oil drilling site. The well
reached a final depth of 3,942 feet on the day of the
reconnaissance. The well was a dry hole. Drilling was
accomplished with fresh-water spud muds: either bentonite or
attapulgite in combination with fresh water, corn starch, cotton
seed hulls, and paraformaldehyde as a biocide. All mud
components were supplied by Hughes Drilling Fluids of Houston,
Texas. Attachment C contains the specification sheets on the
individual mud components as supplied by Hughes Drilling Fluids.
Figure 2 is a schematic diagram of the drilling site. Five
separate pits were constructed for the site: a reserve pit, a
fresh water pit, an overflow pit, a working pit (which resembled
a trench rather than a pit), and a burn pit. All pits were
constructed below grade. All pits were unlined except the fresh
water pit, which had a plastic liner. This was done to prevent
the loss of fresh water in the pit due to percolation into the
ground. Liquids placed in the unlined pits would percolate into
the ground. The total cost of pit construction was $800. In
Attachment A is a series of photos (Photos 1-5) taken from the
top of the freshwater tank that show the different pits. The
largest pit by far was the reserve pit which measured 75 feet by
75 feet.
A near 100 percent mud recirculation system was used at this
site. There was no liquid mud storage. The reserve pit was
designed for a one-time use; all drilling fluids and cuttings
were to be placed in the reserve pit at the completion of
drilling operations. Any fluids that were removed during
drilling were placed in the overflow pit. Photos 6-14 are
closeups of the working pit in sequence from the surface mud
ejection to the recirculation point. Photo 15 is a closeup of
the overflow pit. The reserve pit was to receive between 6,000
and 7,500 bbl of drilling fluids and cuttings. The reserve pit
was to receive no other types of wastes. No waste diesel oil was
generated.
Four thousand gallons of diesel oil were stored at this facility
in a diesel storage tank. The fresh water storage tank also
appeared to have a considerable amount of oil floating on the
surface.
C-383
-------
fs.
o
OJ
00
GtWfRftTfiR
c
R TAMK
\WftTER
Pn
Figure 2. Ott Well #2 Drilling Site Schematic
Diagram
-------
Disposal Practices
At the completion of drilling, all drilling fluids and cuttings
were placed in the reserve pit. There was no planned treatment
of the pit contents. The mud company, Hughes Drilling Fluids,
was to test the pit contents for pH, chlorides, viscosity, and
water loss. The results of these tests were not available at the
drilling site. The reserve pit contents would not be moved for
final disposition. The fluids were evaporated. The dried pit
solids were buried. The pit site was reclaimed by the addition
of new top soil. According to site personnel, there were no
records available regarding the final pit disposition.
Permits
Drilling at this site was authorized by the Kansas Corporation
Commission under API No. 15-195-21863. A copy of this permit is
in Attachment B.
C-385
-------
C-386
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-387
-------
C-388
-------
:Vr<>-^^'W
yvYfi'^w^
-------
I Photo 6. Working and mud recIrcuI at I on pit
LJ
VO
o
Photo 7. Working and mud recIrcuI at Ion pit
-------
OPhoto 8.
I
OJ
VO
Working and mud recircuI at I on pit
Photo 9. Working and mud recIrcuI at Ion pit
-------
36£-D
-------
O
OJ
Photo
Working
and mud rec.rcul
atlon
r.clr<;
-------
---v •>
«.^-iK«rl;^*..-..-LiiW h. .4 /
<"! Photo 14. Working and mud rec I rcu I at I on pit
Photo 15. Overflow pit
U)
-------
ATTACHMENT B: PERMITS
C-395
-------
C-396
-------
f, oh I.N i i.r-, i K i,\ i < > nun i.
(s.-r Mil,-, mi ri-M-iM- s,.
•loath da) >rar
OPERATOR: Uc«n-*...BQ6i
N«n« ....Q.t.l. ..P.r.P.dw fi s xs.t.. .T.u.c. t.. .P f... K n n -•>..) ^
Addr«. ?.,.P.,.
Al'l NIHIIII. i I',
___ *"'
SK NW ;;/9()*«--J-T.p...U.s.R,...24.. _Xwe.,
. , • r-'l. from South Line of Section
• • • • • • Fi. from E*u Line of Section
(Ni.ii- l.xji, »rll .MI Sr.ii.i.i |M»i oil reverse side)
CONTRACTOR: Llcens. * c(iii
Signature of Ojieralor or Agenl
»,-ni,-.l I,-,iv, „, „„,, iM.nn.ljry |i,lf .330
(mini\ l'rci',0
ir.iv, N.,,... ..U^A
l.iiiiinil VIM I.,, ,- , 1,-v.ilnm
.feet
Miniii ip.il H.-ll uiiliin line milr:
Siiil.i. >• |n|., |iv Ali.-in.it. :
IV|Hli in I...ll,,IM i,l I,, si, w.,i,.r 70
IK-plli i.i In,ll.mi ol us.iliU- w;urr .1000
.Siilf.i, r |'ip<- |il.iiiuc.l In IK- srl 2 0 0
Well *.... 2
feet MSL
yes no
—yes —no
Due ,
Kor KCC Use:
Conductor Pipe Required f,.ct; Minimum Sin(j.Wi,,.- l<< .,IMI.-,
This Authorization Expires /.«?• . .<*. fa^ Apmme.l II v
1'cr Gilbert lli^.s
This pluggi
5 p.m. workdays).
Off ii-c
n.uuiiNC. I'uorosAi IF AIIOVI is i> ,v \
revi..w,.,la,,,|appr(U<.,|,irl<.viv,,,.lM,,, ,,,,,.. ,„ •«i.«Rsurl«-cCjsing(,-.||7fcm.u,
is, plug V ...5.9.:.(.ak?.Y.':..Arbuck ^ ^^ ^ j s
• " Vn* I*" *t* i " * ''' '*"**' *l**Pih wi(h * /
3rd piuK &,.. 50... below_t i,__cibo_vo ,l}.i«.Uu a;,,, I no
5th plug (»
(2) Ralhole with
15
l.-i-l I,.K1.,.,I ,., i,,,.,|,,. „.,„ . ,
| f>^ - ('I ....... ,11.1, I .IVIIII. IV I I 11,1 1,1, ,| 1,1
((•jll 7 .1.111. 10 rl |> Ml. »,,, |,,|.u s,
District office use only:
»x-. ,,l
V \ V III
•-X-. ,,l
S»S I.I " " «' -If
*»1 V l,| . .
ll'l Mouvrh,,!,- unit .j,.^, L
' 5
Arms-..
Surface casing of f.-«-l M-I «iil,
Alternate 1 _or 2 surface pip.- v.j> us,-,|.
Alternate J cementing was completed i« ,,
Hole plugged 19
-------
C-398
-------
ATTACHMENT C:
MUD COMPONENT SPECIFICATION SHEETS
C-399
-------
C-400
-------
S516012
EMERGENCY TELEPHONE: (713)680-3823
HUGHES DRILLING FLUIDS
10777 N.W. FRWY..STE 700
HOUSTON, TX 77092
HEALTH 0
FLAMMABILITY 1
REACTIVITY 0
PERSONAL PROTECTION E
WHITE STARCH
SECTION I - PRODUCT IDENTIFICATION
Synonyms
Formula
Corn starch
Variable
Chemical Family: Polysachlaride
CASf :
Unit of Issue:
Application :
Multiple
55 Ib. sack
Filtration
control
Warning
WARNING! NUISANCE DUST I
eyes, skin and clothing.
Avoid high concentration. Minimize contact with
Keep away from heat, sparks, and open flames.
SECTIC
COMPONENT
Starch
)N II - HAZARDOUS
PERCENT (%)
100
5 INGREDIENTS
TLV
2
10 mg/m
(total dust)
Reference
ACGIH, 1984-85
TRANSPORTATION INFORMATION
Classified as a hazardous material according to DOT(49 CFR 172):
Proper shipping name: Not restricted
Hazard Class : Nonhazardous
Identification No. : None
Labels required : None
IMCO class : Nonhazardous
IATA class : Nonhazardous
YES X NO
SECTION III - PHYSICAL PROPERTIES
Appearance A color
Solubility in water
Boiling point
Evaporation rate
Vapor density
pH
White powder
Insoluble
N/A
N/A
N/A
5.0-7.0
Odor :
Melting point :
Vapor pressure (mm Hg):
% Volatile (by vol.) :
Specific gravity :
Odorless
N/A
N/A
8.0 (moisture)
1.5
SECTION IV - FIRE ft EXPLOSION HAZARD INFORMATION
Flash point : N.D. Autoignition temp : 429 C
Flammable limits (% by vol.): N.D. Decomposition temp: N.D.
Extinguishing media : Water, carbon dioxide, dry or chemical foam
Fire ft explosion hazards : Treat as flammable dust when in the finely
divided and suspended state.
C-401
-------
WHITE STARCH page 2
SECTION V - HEALTH HAZARD INFORMATION
Routes of Entry: Inhalation X Ingestion Skin * Eye Contact
Acute effects of overexposure: No data available.
First aid: Eyes : }
Skin . _ -x }
Inhalation: } None required.
Ingestion : }
Additional comments: Follow suggested precautions for nuisance dust.
SECTION VI - REACTIVITY DATA
Stability YES(X) NO( ) Undergoes Polymerizations YES( ) NO(X)
Incompatible materials: Heat.
Hazardous decomposition products: None reported.
SECTION VII - SPILL OR LEAK PROCEDURES
Keep dust to a minimum.Sweep into a waste container.
Waste Disposal
Disposal should be in accordance with federal, state and local regulations.
This material is not listed as a hazardous substance, as defined in Section
101 (14) of the Comprehensive Environmental Response, Compensation and
Liability Act (CERCLA) of 1980.
SECTION VIII - PERSONAL PROTECTIVE EQUIPMENT
Wear cotton gloves, safety glasses and particle dust mask for comfort.
Personal Protection Index "E".
SECTION XI - SPECIAL PRECAUTIONS
Handling & storage: Store in a cool, dry area. Keep dust to a minimum.
Other regulatory agency controls:
Data Sheet Issued: 01/17/86
C-402
-------
S441011
EMERGENCY TELEPHONE (713)680-3823
HUGHES DRILLING FLUIDS
10777 N.W. FRWY.,STE 700
HOUSTON, TX 77092
HEALTH
FLAMMABILITY
REACTIVITY
PERSONAL PROTECTION
STARCH PRESERVATIVE
SECTION I - PRODUCT IDENTIFICATION
Synonyms
Formula
Chemical Family
: Paraformaldehyde
: C3HgO,
: Aldehydes
CASt : 30525-89-4
Unit of Issue: 50 Ib. sack
Application : Biocide
Warning
WARNING! HARMFUL IF INHALED OR SWALLOWED. Causes irritation. CAUTION!
Combustible - Keep away from heat and flame. Avoid breathing dust. Use
only with adequate ventilation. Avoid contact with eyes, skin and
clothing.
SECTION II - HAZARDOUS INGREDIENTS
COMPONENT
Paraformaldehyde
PERCENT (%)
>95
TWA
2 ppm
Reference
ACGIH
TRANSPORTATION INFORMATION
Classified as a hazardous material according to DOT(49 CFR 172); X YES
Proper shipping name: Paraformaldehyde
: ORM-A
: UN 2213
: None
: 4.l--Inflanunable solids
: Flammable solid
NO
Hazard Class
Identification No.
Labels required
IMCO class
IATA class
SECTION III - PHYSICAL PROPERTIES
Appearance A color
White flakes
Solubility in water: 0.17 g
Boiling point
Evaporation rate
Vapor density
pH
Sublimes
N/A
N/A
N.D.
Odor : Pungent
Melting point : Sublimes
Vapor pressure(mm Hg): 1 @ 86°F
% Volatile (by vol.) : 100
Specific gravity : 1.46
302°F
SECTION IV - FIRE * EXPLOSION HAZARD INFORMATION
: 158°F
Flash point (PMCC) : 158F Autoignition temp : 572F
Flammable limits (% by vol.): Upper 73 Lower 7.0
Extinguishing media : Water, carbon dioxide, dry or chemical foam
Fire * explosion hazards : Explosive hazard at high temperatures
C-403
-------
STARCH PRESERVATIVE page 2
SECTION V - HEALTH HAZARD INFORMATION
Routes of Entry: Inhalation X Ingestion X Skin A Eye Contact X
Acute effects of overexposure: Corrosive. Severely irritating to eyes and
respiratory tract. Acute exposure results in pulmonary ademea, chronic
exposure irritates the skin/ producing sensitization and asthma.
First aid: Eyes : Flush with water.
Skin : Wash with soap and water.
Inhalation: Remove to fresh air.
Ingestion : DO NOT INDUCE VOMITING. Seek immediate medical
attention.
Additional comments: Toxicity Data — Oral -Rat LD5n* 800 mg/kg
Skin-Rabbit LDQi 10,000 mg/kg
SECTION VI
- REACTIVITY DATA
Stability YES(X) NO( ) Undergoes Polymerization: YES( ) NO(X)
Incompatible materials: Heat, strong oxidizers, peroxides, acids, ketones.
Reacts with water, releasing dangerous gases.
Hazardous decomposition products: Thermal decomposition products are
hazardous and toxic-carbon dioxide and carbon monoxide.
SECTION VII - SPILL OR LEAK PROCEDURES
Contain area of spill.Do not allow contact with moisture.Sweep into
container. Dispose at licensed waste facility. Reportable quantity-
1000 kg/454 Ibs..
Waste Disposal
Disposal should be in accordance with federal, state and local regulations
This material is listed as a hazardous substance, as defined in Section 10
(14) of the Comprehensive Environmental Response, Compensation Act (CERCLA
of 1980.
SECTION VIII - PERSONAL PROTECTIVE EQUIPMENT
Avoid skin contact.Wear impervious clothing,including goggles,boots an
rubber gloves. Wear vapor respirator when mixing product. Personal
Protection Index "H".
SECTION XI - SPECIAL PRECAUTIONS
Handling * storage: Store in cool, dry area in air-tight drums. Do not al
low contact with moisture. Keep away from heat, sparks and open flames
Other regulatory agency controls: Registry Toxic Chemicals Number RV 05400
DOT: 49 CFR 172.101 Hazardous Materials Table. Subject to additional
labeling requirements of 49 CFR 172.402
Data Sheet Issued: 01/17/86
C-404
-------
S111011
EMERGENCY TELEPHONE (713)680-3823
HUGHES DRILLING FLUIDS
10777 N.W. FRWY.,STE 700
HOUSTON, TX 77092
HEALTH 1
FLAMMABILITY 0
REACTIVITY 0
PERSONAL PROTECTION E
CLOROGEL
SECTION I - PRODUCT IDENTIFICATION
Synonyms ;
Formula :
Chemical Family:
Attapulgite
(OH2)4(OH)2Mg5Sig02 *4H20
Magnesium, Aluminum
Silicate
CASf
-/b-4
Unit of Issue: 50 Ib. sack
Application : Viscosifier
Warning
WARNING! MAY BE HARMFUL IF INHALED OVER PROLONGED PERIOD AND MAY CAUSE
DELAYED LUNG INJURY. Avoid breathing dust. Use NIOSH/MSHA approved
respirator where TLV for crystalline silica may be exceeded.
SECTION II - HAZARDOUS INGREDIENTS
COMPONENT
Free silica
PERCENT (%)
1-3
TLV
10 mg/m
Reference
ACGIH
TRANSPORTATION INFORMATION
Classified as a hazardous material according to DOT(49 CFR 172)
Proper shipping name: Not restricted
Hazard Class : Nonhazardous
Labels required : None
IMCO class : Nonhazardous
IATA class : Nonhazardous
YES X NO
SECTION III - PHYSICAL PROPERTIES
Appearance ft color
Solubility in water
Boiling point
Evaporation rate
Vapor density
PH
Powder,tan
Insoluble
N/A
N/A
N/A
N.D.
Odor
Melting point
Vapor pressure(mm Hg)
% Volatile (by vol.)
Specific gravity
Odorless
N/A
N.D.
16% moisture
2.29-2.36
(colloidal)
SECTION IV - FIRE ft EXPLOSION HAZARD INFORMATION
Flash point : N/A Autoignition temp : N/A
Flammable limits (% by vol.): N/A Decomposition temp: N/A
Extinguishing media ' : Carbon dioxide, dry or chemical foam & water
Fire ft explosion hazards : None.
C-405
-------
CLOROGEL page 2
SECTION V - HEALTH HAZARD INFORMATION
Routes of Entry: Inhalation X Ingestion Skin ft Eye Contact
Acute effects of overexposure: Prolonged and con'tinuous exposure to an
excessive concentration of dust may have an adverse"pulmonary effect.
First aid: Eyes :
Skin : None required.
Inhalation:
Ingestion :
Additional comments: None
SECTION VI - REACTIVITY DATA
Stability YES(X) NO( ) Undergoes Polymerization: YES( ) NO(X)
Incompatible materials: None.
Hazardous decomposition products: Does not decompose.
SECTION VII - SPILL OR LEAK PROCEDURES
Sweep or vacuum up spilled material into a container for disposal.
Waste Disposal
Disposal should be in accordance with federal, state and local regulations.
This material is not listed as a hazardous substance, as defined in Sectior
101 (14) of the Comprehensive, Environmental Response, Compensation, Lia-
bility Act (CERCLA) of 1980.
SECTION VIII - PERSONAL PROTECTIVE EQUIPMENT
Supply adequate mechanical ventilation. Wear NIOSH approved particle dust
mask and cotton gloves for comfort. Personal Protection Index "E".
SECTION XI - SPECIAL PRECAUTIONS
Handling ft storage: Minimize dust generation and exposure.
Other regulatory agency controls:
Data Sheet Issued: 01/17/86
C-406
-------
S110018
EMERGENCY TELEPHONE (713)680-3823)
HUGHES DRILLING FLUIDS
10777 N.W. FRWY.,STE 700
HOUSTON, TX 77092
HEALTH 1
FLAMMABILITY 0
REACTIVITY 0
PERSONAL PROTECTION E
BENGEL
SECTION I - PRODUCT IDENTIFICATION
Synonyms
Formula
: Bentonite clay CASf : 1302-78-9
: (OH)4Sig(Al3 34*Mg0 066)030 Onit of Issue: 50 & 100
Chemical Family: Aluminum Magnesium Silicate Application
Ib. sack, bulk
: Viscosifier
Warning
WARNING! MAY BE HARMFUL IF INHALED OVER PROLONGED PERIOD AND MAY CAUSE
DELAYED LUNG INJURY. Avoid breathing dust. Use NIOSH/MSHA approved
respirator where TLV for crystalline silica may be exceeded.
SECTION II - HAZARDOUS INGREDIENTS
COMPONENT
Silica
PERCENT (%)
3
TLV
3
10 mg/m
Reference
OSHA
TRANSPORTATION INFORMATION
Classified as a hazardous material according to DOT(49 CFR 172):
Proper shipping name: Not restricted
Hazard Class : Nonhazardous
Identification No. : None
Labels required : None
IMCO class : Nonhazardous
IATA class : Nonhazardous
YES X NO
SECTION III - PHYSICAL PROPERTIES
Appearance * color
Solubility in water
Boiling point
Evaporation rate
Vapor density
pH (6% solution)
Gray powder
Insoluble
N/A
N/A
N/A
8-9
Melting point
Vapor pressure(mm Hg)
% Volatile (by vol.)
Specific gravity
N/A
N/A
10% moisture
1.70-2.65
SECTION IV - FIRE * EXPLOSION HAZARD INFORMATION
Flash point
Flammable limits (% by vol.)
Extinguishing media
Fire ft explosion hazards
N.E.
N.E.
Autoignition temp : N.E.
Decomposition temp: N.E.
: Water, carbon dioxide, dry or chemical foam
: None reported.
C-407
-------
BENGEL page 2
SECTION V - HEALTH HAZARD INFORMATION
Routes of Entry: Inhalation X Ingestion Skin A Eye Contact
Acute effects of overexposure: No known danger.
Chronic effects of overexposure: Repeated or prolonged inhalation of dust
may result in silicosis and/or related
respiration ailments.
First aid: Eyes : Flush with water.
Skin : Wash with soap and water.
Inhalation: Remove to fresh air.
Ingestion : Drink water. Induce vomiting.
Additional comments: Suggested precautions for nuisance dust are sufficient
to safeguard health.
SECTION VI - REACTIVITY DATA
Stability YES(X) NO( ) Undergoes Polymerization: YES( ) NO(X)
Incompatible materials: Heat.
Hazardous decomposition products: None.
SECTION VII - SPILL OR LEAK PROCEDURES
Sweep into a waste container.Dispose in land fill.
_^ ^ Waste Disposal
Disposal should be in accordance with federal, state,and local
regulations. This product is not listed as a hazardous substance, as de-
fined in Section 101 (14) of the Comprehensive Environmental Response,
Compensation, Liability Act (CERCLA), of 1980.
SECTION VIII - PERSONAL PROTECTIVE EQUIPMENT
Wear cotton gloves, safety glasses, and particle dust mask for comfort.
Personal Protection Index "E".
SECTION XI - SPECIAL PRECAUTIONS
Handling A storage: Keep dust to a minimum. Keep away from heat, open
flame or electrical sparks.
Other regulatory agency controls: FDA: Safe designation 21 CFR 582.1155
Data Sheet Issued: 01/17/86
C-408
-------
S551211
EMERGENCY TELEPHONE: (713)680-3823
HUGHES DRILLING FLUIDS
10777 N.W. FRWY.,STE 700
HOUSTON, TX 77092
HEALTH
FLAMMABILITY
REACTIVITY
PERSONAL PROTECTION
_0_
B
COTTON SEED HULLS
SECTION I - PRODUCT IDENTIFICATION
Synonyms
Formula
: Cottonseed Hulls
: Variable
Chemical Family: Cellulose
CAS} : Multiple
Unit of Issue: Multiple
Application : Lost circulation
material
Warninc
WARNING! NUISANCE DUST! Avoid high dust concentration. Minimize contact
with eyes, skin, and clothing. Keep away from heat, sparks, and open
flame.
SECTION II - HAZARDOUS INGREDIENTS
COMPONENT
Cellulose
PERCENT (%)
100
TLV
3
10 mg/m
Reference
ACGIH (Nuisance dust)
TRANSPORTATION INFORMATION
Classified as a hazardous material according to DOT(49 CFR 172); X YES
Proper shipping name: Cottonseed Hulls
Hazard Class : ORM-C
Identification No. : None
Labels required : None
IMCO class : None
IATA class : None
NO
SECTION III - PHYSICAL PROPERTIES
Appearance & color
Solubility in water
Boiling point
Evaporation rate
Vapor density
pH
Brown hulls
Insoluble
N/A
N/A
N/A
N/A
Odor
Melting point
Vapor pressure (mm Hg)
% Volatile (by vol.)
Specific gravity
: Odorless
: N/A
: N/A
: N/A
: N.D.
SECTION IV - FIRE * EXPLOSION HAZARD INFORMATION
Flash point : N.D. Autoignition temp : N.D.
Flammable limits (% by vol.): N.D. Decomposition temp: N.D.
Extinguishing media : Water, carbon dioxide, dry or chemical foam
Fire * explosion hazards : Treat as flammable dust when in the suspended
state.
C-409
-------
COTTONSEED HULLS page 2
SECTION V - HEALTH HAZARD INFORMATION
Routes of Entry: Inhalation X Ingestion Skin ft Eye Contact
Acute effects of overexposure: Mo data available.
First aid: Eyes :
Skin : None required.
Inhalation:
Ingestion :
Additional comments: Follow suggested precautions for nuisance dust.
SECTION VI - REACTIVITY DATA
Stability YES(X) NO( ) Undergoes Polymerization: YES( ) NO(X)
Incompatible materials: Heat, oxidizing agents.
Hazardous decomposition products: None reported.
SECTION VII - SPILL OR LEAK PROCEDURES
Keep dust to a minimum.Sweep into a waste container.
Waste Disposal
Disposal should be in accordance with federal, state and local regulations.
This material is not listed as a hazardous material, as defined in Section
101 (14) of the Comprehensive, Environmental Response, Compensation,
Liability Act (CERCLA) of 1980.
SECTION VIII - PERSONAL PROTECTIVE EQUIPMENT
Wear cotton gloves and particle dust mask for comfort.Personal Protection
Index "B".
SECTION XI - SPECIAL PRECAUTIONS
Handling ft storage: Store in a cool, dry area. Keep dust to a minimum.
Other regulatory agency controls: DOT: Hazardous Materials Table 49
C?R 172.101
Data Sheet Issued: 01/17/86
C-410
-------
KENTUCKY
C-411
-------
C-412
-------
Sampling Report
Investigation of Maverick Production, Inc.
Glassco Lease Well No. 1
Henderson County, Kentucky
August 21, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Illinois Basin drill sites developed by the Department
of Mines and Minerals, at the request of EPA. The list was
transmitted via telephone to the EPA contractor on August 18,
1986. Randomization and selection took place during the
telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Mines and Minerals listed the possible sample
sites by permit number and status, as shown below. The list
consisted of nine drill sites in the Illinois Basin:
1. Permit No. 73145, pits open testing on it 8/18/86
2. Permit 73146, plugged dry hole, pit still open
3. J. F. Smith #14, Empire Oil and Gas. Casing set,
waiting on cable tools.
4. Kit Industries, Green Valley Farm Supply. Dry
hole, pits still open.
5. Maverick Production #3, Crapston Lewis. Casing
set, cable tools on for testing.
6. Maverick £1, Glassco. Logging well now, will know
more later.
7. South Coast Oil Company, II Wheatley. Drilling
now, anticipate finishing by Friday or Saturday.
C-413
-------
8. D. K. Parker, #1A McDowell 73266. Started
Saturday, surface casing set, expect to finish by
Friday or Saturday.
9. Texas Gas, Midland Gas Field, Peabody Coal Company
acreage. At total depth, mud rig.
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 6 on the above list
(Maverick tl Glassco). No. 2 on the above list (Permit 73146)
was selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
Further inquiry identified the primary sample site as Maverick
Petroleum Company's Glassco Lease Well No. 1, in Henderson
County, Kentucky. No problems were encountered in arranging
sampling for August 21, 1986.
The back-up site was identified as C&L Resources Development #2
Gertrude Buchanan well, owned by Frank Cox. The back-up site was
not required.
Site Location
The location of the Glassco Lease Well No. 1 is approximately 1
mile west of the intersection of County Road 351 and Tillotson .
Road, and approximately 8 miles east of the Pennyrile and Audubon
Parkways in Henderson County, KY. Figure 1 is a map indicating
the drilling site. The full name and mailing address for
Maverick Production is:
Maverick Production, Incorporated
Route 3, P.O. Box- 238-A
Henderson, KY 42420
Main Office Contact: Otis Walker, President
Phone: 502-521-6022
Attendees
Sampling at the Glassco Lease site was performed by CENTEC
Corporation personnel on August 21, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (Sample Team): Jim Kourmadas, Technician
Jamie Mclntyre, Team Leader
C-414
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Figure 1. Location of Maverick Production, Inc.'s
Glassco Lease Well No. 1, Henderson County,
Kentucky
C-415
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State Representatives:
Operator Representative:
American Petroleum Institute
Representatives:
Joe Lander, Inspection
Supervisor, Department of Mines
and Minerals, Oil and Gas
Division
George Bradel, Environmental
Engineer Chief, Natural
Resources and Environmental
Protection Cabinet
Otis Walker, President
Terry Walker, Geologist
George Holliday, Contracted
Observer
Alan Willson, Contracted Sample
Team Member
Kyle Hodges, Contracted Sample
Team Member
Site Description
The Glassco Lease site is located in a rural, piedmont area. The
climate at this site location is net precipitation. The soil is
described as clay. The site is located over the Illinois basin.
The formation was not specified by the operator. Figure 2 is a
survey of the exact location of the hole.
The depth to the groundwater in the area is 58 feet. The nearest
surface water is Lick Creek located less than 1/4 mile from the
site. There are no drinking water wells located within a 1-mile
radius of the site because all residences in the vicinity use the
county water system.
At the time of sampling, the site consisted of two mud
circulation pits, one settling pit, and one reserve pit. The
drilling equipment had been disassembled but was still at the
site, as shown in Photos 11 and 12. Figure 3 is an approximate
schematic diagram of the site, indicating the directions in which
photos were taken (Attachment A).
This site was an exploratory oil drilling site. Drilling began
on August 14, 1986 and was halted August 18, 1986. The depth was
2,400 feet when drilling was stopped. The well proved to be a
dry hole.
Drilling was accomplished with a Quebracho mud and a lime mud.
Other additives included caustic soda and Magcobar Gel
(bentonite). The Brant Mud Company located in Henderson, KY was
used to run the drilling mud program.
C-416
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WELL LOCATION PLAT
MAVERICK PRODUCTION INC. - TOMMY GLASSCO NO. 1
OPERATOR -
FARM
COUNTY
TOPO SHEET
DATE
SCALE
Maverick Production Inc.
Tommy Classco
Henderson
Spottsville
7/16/86
1" - 200* —
CARTER COORDINATES
13-P-2S
750 FSL, 200 PEL
Elevation » 409.S feet
I HEREBY CERTIFY that the above plat is accurate
and correct and satisfies the requirements of
805 KAR 1:0$9 to the best^of ay knowledge and belief.
Eeve A. Likins
(502) 826-4330
UKiHS i :iOi;«AVE
uo; .1. c';..:.. .,:;I::T
p o. i.n- •'?.'•:
rnC'JOM. M.-ih':- Ky «2420
STATE o? AeiTiiCi
'
\ S. A. UKJSS
2352
RCGIST«r.lD
Figure 2. Survey of Well Location (size of
copy has been reduced)
C-417
-------
Figure 3. Schematic Diagram of Drilling Site
C-418
-------
One unlined reserve pit was constructed onsite to provide
temporary storage of drill cuttings, fresh water, drilling mud,
cement, and produced brine. The operator stated that the
drilling muds were vacuumed into the reserve pit from the mud
circulation pits. The drill cuttings were piped to the reserve
pit from the drilling operation.
The average depth of liquid in the reserve pit was 1/2 foot, and
the average depth of the sludge was 1 foot. Photo 1 shows that
the reserve pit was never filled enough to cover the bottom
completely.
Two pits were constructed for use as mud circulation pits.
Photo 7 shows these pits and the channel that connects them.
Photos 8 and 10 include the settling pit constructed north of the
circulation pits. All four pits onsite were constructed below
grade.
The mud circulation pits had been treated prior to the time of
sampling. During drilling, caustic soda was added to neutralize
the mud to a pH of 7. The entire contents of the pits were
treated, and half of the contents were "jetted" over to the
reserve pit.
Approximately 200 gallons of diesel were stored onsite in tanks
during drilling. The operator estimated that approximately 5
gallons of waste oil had been disposed of in the circulation pits
when a diesel engine developed an injector leak. Another source
of waste oil was rotary chain lubricant used onsite.
Disposal Practices
The operator would not take any steps to restore the site until
after the corn in the surrounding field had been harvested, in
order to minimize the crop loss. The harvest was expected to
take place in October.
The liquid in the pit was to be removed from the site by truck,
although the ultimate disposition of the liquid was not
identified by the operator. The company used for hauling waste
liquids from the site was Russell's Tank Service, located in
Pleasant Ridge, KY. The solids would remain in the pit, and the
pit would be backfilled. The area would be restored according to
recommendations of the Agricultural Soil Conservation Service, a
state-funded service performed by the University of Kentucky.
Permits
A copy of the drilling permit secured by Maverick Production,
Inc. for the Glassco Lease Well No. 1 is located in Attachment B.
C-419
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SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Glassco Lease site, the samples were defined as the
supernatant and solid contents of the waste material in the
reserve pit.
The sample points were obtained by standing on the side of the
pit and reaching in with the sampling equipment. A boat was not
used for sampling because there was not enough liquid surface in
the reserve pit to float on. There was some discrepancy between
actual and measured sample points due to the inaccessibility of
the measured points. Figure 3 indicates the measured sample
points as well as the actual sample points from which the pit
samples were composited.
In addition to the pit samples, a drilling mud sample was
collected from the eastern mud circulating pit. The circulation
pits were connected by the channel shown in Photo 9, so their
contents were assumed to be approximately the same. The eastern
pit was chosen for its lack of surface debris.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked with
stakes to facilitate locating sample points.
The first sample to be collected was the liquid composite. The
thief was used by threading the gaging tape through a pipe,
attaching the thief to the end of the tape, and extending the
pipe over the surface of the liquid as far as the sampler could
safely reach. Care was taken not to allow oil floating on the
surface of the liquid to enter the thief. The liquid from each
sample point was composited in a 5-gallon carboy.
The reserve pit was then sampled for sludge. The dredge was used
to sample the sludge because the sludge was not deep enough and
was too liquid to be retained by the coring device. Two full
dredges were obtained at each sample point, yielding a total
volume of approximately 4 gallons. The solids were composited in
a 5-gallon steel bucket.
To collect the drilling mud sample, a clean, 1-gallon glass jar
was dipped into the eastern mud circulation pit, shown on the
right in Photo 9. This was a grab sample rather than a composite
sample.
C-420
-------
The pH of both the reserve pit sludge sample and the drilling mud
sample was measured onsite after sampling was completed. The pH
was 7 for both samples.
C-421
-------
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-423
-------
C-424
-------
n
Photos t,2,3. Northerly view of drill site
to
Ul
-------
.-•^"^T..~i •:\..l'^-.:„-*,i;^'%-"
Photos 4.5. North end of reserve pit
Photo 6. Southwesterly view of reserve pit
C-426
-------
Photo 7. Southerly view of mud circulation pits and
*•• connecting drainage ditches
10
-j.
Photo 9. Northerly view of connection
between mud circulation pits
Photo 8. Southwesterly view of mud circulation pits
with settling pit In foreground
-------
Photo 10. SettlIng pit
O
I
*>.
to
00
Photo 11. Northeasterly view across drill site
-------
Photo 13. Surface of sludge In. reserve pit
Photo 14. Surface of liquid In circulation pit
-------
0430
-------
ATTACHMENT B: PERMITS
C-431
-------
C-432
-------
COMMONWEALTH OF KENTUCKY
DEPARTMENT OF MINES AND MINERALS P.O. Box 690, Lexington, Kentucky 40586
DIVISION OF OIL AND GAS (606)257-3812
AUTHORITY TO DRILL, DEEPEN, OR REOPEN A WELL
Fee Account No: 786-94
Samples Required:
Type of Bond:
Elevation: 4O9.5O
Proposed Total Depth @ 2535
Permit No: 73198
Datelssued: 28-Jul-198A
Formation: ST GENEVIEVE LS
County: HENDERSON
Deepest Fresh Water @ 35O
Quadrangle: SPOTTSVILLE
This is the authority under the 1960 Oil and Gas Conservation Act. effective June 15, 1960, and the Rules
and Regulations of this Division, for
MAVERICK PROD* INC
RT 3 BOX 238-A
HENDERSON KY 4242O
to drill a well on the below described premises. Location of well to be 13 P 25
0750 _FS1_ 0200 PEL Said well is number 1
and lessor is GLASSCOr TOMMY
m
This permit expires one year from the date of issuance unless drilling operations have commenced, prior thereto. A
completion report and drillers log and electric log, if run, and plugging affidavit if plugged must be furnished to the Oil
and Gas Division within 90 days of completion of drilling operations, in compliance with the laws of the Commonwealth
of Kentucky. Fresh water protection casing must be cemented to the surface or removed at the completion of the drilling
operation. •
THIS PERMIT MUST BE POSTED AT THE WELL SITE BEFORE DRILLING COMMENCES.
This well is permitted only for the purpose of OIL
CALL THE INSPECTOR AT LEAST ONE DAY IN ADVANCE OF DRILLING COMMENCEMENT AND/OR
PLUGGING. TO OBTAIN PLUGGING INSTRUCTIONS FROM THE INSPECTOR YOU MUST IDENTIFY THE
WELL BY PERMIT NUMBER AND PROVIDE THE WELL LOG FOR THE INSPECTOR.
Inspector JAMES M BRYARS JR
ROUTE 2r BOX 474-D
HENDERSON KY 4242O
Home Phone:
5O2 82A O397
Mobile Phone:
ooo ooo oooo
INSPECTOR'S COPY
-------
C-434
-------
Sampling Report
Investigation of Ecus Corporation's
Gamblin Lease Production Facility
Hopkins County, Kentucky
August 22, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a computerized list of 2,454 Illinois Basin production sites
developed by the Madisonville Office of Water, and the Department
of Mines and Minerals, at the request of EPA. The list was
transmitted via overnight mail to the EPA contractor on August
18, 1986. Randomization and selection took place immediately.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Mines and Minerals listed the possible sample
sites by registration number, by status, by operator, by
lease/field name, by type of well, by production rates, and by
discharge type. The EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was Ecus Corporation's Gamblin
Lease Production Facility in Hopkins County, Kentucky. A second
site, the J/H Oil Company's Bettie Moss Heirs Moss Road facility,
was selected as a back-up sampling location in the event the
primary site was inaccessible or inappropriate.
Site Location
The Ecus Gamblin Lease production facility is located
approximately 2 miles west of Earlington, KY via County Road
1337, and 1 mile south of County Road 1337. Figure 1 is a map
indicating the production facility site. The full name and
mailing address for Ecus Corporation is:
Ecus Corporation
212 Main Street
Mt. Vernon, Indiana
C-435
-------
Figure 1. Location of Ecus Corporation's Gamblin Lease Production
Facility, Hopkins County, Kentucky
C-436
-------
Main Office Contact: Lloyd Quinn
Ph: 812-838-4819
Attendees
Sampling at the Gamblin Lease production site was performed by
CENTEC Corporation personnel on August 22, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (Sample Team):
State Representatives:
Operator Representative:
American Petroleum Institute
Representatives:
Jim Kourmadas/ Technician
Jamie Mclntyre, Team Leader
Joe Lander, Inspection
Supervisor, Department of
Mines and Minerals, Oil and
Gas Division
George Bradel, Environmental
Engineer Chief, Natural
Resources and Environmental
Protection Cabinet
Kenneth Paul, Production
Superintendent
George Holliday, Contracted
Observer
Alan Willson, Contracted Sample
Team Member
Kyle Hodges, Contracted Sample
Team Member
Site Description
The Gamblin Lease production facility is located in a rural,
piedmont area. The climate at this site location is net
precipitation. The soil is described as clay. Wells serviced by
this facility are completed in the Jackson Sand formation of the
Illinois basin.
The depth to groundwater in the area is between 40 and 100 feet.
The nearest surface water is a creek located 300 feet from the
site. The nearest drinking water wells are between 1/2 and
1 mile from the site.
The site consists of two oil stock tanks, one brine tank, and one
free water knockout, all shown in Photo 1 (Attachment A). Figure
2 is an approximate schematic diagram of the facility, indicating
the directions in which photos were taken.
The brine tank and the free water knockout are cleaned twice per
year. The stock tanks are emptied once per year. Oil is
separated from the resulting tank bottoms and sold. The final
C-437
-------
\
N
Figure 2. Schematic Diagram of Production Facility
C-438
-------
disposition of the tank bottoms was not specified by the
operator.
At the time of sampling, there were three producing oil wells
being serviced by this facility. These were Gamblin Well Nos.
2, 4, and 5. The location of these wells is shown in Figure 3.
The average depth of these wells was 1,835 feet. They each
produced less than 10 barrels of oil per day. At the time of
sampling, each well produced the following amounts of water:
Well No. 2 produced 10 bbls/day, Well No. 4 produced 15 bbls/day,
and Well No. 5 produced 25 bbls/day. The produced water from
these wells is reinjected into three injection wells to enhance
production on the Gamblin lease.
Chemical treatment of the wells includes the following products:
o Nalco Chemical #4910 (Visco Corrosion
Inhibitor), average usage 3 gallons per week.
o Nalco Chemical #3930 (Visco Corrosion
Inhibitor), average usage 15 gallons per
month.
o Nalco Chemical #1153 (Visco Biocide), average
usage 18 gallons per month, put into brine
tank.
Photo 11 shows the storage area for chemicals used onsite.
Disposal Practices
The produced water from wells at the Ecus Corp. Gamblin lease is
reinjected to enhance production in the area. Photos 5, 6, and 7
show the meters and filters for the three injection wells,
located in a pump shed northeast of the tank battery.
Permits
The operator states that "the wells in this water flood are being
operated by Authorization of Underground Injection by Rule."
Therefore, no copies of permits specific to the operation of the
production facility were available to the sample team at the time
of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
C-439
-------
\ A.C Gomblin
' MULLENAX a SHARP
I
•m«>M*vT
WWfOSCO WATCMFLOOO PATTERN
SUGAR CREEK FIELD ' '
• MOMIN8 COUNTY. KCNTUCKY .
MAkl • !*• «4«'
OATt
OATt
MEVIKDtr
DATE
OATt
JAMES A LEWIS
ENGINEERING
INC.
Figure 3. Location of Wells Serviced by Ecus Corporation's
Gamblin Lease Production Facility
C-440
-------
Sample Point Locations
One fluid composite sample was collected from a sample port in
the brine tank shown in Photo 9. Figure 2 indicates the sample
point from which the fluid sample was composited.
In addition to the produced water sample, a tank bottoms sample
was obtained from the brine tank.
Sampling Methods and Equipment
The fluid sample was collected through a pipe located approxi-
mately 8 inches from the bottom of the brine tank. Photos 8 and
9 show the sample point. The sample was collected in a 5-gallon
carboy.
The tank bottoms sample was collected by dropping the dredge
through an opening in the top of the brine tank. The solids
contained a considerable amount of oil. Conditions on the top of
the tank were hot and slippery, and eventually became too
dangerous to continue sampling. The dredge brought up very
little sample with each drop into the tank, so the total volume
of solids collected was approximately 2 gallons.
Tests for the pH and free chlorine content of the fluid sample
were conducted onsite after sampling was completed. The pH of
the fluid sample was 7, and its free chlorine content was less
than 0.2 ppm (i.e., none detected). The pH of the tank bottom
sample was also 7.
C-441
-------
C-442
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-443
-------
C-444
-------
o
I
ut
Photo 1. Westerly view of production tankage
Photos 2.3. Westerly view of production tankage
-------
0 Photo 4. Brine flow Hne exlt.ng
Photo 5. Two sides of pomp
well heads
house wall.; showing Injection
„„*„ -, MtTTTnn three" U lect Ion wells. Inside
-------
O Photo 8. Liquid sample point at brine tank
Photo 9. Liquid sample point at brine tank
^:.C. .. -. .-^ ' —"•"•~^ • -'iir*-^^ •' -l-
Photo 10. Sampler preparing to take tank bottoms
sample from brine tank
Photo 11. Treatment chemical drums at production site
-------
C-448
-------
ATTACHMENT B: PERMITS
C-449
-------
n
i
iU
en
o
-------
No permit specific to the operation
of this site is available.
C-451
-------
C-452
-------
LOUISIANNA
C-453
-------
C-454
-------
Sampling Report
Investigation of
FMP Operating Company's S/L 195 No. 2 Oil Well
Plaquemines Parish, Louisiana
June 14, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Gulf Coast Salt Dome Basin drill sites (at or near
completion) developed by the Louisiana Department of Natural
Resources Office of Conservation for EPA. The list was
transmitted via telephone to the EPA contractor on June 10,
1986. Site selection took place during the telephone
conversation.
Louisiana state officials preferred to list the possible sample
sites by location (rather than by operator). The EPA contractor
had no interest in the manner the particular sites were listed
(by site name, location, operator, permit number, API number,
etc.) as long as the site could be identified in detail upon
selection. Thus, the EPA contractor had minimal information
which kept to a minimum the amount of bias. No other information
was known about the sites on the list at the time of selection.
Detailed information was obtained only after selection of primary
and back-up sites. The list consisted of six coastal drilling
sites:
1. St. Bernard
2. Cameron
3. Quarantine Bay
4. Lake Washington
5. St. Mary
6. Cameron
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
Quarantine Bay was selected as the primary sample site. St. Mary
was selected as a back-up site should sampling at Quarantine Bay
prove inaccessible or inappropriate.
Further inquiry indicated that the Quarantine Bay site was being
operated by FMP Operating Company at their S/L 195 No. 2 Oil Well
in Plaquemines Parish, Louisiana. Their status was described as
being very near completion during the desired sample time frame.
Plans were made for sampling to be conducted June 14, 1986. The
back-up site was not required.
C-455
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Site Location
The FMP Operating Company's S/L 195 No. 2 oil well is located
approximately 2 miles north of Buras, LA, in Quarantine Bay.
Figure 1 is a map indicating the well site. Figure 2 is a
drawing indicating the exact surveyed locations of the surface
and bottom hole. The full name and mailing address for FMP
Operating Co. is:
Freeport-McMoRan and Partners (FMP) Operating Co.
A Limited Partnership
McMoRan Oil and Gas Co., Managing General Partner
McMoRan Exploration Co., A Division of McMoRan Oil and
Gas Co.
P.O. Box 60009
New Orleans, LA 70160
Main Office Ph.: 504-582-4000
Main Office Contact: Doug Vrooman, Chief Engineer
Ph: 504-582-4662
Attendees
Sampling at the FMP Operating Co. S/L 195 No. 2 well was
performed by CENTEC Corporation personnel on June 14, 1986.
Following is a list of people present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representative:
State Representative:
Operator Representative:
Drilling Contractor
Representative:
Bill Lane, Technician
Jamie Mclntyre, Team Leader
Kerri Kennedy, Project
Manager
Susan de Nagy, Office of Water,
Project Officer
Shile McCarty, Conservation
Enforcement Agent, Dept. of
Natural Resources, Office
of Conservation
Gavin Barefield, Drilling
Foreman
John Hall, Rig Supervisor
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Allan Wilson, Contracted Sample
Team Member
C-456
-------
- ^tlpPfpS%=
VT TOMCAT!
.ATlTUM M* LC
Figure 1. Location of FMP's S/L 195 #2 Well, Plaquemines
Parish, Louisiana
C-457
-------
UJ
CO
CO
LJ
CO
30
* I «
19
54
STATE OF LOUISIANA
PEL- L' '"
INC. LEASE**
3 K5S
56
s.c. a «^
STftlCA"
-•' —r ~r
2 ..-.--.-.- - ••T-^'yj- •;
I i:
v /. :._:..';'cr.u.7 ^/
\. "*» —'.'• ^X
HE8. MO. 4348
CH t C K F O BV a^^^^^^^^1""^ ftJAB^ * •» K. "^^^^^^^^^•^^^•^^"•IMI^™^^ ^^"™*™^'-fc^'illl*ll^^^^""«
HOOMA.^.^^^
A - (498
Figure 2. Survey
(size of
C-458
-------
The drilling contractor for this well was Atlantic Pacific Marine
Corporation (AMPC). A copy of a vendor list, provided by FMP
Operating Co., is located in Attachment C.
Site Description
The S/L 195 No. 2 well is located in a rural, coastal area. The
climate at this site location is net precipitation. At the time
of sampling, the site consisted of the APMC Drilling Rig No. 12,
a cargo barge, and a drilling waste barge moored to the east side
of the rig. Figure 3 is a view of the west side of the rig, and
Figure 4 is a plan view of the main deck. Both these figures
were provided by FMP Operating Co.
The site is located in an oyster bed area within Quarantine Bay,
and is therefore accessible only by boat, or as indicated in
Figure 3, by helicopter. Photo 6 was taken from a boat that was
leaving the drilling site after sampling was completed. Water
depth at the site is 5 to 8 feet.
This site was a developmental oil drilling site. The well was
planned to be completed at 13,850 feet, and its depth the day of
sampling was 13,827 feet. Drilling began April 13, 1986 and was
estimated to be completed by June 15, 1986.
Drilling was accomplished with three fresh water base muds.
These are summarized in the table below:
Mud Type Depth Range (ft)
Spud Mud 0 - 6,000
Lignosulfonate 6,000 - 12,332
Lime 12,332 - 15,021
The change from spud mud to lignosulfonate mud was gradual. When
drilling reached 12,332 feet, approximately 1,516 barrels of
ligno-sulfonate mud were taken to a Francis Drilling Fluids, LTD
mud storage facility, and replaced with approximately 1,592
barrels of lime mud. The address of Francis Drilling Fluids
follows:
Francis Drilling Fluids, LTD
PO Box 1694
Crowley, LA 70527
(318) 783-8685
The lime mud was used when a region of abnormal pressure
containing C02 was reached. It was explained that lime muds
resist thickening in the presence of C02, and that a higher
weight mud is necessary in abnormally high pressure. The lime
mud in use at the time of sampling had been measured to have a
weight of 14.7 pounds per gallon. Copies of mud reports for each
C-459
-------
H-
•X!
C
(D
u>
(D
Ul
ri-
cn
H-
a
ro
H-
CD
3
-2
70
-------
i
•u
a\
Figure 4. Overhead View of Drilling Ria
-------
mud type/ provided by the drilling fluid contractor, IMCO, are
located in Attachment D.
Drilling took longer than expected because a pipe broke at 11/600
feet. It was originally estimated that drilling would take about
40 days. The broken pipe put the drilling schedule three weeks
behind, since it was necessary to drill a new hole. This was
accomplished by partially backing up the hole and sidetracking
around the original hole.
Tanks storing diesel onsite contained 19,320 gallons at the time
of sampling. An exact amount of waste motor oil to be generated
by completion date could not be given at the time.
The barge containing drilling wastes to be sampled by the CENTEC
team served as temporary storage of fresh water, deck drainage,
and cuttings with residual drilling mud that left the mud
circulation system via shale shaker, desilter, and desander.
Figure 5 illustrates the position of the barge in relation to the
drilling rig. The barge was partitioned into four quadrants of
equal size. The quadrants contained liquid and sludge waste in
various amounts, received via pipe from the mud circulation
system located on the main deck of the rig. Photo 2 shows the
CENTEC sample team taking a core sample from the southeast
quadrant of the barge. This photo also shows the shale shaker
and cuttings line located on the overhead platform behind the
yellow railing.
Disposal Practices
Newpark Waste Treatment Systems, Inc. was the contractor hired to
receive and process the drilling waste barges as they were filled
and brought to the nearest treatment facility. Price lists for
the waste handling services provided by Newpark are located in
Attachment E.
The drilling waste that was in the barge at the time of sampling
was the fourth barge-load to be filled since drilling began April
13, 1986. The first three barges were received at the Newpark
facility on April 17, 26, and May 15, 1986, each holding volumes
of 1,610, 1,369, and 1,366 barrels, respectively.
Two barges were kept in service so that as one barge was being
emptied at the treatment facility the other was being filled at
the rig.
Permits
Copies of construction and drilling permits secured by FMP
Operating Co. are located in Attachment B. It should be noted
that the Pel-Tex Oil Company, Inc., appearing on the construction
permit as the applicant, has been acquired by Freeport-McMoRan
Oil and Gas Co., and therefore does not appear on later
documents.
C-462
-------
N
RI6
" AM PC RIG, NO. 12
Pl_ATTZ*K
• \'?.
4
I
BARGE"
DRILLIN6
BARGE:
BOATS
Figure 5. Schematic of Drilling Waste Barge
C-463
-------
-SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Quarantine Bay site, the samples were defined as the
supernatant and solid contents of the waste material in the
holding barge. Figure 5 indicates the sample points from which
the barge samples were composited. As shown in Photo 2, the
sample points were reached by standing on a 2-foot ledge around
the barge and reaching into the quadrants with the sample
equipment.
In addition to the barge samples, drilling mud samples were
collected from points located before and after the drilled hole.
The first mud sample was taken from the holding tank from which
mud was pumped down hole. The second was taken from the shale
shaker effluent as it reentered the circulation system after
coming back up the hole.
Sampling Methods and Equipment
The first sample to be collected was the sludge composite. To
collect this sample, the barge was measured to identify the
center of each quadrant. The sides of the barge were marked with
tape to facilitate locating center points. The coring device was
used with a 5-foot extension rod attached. The sample was taken
by extending the coring device over the quadrant along one
measured axis as a second person sited the device's distance from
center along the perpendicular axis. When the end of the device
had reached center, the second person signaled the sampler to
insert the device at that point. The device usually went into
the sludge at a 30"-45* angle (Photo 3).
The barge quadrants were sampled in counterclockwise order,
beginning with the southeast section. The first sludge cores
were two-thirds full (about 2/3 quart), but each successive
quadrant was more difficult to sample. By the fourth quadrant,
three glass core sleeves had broken, and the teflon sleeve was
not retaining sludge long enough to get it to the steel bucket.
The difficulties with sampling were attributed to the hard-packed
consistency of the sludge, presumably high in sand content. The
last quadrant was finally sampled using the dredge. The sludge
was composited in a 5-gallon steel bucket.
Next, the barge was sampled for liquid. The thief was used by
threading the gaging tape through a. pipe, attaching the thief to
the end of the tape, and extending the pipe over the quadrant in
C-464
-------
the same manner as the coring device, until the thief was located
over the center point. One sampler lowered the thief into the
liquid, and a second sampler pulled the string allowing the
sample to enter the thief. Photos 4 and 5 show samplers taking
thief samples from the northwest quadrant. A problem was
encountered in the first (southeast) quadrant when it was
discovered there were only 2-3 inches of liquid over the sludge.
To sample this quadrant, a clean 1-quart glass jar was lowered
over the side of the barge and held by hand as it filled. The
liquid from each quadrant was composited in a 5-gallon carboy.
The drilling mud samples were also collected by holding clean
1-quart jars in the streams located prior to the hole and exiting
the shale shaker after the hole. These were grab samples, not
composites.
The pH of the barge samples was measured after sampling was
completed. Both the liquid and the sludge samples had a pH of
10.
The samples were preserved with ice and held overnight prior to
the day of shipment. This was necessary because of time
constraints encountered on the day of sampling.
C-465
-------
C-466
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-467
-------
C-46fi
-------
Photo I. Approaching drilling rig from the west
O
I
ID
Photo 2. Core sampling southeast quadrant of drilling
waste barge
- - f~^s*»
Photo 3. Core sampling southeast quadrant of drilling
waste barge
-------
n
i
•*>.
Photo 4.
Liquid sampling northwest quadrant of barge
Photo 5. Liquid sampling northwest
quadrant
-------
ATTACHMENT B: PERMITS
C-471
-------
C-472
-------
FOMM MO ILK
STATE OF LOUISIANA
OFFICE OF CONSERVATION
ATT
Send To Hev Orleana/12
( '.VEIL RLE COPY (
PERMIT TO DRILL FOR MINERALS
N» Ser*203552 API #1707523380
REPERMIT
iMarch 6, 1986
PERMIT $200.00 I
Multiple Zone Processing
Porish
Operator.
Plaquq"t n**a 038
FJ.U South Quarantine Bay 7563
FMP Operating Company. Ltd Ptn 2071
P. Q. Box 6QQOg
City & stat. ffev Orleans. LA 70160
Well Nam, SL 195 ffO. g
LQgat,on Sec —. T19S, R17B
N Ilr°lt2'53" E 7190.92' fr USC&GS "OSTRICA". PBHL; 2580' N 7803*E
of surf. (Repermt-SerteQing-Eamired. ]_X=2.578.850.00
JPTDJ15.000'
COMMISSIONER
Any and a.3T
Ani}iir«ii -CM' c? J* Coni»'vaiion Otder
< ,-
1^0801
C-473
-------
APPLICATJON FOR CfcWCTlON PEWIT
PLAOUEHJHES PARISH DEPARTMENT OF PEWITS
RICIIPT "a. w- PIRMT No.
BATH Vftm _ PERMIT PKS itnn.nn
ZONING BHTRICTt . PERMIT CLERK!
APPLICANT M-T«JK Oil Company,lnc. Anpggss MOO Intarflrat PUia
PHONE H0i <713) €58-8284 Houston. Ttm 77002
Typt of Construction: Coaaaroial In dm trial * Saiamic,
DESCRIPTION or PROPOSED MORX-
>»n for oil t att • »1nlB«l
LOCATION Of PIOPOSID WORK:
AoprenlMttlv ? n<1«s northtrlv of Bur»s. Louisiana
BASE OP OPERATION:
<1) Location: Pel-Tax Oil Coapany, Inc.
(2) Fhona No. at Location: 1-318-237-1654
(3) Mailing addrata at location: PO Box 891. Scott. La. 70583
(4) A»tnt in chargt at baaa o'f oparation: Pat Angers
PROPERTY OWNER OR LEASE OWNER: State of Louisiana ,_..
(Attach a copy of aatborizatioit froa property owner or Uut
ESTIMATED COST: S a.OOP.000 4
CONTRACTOR: Unknown «t th-it
Addraaa:.
Phona No.
THIS APPLICATION WILL NOT BE CONSIDERED UNLESS ALL QUESTIONS ON
THE APPLICATION AND ANNEX "B" ARE COMPLETED AND A COMPLETE SET
OP PLANS AND SPECIFICATIONS OF THE PROPOSED WORK ARE ATTACHED.
; . THIS OFFICE HUSt BE NOTICED NO LESS THAN* 24 HOURS PRIOR TO.THE*
TIME YOUR EQUIPMENT IS. MOVED TO THE JOB SITE.
y'=* * OWE AGENT ORUe>/ESENTATIVE
-------
ANN!/ *•
*"
(IF MORI IFACI It MII&I9, ATTACH ANOTHtR IHItT OF PA»«)
1. Uit rafter aod typo of «a*ta MviBg equipment to to ueed ia .propoeett
work. (land or vater, fit*, h.p., draft, bucket lisa, ton&|«, been ln(tb)
I • w*n bucket dredge
. U»t a\ab«r nd t7P« of b«r|«i to b
(•!«•. draft, aad type of u»«)
During drilling > 1 » 300 HP tug
2 • 40' x 110 deck btrges
la propoaod works
3. Uit ftiobor »d trp* of work boat* and cufi to bo u«*d ia prepovad work: ,
(aixo. draft, Boriapow«r of aach)
Vc win use 2 - 600 HP tugs to nove rig ind 1 300 HP tug to service H?
4. Drillia$ oparatim: (loeaeioa, dapeh of drilliaf, la&d or water rig)
(•rge rig • Proposed depth • -15,000'
S. Method aod route of eraaaeortiag aquipamt to location:
(if watar route, attach plat ahowiag propoead route in rad)
He will enter from touth it OstHc* locks end u»e channel ecross Quarantine
Bay a* shown on plat.
«. Attach drawtag ehovinj propoead location of rig and accessory buildingt.
oil pits, aod any other related structures, sbowint the distance freos
euch structures to highways , levees, draiaage cattail, buildings, or any
other public iaprovemants .
Please see attached plats
7. If this becoaas a production wall, show method of atorage and traas-
pertation of raw materials.
PUts attached
I. Other information:
SPECiriCATIOKS OR COSOITIOSS OF PERMIT APPROVAL:
•APPROVED /
HATE
ACEIR OR «£WSINTAT:VE
C-475
Or—.
-------
C-476
-------
ATTACHMENT C: VENDOR LIST
C-477
-------
C-478
-------
FMP Operating Company,
a Limited Partnership
MEC Division
S/L 195 12
Plaquemines Pariah, Louialana
T19S R17E
AFE * 12442
VENDOR LIST
1. DRILLING CONTRACTOR - Atlantic Pacific Marine - Houma - (504) 868-5330
2. BITS - Hughes - Houma - (504) 872-0414
" Security - Venice - (504) 534-2327
- Smith - Belle Chaaae - (504) 392-2487
- Reed - Harvey - (504) 394-1259
3. CASING CREWS - International Hammers - Houma - (504) 872-6892
4. CEMENT & CEMENT'G SERVICE - Halliburton - Venice - (504) 534-2386
5. CENTRIFUGE - Brandt - Houma - (504) 876-7112
6. CHOKE - Drilco - Houma - (504) 868-6510
7. DIRECTIONAL DRILLING - Helmer - Gretna - (504) 524-9769
8. DRILLING JARS - Dailey Oil Tool - Houaa - (504) 873-7788
9. FISHING SERVICES - Tri-State - Houma - (504) 876-1097
10. FLOAT EQUIPMENT - Davis Lynch - Houma - (504) 868-4510
11. HEVI-WATE - Colony Rentals - Gretna - (504) 524-9769
12. LOGGING - Schlumberger - Lafayette - (318) 261-8104
13. MUD CLEANER - Brandt - Provided with Rig
14. MUD SERVICES - IMCO - Venice - (504) 368-2622
15. MULTI-SHOT - Sperry Sun - Harvey - (504) 393-9810
16. RENTAL EQUIPMENT - Patterson Rentals - Venice - (504) 534-2627
17. STABILIZERS - LOR - Lafayette - (318) 232-4245 (17j)
- Helmer - Gretna - (504) 524-9769 (12t & 8J)
18. SURVEYOR - Morris Hebert - Houma - (504) 879-2731
19. SUPPLIES - Continental Emseo - Venice - (504) 534-2389
20. TUGS & BARGES - C-Craft - LaRoae - (50A) 392-7980
21. WELL HEADS - Cameron - Harvey - (504) 366-4528
22. WELL HEAD PREHEATING - Heat Treating Int'l - Gretna - (504) 363-0550
-------
C-480
-------
ATTACHMENT D: MUD REPORTS
C-481
-------
C-482
-------
IMCO Services g
A Halliburton Company
MM N. Conn* Dr. PO. So< TWOS
HouXw, TX 77327 A/C 713MM300
DRILLING MUD REPORT NO.
COUNTY0RARISH OR OFFSHORE STATE/PROVINCE
OPERATOR
REPORT FOR
SECTION. TOWNSHIP. RANGE
WELL NAME AND NO.
OR BLOCK NO..
DRILLING ASSEMBLY
CASINO
MUDVOLUME(BBL)
CIRCULATION DATA
BIT SIZE
TYPE
JET SIZE
iURFACE
HOLE
PITS
PUMP SIZE
IN.
ANNULAR VEL (ft/mln)
DRILL PIPE
SIZE
TYPE
LENGTH
INTERMEDIATE
TOTAL CIRCULATING VOLUME
SVL
GE WEI
PUMP MAKE, MODEL
ASSUMED
CIRCULATION
PRESSURE (BSD
DRILL PIPE
TYPE
LENGTH
INTERMEDIATE
ln.» It.
IN STORAGE WEIGHT
bbV»tk
MWtnln
BOTTOMS
)RILL COLLAR SIZE
LENGTH
PRODUCTION OR LINER
m. • n.
MUD TYPE
JLJl
TOTAL CIRC
o*l/min
•mpto From
im« Stmpte Taken
owlln* Tamp«ratu(« (*F)
l/(PPO)
MUD PROPERTIES
MUD PROPERTY SPECIFICATIONS
U F.L. H/PIT
/Kg
D F.L. D PIT
WEIGHT
VISCOSITY
FILTRATE
RECOMMENDED TOUR TREATMENT
IMCO
light
C id Point (lb/100 ftt
I Strength (lb/100 ft1) 10 »«CHO mm
/ /j
rats API (cm«/30 mln)
HTHP Filtrste (Ctrl'/So mln) 9
• Thickness (32nd In. API/NTHP)
da Content (•/, By Von 11 calculated I/retort
.REMARKS
ild Content (% by Vol) OllftVatef
J Content (% by Vol)
lylens Blue Capselty
H Strtp f/Meter
Unity Mud |P»>
Inlty Filtrate (Pf/Mf)
de(mg/L)
SOLIQS EQUIPMENT RUN LAST 24 HOURS (Please Fill In)
«MA*CO .1
SHAKER «*
MUO Cl EANER
mesh
mesh
CENTRIFUGE
DESANOER _
DESIITER
» 'no
10
<0
HHP.
CRITICAL VfLOCITY
DP _____ DC
6*3363
EQUIVALENT CIRC DENSITY
Csfl.
Shoe TO
PHONE
WAREHOUSE PHONE DAILY COST
CUMULATIVE COST
MOR
1 REV. 4-S4
IN US.A
t-M SOU
NOTICE ANY OPINION ANOOR RECOMMENDATION. EXPRESSED ORALLV OR WRITTEN HEREIN. HAS BEEN PREPARED CAflEFULLV AND
MAY BE US«O IF TH6 USHt SO B.ECTS YOHei». NO RCPRCSENTATION OR WARRANTY IS MADE BY OURSELVES OR OUR ACEN T S AS TO
ITS CORRECTNESS OB OOMPUETENES& AMD NO LIAONJTY IS ASSUMED FOR ANY DAMAGES RESULTING FROM THE \Kf n* uuc
-------
IMCQ Services
«9»*ongiMAU.ieo*T>'»C<>'n« Ttmo«r»tu'» (f)
M. O«T
WEIGHT
VISCOSITY
FILTRATE
RECOMMENDED TOUR TREATMENT
Otpih (ft)
Q IMCO BAR
Dlib/euft) O$ogr
Q IMCO GEL
Funnel Vucotity (s*c/qt) API 9
D IMCO BR1NEGEL
Pl»ttie Vitcoiity ep 9
Q IMCORO-111
wiri Point (lb/100ft2)
D IMCOVC-10
Get Strtnqth Ob/100 ft2) 10 Me/10 min
D »MCO THIN
Filtrate API (cm3/30 mm)
CAUSTIC
API HTHP Filtrate (cm3/30 mm) 9
C»kA Thickneis (32nd in. API/HTHP)
D
Solids Content M by Vol) D cileulmed Qtetort
REMARKS
Liquid Content {% by Vol) Oil/Watef
Sand Content (% by Vol)
Metnylene Blue Capacity
ygigg
pH O Strip
Alkalinity Mud n Img/L)
CRITICAL VELOCITY
DP DC
EQUIVALENT CIRC DENSITY
CLOSING
IMVtNTOHY
^ l4»
m \w \wr
&&
^ HI-SP SHAKER
3 MUD CLEANER
0DESANOER
^DESILTEH
D CENTRIFU
C OEGASSth
*7yV
PHONE
WAREHOUSE PHONE
DAILY COST
CUMULATIVE COST
NOTICE- ANY OPINION AND'OR KECOMMENOATION. EXPRESSED ORALLY OR WRITTEN HEREIN. MM HEN PREl-AfUn » AHr.«ui- v
MAY BE USED IP THE USCR SO ELECTS. HOWEVER. NO REPRESENTATION Ol» (WARRANTY is MADE »Y OJRSEI.VES an (»u'< A. ,f \Ts
ITS CORRECTNESS OR COMPLETENESS. A>0 I»O LIAeiLlTY IS ASSUMED POP ANY lAMAGf 5 MEilll 'IN(i PROM THP USI- 1)1 SA-f
-------
DRILLING MUD REPORT NO.
DEPTH
PR ESENTjlv l
COUNTyJWUlSH OR OFPSHORE STATE/PHJ»VI\CF
MUD PROPERTIES
MUD PROPERTY SPECIFICATIONS
implt From
Q PH.
rPIT
a Swnplt Taken
>wlin« T«mp«r«(ur*
Q P.C. D PIT
WEIGHT
VISCOSITY
FILTRATE
RECOMMENDED TOUR TREATMENT
pth (ft)
O
BAR
ijht elppg} Ddb/cuft) Otpgr
D IMCO GEL
l Viscosity (s«c/qt> API 9
D IMCOBRINEGEL
Hie VJSCQSiCV CO 9
Q IMCORD-111
Id Paint (Ib/100ft2)
D IMCO VC-10
Strength lib/100 ft2) 10 »c/10 min
D IMCO THIN
rat* API (em3/30 mm)
Q CAUSTIC
HTHP Pil|r»t« (an3/30 min) 9
a
l Thicknws (32nd in. API/HTHP)
it Content (% by Voll Q calculated {/retort
REMARKS
id Content (% by Voll Oil/W»t»r
I Content 1% by Vol)
ylene Blue Capacity
3 Strip S^eter 9
inity Mud (Pm)
inity Filtrate (Pf/Mf)
late Alkalinity Filtrate IP]/Pz)
de (mq/L)
Hardness as Calcium (mg/L)
BIT HYDRAULICS
HHP
HHPB
.HSIB
CRITICAL VELOCITY
DP DC
EQUIVALENT CIRC DENSITY
SSS
37S
H HI-SP SHAKER (HOESANOER n CENTRIFUGE
WUD CLEANER 5/DESILTER G DEGASSEH
ATOR
HEV. 0411 JOM
IN II.5.A
PHONE
WAREHOUSE PHONE
DAILY COST
CUMULATIVE COST
NOTICE ANV OPINION ANt»OR RICOMMINDATION. fXPRESSEO ORALLY OR WRITTEN HEREIN, HAS SEEN ffU'f.flU) CAHrni. , v AM.
MAY |( USED IP THE USER SO ELECTS HOWEVER, NO REPRSSENTATIO11; OR WAORANTV « MADE BV OUflSRI vrj JH .).i^< •.;><.'' A. i.
ITS CORRECTNiSS OR COMPLETENESS, ANO NO LIABILITY IS ASSUMED 'OR AMY fJAMAOf S RESUI TIMR rnOM Tt'E ur.F Ol
-------
C-486
-------
ATTACHMENT E: PRICE LISTS FOR
WASTE HANDLING FACILITY
C-487
-------
C-488
-------
NEWPARK WASTE TREATMENT SYSTEMS, INC
GULF COAST PRICE LIST
EFFECTIVE JANUARY 1,1986
PRICE LIST FOR DISPOSAL OF NON-HAZARDOUS OILFIELD WASTE AND SERVICES AT NEWPARICS
GULF COAST FACILITIES. ALL PRICES ARE F. O. B. CLOSEST PROCESSING FACILITY.
NON-HAZARDOUS OILFIELD WASTE PER BARREL
WATER BASE MUD WASTE (A) (1) $ 7.50
WATER BASE CUTTINGS (2)
OIL BASE MUD WASTE (B) (1) 9.75
OIL BASE CUTTINGS (2)
PRODUCTION PIT AND TANK SLUDGES 10.75
PRODUCED SAND AND SOLIDS 10.75
PRODUCED SAND AND SOLIDS IN 55 GALLON DRUM 55.00/DR
PRODUCED FORMATION FRESH WATER
AND RING LEVEE WATER 5.00
(A) WATER BASE MUD WASTE-WASH WATER $ 5.00
(B) OIL BASE MUD WASTE-WASH WATER 6.00
(1) ALL MUD WASTE PRICES ARE BASED ON £ 30% SOLIDS BY
VOLUME. WATER BASE MUD WASTE CONTAMINATED WITH
GREATER THAN 10% OIL BY VOLUME WILL BE CHARGED AT
OIL BASE MUD WASTE PRICES.
(2) CUTTINGS AND NON-PUMPABLE MUD WASTE WILL BE
PRICED ON SOLIDS CONTENT, PRICES AVAILABLE UPON
APPLICATION.
EQUIPMENT AND SERVICES RATES PER HOUR
SUPERVISOR ' (3)
OPERATOR
HELPER
PUMPING EQUIPMENT
CRANE WITH OPERATOR (4)
CRANE WITH OPERATOR CLAMBUCKET OPERATION
BOBCAT WITH OPERATOR
AIR COMPRESSOR - (300 CFM) (FUEL INCLUDED)
DETERGENT- DEGREASER
(3) A SUPERVISOR CHARGE WILL APPLY TO ALL RECEIVING
AND CLEANING ACTIVITIES AT NEWPARK DOCKS.
(4) NIGHTTIME AND WEEKEND CALL OUT RATES WILL BE CHARGED AT SOME FACILITIES.
BOAT TANK AND BARGE CLEANING WILL BE CHARGED AT PREVAILING RATES PLUS 20%.
TERMS: NET 30 DAYS FROM RECEIPT OF MATERIAL
TAXES: WILL BE ADDED WHEN APPLICABLE
$ 25.00
20.00
15.00
60.00
125.00
150.00
70.00
175.00/DAY
5.00/GALLON
C-489
-------
NEWPARK WASTE TREATMENT SYSTEMS, INC
SOLIDS ADJUSTMENT CHART
FOR SOLIDS ABOVE 30%
THIS CHART SHOULD BE USED WHEN ADJUSTING PRICE FOR MUDS OR CUTTINGS WITH
SOLIDS CONTENT ABOVE 30% BY VOLUME.
EXAMPLE: OIL BASE MUD WASTE, 40% SOLIDS
CALCULATION: PRICE ADJUSTMENT
1$9.00 x 1.327) X ACTUAL VOLUME
$11.94 X ACTUAL VOLUME
31%
32%
33%
34%
35%
36%
37%
38%
39%
40%
41%
42%
43%
44%
45%
46%
47%
48%
49%
50%
1.033
1.066
1.099
1.132
1.165
1.198
1.231
1.264
1.297
1.327
1.360
1.393
1.426
1.459
1.492
1.525
1.558
1.591
1.624
1.657
51%
52%
53%
54%
55%
56%
57%
58%
59%
60%
61%
62%
63%
64%
65%
66%
67%
68%
69%
70%
1.690
1.723
1.756
1.789
1.822
1.855
1.897
1.932
1.966
2.00
2.033
2.066
2.099
2.132
2.165
2.198
2.231
2.264
2.297
2.327
' 1 /1 /85 OIL BASE MUD WASTE PRICE PER BARREL
C-490
-------
NEWPARK WASTE TREATMENT SYSTEMS, INC
SCHEDULE OF FREIGHT CHARGES
EFFECTIVE JANUARY 1,1986
THE FOLLOWING SCHEDULE OF FREIGHT CHARGES APPLIES TO WASTE MATERIAL
RECEIVED AT ONE OF NEWPARICS COASTAL COLLECTION POINTS AND
TRANSPORTED BY BARGE TO THE COMPANY'S NEAREST TREATMENT FACILITY.
RECEIVING POINT
NEAREST TREATMENT
FACILITY
FREIGHT CHARGES TO THE
NEAREST TREATMENT FACILITY
VENICE. LA
MORGAN CITY, LA
INTRACOASTAL, LA
SABINE.TX
GALVESTON, TX
PORT O'CON NOR, TX
INGLESIDE.TX
VENICE, LA
VENICE, LA
VENICE, LA
INGLESIDE.TX
INGLESIDE, TX
INGLESIDE.TX
INGLESIDE.TX
$ 0/BBL
.95/BBL
1.50/BBL
.95/BBL
.75/BBL
.50/BBL
0/BBL
C-491
-------
C-492
-------
Sampling Report
Investigation of Sun Exploration and Production Company's
Sweetbay and Bateman Lake Tank Battery No. 2
St. Mary Parish, Louisiana
June 16, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active coastal Gulf Coast Salt Dome Basin production
sites developed by the Louisiana Department of Natural Resources
Office of Conservation at the request of EPA. The list was
transmitted via telephone to the EPA contractor on June 13,
1986. Randomization and site selection took place during the
telephone conversation.
Louisiana state officials listed the possible sample sites by
location, operator, and tank battery. The EPA contractor had no
interest in the manner the particular sites were listed (by site
name, location, operator, permit number, API number, etc.) as
long as the site could be identified in detail upon selection.
Thus, the EPA contractor had minimal information which kept to a
minimum the amount of bias. No other information was known about
the sites on the list at the time of selection. Detailed
information was obtained only after selection of primary and
back-up sites. The list consisted of ten coastal production
sites:
1. Sun - Bateman Lake
2. Chevron - Romere Pass
3. Texaco - Lake Washington, 212A
4. Chevron - Quarantine Bay, Tank Battery #2
5. Shell - West Empire, Lease 3603
6. Texaco - Venice Buras Levee Dist. Tank Battery
7. Texaco - Venice, C. L. Johnson Tank Battery
8. Shell - E. Mississippi River
9. Texaco - Lake Washington Tank Battery SL 1464
10. Chevron - W. Delta Block 83
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 1 on the above list
(Sun - Bateman Lake). No. 7 on the above list (Texaco - Venice,
C. L. Johnson Tank Battery) was selected as a back-up site in the
event the primary site was inaccessible or inappropriate.
Further inquiry identified the primary sample site as Sun
Exploration and Production Company's Sweetbay and Bateman Lake
C-493
-------
Tank Battery No. 2 in St. Mary Parish, Louisiana. No problems
were encountered in arranging sampling for June 16, 1986. The
back-up site was not required.
Site Location
The Sun E&P Sweetbay and Bateman Lake Tank Battery No. 2
production facility is located approximately 2 miles south of
Morgan City, LA via the Atchafalaya River in St. Mary Parish, and
approximately 31 miles southwest of the Mississippi River.
Figure 1 is a map indicating the production facility site. The
full name and mailing address for Sun Exploration and Production
Company is:
Sun Exploration and Production Company
Gulf Coast District
P.O. Box 31570-C
Lafayette, LA 70503
Main Office Ph.: 318-988-4870
Main Office Contact: Richard Spell, District
Environmental Coordinator
Attendees
Sampling at the Sun E&P Sweetbay and Bateman Lake Tank Battery
No. 2 production site was performed by CENTEC Corporation
personnel on June 16, 1986. Following is a list of people
present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representatives:
State Representative:
Kerri Kennedy, Project
Manager
Jamie Mclntyre, Sample Team
Leader
Bill Lane, Technician
Susan de Nagy, Office of Water,
Project Officer
Mitch Dubensky, Office of
Analysis and Evaluation
Richard Montgomery, Aquatic
Biologist, EPA Environmental
Research Laboratory, Gulf
Breeze
Carrol Wascom, Assistant
Director, Injection and
Mining Division, Office
of Conservation, Department
of Natural Resources
C-494
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I SUN EXPLORATION AND PRODUCTION CO
Quit Coast District - L«f«y»tt». L/l
Figure 1. Location of Sweetbay and Bateman Lake Tank
Battery #2, St. Mary Parish, Louisiana "
C-495
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Operator Representatives: Richard Spell, District
Environmental Coordinator
Clarence Toupe, Production
Engineer
Melvin Childers, Lease Operator
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Allan Wilson, Contracted Sample
Team Member
Other Observers: Gary Petrazzuolo, Technical
Resources, Inc.
Lynn Bowler, Technical
Resources, Inc.
Site Description
The Sun E&P production facility is located in a rural coastal
area. The climate at this site location is net precipitation.
The facility sits on a wooden platform constructed over a marsh
(see photos, Attachment A).
The site consists of one gun barrel, two oil stock tanks, one
brine tank, two heater-treaters, and other related process units
(Photos 2, 3, 4). Figure 2 is an approximate schematic diagram
of the facility, indicating the directions in which photos were
taken. Figure 3 is a flow diagram of the production system,
provided by Sun E&P.
The schedules for cleaning tanks on the site are not rigorous,
but are different for each type. The gun barrel is cleaned every
3 to 5 years. The production tanks are cleaned every 3 years,
although the bottoms from these tanks are circulated to a
heater-treater and back to the gun barrel on a daily basis. The
heater-treaters are cleaned every 1 to 2 years, the last
time being 6 months prior to EPA's sampling visit. The brine
tank is skimmed occasionally to remove the oil layer that builds
up, but is seldom cleaned thoroughly. The oil layer had been
skimmed from the brine tank some time within the 30 days prior to
EPA's sampling visit. It was not known when the brine tank had
last been thoroughly cleaned.
The facility treats incoming oil and water by adding an emulsion
breaker and scale inhibitor to the system prior to the gun
barrel. Photos 8 and 9 show the location of a drum containing
"Tretolite" demulsifier. The demulsifier is added at a daily
rate of 1 gallon per 100 barrels of fluid treated. The scale
inhibitor is added at a daily rate of 1/2 gallon per 100 barrels
treated.
C-496
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Figure 3. Flow Diaaram of Tank Battery No. 2
-------
At the time of sampling, there was one producing oil well and two
producing gas wells feeding into Tank Battery No. 2, although one
gas well was temporarily closed. Collectively, these wells
produce daily quantities of 100 barrels of oil, 2 million
standard cubic feet of gas, and 640 barrels of produced water.
Attachment C includes a copy of meter readings from the Lease
Automatic Custody Transfer (LACT) unit for the first half of June
1986, showing a daily production average of 99 barrels of oil.
Also included in Attachment C is another report from the LACT
unit, showing the percentage of oil leaving the facility that is
basic sediment and water (BS and W).
Disposal Practices
As shown in Photos 6 and 7, the produced water is ultimately
disposed of by discharging directly to the surrounding coastal
waters. Samples are taken from the influent and effluent of the
brine tank each month, in accordance with the discharge permit.
Solids from the bottom of the brine tank are vacuumed into a
barge and hauled offsite. However, details of the final
disposition of the solids were not available at the time of
sampling.
Permits
The Sun E&P Co. Sweetbay and Bateman Lake Tank Battery No. 2
processes incoming oil and gas from State Lease No. 1337.
Attachment B contains a copy of a letter from the Louisiana
Department of Environmental Quality informing production
facilities of the need to submit permit applications with regard
to recent changes in State pollution control regulations.
Following the DEQ letter is a copy of Sun's response letter and
one page of the attachments that identify the location and
quantity of Sun's produced water discharges.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Sun E&P site, one fluid composite sample was collected
from the discharge line from a produced water holding tank.
Figure 2 indicates the sample point from which the fluid sample
was composited.
C-499
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Sampling Methods and Equipment
The fluid sample from the tank discharge was collected through a
4-inch-diameter pipe extending from the side of the tank, about 3
feet from the top of the tank (Photo 6). The sample was
collected in a 1-gallon glass bottle held under the flowing
discharge/ then transferred to a 5-gallon carboy. Photo 5 shows
a sampler carrying a filled 1-gallon bottle away from the
discharge point.
The 5-gallon carboy containing the tank discharge sample was
transported offsite to the CENTEC van where it was separated into
appropriate sample bottles.
The pH of the fluid sample was tested after sampling was
completed. The pH of this sample was 7.
C-500
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-501
-------
C-502
-------
Photos 2,3,4. Production tankage
-------
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Photo 5. Liquid sampling
Photo 6. Side view of produbed fluid
tank dIscharge ;
-------
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C-505
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ATTACHMENT B: PERMITS
C-507
-------
C-508
-------
PATRICIA L. NORTON OFFICE OF WATER RESOURCES J. DALE GIVENS
SECRETARY ASSISTANT SECRETARY
APR 211986
Gentlemen:
Re: Notification of EXISTING Oil and Gas Production Facilities
This is to notify you of alternative water discharge permit application
procedures for existing facilities.
The Louisiana Water Pollution Control Regulations, which became
effective November 20, 1985, require that operators of existing
unpermitted discharging facilities submit a complete permit application
for each such facility within 180 days of the effective date of the
regulations. All state permits issued prior to January 1, 1980 shall
expire one year from the effective date of the regulations. State
permits Issued after January 1, 1980 shall expire six years after their
effective date. All applications for permit renewal must be submitted
at least 180 days prior to the expiration date.
We are currently developing a general permit for oil and gas
production facilities. The attached optional permit application form
will serve to satisfy the notification requirements for existing
facilities as outlined in the Louisiana Water Pollution Control
Regualtions. The application package should include a transmittal
letter and the attached application form and certification statement.
0509
NATURAL RESOURCES BUILDING • P.O. BOX 44066 • BATON ROUGE, LOUISIANA 70804 • PHONE (504) 342-6363
-------
Sun Production
Operations Division
GuK Coast District
Sun Exploration and
Production Company
Maw 15 IQflfi 3639 Ambassador Cattery Pi
nay ia, i?ou POBox3i570C
LafayetreLATOSO: 1570
3189884870
Mr. J. Dale Givens, Assistant Secretary
Office of Water Resources
P.O. Box 44091
Baton Rouge, La. 70804
RE: Water Discharge Permit Applications for Existing Facilities
Dear Mr. Givens:
Enclosed are permit applications for the existing discharges
from facilities operated by Sun Exploration and Production Company,
Gulf Coast District, Lafayette, Louisiana. Included in this
application are two gas processing plants, seven discharges of
comingled produced water and deck drainage, three sewage
discharges, seven deck drainage discharges, and eighty-two storm
water discharges, these discharges are detailed on the attached
notification forms.
We did not have enough time to complete the sampling and
analyses of our produced water discharges and receiving waters.
this information will be submitted in about a week.
Very truly yours,
i chard A. Spe11
District Environmental Coordinator
RS/wd
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-------
I
Ui
Qp«r«tor Sun Exploration I Production Co.
Addr«ti P.O. Box 31570C
l«fayi.tte. la. 70503
Fttld Bateman/Sweetbav T.ak« F»rt«li
LOUISIANA KMtTMBIT OP MVIRONMMTAL QUAUTT
orricE or HATER RESOURCES
EXISTING OIL AMD CAS PRODUCTION PACIUTB
HOTiriCAnOH POM
St- - M» ru
PACIUTT
HAKE
LOCATION (1)
UTITUOE
KUMBBR OP PACIUTIES THAT ONll
DISCHARGE STORM HATE* (3)
urns in ic
SEC.
TS
R
TTPB OP DISCHARGE
PROD.
HATER
STORM
HATER
SDUGE
OTHER (SPECIF!)
RECEIflNS
HATER
RECEIVING
HATER
CHLORIDES
(PPT) (2)
PRODUCED
HATER
CHLORIDES
(PIT) (2)
PRODUCED
HATER
TOUIME
(BPD)(2)
8 niles SSW of Moraan Citv
UST EACH PACIUTT WITH HSCBAIICES IN ADDITION TO STORM HATER " '"" " "
Bateman Lake
Battery I
Bateman Lake
Battery II
29*35'
27"
29*35'
57"
91 12'
58.5
91 14'
45"
IS
S/L
1337
ST
3035
17S
17S
IDE
12E
X
X
X
X
B«y°u Shaffe
at the
Atchafalaya
River
Atchafalaya
River
DISCHARGE POINT LOCATIONS IMNTIPIED ON ATTACHED MAP (2) THIS MTA IS ONLT NECESSARY IP PROniC D HATER IS "DISCHARGED
'•"> GIVE GENERAL LOCATION OF FIELD
100
125
DEO-OC-02 LHU
-------
C-512
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ATTACHMENT C: LEASE AUTOMATIC CUSTODY
TRANSFER (LACT) UNIT REPORTS
C-513
-------
C-514
-------
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Batman Uta U.
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Sampling Report
Investigation of Mobil Oil's Bayou Blue Production Facility
Iberville Parish, Louisiana
June 17, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active upland Gulf Coast Salt Dome production sites
developed by the Louisiana Department of Natural Resources Office
of Conservation at the request of EPA. The list was transmitted
via telephone to the EPA contractor on June 11, 1986.
Randomization and site selection took place during the telephone
conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
Louisiana state officials listed the possible sample sites by
operator and specific location. For simplicity of selection, the
list was transmitted using only operator names. The list
consisted of ten upland production sites:
1. Superior Oil
2. Amoco Production
3. Eenova
4. Union - Texas Petroleum
5. Chevron
6. Evergreen Energy
7. Lakeshore Petroleum
8. Republic Mineral Corporation
9. Celeron
10. Shell
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 1 on the above list,
Superior Oil. No. 7 on the above list (Lakeshore Petroleum) was
selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
C-517
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Further inquiry identified the primary sample site as the
Superior Oil Company Bayou Blue site in Iberville Parish. The
production facility was currently operated by Mobil Oil Company.
No problems were encountered in arranging sampling for June 14,
1986. The back-up site was not required.
Site Location
The Mobil Oil Bayou Blue production facility is located
approximately 8 miles south of Grosse Tete, LA via Highways 77
and 386 in Iberville Parish, and approximately 11 miles west of
the Mississippi River. Figure 1 is a map indicating the
production facility site. The full name and mailing address for
Mobil Oil is:
Mobil Oil Exploration and Producing Southeast Inc.
Onshore Division
3861 Ambassador Caffery Parkway
P.O. Box 51108
Lafayette, LA 70505
Main Office Ph.: 318-988-5200
Main Office Contact: James Green, Environmental and
Regulatory Engineer
Ph: 318-988-5691
It should be noted that the Superior Oil Co., named on a sign
appearing in Photo 1, was acquired by Mobil Oil.
Attendees
Sampling at the Mobil Oil Bayou Blue production site was
performed by CENTEC Corporation personnel and EPA personnel on
June 17, 1986. Following is a list of people present at the time
of sampling:
CENTEC Corp.: Kerri Kennedy, Project Manager*
EPA Representatives: William Telliard, Chief, Energy
and Mining Industries Branch,
Industrial Technology
Division, Office of Water*
Susan de Nagy, Office of Water,
Project Officer
Dan Derkics, Chief, Large
Volumes Section
*Indicates sample team member. This site was sampled
concurrently with a drill site in Pointe Coupee Parish, LA where
another CENTEC Corp. team was sampling.
C-518
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BAYOU GOULA
SCO. 37 TIOS RISC
o»
Figure 1. Location of Mobil Oil's Bayou Blue Production
Facility, Iberville Parish, Louisiana
C-519
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State Representative:
Operator Representatives:
American Petroleum
Institute Representative:
Other Observer:
Site Description
Carrol Wascom, Assistant
Director, Injection and
Mining Division, Office
of Conservation, Department
of Natural Resources
James Martin, Environmental and
Regulatory Manager
Ory Persick, Production Foreman
George Holliday, Contracted
Observer
Robert Cooper, Interstate Oil
Compact Commission
The Mobil Oil Bayou Blue production facility is located in a
rural, flatland area. The climate at this site location is net
precipitation. The soil is described as sandy loam.
The depth to the groundwater in the area is between 500 and 600
feet. The nearest surface water is a stream located less than
1/2-mile from the site. There is one potable water well located
on the site.
The site consists of two heater-treaters, one gun barrel, one
free water knock-out, four oil stock tanks, and two brine tanks
(Photo 2). Figure 2 is an approximate schematic diagram of the
facility, indicating the directions in which photos were taken
(Attachment A). Figure 3 is a flow diagram of the production
system, provided by Mobil. With the exception of the stock and
brine tanks, each vessel is cleaned at least once every 12
months. The stock and brine tanks are cleaned only when
necessary.
The facility treats incoming oil and water by adding an emulsion
breaker to the line entering the gunbarrel. This line carries
the water phase effluent from the free water knockout (Figure 3).
At the time of sampling, there were 41 producing oil wells out of
103 drilled in the Bayou Blue Lease, with 12 or more wells being
shut-in. All wells in this field are strippers. During the
month of June 1986, these wells produced total quantities of
24,660 barrels of oil, and 299,211 barrels of produced water.
The producing wells range in depth from 1,300 to 7,000 feet.
Less than 100,000 standard cubic feet of gas were also produced
from the Bayou Blue field at the time of sampling. Photo 4 shows
the dehydrating equipment used to process incoming gas. Most of
the gas produced from the Bayou Blue field is used on site.
C-520
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--*—«•—*—»-—x -~x—x—«
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ISJECTIOM
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BRINE:
TAMKS
STOCK TANKS
FvJKO :
MT;
Figure 2. Schematic Diagram of Production Facility
C-521
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Disposal Practices
As illustrated in Figure 2, the produced water is ultimately
disposed of in two injection wells located onsite. Solids
collected when tanks are cleaned are taken to Reliable Production
Service, Inc., a commercial waste treatment facility where solid
wastes are land farmed, as dictated by state regulations. The
address for Reliable is
Reliable Production Service, Inc.
PO Box 176
Livonia, LA 70755
504-637-2381 or 504-638-8146
Permits
The production facility operates two injection wells. The serial
numbers and names of these wells are SN 063271-Schwing No. 59,
and SN 064731-Schwing No. 62. The issuing authority for
injection well serial numbers is the Louisiana Department of
Natural Resources. No operating permits were available for
copying at the time of sampling.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Bayou Blue site, two fluid samples were collected. One of
the samples was taken from the discharge line of the pump that
feeds the injection wells, and the other sample was taken from
the free water knockout effluent before emulsion breaker is
added. Figures 2 and 3 indicate the sample points from which the
fluid samples were collected.
Sampling Methods and Equipment
The fluid sample from the pump discharge was collected through a
sample port consisting of a tube and stopcock. This sample was
composited in a 5-gallon carboy. The pump house is visible in
Photo 3, at the end of the row of tanks.
The 5-gallon carboy containing the pump discharge sample was
transported offsite to the CENTEC van where it was separated into
appropriate sample bottles.
As shown in Photos 5 and 6, the fluid sample from the free water
knockout was collected through a tube and stopcock that tapped
C-523
-------
the discharge line. This sample was added to the schedule by the
project officer onsite. The sample was collected directly into
sample bottles.
The pH of the sample collected from the pump discharge was
measured after sampling was completed. The pH of this sample
was 7.
C-524
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-525
-------
C-526
-------
tn
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Photo t. Sign in front of skim tank
Photo 2. Northerly view of production site
Photo 3. Northerly view of stock and brine tanks and
pump house
Photo 4. Gas processing equipment
-------
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Photo 6. Liquid sampling at FWKO
Photo 5. FWKO and sample tube In water
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Photo 8. Incoming pipelines
Photo 7. Northeasterly view of gun
barrel (right)
-------
C-530
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ATTACHMENT B: PERMITS
C-531
-------
C-532
-------
No permit specific to the operation
of this site is available.
C-533
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C-534
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Sampling Report
Investigation of Westland Oil Development Corporation's
Joseph Earl Bajoie No. 1 Oil Well
Pointe Coupee Parish, Louisiana
June 17, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of upland drill sites (at or near completion) in the Gulf
Coast Salt Dome Basin developed by the Louisiana Department of
Natural Resources Office of Conservation at the request of EPA.
The list was transmitted via telephone to the EPA contractor on
June 10, 1986. Randomization and site selection were conducted
during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The list used for selection of this site consisted of field names
(each containing an active drill site) for selection purposes.
The field names were assigned numbers as they were transmitted as
shown below:
1. Anse La Butte
2. Eunice
3. Irene
4. Profit Island
5. Perry Point
A random number table was used to select the primary and back-up
sample sites. No. 2 on the above list (Eunice) was selected as
the primary site. In case the primary site was inaccessible or
inappropriate, No. 4 on the above list (Profit .Island) was
selected as the back-up site. On further investigation, the
Eunice site had already completed operations. Wastes had been
injected in to the well annulus for disposal. Thus the back-up
site was sampled.
Further inquiry with the Office of Conservation identified the
back-up site as Westland Oil Development Corporation's Joseph
Earl Bajoie No. 1 Oil Well in Pointe Coupee Parish. Arrangements
were made for sampling be conducted on June 14, 1986.
C-535
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Site Location
The Joseph Earl Bajoie No. 1 oil well is located approximately 1
mile southeast of the intersection of Highways 414 and 415 in
Pointe Coupee Parish/ Louisiana. Figure 1 is a map indicating
the well site. The full name and mailing address for Westland
Oil is:
Westland Oil and Development Corporation
P.O. Box 900
Montgomery, Texas 77536
Main Office Ph.: 409-582-6464
Main Office Contact: H.P. Goodrich
Attendees
Sampling at the Joseph Earl Bajoie No. 1 oil well was performed
by CENTEC Corporation personnel on June 17, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team):
EPA Representatives:
State Representatives:
Operator Representatives
Kerri Kennedy, Project Manager
Jamie Mclntyre, Sample Team
Leader
Bill Lane, Technician
William Telliard, Chief, Energy
and Mining Industries Branch,
Industrial Technology Div.
Office of Water
Susan de Nagy, Office of Water,
Project Officer
Dan Derkics, Section Chief,
Office of Solid Waste
Mitch Dubensky, Office of
Analysis and Evaluation
Rob Franke, Office of Solid
Waste, Region VI
Carrol Wascom, Assistant
Director, Injection and
Mining Division, Office
of Conservation, Department
of Natural Resources
Shile McCarty, Enforcement
Agent, Office of
Conservation, Department of
Natural Resources
Kenny Bland
C-536
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o
Ol
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Drilling Contractor
Representative:
Gary Workman, Drilling Super-
intendent, Land Rigs, Penrod
Drilling Company
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Allan Wilson, Contracted Sample
Team Member
Other Observer:
Site Description
Robert Cooper, Interstate Oil
Compact Commission
Figure 2 is a diagram of the exact surveyed location of the
Joseph Earl Bajoie No. 1 oil well, which is located in a rural,
flatland area. The climate at this site location is net
precipitation. The soil in the area is a layer of rich topsoil
over clay. The depth to groundwater is between 0 and 25 feet,
and the nearest surface water is a creek located northwest of the
site. The nearest drinking water well is approximately 1.5 miles
from the site.
At the time of sampling, the site consisted of the Penrod
Drilling Rig No. 28 and two pits. The entire site and the road
leading to it were covered with a wood plank deck, visible in
Photos 2 and 8. The area surrounding the site was wooded. The
road leading to the site was cut through corn fields. Access to
the road from the highway was blocked by a locked gate. Figure 3
is an approximate schematic diagram of the site location, indi-
cating the directions in which photos were taken (Attachment A) .
This site was a developmental oil drilling site. The well was
drilled to 16,800 feet at the time of sampling. Drilling began
May 5, 1986 and was estimated to be completed by mid-July, 1986.
The following table summarizes the drilling muds used to drill
the well to a total depth of 18,820 feet:
C-538
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-Tu £
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f
76
9963
WV'//-. S «v-»t» «*
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Figure 3. Schematic of Drilling Site
-------
Mud Type Depth (feet)
Spud Mud:
o Native fresh water mud with
bentonite, lime, and sodium
bicarbonate additives 0 - 9,000
o Barite and lignite added 9,000 - 10,500
Oil-Emulsion Mud:
o Additives included diesel
oil, barite, water, and
emulsifying chemicals (oil-to-
water ratio maintained at 85/15) 10,500 - 18,820
Copies of the mud logs were considered confidential by the
operator.
The two pits at the site are shown in Photo 3, 4 and 5. The
reserve pit is the one to the right of the levee in this photo,
and the emergency pit is to the left. The reserve pit was
considerably more full than the emergency pit, and had a sheen on
its surface (Photos 14 and 15). The emergency pit was said to
contain only rain water and wash water. The intended use of the
emergency pit was to take up overflow from the reserve pit. A
pipe buried in the dividing levee (Photo 5 and Figure 3) served
to direct any overflow from the reserve pit to the emergency pit.
The reserve pit was designed for the temporary storage of drill
cuttings and residual drilling mud that left the mud circulation
system. Photo 4 shows the cuttings line through which drill
cuttings were piped to the pit. The pit was constructed slightly
below grade with bermed sides built up above grade, giving a
total depth of 11 feet. The depth of the liquid in the pit at
the time of sampling was 5 to 6 feet, and the sludge depth was 3
to 4 feet.
Disposal Practices
The supernatant liquid in the reserve pit was intermittently
reinjected down hole between depths of 4,000 and 7,000 feet. The
hole was constructed with 13 3/8-inch casing to 4,000 feet
cemented to the surface, and 9 5/8-inch casing between 7,000 and
15,312 feet cemented back to 7,000 feet. This left the zone
between 4,000 and 7,000 feet open for reinjection. At the time
of sampling, a pump was turned on and removed approximately
6 inches of depth from the pit. The recent loss of liquid is
evident in Photo 12, on the side of the pit just above the
surface.
The liquid would be vacuumed up and hauled off site to a
treatment facility in the event that the liquid could not be
reinjected any longer. This was considered a last resort measure
due to its high cost (roughly between $70,000 and $100,000) as
0541
-------
compared with that of reinjection (roughly $10,000). No liquid
had been hauled off site as of the time of sampling.
At the end of their use, both pits were to be closed by removing
all the liquid and allowing the solids to dry as much as
possible, land farming the solids, and leveling the pit to grade.
These procedures are based on an agreement between the operator
and the landowner.
Permits
A copy of the drilling permit secured by Westland Oil Development
Corporation is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-S7-005).
Sample Point Locations
At the Westland site, the samples were defined as the supernatant
and solid contents of the waste material in the reserve pit.
EPA personnel and CENTEC sample team members declined to sign a
release form required by the operator for entering the pit in a
boat. Therefore, the sample points were obtained by standing
inside the bermed edge of the pit and reaching in with the sample
equipment, as shown in Photos 12, 14, and 15. There was some
discrepancy between actual and measured sample points due to the
inaccessibility of the measured points. Sample point locations
were ultimately directed onsite by the Project Officer. Figure 4
indicates the measured sample points as well as the actual sample
points from which the pit samples were composited.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the mid-points of each side. The measured points were
marked with stakes to facilitate locating sample points.
The first sample to be collected was the liquid composite. The
thief was used by threading the gaging tape through a pipe,
attaching the thief to the end of the tape, and extending the
pipe over the surface of the liquid as far as the sampler could
safely reach. One sampler lowered the thief into the liquid, and
a second sampler pulled the string allowing the sample to enter
the thief. The liquid from each sample point was composited in a
5-gallon carboy.
C-542
-------
D
Figure 4. Measured vs. Actual Sample Points in Reserve Pit
C-543
-------
The reserve pit was then sampled for sludge. First, the coring
device was used with two 5-foot extension rods attached. The
sample was taken by extending the coring device as far into the
pit as safely possible. Photo 12 shows a sampler using the
coring device, and Photo 13 shows the sample obtained from that
point. The coring device was used only once, however, because
the sludge was too dense to enter the glass core sleeve without
breaking it. The dredge was used on the remaining sample points,
as shown in Photo 14. The solids were composited in the steel
bucket shown in Photo 13.
Both the liquid and sludge samples were tested for pH after
sampling was completed. The pH was 8 for both samples.
C-544
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-545
-------
C-546
-------
o
I
at
Photo 2. Southerly view away from reserve pit
Photos 3,4,5. Emergency and reserve pits viewed from drilling rig
-------
Photo 6. Easterly view across emergency pit
Photo 7. Westerly view of dike and emergency pit
D
I
ui
,u
CO
-------
Photos 9,10. Stick pile and drainage pond
O
I
Photo II. Diversion ditch behind trailers
-------
n
I
m
en
o
Wfc&*&
?£/m^-- \ jj-> • iT.^ ^^>fe»^ *
- v«.*3*»\».7Mri.—-. .^jji^.ui.tiCiA.c^',1, -j,^
Photo 13. Core sample In steel bucket
Photo 12. Core sampling In south corner
of reserve pit
-------
Photo J4.
... ,. south corner o,
Photo 15.
-------
C-552
-------
ATTACHMENT B: PERMITS
C-553
-------
C-554
-------
{ V/5LL FtLS COPY
FOflM MO 13.ft
STiTE cc LC.J!SlV,A PERMIT TO DRILL FOR MINERALS PERMIT $200.00
OFFICE OF CONSERVATION Multiple Zone Processing
ATT
Send To IT9V OlTlfmn3/2 P«t» MflTTh 27, IS
^ Serd(20376l A"' ^1707720376
Pointa Coupoo 039 _ PI.M Profit TBlagd 7558
Operotor _ WffB'tlflTvli ^H D^y^lTr"ff°T^ Corp* ^379
y 8328
G»y & ^tnt» Matairlo, LA 70009
Weii Nnmg Joseph Earl Bajola ]?o. 1
Locot.cn
Fr HW/q of Sflti Q9, go E alg Sea line 1233.51 *5 th S Q RA for
-387^08' to loo.
Pm-l8,8QOJ
/• ne •-•' R-.-erw.if c' &" f 0 *0 ConT-eion TUSC-
COMMlSSlONCM
ISSUING AUTMOWITY '] Q ^1 *1 "7
C-555
-------
C-556
-------
MICHIGAN
0557
-------
C-558
-------
Sampling Report
Investigation of Wolverine Gas and Oil Company, Inc.'s
Hanover 7 Central Production Facility
Jackson County, Michigan
July 29, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Michigan Basin production sites developed by the
Michigan Department of Natural Resources at the request of EPA.
The list was transmitted via telephone to the EPA contractor on
July 22, 1986. Randomization and site selection took place
during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Natural Resources listed the possible sample
sites by permit number. The list consisted of ten sites:
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
32780
4054
16795
39084
38001
38503
29468
29469
30594
37916
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 4 on the above list
(permit no. 39084). No. 2 on the above list (permit no. 4054)
was selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
Further inquiry identified the primary sample site as the
Wolverine Oil and Gas Company, Incorporated's Gorham 3-7 well in
C-559
-------
Hanover Township of Jackson County, Michigan. No problems were
encountered in arranging sampling for July 29, 1986.
The back-up site was identified a Harry E. Tope's Joseph E. Reed
No. 4 well in Buckeye Township of Gladwin County. The back-up
site was not required.
Site Location
The Wolverine Hanover 7 production facility is located
approximately 300 feet northeast of the intersection of Grover
and Fowler Roads in Hanover Township, Jackson County, MI. Fig-
ure 1 is a map indicating the production facility site. The full
name and mailing address for Wolverine is:
Wolverine Gas and Oil Company, Inc.
(Controlled by Star, Inc.)
One Riverfront Plaza
55 Campau, N.W.
Grand Rapids, MI 49503
Main Office Ph.: 616-458-1150
Main Office Contact: Ron Suckle (works for Star, Inc.)
Ph: 616-946-7111
Attendees
Sampling at the Hanover 7 production facility was performed by
CENTEC Corporation personnel on July 29, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (sample team): Jamie Mclntyre, Sample Team
Leader
Bill Lane, Technician
State Representative: Dave Davis, Geologist, Michigan
Geological Survey Division,
Rose Lake Field Office
Operator Representative: Paul Whitham, Field Engineer
(Star, Inc.)
American Petroleum Institute
Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Amy Crum, Contracted Sample
Team Member
C-560
-------
EATON
Figure 1. Location of Wolverine Gas and Oil Company's
Gorham Lease Production Facility, Jackson
County, Michigan
C-561
-------
Site Description
The Hanover 7 production facility is located in rural flatland.
The climate at this site location is net precipitation. The soil
is described as a layer of top soil over clay and sand, and there
are marshes in the vicinity of the site. Wells serviced by this
facility are completed in the Black River formation of the
Michigan basin. -
The depth to groundwater in the area is estimated to be 90 feet.
The nearest surface water is a creek located between 1/2 and 2
miles from the site. The nearest drinking water wells are
associated with farms within a 1/2-mile radius of the site.
At the time of sampling, the site consisted of three oil stock
tanks, one brine tank, four heater-treaters, and other related
process equipment, shown in Photo 1. Figure 2 is an approximate
schematic diagram of the facility, indicating the directions in
which photos were taken. Figure 3 is a flow diagram of the
facility, provided by the operator.
All the equipment at the facility was new, and had been in use
only 6 months at the time of sampling. Therefore, a cleaning
schedule for the equipment had not been established as yet.
Treatment chemicals used onsite include demulsifiers and parafin
dispersants. Approximately 16 gallons per month of "CMR-5"
(demulsifier) is used at the four heater-treaters (4 gallons/
treater). Approximately 15 gallons per month of either "PD-100"
or "WGH-123A-4272" (parafin dispersants) are used in the
flowline. No corrosion or scale inhibitors are used at this
facility.
At the.time of sampling, there were five producing oil wells
within a 1-mile radius serviced by this facility. These wells
were producing approximately 400 barrels of produced water per
day, at that time. One of these wells, Gorham No. 3-7, was
feeding into the second heater-treater from the right in Photo 1.
The oil and water are piped from the heater-treaters to the
appropriate tanks, shown in Photo 4.
The Gorham Well No. 3-7, shown in Photo 9, produced oil at a rate
of 100 barrels per day at the time of sampling. The well had
been recently completed at approximately 4,600 feet.
Disposal Practices
At the time of sampling, the produced water in the brine tank was
hauled by truck to "Dean Center's" disposal well in Jackson
County, MI. The name of the company used to haul the brine is
Joslin, Inc., located in South Boardman, MI.
C-562
-------
\
N
^US
Figure 2. Schematic Diagram of Production Facility
C-563
-------
FLOWLINE
^
FLOWLINE
FLOWLINE
FLOWUNE A " C 5
/•^ '"r *
9 55
Sf
*1
El
n
FLOWLINE /T^ r J
N
s
-------
The operator later submitted that the produced water is now
disposed of in the Savage Well No. 2-18A, which was drilled and
completed in October, 1986.
Permits
No permits specific to the operations of the production facility
were made available to the sample team at the time of sampling.
However, the operator later submitted a copy of a letter from the
Region 5 EPA, indicating that Wolverine had applied for a salt
water disposal well permit. A copy of this letter is located in
Attachment B.
A copy of the drilling permit secured by Wolverine for drilling
the Gorham Well No. 3-7 also is located in Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Hanover 7 site, one fluid composite sample was collected
from a sample port in the heater-treater that services Gorham
Well No. 3-7. Figure 2 indicates the sample point from which the
fluid sample was composited.
Sampling Methods and Equipment
The fluid sample from the heater-treater was collected through a
valve in a sight glass located in the lower half of the tank, as
shown in Photos 7 and 8. The sample was collected in a 1-gallon
glass bottle held under the flowing discharge, then transferred
to a 5-gallon carboy. The small amount of oil present in the
sample was removed by "topping-off" the carboy with produced
water until the oil layer had overflowed down the sides of the
carboy. This was done over a plastic bag to keep the liquids
contained.
Tests for the pH and free chlorine content of the fluid sample
were conducted onsite after sampling was completed. The pH was
7, and the free chlorine content was less than 0.2 ppm (the
lowest detectable limit).
C-565
-------
C-566
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-567
-------
C-568
-------
Photo 1. Full view of production site
Photo 2. Southerly view of four heater-treaters
n
I
U1
a\
vo
Photo 3. Southerly view of four heater-treaters
-------
Photo 4. Northerly view of stocK tanks
n
I
en
-j
o
Photo 5. Southwesterly view of heater-treater that
was sampled
-------
Photo 7. Inside heater-treater that MBS sampled
n
I
in
Photo 8. Sampler showing how and where sample was taken
(not actually sampling)
Photo 9. Well No. 3-7 (west of production site)
-------
C-572
-------
ATTACHMENT B: PERMITS
C-573
-------
C-574
-------
J"i~O *J ~' OEP*GEOLOGlCAL SURVEY DIVISION
LANSING. MICHIGAN 46909
PERMIT TO
gj DRILL O DEEPEN fj REWORK Q OPERATE
GRANTED UNDER PROVISIONS OF
Act 61. P.A. 1939. as amended Q Act 31S- P-A- 1959- as amended
(M.C.L. 319.1 to 319.27) (M.C.L. 319.211 to 319.236)
Violation of and/or non-compliance with the provisions
of the acts and conditions of permit may result in penalties.
Permit is issued based upon the attached stipulations which are
hereby incorporated in its entirety by reference.
ELL NAME WELL NO.
•orhara <-*3-7
"~*3SrjC4' - ]
DATE ISSUED
6/24/35
TYPE OF WELL
Oil and or Gas
Rotary
Wolverine Gas & 011 Co
1037 Trust Bldg
40 Pearle N.W.
Grand Rapids, HI 49503
—. -'- . u _
EXPIRES
6/24/35
TARGET FORMATION • • -i
- - ' Black R1vor
INTENDED DEPTH • —
4600'
.. Inc.
FOOT AGES.
of SW frc.'J* SW frc'% Sec. 7, T4S, R2W; Hanover Tte>,, Jacfcson Co.
ft. from South and 342 ft. from West line of quarter section
ft. from South and 34"3 ft. from Eajt line of drilling unit
O 0. SIZE WT./FT. • .
11-3/4" 42#
8-5/8" 24#
5-1/2" 15. 5#
CASING AND SEALING REQUIREMENTS
CASING
GRADE CONDITION DEPTH
H-40
K-55
K-55
New
Hew
New
4I01 ,
4GOO
CEMENT
SACKS
C to S
150+
as needed
WOC. (MRS )
12
12
^^^ I
"NOTICE AIJD REQUIREMENTS FOR SOURCES OF HATER AND WATER WELLS USED III CONJUNCTION
WITH OIL AMD GAS OR MINERAL WELL DRILLING, AND OPERATIONS", December 1, 1984 1s
made part of and a condition of this permit.
Strip topsoll In coltlvated field prior to constructln?cut and fill pad.
Place pits along western side of location in highest ground..jf-
Construct earthen dikes around perimeter of drill pad.^,
6 TO BE NOTIFIED BEFORE ORILLINS/QgEPENlNG STARTS
BY
»t Lansing Field Office 517-373-1233 Hilton A. Gere, Jr., Permit Coordinator
PAGE 1 of PAGE(S) 517-373-9290
FOR TH£ SUPERVISOR C* WELLSfjn'.FPAL V.E...5
C-575
a», i 1,4
-------
APPttCATION FOR PERMIT TO DRILL OR-BSEPEN
A WELL FOR OIL, GAS, BRINE DISPOSAL,
HYDROCARBON STORAGE OR SECONDARY RECOyERY
Under Authority 'of Act 61, P.A. of 1939, As Amended
i? M*AIL TO:
STATE OF MICHIGAN
DEPARTMENT OF NATURAL RESOURCES
GEOLOGICAL SURVEY DIVISION
Box 30028, Lansing, Michigan 48909
SEE INSTRUCTIONS ON REVERSE SIDE
2. H Fed. Employer Went. No. | D Soc. Security No.
38-1710995
j App«c*<«>n lor permit to drill lor-
_ Oil and .-, Brine ._. Hydrocarbon Secondary
1AJ or Gas LJ Disposal I—I Storage LJ Recovery
4 Application to: (no lee required)
.1. /», Ravis* /
Deepen
Application
c*neel •
Transfer
S. Ft* enclosed
E No D Yes $
6 Do prior permits enisl lor this well'
D No S Yes { D Drilled D Termin'd
7 List eecft permit number
39084
LOCATE WELL AND OUTLINE UNIT
ON SECTION PLAT — 640 ACRES
I. Applicant: (name each "owner" as they are bonded)
WOLVERINE GAS & OIL CO., INC.
(616)458-1150
9. Mama: (operator only il more than one "owner") Phone:
1037 TRUST BLDG., 40 PEARL N.W., GRAND RAPIDS, MI 49503
10. Leaae or well name: (be tmel aa possible)
GORHAM
Well number
3-7
WILLIAM WORTH
12. Address: Phone-
606 S. THOMPSON ROAD, JACKSON, MI 49201
13. Surface location deaenptien (See* instructions, nem 4)
S l/&af SW fro?3. 1/4 ofs^nfrc'l 1/4
14. Township
HANOVER
County
JACKSON
li. Bottom note location description il directional anil (See instructions, item 5)
SAME AS S.L. Mot * Section T.
It. Tawnsmp
SAME AS S.L.
County
17. LOCATE WELL IN TWO DIRECTIONS PROM NEAREST LINES OF QUARTER SECTION AND ORILUNQ UNIT. (See instructions. Items 4 4 5|
***** 330 . H— .«,«. SOUTH . .... .„„ 343 .. WEST
_lt. from (N/S
b. Location- _SAME_AS-J5n,lram (N/S)
Drilling
^. o»t. 330
. Line at quarter section. AND
_ Line ol quarter section AND
. It rrom (E/W)_
.It. from (E/W)_
. Line ot quarter section
. Line ol quarter section
horn (N/SI_SQUTH_
.Line ol flnihng unit AND
343
.It. Iron IE/W)
ESST
. Line ol drilling unit.
It. Drilling contractor:
Telephone.
1f. Kind of ICM
Me (Aota'y- CAO*«. eomtwution)
ROTARY
20 Mtenoed oeptn
4600'
BLACK RIVER
22. la sour oH or gas aapeeted?
E No | D Yd. :>, new
Depth
*\0&Q
^y.Au_'.
<*ouu
CEMENT
Sacka
C to S
L> to A
is need
WAj&(nnvl
13-
I7_
ed^.,
25 Sena correspondence ana permit to Address
MUD
wt.
Via.
LIDSCO. INC.. P.O. BOX 174, TRAVERSE CITY, MI 49685-0174
LEAVE tUUKK
PermR
?
t -I i^l 11
2S"TO DRILL
D TO DEEPEN
26 Name ol applicant s agent (Print)
JANTS T.. BSTRBAM
Pnone
C616"! Q.41-7628
Date
10/02/85
FOR CASHIER'S USE ONLY. OO NOT WRITE IN T
t *
C"576
White — Lansing tile
2 Canary — Cashier copy
3 Blue — District review
logteal Survey U*a> Only
4 Pmk — Region review
S Goldenrod — District Ine i»
6. Grej«n —• Applicant tile (»/(
-------
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY
REGION 5
230 SOUTH DEARBORN ST.
CHICAGO, ILLINOIS 60604
1CM.Y TO THE ATTENTION OF:
November 12, 1986
CERTIFIED MAIL
RETURN RECEIPT REQUESTED 5WD-TUB-9
Mr. S1d Jansma
Wolverine Gas and 011 Co.
1 Riverfront Plaza
55 Campau, North West
Grand Rapids, Michigan 49503
Re: Draft Permit IMI-075-20-0006
Dear Mr. Jansma:
In accordance with Federal Underground Injection Control Program
permitting procedures, enclosed 1s a copy of the draft permit for the
salt water disposal well, Savage I2-18A (EPA Permit IMI-075-2D-0006) 1n
Jackson County, Michigan.
According to Federal Regulation 40 CFR 124.10(b) a public notice of the
preparation of a draft permit shall allow at least 30 days for public
comment. At the end of the public comment period you will be notified if
any significant changes 1n the draft permit are required. If no major
changes are made, the permit will be Issued.
Sincerely yours,
Valerie J. Jones .Acting Chief
Underground injection Control Section
Enclosure
cc: R. Thomas Segal1. Michigan DNR
Charles Brown, EEI
C-577
-------
C-578
-------
Sampling Report
Investigation of Sun Exploration and Production Company's
Cameron Lease Well No. 1-10
Gladwin County, Michigan
July 30, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of Michigan Basin drill sites (at or near completion)
developed by the Michigan Department of Natural Resources at the
request of EPA. The list was transmitted via telephone to the
EPA contractor on July 21, 1986. Randomization and site
selection took place during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Natural Resources listed the possible sample
sites by operator and county. Their source for the list of drill
sites was the weekly Michigan Oil and Gas News, which gives
weekly rig locations. The list consisted of seventeen Michigan
Basin drill sites:
1. Livingston Co. - Terra Energy
2. Livingston Co. - Dart Oil and Gas Corporation
3. Barry Co. - Allexco
4. Arenac Co. - Amoco
5. Arenac Co. - Benchley
6. Crawford Co. - Onion Oil Company
7. Gladwin Co. - Sun Exploration and Production
Company
8. Ogemaw Co. - Marathon Oil
9. Roscommons Co. - Federated National Resources
Corporation
10. Manistee Co. - Preston Oil Company
11. New Aygo Co. - Wolverine Oil and Gas Company
12. New Aygo Co. - Wolverine Oil and Gas
Company/Pet rosta r
13. Osceola Co. - H. L. Brown
14. Osceola Co. - Tetrostar
15. Alpena Co. - H. L. Brown
16. Otsego Co. - Mosdacher/Scandia
C-579
-------
17. Tresque Isle Co. - Trend Well Oil Corporation
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 7 on the above list
(Gladwin Co. - Sun Exploration and Production Company). No. 17
on the above list (Tresque Isle Co. - Trend Well Oil Corporation)
was selected as a back-up site in the event the primary site was
inaccessible or inappropriate.
Further inquiry identified the primary sample site as Sun
Exploration and Production Company's Cameron Lease Well No. 1-10,
in Gladwin County, Michigan. No problems were encountered in
arranging sampling for July 30, 1986. The back-up site was not
required.
Site Location
Cameron Well No. 1-10 is located approximately 300 feet northwest
of the intersection of Kerswill and McCollough Roads in Grout
Township in Gladwin County, MI. Figure 1 is a map indicating the
drilling site. The full name and mailing address for Sun
Exploration and Production is:
Sun Exploration and Production Company
1320 Waldo
P.O. Box 999
Midland, MI 48640
Main Office Contact: Mark Dalton
Northern District Environmental
Coordinator
Phone: 517-839-5831
Attendees
Sampling at the Cameron Lease site was performed by CENTEC
Corporation personnel on July 30, 1986. Following is a list of
people present at the time of sampling:
CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representative: Jim Skipper, Geologist,
Michigan Geological
Survey Division, Mt. Pleasant
District Office
Operator Representatives: Mark Dalton, District
Environmental Coordinator
Mike Fandell, Health and Safety
Coordinator
Clayborn Hunter, Drilling
Foreman
C-580
-------
+
Figure 1. Location of Sun Exploration and Production Company's
Cameron Lease Well #1-10, Gladwin County,-Michigan
C-581
-------
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Amy Crum, Contracted Sample
Team Member
Site Description
The Cameron Lease site is characterized as rural, flatland. The
climate at this site location is net precipitation. The soil is
described as a red clay bed under loam. The well was completed
in the Prairie du Chien formation in the Michigan basin.
The depth to the groundwater in the area is between 26 and 50
feet. The nearest surface water is a swamp less than 1/2 mile
from the site. The nearest drinking water wells are associated
with seven houses within a 1/2 mile radius of the site.
At the time of sampling, the site consisted of one drilling well
and one reserve pit. The drilling rig, Bigard Drilling Company's
Rig No. 18, is shown in Photos 1, 2, and 3. There were several
trailers onsite serving as offices and living quarters for the
crew. These were all situated on the side of the rig opposite
the pit. Figure 2 is an approximate schematic diagram of the
site, indicating the directions in which photos were taken
(Attachment A).
This site was an exploratory drilling site. Total depth of the
well was reached at 12,700 feet. Total depth had been permitted
for 13,000 feet. Drilling began on April 27, 1986 and total
depth was reached on July 24, 1986. A date for completion of the
well was unknown because the crew was waiting for further orders.
Mud was being circulated, but all other activities had been
halted.
Drilling was accomplished with a spud mud, followed by a lime
mud. At the time of sampling, a polymer mud was being circulated
with saturated brine.
One lined pit was constructed onsite to provide temporary storage
of drill cuttings, residual drilling muds from the circulation
system, waste crude oil, and miscellaneous trash. The operator
suggested that there would also be considerable amounts of salts
in the pit, due to the nature of the formations they had drilled
into. The pit contents were piped from the mud circulation
system, as shown in Photos 5, 9, and 13. The pit was in use as
of April 27, 1986, and was expected to be out of service some
time in August 1986.
Construction requirements of the pit included a 20-millimeter PVC
liner, clearly visible in Photo 10. The sides of the pit were
C-582
-------
Figure 2. Schematic Diagram of Drilling Site
C-583
-------
required to have a three-to-one slope, and the depth could be no
less than 4 feet above the top of the groundwater in the area.
At the time of sampling, the average depth of liquid in the pit
was 2 feet, and the average depth of the sludge was approximately
7 feet. These quantities were estimated by the operator.
Pit contents included an estimated 1,700 to 2,200 barrels of
cuttings, drilling fluids, and wastewater (deck drainage)
generated from drilling operations. In addition, an unspecified
amount of cement had gone to the pit when the surface pipe was
cemented in place.
A tank storing diesel onsite could hold a volume of 21,000
gallons. The volume of diesel onsite at the time of sampling was
2,500 gallons. The operator estimated that less than one gallon
of waste oil had been generated onsite and put in the pit.
Disposal Practices
The operator stated that liquid from the pit was removed by
vacuum truck three times per week, and taken to "a variety of EPA
approved disposal wells." Time did not permit collecting a list
of these disposal wells. Two companies that had been used to
haul pit fluid to disposal wells included KalCon and Seiler
Companies. Copies of invoices for the hauling services provided
by these companies are located in Attachment C.
Solids would remain in the pit, to be encapsulated by turning the
apron of the PVC liner into the pit, covering the pile with a
second PVC liner, and backfilling the pit. The site would be
restored to its original grade, but further restoration would
depend on the ultimate disposition of the well.
Permits
Sun Exploration and Production Co. secured permits to drill, and
later to deepen, the Cameron Lease Well No. 1-10 in Gladwin
County, Michigan. Copies of these permits are located in
Attachment B.
SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
C-584
-------
Sample Point Locations
At the Cameron Lease site, the samples were defined as the
supernatant and solid contents of the waste material in the
reserve pit. Figure 2 shows the locations of the sample points.
In addition to the pit samples, a drilling mud sample was
collected from the mud circulating area. The sample was taken
from the flowing effluent shown in Photo 11 leaving the first
shale shaker in the system. The shaker that was sampled is
visible in Photo 1 at the far left end of the mud tank, directly
above the cuttings pile in the pit.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 2, and to locate the
center of each quadrant. The measured points were marked with
stakes to facilitate locating sample points.
The sample points were accessed by boat. The boat was paddled to
the measured sample points and held in place with two anchors.
The first sample to be collected was the liquid composite. The
thief was used to obtain this sample.
The reserve pit was then sampled for sludge. The dredge was used
to sample the sludge because the coring device could have
possibly punctured the lining of the pit. Photo 6 shows samplers
tossing the dredge from the boat in the northwest corner of the
pit. Two full dredges were obtained at each quadrant, yielding a
total volume of approximately 5 gallons. The solids were
composited in a 5-gallon steel bucket.
To collect the drilling mud sample, a clean 1-gallon glass jar
was held under the flow leaving the shale shaker shown in
Photo 10. This was a grab sample rather than a composite sample.
Tests for the pH and free chlorine content of the pit samples
were conducted onsite after sampling was completed. The pH of
both pit samples was 7. The free chlorine test, which is only
performed on liquid samples, was immeasurable, but caused the
liquid to bubble out of the test cell. The apparent chemical
reaction caused by this test was reported to the receiving
laboratories.
After sampling was completed, the samples were split with Sun
Exploration and Production Company. This occurred at the request
of Sun representative, Mark Dalton, and at the direction of Mr.
William Telliard, EPA Project Quality Assurance Officer. Bottles
for the split samples were supplied by the API sample team. Each
sample bottle given to Sun was filled, labeled, and signed by
CENTEC sampler, Jamie Mclntyre. A copy of the Chain of Custody
form used for these samples is located in Attachment D.
C-585
-------
The samples were preserved with ice and held overnight prior to
the day of shipment. This was necessary because of time
contraints encountered on the day of sampling.
C-586
-------
ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-587
-------
C-588
-------
Photos 1.2,3. Westerly view of drill site
O
I
m
CO
II
Photo 4. Samplers In southwest corner of reserve pit
-------
Photo 5. Samplers In southwest corner of reserve pit
Photo 6. Samplers roovlnq toward northwest corner of
reserve pit
Photo 8. Samplers next to cuttings pile In southwest
-------
Easterly view across south end of reserve pit
Shale shaker (upper left) and cuttings pile
Photo II. Effluent from shale shaker
Photo 12. Effluent from shale shaker with API samplers
In background
-------
$ Photo ,3. Cuttings line positioned over reserve pit
Photo 14. Cyclone(s) located over mud
reclrculatlon tank(s)
-------
ATTACHMENT B: PERMITS
C-593
-------
C-594
-------
STATE OF MICHIGAN
DEPARTMENT OF NATURAL RESOURCES
O fl Q y GEOLOGICAL SURVEY DIVISION
L. \J J / BOX 30028
LANSING. MICHIGAN 48909
PERMIT TO
jgl DRILL Q DEEPEN Q REWORK Q OPERATE
GRANTED UNDER PROVISIONS OF
XX Act 61. PA. 1939. as amended Q Act 315, P.A. 1969. as amended
(M.C.L. 319.1 to 319.27) (M.C.L. 319.211 to 319.236)
Violation of and/or non-compliance with the provisions
ol the acts and conditions of permit may result in penalties.
rhis permit includes as requirements all the operations and methods
proposed by the applicant, unless rejected or titered by the ONR, and
along with the attached stipulations are incorporated in its entirety by
reference.
WELL NAME WELL NO.
' Cameron '1-10
LOCATION AND FOOTAGCS
•*~ "IWlo.,,
•39772 1-30-86
CANCEL ANO TRANSFER ISSUED
DEEPENING PERMIT
PERMIT EXPIRES
1-30-87
ISSUED TO
011 and or G as
FORMATION
Prairie du rMen
DEPTH
'I? 200'
KINO OF TOOLS
Rotary
6un Exploration^ Production Co.
Box 999
1320 Waldo Rd
Midland MI 48640
SPt SPs SBt Section 10, T18N, R2W, Grout Twp. €ladw1n Co.
330 ft. from South and 330 ft. from East line of quarter section
330 ft from South and 330 ft. from East line
ofd drilling unit
CASINO AND SEALING REQUIREMENTS
CASING
00 SIZE WT/FT. GRADE CONDITION DEPTH
24" .5" Wall PE New
16" 75* K-55 New
100'+
700 '"
10-3/4" 51-60.7* L-80 & SS-95 ,". New "6450*
7-5/8' 26.4-39* L-80 New
5' 15* N-80 New
*If no abnormal pressures 1n the A2 or Al Carts
* 9200-10300'
* 12200'
CEMENT
SACKS WOC (MRS)
600 12
1900 16
600 24
"300 24
or sloughing shale problems In the Utica .
Shale are encountered, then the 9-1/2* hole size will be reduced to 8-1/2" and a 5-1/2" long
string will be run Instead of the 7-5/8* Intermediate casing & 5" Uner.
1. HYDROGEN SULFIOE (M GUIDELINES APPLY. SEE NO. 10 ON REVERSE 8IESIDE OF THE PERMIT.
2. Materials expected to be exposed to H2S environments oust meet the standards for
resistance to sulffde stress cracking outlined 1n the NACE Standard
MR-01-75, "Sulflde
Stress Resistant Metallic Material for 011 Field Equipment*. 1978 revision.
3. Reserve pit 1s to be located north of well.
4. Mt. Pleasant office Is to be notified prior
ICE TO BE NOTIFIED BEFORE DRILLING/DEEPENING STARTS
t. Pleasant Field Office 517-773-9965
PAGE 1 ol
to encapsulation of pit.
BY ]' -Y <•' /
Rex TefertHler
PAGE(S)
FOR THE SUPERVISOR
i
t
7!3~"
517-373-9TBST COORDINATOR
OF WELLS/MINgRAL WELLS
1
C-595
PR 7700
O... •»;•€
-------
APPLICATION FOR PERMIT TO DRILL OR DEEPEN.
A WELL FOR OIL, GAS, BRINE DISPOSAL,
HYDROCARBON STORAGE OR SECONDARY RECOVERY
Under Authority of Act 61, P.A. of 1939. As Amended
0
\J n.WM.1 r. IV r I I
R 7207
Rev 2/81
MAIL TO:
STATE OF MICHIGAN
DEPARTMENT OF NATURAL RESOURCES
GEOLOGICAL SURVEY DIVISION
Box 30028, Lansing, Michigan 48909
SEE INSTRUCTIONS ON REVERSE SIDE ->•
ace inamuunuraa
3 Acoi'canon lor permit to drill for
-, Oil and _-. Srme _ Hydrocarbon Secondary
-jt Of Gas U Disposal U Storage I—I Recovery
6 Do prior permits exist for tfiis weft9 "
_X No Q Yes I D Drilled D Termmd
4 Application to (no lee required)
Revise Cancel and
I—J Deepen I—I Application I—I Transfer
2 £] Fed. Employer Ident. No. | G Soc. Security No.
23-1743284
5 Fee enclosed
D No G3 Yes S 100.00
List tacn permit number
LOCATE WELL AND OUTLINE UNIT
ON SECTION PLAT —640 ACRES
W
~~
—
.- _
-— -
— 1
--
_ _
__
1
— 1
t
1
1 H
1
1
I
• t
\ /
\ '-
— f - -
i
U- 1 - .
1
1
1 1
—
•-
o
...
— i
,-J
i
i
_ n
i
— — .
— •
•-
-
>*•»
._.
_ ..
r — •
• "m «
a Applicant, (name each owner" at tney are bonded)
Sun Exploration and Production Company
9 Address, (operator only if more than on* "owner')
Box 999 - 1320 Waldo Rd., Midland, MI 48640 (517) 839-5800
10. LMM or wott nvrw. (tM bntf as possiblt)
Cameron
Well number-
1-10
n. Surface owner:
Alex Acres
12. Addraaa. Phone
4789 W. Cedar. Gladwin. MI 48624 (517) 426-7969
13. Surlac* location description (Sa* instructions, item 4)
SE *ol SE *"' SE *Sect.on 1Q T 18N « 2W
14 Township
Grout
County
G1adwi n
15. Bottom note location description ,f directional dnfl (See instructions, item S\
V. of V. ol V. Section T
18 Township
County
•' LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES Of QUARTER SECTION AND DRILLING UNIT. (See instructions, items 445)
330 n from img) SOUth Line ol quarter section. AND 330 ft. from is/w> EdSt
Surface
a Location
Bot Hole
D Location .
Drilling
c 'Jntt
.n. from IK'S).
330
. ft. from (N/SI-
South
. Una ol quarter section AND .
Line of dnllmg unit AND
.It. Irom (E/W)_
330
. ft Irom (E/W)
East
_ Lin* of quarter section
_ Line of quarter section
... Line of drilling unit.
18 Drilling contractor
Not yet awarded
T*i«phon*.
19. Kind of tools (Rotary, cable, comom.iiooi
Rotary
20. IMwndwJ d*ptn
az.zoo1
21. Inlenaed farmaoan
'rairie du Chi en
22. Is sour 0*1 or o«s •«p«ct*d?
n NO | c Y., QQ' 10 300
i??nn-
Lf_nn ahnnrm
"countered,
QeoL Form
be drivi
GL Drif
"F" Sal-
Niag-Tri
PdC
L! pressi
:hen the
BK Ola.
rn
: 20"
: 14-3/4
pnt. 9-1
6-1/2"
ires in
9-1/2"
CASINO
O.D. Size
24"
16"
10-3/4
2" 7-5/.
5"
he A2 o
ole siz
Wty R. — Grade — CondlUon
0.5" wall - Pt - new
75# K-55 new
1 51-60. 7# L-80 & SS-<
i" 26.4-39# L80 new"ty
15? N-80 new >
• Al Carbs or slouqhlr
>will be reduced to i
Depth
±1UU'
7UU1
5 6450'
M-lOSOf
12200'
g shale
.-1/2" ar
« send eorr.spono.nc. .no B.,m,t t0 Address run nstead of the /-b/«" i ntenned
CEMENT
Secka
—
600
1900
1 600
300
jrobier
d a 5-
iate ce
W.O£Qn,;
—
12
16
9/1
2<
is in •
12" 1c
isir
MUD
Wt.
--
a./
R VI
) ?-1
J.2-:
ie Ut
iq st
VI*.
—
50
n ? rt
Q S '
0.8 •
resn
ring
W.
--
NC
R I
0-f
0-'
RT
W1
ig & b" Uner.
Sun Exploration and Production Company - Box 999 - 1320 Waldo Rd., Midland, MI 48640
Date Issued
.L" if '%**
Permit
-------
2397
STATE Of M»CT«^_.
DEPARTMENT OF NATURAL RESOURCB9 _.
GEOLOGICAL SURVEY DIVISION
BOX 30028
LANSING. MICHIGAN 46909
PERMIT TO
OPERATE
Q DRILL .3 DEEPEN Q REWORK
GRANTED UNDER PROVISIONS OF
Act 61. P.A. 1939. as amended O Act 315. P.A. 1969, as amended
(M.C.L. 319.1 to 319.27) (M.C.L 319.211 to 319.236)
Violation of and/or non-compliance witn the provisions
of the acts and conditions of permit may result in penalties.
fhis permit includes as requirements all the operations and methods
proposed by the applicant, unless rejected or altered by the DNR. and
along with the attached stipulations are incorporated in its entirety by
reference.
PCKMIT ISSUED
39772 7/11/86
CANCEL AND TRANSFER ISSUED
DEEPENING PERMIT
2302
PERMIT EXPIRES
7/11/87
Tff 6 OF WCLL
Oil or Gas
FORMATION
Prairie du
Chi en
DEPTH
13,000'
KINO OF TOOLS
Rotary
WELL NAME
Cameron
1-10
ISSUED TO
Sun Exploration and Production Company
Box 999
1320 Waldo Rd.
Midland, HI 48640
LOCATION AND FOOTAGES
SZk S&t SEH. Sec. 10, T18U, R2W, Grout Twp., Gladwln Co.
330 ft. from South and 330 ft. from East line of quarter section.
330 ft. from South and 330 ft. from East line of drilling unit.
CASING
QRAOE
CASINO AND SEALING REQUIREMENTS
CONDITION DEPTH
5 1/2"
Conductor
750 K-55 New
51-60.7* L-80 & SS-95 New
Deepen to 13,000'
17-20* N-SO Hew
100'
700'
6450*
13,000'
600
1900
1700
WOC (HHS|
12
16
48
1. HYDROGEN SULPIDE (H2S) GUIBELXHES APPLY. SEE NO. 10 021 REVERSE SICE OF THE PERMIT.
2. Materials expected to be exposed to H2S environments must meet the standards for
resistance to sulfide stress cracking outlined in the RACE Standard MR-01-75, "Sulflde
Stress Resistant Metallic Material for Oil Field Equipment", 197S revision.
3. Reserve pit la to be located north of veil.
4. Mt. Pleasant office Is to be notified prior to encapsulation of pit.
fFlCE TO BE NOTIFIED 8EFOBE OBILLINO/DEEPENINO STARTS
Mt. Pleasant Field Office 517-773-9965
BY ' •"
David II. Bechler for
-/'/ /'• &'•+-••'
PERMIT COORDINATOR
PAGE i of
PAGE(S) Hex Tefertiller 517-334-6974
FOR THE SUPERVISOR OF WELLS/MINERAL WELLS
cinccno
oem iiRPMFMT!1?
PR rzoo
R«v. 7/85
C-597
-------
APPLICATION FOR PERMIT TO:
REWORK OR G OPERATE A WELL
MAIL TO
MICHIGAN DEPARTMENT OF NATURAL RESOURCES
GEOLOGICAL SURVEY DIVISION
BOX 30028. ^ANSING. MICHIGAN 48909
•','/
/
AND/OR FALSIFICATION OF THIS INFORMATION
MAY RESULT IN FINES AND/OR IMPRISONMENT.
BY AUTHORITY OF:
la " Act 61. PA 1939 as amended
y. Oil & Gas
~ Snne Disposal
C Hydrocarbon Storage
C Seconday Recovery
A=r''Cation to (no fee required it permit is valid)
-^**
Revise Application ~ Cancel and Transfer C Convert to II
10
~ Act 315. PA
__ Disposal
^_ Brine
~ Test Well Type
H Single
19ii9 as amended
_ Storage
Blanket
3 Fee enclosed
5C No C Yes
4 Do prior permits exist7
^ No 5£ Yes ij( Drilled H Abandoned/Terminated
5 i_is: each permit number
39772
Surety Bond-
X Blanket ~ Single Well
6. Fed. Employer Idem. No or Soc. Security No.
23-1743284
6. i_ Attached
X On File
9. Bond No.
8074-71-81
10. Bond Amount
$50.000.00
Applicant (name each owner as they are bonded)
Sun Exploration and Production Company
*2 Address- (operator only if more Man one owner")
Phone:
Box 999 - 1320 Waldo Rd.. Midland, MT 4flfi4n (si?)
13 Lease or well name: |Se as brief as possible)
- Cameron
Well number:
1-10
1- Surface owner
Alex Acres
i5 Address
4789 W. Cedar. Gladwin. MI 48624
Phone
(517) 426-7969
LOCATE WELL AND OUTLINE UNIT
ON SECTION PLAT - 640 ACRES
N
W
15 Surface location (See instructions)
SE * ^E * of SE *
sec.
18N R-2W
Township
Grout
County
GTatlvdn
Bottom hole locaron if directional dnll (See instructions)
'i Y« Of '* of Sec. T.
Township
County
R.
13 LOCATE WELL IN TWO DIRECTIONS FROM NEAREST UNES OF QUARTER SECTION AND DRILLING UNIT. (See instructions)
330 ft. from (MfS) SOUth Line of quarter section. Ann 330 ft. from (E/W) __EaSi— Line of quarter secttor
ft. from (N/S) Line of quarter section. AND It .from (E/W) Line of cuarter sectior
SOUth Line of drilling unit. Ann 330 ft. from (E/W) EjSt Line ot drilling um
Surface
3 Location:.
Bot. Hole
s Location- .
Drillmg
c Unit-
_ft. from
1 9 Drilling
contractor
RinarH
Hr*l 111 nfl
Cn
20.
Kind of tools (Rotary,
Rotary
cable.
combination)
21
Is sour oil
D No
or gas expected''
BE Yes
72. Blriwout control diagram enclosed
C No £ Yes
23 Blowout control (Detail equipment type. size. mm. rating, testing, choke manifold, etc. See instructions)
See attached
2- intended Total Depth
. c13,000'
25. Formation at Total Depth
Prairie du CM en
26. Producing Formation
PrairMo Hn fhion
27. Objective Pool or Field
Prairie du Chien
PROPOSED DRILLING, CASING, CEMENTING AND SEALING PROGRAM
HOLE
Depth
100'
?nn'
6450'
13000'
Geol Form
Drift
pi nn' ft
"F" Salt
PdC 9-1
Bit Dia.
Drive
?r>"
14-3/4
/2"» R-
CASING
0.0. Size
24"
1«"
10-3/4
I/?" S-l
Wt./Ft. — Grade — Condition
Conductor
?«;# \(.^ new
51-60. n L-80 & SS-95
new
Dppppn t.n 13,nnn'
PHP
/?" 17-?n< N.RO npw
Depth
inn1
700'
6450'
i ^nnn •
CEMENT
Sacks
~ ^
500
1
-------
ATTACHMENT C: INVOICES FOR PIT FLUID
HAULING SERVICES
C-599
-------
C-600
-------
-*•
ALBION, MICH. 49224 June 30
In Account With
-.«M-
SE1LER TANK TRUCK SERVICE;' INC.
Fully Insured
P.O. Box 364 Albion, Michigan 49224 Phone Area 517629-4810
DS
CS 40382
N2 88279
PLEASE REMIT TO:
MB Unit
No. 9384
Milwaukee, Wl. 53201
June
June
June
June
June
June
-
21
21
21
21
23
23
-
Lease: Camercn 1-10 '
Field Ticket * 1508 7 hrs
Field Ticket £ 1630 7 hrs
Field Ticket * 1098 9*« hrs
Field Ticket #812 9% hrs
Furnished Transport and Cceratcr to
haul brine
to rig.
33 hrs 3951.75
.* - -.- . .• .. O^Gcount
Field Ticket * 313 10*$ hrs
Field Ticket * 1S30 11 hrs
Furnished Transport and Operator to
haul oit water to Oisccsai.
213* hrs §551.75
Discount
Disposal Charce 9£0 bbl @.25C
Total
i
o crElYED
RBV**1**^-
* Hor«M»OUM
i JUL051SS3 ••
torn .w--
JATNC f IAI» TW* • —
\
t
S1707
(? 165
$1112
(S 107
5 245
76
00)
63
50)
OC
f-2792
G9
TERMS: Our FINANCE CHARGE on accounts ovw 30 day* i* a fixed amount of 1V, % p«r month which is 18% ANNUAL PERCENTAGE RATE.
Accounts Due In 30 Days
-------
/*LBION, MICH. 49224.
V- ' • -
.198
In Account With
SEILER TANK TRUCK SERVICE, INC.
Fully-Insured
P.O. Box 364 Albion, Michigan 49224 Phone Area 517629-4810
Sun S::T? Lcrati. en
8S921
P.O. 3cx 599
Midland, MI 43640
CS-403C2
PLEASE REMIT TO:
MB Unit
No. 9384
Milwaukee, Wl. 53201
Auo
Auc
Auc
.iUC
Auc
AUC
Auc
.AUC
Auc
4lUg
Auc
AUC
Auc
12
13
9
9
10
10
11
12.
12
12
13
i j
13
-
i _ 1
Lease: Cameron 1-1*0
Field Ticket i 2459 6 hr
Field Ticket if 2465 3 hr
Field Ticket f 1957 2h hr
Field Ticket 7 24S5- 5 hr
Field Ticket i 24S5- 15 hr
Field Ticket * 2545- 4*5 hr
Field Tickec * 251S 5 hr
Fielc Ticxec :.f 2s 19 11 hr
Field Ticket #-2490 5 hr
k'leiti Ticket w 24^5 2*5 hr
Field Ticket # 2491 5 hr
^'ieic vic.cec s £
-------
ALBION, MICH. 49224 ^UCUS - 2.3
In Account With
SE1LER TANK TRUCK SERVICE, INC.
Fully Insured
P.O. Box 364 Albion, Michigan 49224 Phone Area 517 629-4810
193
Sun ":;
tion. ."
P.O. Zcx 99S
I lid land, t-:i 45640
CS-40332
N2 '86937
PLEASE REMIT TO:
MB Unit
No. 9334
Milwaukee, Wl. 53201
>.uc
^
4
20
Lease: Car.ercn 1— 19
Field Ticket •? 1215
ITurnished 70 bbL Tanden Vac Truck and
Operator tc ;.aul pit watar to cispcsaJL.
3 hrs §545.00
Discciaal. Cliarrs
ISO bbL 3.25*
Total
^
RcCtiVtD
K.~';~T: '.'.anti
ftiw 9 7 1986
..• . "is r\
rn STCO VI.U.T- J _
rvr N-i ' •' "" • ° — r^=:
>.
314^
3 37
-
•^^
.
00
5G
iUCl
50
TERMS: Our FINANCE CHARGE on oCEOunts ov»r 30 day* if a (lx«d amount of 1 Vt % per month which it 18% ANNUAL PERCENTAGE RATE.
xounti Due In 30 Days C-603
-------
ALBION. MICH. 49224
In Account With
SE1LER TANK TRUCK SERVICE, INC.
Fully Insured
P. O. Box 364 Albion, Michigan 49224 Phone Area 517 629-4810
CttCCeTi.-=r
<3 / i • j o
PLEASE REMIT TO:
MB Unit
No. 9384
Milwaukee, Wl. 53201
c.Truj. ndrci '. I*er. rr- -^.-j
Tctai
TERMS: Our FINANCE CHARGE on accounts ov«r 30 daypiiatfvgd amount of 1". % pw month which is 18% ANNUAL PERCENTAGi
All Accounts Due In 30 Days ^
-------
CCrSSTaUCTiON S23VJC2
mJm ^^» V» 4»«3» VE^^ Via/ JL» «fc PC BOX 41 KAUASXA. MICHIGAN 49646 PHONE (616) 258-9134
eiw«« «»v,cs • "O«o luaAiM . MMMIWUNCI • .XCAV.TINO EMAN HOOERHEIDB JI. DENNIS HOCERHE1DE
OOZXK MKVICC • IOUVMCNT MAMBUMO • MIDI HUI
OIL. fltUO TDUCKINa • MPT1C STSTIMS
™« STJN- PRODUCT^?; COMPANY ^ * M ^HOR.ZEO .,,„ ^ ^
««-,, P.O. BOX 999
<"!TYll5TiT* MIDLAND. 'H
r OWE |
S/^/Sfi
5/Ob/36
5/06/o6
5/06/36
5/06/3S
5/07/86
3/07/36
S/Oo/86
3/oa/ae
5/09/S6
/" \ rKv) * LOCATION Crt:-[£'»GM 1-10
/XW
10
A 4453"
OEsaumoN. I PRICE L AMOUNE .-•• 1
* ^ nniras v/TA>nra» -rav B«rf?n T)I?*:T!?VII Trs* TISOQ
5.00 HOURS W/TANKER TPJC. HAULED 2a7 SSL 3RT>^ TN'TO LOCATT
:\.ra PUT
3. 00 HOUIIS '•„'
r" T^JKS Ts.. "US^'O^f;^ Tfy 40;"1'1
/T^t'KZS TV -VU'FD 130 l^L 1?^O'-: Vr^^VF ^7
TO ?. dOLDE^ 41 S-.JO r*. TO«P»nVO 7^' &»«7
3.00 SOUltS "»
PIT TO
2.00 HO'JSS W
/T^IKER TI1K. 'ULTLHD 130 33L '.JATSR j?^CII 1ES.
F-FOLOrZIAI.' .>! S'iO (?. T'OnffMTtfli^ TCTC ?"56i?
/TAiTER T!TC. --4nLffD 130 33^ «RT-.V T-TTO T,nr\TT
r CF. SODfTJTW^ TRK 7^fi7
S.SO ««oL-3 :;/?4i-fitKTi r.^- BATT:*T» 7-.-1 r.sr. ^VT^TT T»rrc 5JAr
TA^rKS FOR. RIG H. RJDEJJISH^ TC^ 4-63
5.00 HOUP.S >T
/T.V'TSI T\Jv •iATJTj'T) 4Q'"< ii'H' TTCT"!' t*r*'"T '5T>Ar>
T^,r *OR STJ CF wo^i^rr^^ -jx: •'37-'
r; Afl iiAir^c '..'
/TA;
.;(.
THTAf
•";n ; -i
^77 "0
1 «T A f |
i f,f. ,-r>
"• ' •"' 'D
'L ? 0 Q M
iil ""1
v,, ,n
44 •s '("i
.,.. .
<•- -.-.
. ^ ^ , -.
KAUASKA CONSTRUCTION SERVICE INC. 2% AFTER 30 DAYS
INVOICE
C-605
-------
CHAN* MMVICC • "0*0 BUHDUM • M«KT«NANC«
OOZtH HMVICI • IOUWMCMT MAMOUM • MIDI MIX
OH. Pl«L0 TBUCKINO • MPTIC SVSTWMS
POBOX48 KALKASKA, MICHIGAN 49646 PHONE (616) 258-9134
EMAN HOGWHE10E J«. DENNIS HOGERHEIDE
S '•'"" • •«-
a,Tlrr vcfl ^. (e
,./T,.._r.t, ^J. ,..)lf
PRVrr ,,vfl ,.,T ,n
. — • -.„
\ .%;-»..-..--..
,
^--
* — ".
1 "AY ._.-> -.-:...-
DESCHIPTiar*- . _ ...
. HAULED 420 33L t«Hi:fE I!JTO LOC.
±JS^ TCK l^Oil
„, lsn ^RT pTi-TATira nnr rn rm
r, ,?Wi,.,,I..n Trt- 7,r,,,
ITTrn ,<7 .rt,( 9l-..aTra 70 ......^
-T,rjiB^. Trr <;,,i
-^ -«„ w- pT-H-^ti -1 r.-n
;rnrv.?:.^ 7(,f, ioao
^ &,r. --,. ^TTt.'iTr-? Tr> r.TC-pnriT
viwjif.q^ T,-nr ^iqh
^^^^^^^^^^^^^^^^B
55. an
1 I«
» 1 "•
1 . i :>,
1 i;-
•nvr^r
l^^^^^T^^^^^3]
470. rO
121 nn
-^ ,A
i-,7 np.
'.',A 4r.
1 <'< 4 TK
KALKASKA CONSTRUCTION SERVICE INC
AFTER 30 DAYS
INVOICE
C-606
-------
XALXA5XA COrsST^UCTiCiS ScSVlCS INC
POBOX4« -KAIKASXA, MICHIGAN 49644 PHONE (616) 1 i8-9134
C*AN« M*v,ci • «a«a ~W..MO . ..A.NT.NAMCI . KCAVATWO EMAN HOGERHEIDE JR. DENNIS HOGSRHEID6
OQSIt SVftVICI • KOUIPMCWr HAMOLIMO • ftVOI MIX
on. fimuo mucxma • MPTIC SYSTVMS
SOIOTO .
ADDRESS .
CITY & STATS.
SUN PRODUCTION COMPANY
P.O. 30X 999
VT 4:
.nfiAft / a* \(
AUTHORED gOB ACgLm
LOCATION CAI-iERAOM 1-10
(7
A 4551
DATE I
5/13/86
6/13/86
5/16/H6
S/1S/8*
6/Ui/S*
«/!7/rtfi
1
DESCRIPTION.- .... - - PMICE- , - . U, -•; - MMOUmr^H
^'/TANKER TPJt. •r,'AI7T."'D 1 SS RRL BST?i'P OUT 0" PTT TO OT^Pfl^VT.
AT 1 )<< PrT> URT n im'TASW^ rnr ST?7
^/TAirscss. T=b;. KAITLSTJ PTTUATSR OUT OF PTT TO ^TSPO^AT.
70.1 «T. .71.^7-
'.T/TA\--?. T^K.. rr.Afrr..--n w
4<50 8UT. AT 1.13 ?T
v ^RT. (r cnnP-iTwi rr..- 40^7
-,7^?. r»rrr HP PKTI nn
5A.43
^ &,
•>«/ Ort
, ^ K,
KALKASKA CONSTRUCTION SERVICE INC
2% AFTER 30 DAYS
INVOICE
C-607
-------
PO8OX4* KALKASKA, MICHIGAN 49646 PHONE (616) 258-9134
ow* SCMVICI . IKJAO muiuiiHO » .MW.TIJ.A..CE • «xe*WATiNa EMAN HOGERHEIDE JR. DENNIS HOGERHEIOE
OOZXK HHVICI « tOOI^XBMT MAMOUMO » »«OI M« . . •
on. n«u> TKUCXIHO • MFTIC sv«n»m '
^ SUN PRCDUCTTOM COMPAQ 7^ ID -, AUTHORED JIM SM1TH/3bB ACSLS7
P.O. SO'-C 999 ° A^Or^ ""4/V LOCATION CAMERON 1-10
ADDRESS k-iv ^ -'OVQl
A 455
| OATE. |T - QESCHIPTIONi- . . - . - |^_ PWCE- : jfc.-r.-j. AMQUNr «
fi/^n/^fi
6/21/G6
6/21/36
R/-Q/8S
T/21/S6
fi/?7/flfi
7/Ol/Hh
7/,V/«ft
7/iT^/A^
sS*s^
c . .^
\
\
i
\ ,
i!/TAvnft? T-JTT. KAT,I m i "?n n:u Ti-'T'ja'rrR nnr rn
F. KOLDC"^,' rfi SVD n*. RiisHONf:'* rr? -i^s
5.00 HOURS W/VAC. TSK. HAULED 160 BBL SRIIffi DITO LOCATION
(a. FASR) TCK 6294
, r,n ..„,„<. C/TV^V-, T,,- j.^m -»r,n UT:T qa^rr T-W, Tr."r-,
^..n PTIT .,^0 -,n!,r PTT, rir pnn..TTC.n ,^ /|CV)Q
2. CO ^O!ri?s '."/TiNiTra TP."_ HArn.Tm t^n RTIT. rtPT'-nr rn Trtr^T^nv
r, ,TNS,0i!r^ Trr 771i
0/ nn ,rf.1T,q :T/T,,r~, -^., 3AT^.im inn anr. «T,!P r^,-. a*r.
Fno .,..TT,T,Tf: .., r-r.wMrt frv 7335
..;/T i._ri.,, T-,.r ^iITTKTy ^rn ,.,,. OTWA.Bl_ „,...
^rsyTjV.. prr -,.r „ .:nTnP.,4ft jjt ,,-T, ^ Hnrtir>fT«-j>
TT< 1"S.'?I
9/TiVS"'-""'? TT?tT triTTT '"1 ARH UBT pTTT^jlT^ • "5V {_("»/"•
B,?c^,f.,, SZZ~^ > ^
^^X./T^.v,, „,. „,.,„„ ,,« £lr ^r-TlTSp .,^ ,«c
x^T^> 7 ,V". -4v «i v-n (T> an«wr^ rrv 7^x
r\H •* \
V » r--- A^n unr pTTTT^-nrs1 ^^77 T_-">r
.^ _^gfi»r ...^.^^j, c^ -r .^p^-^, ,.^. 10,.,3
,V^' ^
-------
PO8OX4J KAUCASKA, MICHIGAN 49646 PHONE (616) 253-9134
OIAN. M»VIC* . »o«o .u,u>««a • «««T.H«HC« . «O.VAT,N« EMAN HOGSRHSIOE J«. DENNIS HOGERHEIOE
OO2ZR SCRVICS • (QUIPMINT H«MOUMd • MCDI MIX
on. ntiD muCKiNa • MPTIC svsnus
P.O. BOX 999
AUTHORIZED
BY
BOB
IOCATION CAMERON 1-10
'•IIDLAJrD, J^
43640
A 4555
OAT& | nscJiipnanfc" •-,-. {:--.-.> o««-c - |_^, ... ftMfnmF^...- ^
7/11/86
7/14/86
7/14/36
7/14/86
7/14/36
W/TASKSH T*X. HAULED 450 BBL PITWATER OFF LOCATIO
TO PL. fiOT.DFMAM #1 SWD <"R. 5TJSHONG} TCX 7347
7.00 SOURS W/TAHKER TRK. HAULED 300 BBL BRINE INTO LOCAIO
tOR DRILLING RIG (R. BUSHON-G) TCX 7349
W/TAJKER TRK. HAULED iso BBL PITCATER OFF LOCATIO
TO F. HOLDEMAS #1 SOT (R. BOSHOHGDTCK 7348
3.50 HOURS W/TA«KE2 TRK. HAULED 150 BBL BRIME INTO LOG.
FOR URILLIITO RIG. (J. RODEHISH) TCX 6373
y/TAITKER TRK. HAULED 300 BBL PITOATEB. OFF LOG.
TO F. HOLDEMAN #1 SOT (J. RQDENISH) TCK 6374
^\
^t.^ \
^?^\&* \
(^ ^^ ,^ ]
\ ,\\ ^ ' **^ ,
\ ^., ^^
\ ^^^^
\ ^^^
t 1.18
PER BBL.
I 55.40
r i.is
55.40
lilS
TOTAL
\
^
531.00
387.50
177.00
193.90
354.00
1,643.70
KAIXASKA CONSTRUCTION SERVICE INC.
2% AFTER 30 DAYS
INVOICE
C-609
-------
CwiSiTxi-CTiCiS Si.tviCi
A«« s«»wic« • «OAO •UIUJINO • -*I«T«NA«C«
OOZ*» MMVICI • IQumUHT HAMQUNO • ««0I MIX
on. ri*\a THUCKIMO • seme SYSTEMS
POBOX4C KA1.KASKA, MICHIGAN 49644 PHONE (616) 258-9134
EMAN HOGE*HEIO« J«. DENNIS HOGERHEIOE
SOIOTO
AOORESS -
CITY & STATE-
AUTHORIZED BQB ACKLEY
P.O. BOX 999
:HDLAI-iD. MI 46640 i .-
LOCATION CA2-JERAOH 1-10
A 45c
| OATE- - I1-' - •' ' OkbCJUWIOJ*.-
7/17/86
7/24/G6
7/25/36
7/25/86
'7/25/86
r.m / "** A ^TIT^I *T*VTT P A 1 ^ ^T) A *^ H
-rtKT. PTTVATTTTJ n
. --.--• . - |. , .-- MICE ..... (. ..-AMOUNT.
rn- rn KZX TRK. HAULSD 150
#1 S*«D fR. BUSiiOi'G)
SBL PITwATER OUT TO F. HOLCEJiAN
TCK 11112
33L PITWATES OUT TO F. SDUJEMAJT
TCX 5^05
BBL PIWATER OUT TO F. HOLDS-IAN
TCK 12642
BBL PiriATES. OUT TO F. KOLDEMAN
TCK 12120
R-gcTTvl
HorU«»« uU»Ut
JUL 5 1 1981
.„_.- VSSffffiO
p>v kirT IJ.TSS r.SAN _
i .ifi ,
1.18
1.18
1.18
1.13
TOTAL
D
i
.
. — =1
-^ r*
531.00
1 77 . ",.->
177.00
177.00
1,59"?. DO
KAUASKA CONSTRUCTION SERVICE INC.
2<* AFTER 30 DAY!
INVOICI
0610
-------
XAUA5XA CCiMSVaUCTiCN S2HV3C2 INC
PO BOX 4« KAU ASK A. MICHIGAN 49646 PHONE (6161 25 S-9134
CMMM MKVICI • HOAO funjHNO • MAiMT«HA»c« . Mc*v*TiNa fMAN HOGE8HEIOE JR. DENNIS HOGS8HE1DE
OOZER MHVIC* • COUII>MwAPTlTH WATER
TROH OP5N TOP TA1*!^, ',T ^-r TtTTO TIFCX7VP ^TT
^n. STAMPED TCK lZu«m
2.50 HOiniS U/TAKJCS3 TRK. START5:t) -.O.AbTrCr; i/ATKB FSnM" T>TTr
HAD 40-50 BBL ON. '/HEN S^'JT 3PHM. RETiniMSn Tm? N'FXT
DAY TO CONTIITCE ('A. •'?usHo•^;«^ TCT:-; •'sng
9 tf/TAwKER TSK. iA.'JvSp 600 BSL ?TT7ATFT? OFV TO sTJTl
^.T. fcor^TT *'•?•! rrr-: 1-5^4?
fi
?
i
!
\ "'
\ 1 R
riA oi.^,
i? <5S
«n..in
1 1 R
TOTAT
^~ /.*••" ^ »*
..z *
k'. -. .-* '* *
M T n 8 }®
^U« - "• '"
•:D
7c1^ MO
" on
7^3 "n
1 -v?S OM
.... r
~U i
.«
86
!
_J_l
KALKASKA CONSTRUCTION SERVICE INC.
-.' ._ - -- 1% AFTER 30DAYS
INVOICE
C-611
-------
Si.SViCi i.SC.
POBOX4* KALKASKA. MICHIGAN 49646 PHONE (616) 258-9134
CXANI SCMVICI • ftOAO •IHLDINO • MAWTONANC* • IXCAVATINC EMAN HOGERHEIDE JR
OOZIK MMVICf • (QUm««NT HANOUMS * MDI MIX
DENNIS HOGcRHEIDE
OIL ^I*»-D TWUCKIWO • SCPTIC SY3TCM3
,„„,„ SUN PXOBUCTIOM COMPANY ,— x P\ A1
P.O. BOX 999 / \ ^^ LC
THORIZED CLAY30RN HUNTER
CATION cvno** is 10
mv.«A« ;ji^LA^n. :-ti 456413 (_./ . . —
I naxfe. .--*••
•J/04/.36
•}/05/86
L:---. - -- ..--.• . DBCfllPTlQNw „ ........ ......... .,,......- ,
2.*;/TAiiKZa TRK. EA'JL'zD PIT:;AT5K TO DISPOSAL 150 S3L .J
(?.. SUSHON'G^ TCK 5514
3.50 HOURS W/TA:33H T3K. HAUL2D «'ATZ?. OUTGO? GAS BUSTER
3UC1CZD O'JT OP2S TOP TANK ix)'^ TO "TO. TCP^m OrT
VAT2A FSO:-! PIT. TIAUL2D TO ST«)
"/TAl^KEK TRX. HAULS 1 "..CAD PITfoATSR TO DTS?OSAL 15033'
DISPOSAL F2E OS 1ST LOAD 150 33L fl
- t r-f-^T-.
\ '• •:•'•*
1 -. /x a v»*J«J
i AVJU J ° u
\ -""^TTB ' ""
j r^-f^j:!!!.'.- J- """ "
— pwce -
1.13
i-'i.A dou
50.00
^ 1 1
-------
.XA5.CA CONSTRUCTION ScSVlCa INC.
POBOX4< KALXASXA, MICHIGAN 49646 PHONE (616) 258-9134
e»«N« um.ee - «OAO .U,U>.N« . «.«T«NA«ee • excAv»T,«o EMAN HOGERHEIDE JR. DENNIS HOGEUHEIOE
OOZCH sewvice • lOumwCNT MAMOUWO • ncoi MIX
on. rmui mjocina * seme STSTWMS
SOIDTO _
MJO«SS .
CITY & STATE.
SUi: PRODUCTION COZ1PXNT
999
AUTHORIZED .-~
BY '
LOCATION cjui£Ro:; 1-10
MDLAI.T). MI 4,°S40
\Cr
A 4566
OAIE. . . . DESCRIPTION**- . . PRICE- • K ----- fffffPUt™^ 1
h/U!/3'>
C/21/S5
S/21/U6
•J/L.i/36
o/t3/u6
d/:s/u&
4.50 rtOUT<3 V/TAC. T7C\. OAULZD 40 ddL FilrlSKT/ATER I:7TO LOC
TO GUM uT ;rLT; IN BRINE TAIfK, SUCIO^J CUT GO dBL ^"U2
^"D BLO:» Ii,TO A2S22VE PIT (D. 3TA1-IPER) TCK 11154
4.00 "CJ33 ,./7AC. lid;. ilAULZD GC tlL "^£jU;:ATKS. TO GTUi
ill? ..-'.ITJ Il< 37.1!l£ 7AV.K, LIAULcD Oi'F UO 3aL PITTv'ATSl TO
i}Tjr":iSAi. (if. 3T^.^E?.^ TCK Ilio7
5.50 iOuL->S w/'/AC. "ISA. LOADED 40 5BL "/iijiSii'.'ATSi Ai.15 \jl~Ai
i:;TO OT-Eil V\c. Ti^' Vi** «•• rs
111 AXU Aj :^--J.A J- '.ii-L, T.x .-CiJ LV/U& 1C ortU
(o. :TA:T?..-C) 'cr' inea
j.5J iroucis -V/TAC. -;-.tx. '^^HKJ LIIJEH A:.-D «-&.u:i -:••• PATCI
rL^r Sli/a 07 ^I.-iir.. SUCKED vf T;ArER F7.CT.1 vJT SIDE
lu^ULZi TO S"3 (K. S'JSHOKG) TCK 1124t;
2.00 auL'iiS '-f/VAC. T-'Jal, SUCiGD LT 10 3£L '.-i&ZZZ. I'XO.-i PIT
«'iilj«i FTL-IXO PIT, liAULZD TO J"-"t) ^R. ^USHC ••'}
^ p-^
L'Ucs. L.^^-ri ....... r p.
^ k £ i, c 1 V E D
UICPOS*-!. fiZZ Nar'ht n:-»rf.-t 120 &feU y
ou, - 1—
KMif A^KA^CDNStlTf f^TlQW-WB /ICE INC
fAT NOT UTSa tM*N
42.95
ftZ.95
D 42.95
42.95
4Z.05
42.95
.50
TOTAL
H3..M,
171.20
236.23
193. iU
•? ~ 2 •> ••>
05.90
6'J.O'J
1.176.7-
2% AFTER 30 DAYS
INVOICE
C-613
-------
vo
I
-------
ATTACHMENT D: CHAIN OF CUSTODY FORM FOR
SAMPLES SPLIT WITH SUN E&P COMPANY
C-615
-------
o
o\
o\
-------
imiKlcr OR FACILITY
SAMPLER
SAMPLE
Sun E&P Compc
PRESERVATION
Name:
Address:
FIELD: M};
Address: c
H
Signature:
. /fTufyre-
A»*l«c 3«r PROPERTY NO:
SAHPIE
NUMBER
LOCATION
DATE
TIME
SAMPLE TYPE
GRAB/COMP/OTHER
NO. OF
CONTAINERS
ANALYSIS
REQUIRED
REHARKS
1
«
f «^
RELINQUISHED BY (Signature)
2/
RECEIVED BY (Signature)
DATE
TIME
SHIPPED VIA:.
DATE:
FROM:
TO:
BILL NO:
ADDITIONAL REMARKS:
r^rf
****/ p+'^jm-rUtttt^ .
SHIPPED VIA:
DATE:
FROM:
TO:
Form No.
BILL NO:
ALL ANALYSIS PERFORMED BY EPA
APPROVED PROCEDURES
D YES [] NO
-------
C-618
-------
Sampling Report
Investigation of Powell Production, Inc.'s
Savarino and Stoll Well No. 6-21
Hillsdale County, Michigan
July 31, 1986
SITE INFORMATION
Site Selection
This site was randomly selected by EPA as described in the
sampling strategy document in Appendix B of the EPA Technical
Report (EPA 530-SW-87-005). This site was selected randomly from
a list of active Michigan Basin drill sites developed by the
Michigan Department of Natural Resources at the request of EPA.
The list was transmitted via telephone to the EPA contractor on
July 21, 1986. Randomization and site selection took place
during the telephone conversation.
The EPA contractor had no interest in the manner the particular
sites were listed (by site name, location, operator, permit
number, API number, etc.) as long as the site could be identified
in detail upon selection. Thus, the EPA contractor had minimal
information which kept to a minimum the amount of bias. No other
information was known about the sites on the list at the time of
selection. Detailed information was obtained only after
selection of primary and back-up sites.
The Department of Natural Resources listed the possible sample
sites by operator and county. The list consisted of four sites:
1. Hillsdale Co. - Powell Production
2. Hillsdale Co. - Patrick Petroleum
3. Jackson Co. - Adolf Roszeki
4. Otsego Co. - Northern Michigan Oil and Land
Company
As indicated above, the EPA contractor assigned numbers to the
members of the list as they were transmitted. A random number
table was used to select the primary and back-up sample sites.
The randomly-selected primary site was No. 2 on the above list
(Hillsdale Co. - Patrick Petroleum). No. 3 on the above list
(Jackson Co. - Adolf Roszeki) was selected as a back-up site in
the event the primary site was inaccessible or inappropriate.
Further inquiry identified the primary sample site as the Powell
Production lease in Moscow Township near Jonesville, Michigan.
Further inquiry indicated that the well was not near completion,
so the site was considered inappropriate for sampling.
The operator of the back-up site remained inaccessible during the
scheduling period. Although EPA contacted the operator one day
C-619
-------
prior to sampling, arrangements could not be made in time for
sampling on July 31, 1986.
A second back-up site was selected by a coin toss. The No. 1
site above (Hillsdale County - Powell Production) was selected.
Further inquiry identified the sample site as Powell Production
Incorporated's Savarino and Stoll Well No. 6-21. No problems
were encountered in arranging sampling for July 31, 1986.
Site Location
Savarino and Stoll Well No. 6-21 is located approximately 3,000
feet northwest of the intersection of Dennings and Sterling Roads
in Moscow Township in Hillsdale County, MI. Figure 1 is a map
indicating the drilling site. The full name and mailing address
for Powell Production is:
Powell Production, Incorporated
404 East Chicago Street
P.O. Box 184
Jonesville, MI 49250
Main Office Contact: Mike Nichols
Vice President of Lands
Phone: 517-849-2727
Attendees
Sampling at the Savarino and Stoll Lease site was performed by
CENTEC Corporation personnel on July 31, 1986. Following is a
list of people present at the time of sampling:
CENTEC Corp. (Sample Team): Bill Lane, Technician
Jamie Mclntyre, Team Leader
State Representative: Dave Davis, Geologist, Michigan
Geological Survey Division,
Rose Lake Field Office
Operator Representative: Mike Nichols, Vice President of
Lands
American Petroleum
Institute Representatives: George Holliday, Contracted
Observer
Lloyd Deuel, Contracted Sample
Team Member
Amy Crum, Contracted Sample
Team Member
Operator representative Mike Nichols arrived at the site at
approximately 2:00 p.m., after sampling was completed. He stayed
long enough to provide detailed information about drilling
activities.
C-620
-------
CO ; JACKSON
... 7
B—sjL._.-te:__ii._A..L-v—4
CO
Figure 1. Location of Powell Production, Inc.'s Savarino
and Stoll Well #6-21, Hillsdale County, Michigan
C-621
-------
Site Description
The Savarino and Stoll Lease site is located in rural flatland.
The climate at this site location is net precipitation. The soil
is described as a red clay bed under loam. The operator said
that a layer of "Marshal Sandstone" was reached at 385 feet
downhole. The well was completed in the Glenwood section of the
Prairie du Chieh formation in the Michigan basin. The operator
also called this the "St. Peter Sandstone." Figure 2 is a
survey of the exact location of the well.
This well was one of approximately 70 wells that were producing
in the Stoney Point field at the time of sampling. The wells in
this field range in depth between 4,200 feet and 4,600 feet.
The depth to the groundwater in the area is between 70 and 80
feet. The nearest surface water is Goose Lake, 4 miles east of
the site. The nearest drinking water wells are associated with
nineteen residences within a 1-mile radius of the site.
At the time of sampling, the site consisted of one reserve pit.
The drill rig and all associated equipment had been removed from
the site. The well head, located approximately 50 feet east of
the pit, is shown in Photo 4. Figure 3 is an approximate
schematic diagram of the site, indicating the directions in which
photos were taken (Attachment A).
This site was a developmental oil drilling site. The well was
completed at 4,360 feet. Drilling began on July 10, 1986 and
total depth was reached on July 19, 1986.
Drilling was accomplished with a fresh-water mud, a polymer mud,
and finally a saltwater mud. The following table summarizes the
products used during drilling:
Depth (ft}
0 - 385
Mud Type
Fresh-water
385 - 3600 Polymer
3600 - 4360 Saltwater
Constituents/quantity
8.3 Ib-fresh water/800 barrels
Montmorilonite (bentonite)/5,600 Ibs
Sodium carbonate/50 Ibs
Sodium hydroxide/100 Ibs
Shredded newspaper/100 Ibs
8.3 Ib-fresh water/800 barrels
Milo-gel (cornstarch)/700 Ibs
Salt-gel (atopulgite clay)/1000 Ibs
Quick Seal (cellophane and
straw)/100 Ibs
Floxite (flocculent and wetting
agent)/6 Ibs
400 barrels of polymer mud were
replaced with 400 barrels of
10.4 Ib-salt brine
C-622
-------
^—
$8*11 H0catt0n
POWELL PRODUCTION, INCORPORATED
Well Name and Number: Savarino - Stoll, 6-21
Location: Southeast 1/4 of Northeast 1/4 of Southeast 1/4 of Section 21,
Town 5 South, Range 2 West, Moscow Township, Hillsdale County, Michigan.
ETAsr-UesT 14 bus SECTION ai^
. * WORTH UUITLJUE
m
12
Q
S
/)
Hi
2
J
WOffTH
* lANJ 8'.;;
. <\ £u!r..-D
1 -— ACCESS r
O
SOUTH la LmeSecnaa2( * SOOTH
11 Pruduction, Incorporated
East Chicago Road
sville, Michigan 49250
9, 1986
-62
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William A. Worth, L.L.S. #19009
Figure 2. Survey of Well Site
C-623
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Chlorine was added to the fresh water before it was mixed into
the mud system.
The operator stated that a "slight loss of drilling fluid"
occurred during drilling in the Niagara formation, between depths
of 2,350 and 2,850 feet. The operator estimated that not more
than 150 barrels of fluid were lost over three days of drilling.
One lined pit was constructed onsite to provide temporary storage
of drill cuttings, residual drilling muds from the circulation
system, and miscellaneous trash. The pit contents were piped
from the mud circulation system over the apron of the pit liner.
The pit was in use as of July 10, 1986, and was out of service as
of July 19, 1986.
Construction requirements of the pit included a 20-millimeter PVC
liner, clearly visible in Photo 2. The sides of the pit were
required to have a three-to-one slope, and the depth could be no
less than 4 feet above the top of the groundwater in the area.
The operator used Everett Sparks Excavation in Jonesville, MI to
construct this pit.
The average depth of liquid in the pit was 2 feet, and the
average depth of the sludge was 1 foot. The distance from ground
level to the surface of the liquid was approximately 5 feet.
During the drilling operation, diesel was stored onsite in tanks,
although the operator could not estimate the quantity used during
drilling.
Disposal Practices
The liquid in the pit was to be vacuumed into a truck and hauled
to "Dean Center's" saltwater disposal well in Jackson County, MI.
Solids would remain in the pit, to be encapsulated by turning the
apron of the PVC liner into the pit, covering the pile with a
second PVC liner, and backfilling the pit. Prior to closing the
pit, a decision would be made whether to stabilize the solids
with kiln dust in order to make it a firmer mass. This is done
to prevent the soil over the pit from sinking in the following
years. The site would be restored to its original grade,
including adding fertilizer and top soil.
Permits
A copy of the drilling permit secured by Powell Production, Inc.
to drill the Savarino and Stoll Well No. 6-21 is located in
Attachment B.
C-625
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SAMPLING INFORMATION
Sampling efforts at this site followed the sampling procedures
and protocols for field sampling as outlined by the Sampling Plan
and Sampling Quality Assurance/Quality Control Plan in Appendix G
of the EPA Technical Report (EPA 530-SW-87-005).
Sample Point Locations
At the Savarino and Stoll Lease site, the samples were defined as
the supernatant and solid contents of the waste material in the
reserve pit.
The operator did not permit the sample team to enter the pit in a
boat. Therefore, the sample points were obtained by standing on
the side of the pit and reaching in with the sample equipment, as
shown in Photos 5 and 6. There was some discrepancy between
actual and measured sample points due to the inaccessibility of
the measured points. Figure 3 indicates the measured sample
points as well as the actual sample points from which the pit
samples were composited.
Sampling Methods and Equipment
To collect samples from the reserve pit, the pit was measured to
identify the four quadrants shown in Figure 3, and to locate the
center of each quadrant. The measured points were marked with
stakes to facilitate locating sample points.
The first sample to be collected was the liquid composite. The
thief was used by threading the gaging tape through a pipe,
attaching the thief to the end of the tape, and extending the
pipe over the surface of the liquid as far as the sampler could
safely reach. One sampler lowered the thief into the liquid, and
a second sampler pulled the string allowing the sample to enter
the thief. The liquid from each sample point was composited in a
5-gallon carboy.
The reserve pit was then sampled for sludge. The dredge was used
to sample the sludge because the coring device could have
possibly punctured the lining of the pit. Photo 5 shows samplers
tossing the dredge from the east side of the pit. Two full
dredges were obtained at each sample point, yielding a total
volume of approximately 4 gallons. The solids were composited in
a 5-gallon steel bucket.
The liquid and sludge samples were tested for pH after sampling
was completed. The pH was 7 for both samples. The liquid was
also tested for its free chlorine content. The result of the
test was immeasurable because the liquid bubbled out of the test
cell. The apparent chemical reaction caused by this test was
reported to the receiving laboratories.
C-626
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ATTACHMENT A: PHOTO DOCUMENTATION OF
SAMPLING ACTIVITIES
C-627
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C-628
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I Photo 1, Southwesterly view of reserve pit
Photo 2. Southerly view of reserve pit
*^-&-.--.-v.-.^.»:... ••^sai&ii'
Photo 3. Northerly view of reserve pit
Photo 4. Well head with reserve pit In background
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C-630
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Photo 8.
Large -.pudd.e" at southeast corner of p,t
Photo 9.
Bags of unused drj,,|flg ro(jd
Photo !0. Unused bag of -Magcog.l
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C-632
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ATTACHMENT B: PERMITS
C-633
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C-634
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DRILL G DEEPEN
REWORK OR C OPERATE A WELL
MAIL TO:
MICHIGAN DEPARTMENT OF NATURAL RESQUflCES U»
GEOLOGICAL SURVEY DIVISION
BOX 30028. *ANSING. MICHIGAN 48909
NON-SUBMISSION AND/OR FALSIFICATION OF THIS INFORMATION
MAY RESULT IN FINES ANO/OR IMPRISONMENT
BY AUTHORITY OF:
ACI Si PA 1939. » amended
On 4 G*s
Brine Ouoosal
Hyotoca'Oon Storage
Secondly Recovery
IB
ACI 31S PA >9o9. as a«r«nOed
Disposal SioiaM«
Brine
Test Welt Type
Smg'e
SUnkai
2 Application 10: (no fee requirea il permit is »ana)
. Deepen ~ Revise Application ^ Cancel and Transler
Convert 10
Fee enclosed:
i; No £ Yes
4 Qo prior permits ••lit''
X No !1 Yt» ". Drilled
tacTi permit
Surely Band-
X Blannet
Single Well
6. Fed. Employer Iflem No or Sac. Security No.
38-2390443
Attacned
File
9. Bond NO.
#4506292
10. Bond Amount.
S50.000.00
Applicant: (name eacn owner at tney are oorxleO)
Powell Production, Inc.
. _^
RELE.VEP
Address: (operatoToniy \l mere man one "owner")
404 E. Chicago St., P.O. Box 184
Jpnesville, Michigan 49250
Phone:
(517) 849- (aw lake
'3. Lease or we* name: (Oe aa anel aa posnoie>
SavarinoLStoll
# 6-21
Surla
David L. Stoll and Edith Stoll
'5. Address:
R. R. 13 Loogootee, Indiana 47553
LOCATE WELL AND OUTLINE UNIT
ON SECTION PLAT - s irOm . 3Mj»out control (Detail •outworn type. sit*, mm. rating, leaong. CMM
See attached Form R 7200-1-S1
intended Total Oeptn
4360'
29. Formation at Total Oeptn
Prairie du Chien
28.
Trenton-Slack River
27. Ooteowe Pool or FWM
Stoney Point
PROPOSED ORILUNQ, CASINO. CEMENTING AND SEAUNO PROGRAM
HOLE
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$end correipondenc* ind permit to: Address
hn R. Powell 404 E. Chicago St., P.O. BOX 184, Jonesville, Michigan 49250 (517) 849-2727
/ Ptrmn
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FOR CASHIER'S
FOR ONfl USE ONLY
Date issued
^«rfk«.
USE ONLY. OO NOT WRITE
Numoer
^LV2±
IN THIS SPACE
30. Appfccxdon Pr*0"*^ 8yt (Pwit) Pftonti
Michael P. Nichols (517) 849-2727
"^Mtf?l?^7fcjffi£?
1 M* '700-1
— C-635
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