United States
Environmental Protection
Agency
Industrial Technology Division	NOVEMBER 1985
WH-552
Washington, DC 20460
Water
Preliminary
Effluent Characterization
Study
Onshore Oil and Gas
Air Drilling Technology
Five Sites in West Virginia

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§ £% \	UNITED STATES ENVIRONMENTAL PROTECTION AGENCY
I xsffz ?	WASHINGTON, D.C. 20460
NOV I 51985
SUBJECT: West Virginia Five Site Study
Correction Sheet
FROM:	William A. Telliard, Chief
Energy & Mining Industry Branch
Industrial Technology Division^
TO:	Addressees
The following is a list of typographical errors in this
report that will be corrected for the second printing.
1.	Page i - 1st line: Delete the word "draft".
2.	Page 3 - 2nd paragraph, line 10: Insert the
following sentence. However, part of the
problem with reinjection is that there are
presently no commerical centralized rein-
jection facilities in West Virginia.
3.	Page 5 - 2nd line: Replace the word "three" for the
word "four".
4.	Page 6 - 3rd paragraph, 5th line: Insert the
words "a small" between the words "only"
and "number".
5.	Page 9 - 3rd paragraph, 2nd line: Delete the words
"four" and "five"; and, replace with the
words "five" and "six" respectively. Also,
delete the semicolon on that line.
6.	Page 11 - 2nd paragraph, 6th line: Delete the words
"Attachment F".
7.	Page 14 - 3rd paragraph, 1st line: Replace the "n"
in "Planger" with a "u" to read "Plauger".
8.	Page 28 - Table 8: All measurements are mg/1 unless
specified.
9. Page 33 - 2nd paragraph, 6th line: Replace the
number "53" with "36".

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-2-
10.	Page 34 - 1st paragraph, 5th line: Insert the word
"was" between the words "it" and "thought".
11.	Page 35 - 2nd paragraph, lines 2,4, and 17; 3rd para-
graph, lines 1 and 2; and Page 36, Table II:
Delete the "3" in every B0D35 so that the word
reads B0D5.
12.	Page 36 - 1st paragraph, line 6: Insert the word "are"
between the words "Table 8" and "adjusted".
- Last bullet on the bottom of the page: Replace
the "s" in the word "is" with a "f" to read "if".
13. Page 38 - 2nd paragraph, 4th line: Replace the word
"Attachment" with the word "Appendix".

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RESULTS FROM THE JOINT
PRELIMINARY EFFLUENT CHARACTERIZATION STUDY
FIVE OIL AND GAS EXTRACTION FACILITIES
IN WEST VIRGINIA UTILIZING
THE AIR DRILLING TECHNOLOGY
EPA/INDUSTRIAL TECHNOLOGY DIVISION
WEST VIRGINIA DEPARTMENT OF NATURAL RESOURCES
WEST VIRGINIA OIL AND GAS EXTRACTION INDUSTRY
NOVEMBER, 1985

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DISCLAIMER
The information in this draft document has been cooperatively
funded by the Environmental Protection Agency, West Virginia's
Department of Natural Resources and the participating oil and gas
companies. It has neither been subject to EPA's peer and
administrative review nor approved for publication. Approval
does not signify that the contents necessarily reflect the views
and policies of the U.S. Environmental Protection Agency, nor
does mention of trade names or commercial products constitute
endorsement or recommendation for use.

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TABLE OF CONTENTS
Page
Abstract	iii
Introduction 	 1
Background 	 2
-	Regulatory History 	 2
-	Air Drilling 	 5
Experimental Design .. 	 8
-	Objective 		8
-	Selection of Sampling Sites 		8
-	Pit Fluid Treatment Schemes 		11
-	Methods and Materials 		11
Results 	13
-	Site Descriptions	13
-	Drilling Materials Used 	 16
-	Data 	16
Discussion	32
-	Effluent Characterization 		32
-	Organics 	33
-	Inorganics 	34
-	Conventional and Nonconventional	35
-	Toxicity Tests (Aquatic Bioassays) 		36
-	Treatment Cost	37
Conclusion	38
Attachment A - Well History Questionnaire	A-l
B - Cost Questionnaire	B-l
C - Cabot-Kanawha Letter	C-l
D - Treatment Methods Utilized	D-l
E - Sampling Instructions 		E-l
F - Toxicity Testing Information	F-l
ii

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ABSTRACT
EPA's Industrial Technology Division (ITD), in conjuction with
West Virginia's Department of Natural Resources (DNR) and West
Virginia's oil and gas extraction industry conducted a five site
pollutant analysis of waste streams produced from the air
drilling technology. The purpose of this project was to begin an
effluent characterization of the waste streams produced from air
drilling because of West Virginia's DNR and industry contingent
concerns that the existing zero discharge BPT effluent limitation
guidelines for the onshore oil and gas extraction industry
subcategory did not directly address the air drilling technology
in the 1976 BPT oil and gas development document. As a result,
both parties believe that the drilling conditions (and effluents
produced) in their state are different enough to warrant EPA's
review of the applicability of the zero discharge requirement to
facilities in West Virginia. No policy determinations are made
in this technical report.
Composite samples were taken during different phases of air
drilling (i.e. spudding, cementing, fracturing) and after
different pit treatment schemes, i.e. neutralization, mixing,
aeration, and settling periods ranging from 1 to 21 days. Most
samples were analyzed for 27 inorganics. Fifteen samples were
analyzed for organic priority pollutants, cyanide, BOD, COD, TSS
and oil and grease. Methods used include EPA's methods 1624 and
1625 (organics) and 200.7 (metals). West Virginia DNR analyzed
specified samples for chlorides, conductivity, other
nonconventional pollutants, and conducted toxicity tests. Each
site had a well history questionnaire completed voluntarily by
the participating company. This form provides background
information on the drilling operation, location, products used,
and summarizes the treatment methods. The industry also
submitted treatment cost estimates for each facility.
EPA is utilizing the results of this study as a preliminary
effluent characterization assessment of the wastes produced from
the air drilling technology. The results are being used to
evaluate whether the BPT regulation for the onshore oil and gas
subcategory is applicable to the air drilling technology utilized
by the majority of oil and gas drilling operators in West
Virginia.
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INTRODUCTION
EPA, in conjuction with West Virginia's Department of Natural
Resources (DNR) and West Virginia's oil and gas extraction
industry conducted a five site pollutant analysis of waste
streams produced from the air drilling technology. The purpose
of this project was to begin a program to characterize the
effluent produced from air drilling. West Virginia's DNR and
industry members concern is that EPA did not adequately consider
the air drilling technology in the development of the BPT
regulations for onshore oil and gas facilities. As a result,
both parties believe that the drilling conditions (climate,
geology, well size, and disposal options) and effluents produced
in their state are different enough to warrant EPA's review of
the applicability of the zero discharge requirement to West
Virginia. No policy determinations are made in this technical
report.
This report describes the regulatory background that led to the
initiation of this project. It also describes what air drilling
technology is and why the West Virginia industry contingent and
DNR believe this drilling technology warrants special review.
Through the cooperation of the West Virginia's DNR and oil and
gas industry, EPA collected as much information as possible
regarding the drilling activities and the wastes produced at the
five selected sites. To this end the project was a success. As
presented in this document, comprehensive sample analyses were
conducted to determine concentrations of organic, inorganic,
conventional and nonconventional pollutants. In addition, the
industry supplied waste treatment costs and well history
information, while the state conducted toxicity tests (aquatic
bioassays).
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BACKGROUND
Regulatory History
On April 13, 1979 the EPA promulgated the Best Practicable
Technology Currently Available (BPTCA) Effluent Limitations
Guidelines for the onshore segment of the oil and gas extraction
industry point source category. This regulation has four
subcategories: onshore, stripper, wildlife and agricultural use,
and coastal. The onshore subcategory is the subcategory of
concern to West Virginia and is the subject of this study.
West Virginia's DNR received National Pollutant Discharge
Elimination System permitting authority on May 10, 1982. After
receiving permit authority, their State became aware that the oil
and gas extraction industry was not achieving the BPT onshore
subcategory zero discharge requirement for all wastes streams.
Another factor that contributed to West Virginia's involvement
with the oil and gas industry was an unexpected increase in
drilling beginning in 1982. The State shortly thereafter
contacted EPA to request guidance on how this matter should be
addressed. West Virginia expressed concern to EPA that air
drilling technology was the predominant drilling technology used
in the State and that this technology was not adequately
considered in the development of the BPT regulations for the oil
and gas extraction industry point source category.
The Agency acknowledged that the air drilling technology was not
directly considered in regulation development. EPA agreed to
participate in a cooperative study that would develop more
information about air drilling effluents. However, EPA's
agreement to participate in the cooperative study does not imply
that the wastes produced from air drilling are so different that
the zero discharge is not applicable.
Most of West Virginia's problems result from improper disposal of
pit fluids. The term "pit fluids" is used in this document as a
generic term meaning any fluids (connate water, wastewater,
foamants, defoamants, stimulation fluids ...) that are pumped
into an open earthen pit during air drilling operations. This
term is to be differentiated from the term "drilling fluids"
("muds") which refers to only those fluids that are primarily
comprised with such components as barite, bentonite (clays),
lignosulfonates and are used as the medium during the
drilling process instead of air, gas, or foam.
Members of West Virginia's oil and gas industry believe that the
existing zero discharge requirement is not applicable to their
geographical and technological drilling circumstances. They have
told EPA on numerous occasions that the development document's
guidance is insufficient for their circumstances. As stated,
guidance options included in the development document to achieve
zero discharge are reinjection, earthen pits (for evaporation),
road spraying, and land application. A discussion of each
guidance option as it is perceived by West Virginia's DNR and
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utilized by the oil and gas industry in West Virginia is
presented below.
Reinjection appears to be automatically dismissed as an option
state-wide because in many areas the underlying geologic
formations are supposedly not suitable (i.e., tight,
non-porous), and/or the cost of reinjection may be
prohibitive.
Presently, reinjection occurs at a few West Virginia oil fields
where secondary recovery techniques are being utilized. It is
also being used at a few drilling sites (for example-the Cabot-
Kanawha site in this study) where the pit fluids may be
reinjected to stimulate the well. Although the practice of
reinjection is not widely used in West Virginia at this time,
this fact does not mean that increasing its future use is
restricted. In fact, reinjection is still considered one of the
best permanent disposal options for certain wastes and specified
locations.
Preliminary research indicates a lack of state-wide data that
adequately reviews the cost of reinjection and reviews the
ability of West Virginia's geological formations to accept
reinjected fluids. In May 1984, the industry voluntarily
submitted reinjection cost information intended to illustrate,
based upon their own findings, that reinjection could possibly
reduce a companies profit margin thereby affecting the
industry by reducing the number of future investors.
Earthen pits are widely used because they are necessary for short
term storage of pit fluids. However, problems arise when the
earthen pits are used for long term storage. Several factors
prevent pits from being used for long term storage in West
Virginia. First, West Virginia has a reclamation law requiring
that the drilling site must be reclaimed within 6 months after
drilling is completed. Secondly, West Virginia is in a net
precipitation area. Thus these fluids will not normally
evaporate. In fact, if anything the pit volume will increase
over time. Third, fluids from pits that are located over fresh
water aquifers have the potential to cause groundwater
contamination through leaching. Fourth, these pits (even when
constructed properly), are not adequately designed for long term
storage. Pits breach either because operator error or because
the pit's construction was insufficient to hold the fluids even
for a short duration (six months). The latter problem includes
factors that should have been considered prior to construction
such as: poor estimation of the ultimate quantity of pit fluids
(i.e., producing a greater volume of fluids than the pit will
hold); not accounting for rainfall, runoff, and snowmelt entering
the pit; not lining the pit with plastic; and, not properly
digging the pit into the ground.
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Road spraying does not appear to be viable alternative for pit
fluids. Research in related areas (brines and stimulation
fluids) has shown surface damage of roads occurs and there is a
greater risk of environmental and human health effects.
Therefore, road spraying is not favorably considered as an
option.
Land application has been considered and is actively utilized by
West Virginia. Land application is favorable because it allows
the operator to be in compliance with the BAT zero discharge
requirement. Also, it allows for prompt convenient disposal of
treated pit fluids and permit site reclamation. There are some
drawbacks to land disposal of treated pit fluids. For example,
land application is not a viable alternative on rocky terrain
or when the ground is frozen. Also, it requires that the
operator be authorized to use the surface of the land for that
purpose. At this time, land applicable is deemed favorable
because no observed gross effects have been noted. However,
no data on the effects of land application for these fluids has
been made available. This is an important consideration to keep
in mind if planning to land apply on prime agriculture land
or over a shallow drinking water aquifer.
Since 1982, West Virginia DNR has been working closely with the
oil and gas drillers in their State to determine viable
alternatives for the permanent disposal of pit fluids. As a
result, a State/industry phased research program was initiated.
The purpose of this program was to collect information on the
constituents of pit fluids and to determine what treatment
options may be applicable.
As of October, 1984, 22 out of 25 test sites have land applied
the treated effluent. The remaining sites were allowed to
discharge into a stream. Throughout the entire program, West
Virginia has repeatedly asked for relief from the onshore
subcategory BPT requirements. However, the purpose of this study
was to learn about the air drilling technology and the wastes
products produced, and not to make policy determinations for West
Virginia.
EPA's Industrial Technology Division - ITD (formerly the Effluent
Guidelines Division in the Office of Water) currently is
reviewing data from this study and other information to determine
whether the effluents produced from air drilling differ from the
effluents produced from the drilling technologies that use other
drilling mediums (gas, drilling fluids) and whether the air
drilling technology (even if it is different and was not
considered in the development document), is capable of achieving
the zero discharge requirement.
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Air Drilling
Air drilling is the predominant method of drilling oil and gas
wells in West Virginia. Air drilling is favored for four main
reasons. First, the underlying geological formations are hard
rock and air drilling technology is the most efficient. Second,
West Virginia wells are generally considered shallow (3,000-6,000
ft) thereby not requiring the use of fluids to maintain
subsurface pressures. Air drilling may be used to drill deeper
wells if the underlying formations and subsurface pressures are
suitable. Third, the cost to drill a well using air is usually
much lower than for using drilling fluids.
In air drilling, compressed air is used to lift cuttings back to
the surface. Once the cuttings reach the surface, water is
injected into the cuttings return line for dust control. This
slurry of cuttings and water is deposited into an earthen waste
pit at the well site. Air drilling refers more to the medium
used for drilling than to the actual drilling process such as
cable or rotary drilling.
Before drilling can begin, a waste pit is constructed near the
proposed well site. Pit size varies considerably because of
terrain and operational techniques. An average pit has
dimensions of about 60 ft x 100 ft x 5 ft.* The use of
synthetic liners is not presently a requirement; however, the
operator is required by regulation to have an impervious
pit. Therefore, the use of synthetic liners is left to the
discretion of the operator; even though the state does encourage
operators to have waste pit bottoms covered with lime or mulch
before a thin (about 5 mil.) plastic liner is placed.
At the start of drilling operations the pit is usually dry.
Water is either trucked in or pumped from nearby streams for
injection into the cuttings return line for dust suppression or
for reinjection for fracturing. (Refer to the Cabot-Kanawha site
as a case example.) As the fresh water supply is depleted, pit
fluids can be circulated to replace the fresh water that was used
for dust suppression.
It usually takes 10-14 days to drill an average well in West
Virginia. Most wells are drilled into the middle to lower
Devonian formations, which are approximately 5,000 feet below the
surface. Within approximately the first 300 feet of drilling,
connate (or formation) water, is usually encountered. Foamants
and/or surfactants are used to remove the connate water from the
drill hole. Downhole water is coverted to foam, which is then
air-lifted out of the well. This foam is displaced through the
cuttings regurn line into the pit. Defoamants are added to the
pit fluid after foam is discharged into the pit.
*This number applies to an average that was computed from
approximately 16 sites visited in April, 1984 in West Virginia.
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When drilling is completed, the well may be stimulated to
encourage production. Fracturing is the stimulation process used
to crack the formation surrounding the trapped oil or gas in
order to increase the flow of gas into the well.
Some wells drilled in West Virginia use water to hydraulically
fracture the formation and stimulate the wells. Other fracturing
processes use foam, nitrogen, or a combination of these mediums.
Stimulation fluids are displaced into the pit after fracturing.
Water fracturing increases the amount of pit fluids compared to
the use of nitrogen to fracture a formation. The drawback to
nitrogen as a fracturing medium is higher costs and formation
structure. Hence, additional pits are often excavated in order
to contain the increased amount of pit fluid when water
fracturing is anticipated.
Once drilling and stimulation processes are completed, the pit
must, by state statute, be reclaimed within 6 months.
Reclamation includes razing the pit and seeding the area.
Prior to the state/industry effort to develop a general
permit in West Virginia there was an unacceptable high number of
pit failures. Breaching occurs because of excessive rainfall,
snowmelt, amounts of pit fluids used, and oeprator error.
Regardless of the cause of breaching, the result of the act
causes the release of pit fluids into the surrounding terrain,
sometimes reaching drainage or streams.
During the interim program only a smail percentage of pits of
all existing pits were treated and discharged following the
guidelines cited in the West Virginia Department of Natural
Resources (DNR) Interim Guidelines for oil and gas well
operations. This is because there were only number of operators
allowed to participate in the program. One of the reasons the
program was initiated was the fact that if the pit fluids are
left untreated and discharged in an uncontrolled manner,
environmental damage can occur.
Under West Virginia's Interim Guidelines, water is discharged
using land or stream application methods after the wastes are
neutralized and settled. In land application, the pH of the pit
fluid is raised from about 5 to between 8 and 10. The pH
is maintained and monitored at this level for 24 hours, then the
pit fluids are released onto the surrounding ground. The
same pH adjustment occurs when pit fluids are stream
applied.	In addition, according to the state's
guidelines, the discharge is metered into the stream at a 1:300
ratio to ensure state water quality standards are met.
After drilling, stimulation, and pit reclamation are completed,
the well is ready to start producing. Well sites consist of a
well head (Christmas tree), gas/liquid separator, and storage
tank. The separator is designed to "knock-out" produced water
and oil from the gas. Typically, produced water (brine) and oil
accumulates in the storage tank. The brine is apparently emptied
onto the surrounding ground, or hauled off, and the oil is
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periodically skimmed off and recovered. According to industry
sources, most fluid is produced during the first few months of
production; it consists mostly of fracturing fluids. After the
first few months, brine production is relatively constant,
averaging about 8.6 gallons/day per well. It is generally known
(but not documented) in West Virginia that brine production
increases with the life of the well. These fluids are supposed
to be collected in tanks and trucked to central locations where
they can be reinjected. However, since the DNR does not perceive
these fluids as a major concern, the disposal of these fluids is
not closely monitored.
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EXPERIMENTAL DESIGN
Objective
EPA's objective for the five site study was to gather information
about where air drilling technology is used, begin to assess any
generic characteristics of the effluent produced from the air
drilling technology, and to examine the effectiveness of several
pit fluid treatment schemes. The purpose did not include making
any assumptions on the accuracy of the data submitted by the
state or industry, but to present the facts as they were
supplied. Also, this study did not attempt to make any policy
decisions. Overall objectives were achieved through the
cooperation of West Virginia's DNR and their oil and gas
industry.
The role of the industry was to supply the Agency detailed
information on the costs of drilling and treatment, submit copies
of the drilling logs with the names and amounts of products used,
to supply background site specific information, and to assist
West Virginia's DNR sampling team when necessary.
West Virginia DNR's role was to coordinate the test program with
industry and EPA as to when and how samples were collected and
shipped; offer a training seminar for industry personnel, to
conduct toxicity tests (aquatic bioassays) on the effluent from
the five sites, and to analyze some samples for parameters of
particular interest to the state.
The Agency's primary role was to supply the contract support
required to have samples analyzed for the organic priority
pollutants, for 27 inorganics, and conventional pollutants.
Selection of Sampling Sites
In order of importance, the following list of criteria was
established to select sites.
1.	Wells that would begin drilling the first week of August,
1984 and would provide for impoundment of wastes for one
to three weeks prior to discharge.
2.	The sites should be geographically dispersed within the
state.
3.	The wells being drilled should represent a range of depths.
4.	The sites should illustrate different operator
practices; e.g., to determine how effluent quality values
with different fracturing procedures (i.e. water, nitrogen,
acid).
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During the site selection process, the above mentionned criteria
were considered. It was not possible to select sites based
solely on the selected criteria. Monetary constraints limited
the number of sites that could be tested. Moreover, the seven
week sample collection window also limited the number of
locations and types of operations that could have been used for
this study. Initially there were 16 sites. The final number
chosen was six, with only five of these sites submitting data.
Cabot-Kanawha apparently used its pit wastes as stimulation
fluids to fracture the well. It was considered the sixth site.
The letter included in Attachment C submitted to EPA from the
Cabot Oil and Gas Company documents this fact. EPA originally
learned that the pit was empty when the DNR state inspectors
arrived at the site to collect the samples. Even this "accident"
of reinjecting the pit fluids to fracture the well proved to be
beneficial to the overall objective of this project. This
incidient indicated that reinjection of pit fluids should not be
ruled out as a viable option to achieve zero discharge. It shows
that further research in this area is still needed.
Six sites involving four companies were chosen for this study.
The six sites are referred to in this report as follows:
1.	J&J/Kepco-Ritchie
2.	J&J - Barbour
3.	Chesterfield - Doddridge
4.	Union - Upshur
5.	Cabot - Putnam
6.	Cabot - Kanawha
Figure 1 is a map of West Virginia that shows each of the six
drilling locations. Note that four of the five counties; where
the selected sites are located, are within the 80 percent
drilling area for West Virginia shown on Figure 1. Table 1
provides additional information on drilling dates, pay zone,
depth, and the fracturing process.
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, / usiA
HAUMHtaC (, ^ * y{v I
WEST VIRGINIA
SCALE
9 ?'¦« » 3° <¦' MILES
X
)
v
FIGURE 1
Represents about 80% of total
permits to drill during 1979-82
(Heavily Drilled Area)
Represents the approximate
location of the drilling
site
DUPLICATING PRODUCTS CO., INC. No. 2 Virginia Street East, Charleston, W. Va.

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Well Operator
1
Union
Date	Date T.D.
County Spudding Stim. Comp. (ft) Pay Zone
Upshur 08/14/84 08/24/84	4200 Benson
2
J & J
Barbour 08/15/84 08/21/84	5400 Alexande
Benson-E
3 Chesterfield Doddridge 08/15/84 08/27/84	4600- Alexande
500 - Benson
4
Cabot
Kanawha 08/14/84 08/31/84	4200 Shale
5 J&J/Kepco Ritchie 08/22/84 08/30/84	5800 Alexande
Devonian
6
Cabot
Putnam	08/15/84 09/07/84	5400 Oriskany
Newburg
TABLE 1
Pit Fluid Treatment Schemes
Only on-site, low cost, conventional treatment schemes such as
skimming, neutralization, mixing, aeration, and settling were
considered for this project. Originally, there was supposed to
be a representative distribution of all different treatment
methods. As mentioned, that requirement changed when budget
constraints reduced the number of test sites. In addition, it
was determined that the best treatment would probably include all
of the stated methods with the only major variables being the
volume of pit fluid mixed and aerated, amount of lime needed to
neutralize the pit fluids and settling time. Therefore, of the
five sites only the Union site was different. At Union-Upshur
site only neutralization was performed. Another variable which
had to be considered was that each operator was allowed to use
their own drilling method and to select which additives to use
during the operation. Refer to Attachment D for a discussion on
the treatment methods utilized. Although each company was given
the option of disposing the treated pit fluids via stream
discharge or land application, all chose land application.
Methods and Materials
EPA supplied shipping and sampling instructions for DNR and
industry personnel to use. Sampling containers were cleaned and
shipped according to the instructions in Attachment E. Composite
samples were taken and documented according to Attachment E.
Organics were analyzed according to EPA methods 1624 and 1625
(Attachment F) and inorganics were analyzed according to the 200
series listed in the document EPA—0/4-79-020. BOD, COD,
cyanide, phenolics, TSS, and oil and grease according to Standard
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Methods	#507,
EPA—0/4-79-020 (Method
Standards	Methods
respectively. Samples
Virginia DNR personnel.
EPA—0/4-79-020	(Method	4103),
3352), EPA—0/4-79-020 (Method 420.1)
#2080,	and	EPA—0/4-79-020
were collected predominantly by West
There were a few instances where DNR was
unable to be on site at a particular time, thereby requiring that
an industry representative collect and ship the sample.
Treatment methods used are outlined in Attachment D.
Pit measurements by DNR personnel were taken using a measuring
tape. Measurements were taken from the water's edge to the
water's edge at each corner of the pit. No samples were
collected if an oil sheen was on the water surface. As a result,
there were instances when DNR officials did not collect a
particular sample. This sampling restriction may skew program
results. Other pit measurements and background site description
information was supplied to EPA by the industry.
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RESULTS
Site Descriptions
J & J, Kepco ^ Ritchie
1. J & J Enterprises, Incorporated, and Kepco,
Incorporated, jointly drilled well number WK-353 in Ritchie
County, West Virginia. It took the company 15-16 days to drill
and fracture the well. A combination of air and foam was
used to drill the well. The fracturing process used was
water with nitrogen assisting. Total well depth is 5995
feet. Pit fluids were recirculated for dust suppression.
A pit 40 ft x 100 ft x 3-4 ft was constructed on a 4 to 6
percent slope to the East and 3000 ft to the nearest stream.
(DNR officials measured the pit site to be 42 ft x 144 ft.) The
pit was neither prelimed nor lined with plastic. 2700 BBLS of
water were hauled 3 to 5 miles to the drilling site.
Approximately 52 BBLS of additives were used during the
operation. Total estimated pit volume when discharging was 1700
BBLS. This discrepancy in volume estimates highlights the severe
limitations of this study. At 778 ft a fresh water aquifer was
encountered. The amount of water displaced into the pit from
this fresh water aquifer is unknown.
Pit fluids were allowed to settle for 3 days prior to treatment.
Treatment consisted of pH adjustment, mixing, and aeration.
Mixing and aeration were done within 24 hours of each other. Pit
fluids were land applied after treatment was completed.
J & J 2 Barbour
2. J & J Enterprises, Incorporated drilled well number S-1042
on the Rexroad Farm in the Glade District in Barbour County,
West Virginia. It took the company 13 days to drill and
fracture the well. A combination of air and foam was used to
drill the well. The fracturing process used was foam with
nitrogen. Total well depth was 5550 ft. Pit fluids were
recirculated for dust suppression.
A pit approximately 100 ft x 40 ft x 3 ft-4 ft was constructed on
a 0-2 percent slope to the East. DNR officials when sampling
measured the pit size to 123 ft X 52 ft. The pit was built 500
ft from an intermittent stream. Neither preliming nor lining the
pit with plastic was utilized. 1500 BBLS of water was hauled
five miles to the drilling site. Approximately 28 BBLS of
additives were used during the operation. Total estimated pit
volume at the time of discharge was 1000 BBLS. (Note the
discrepancy.) Fresh water was encountered at approximately 164
ft. Amount of water displaced into the pit is unknown.
13

-------
Treatment consisting of pH adjustment (1400 lbs of hydrated
lime), mixing, and aeration (circulating the pit volume twice
with a 3-inch pump).
All of the treatment occurred 4 to 5 days after flow back was
completed. The pit fluids were allowed to settle for 17 days
prior to discharge. Pit fluids were land applied.
Chesterfield - Doddridge
3. Chesterfield Energy Corporation drilled the Planger #4 well
in Buffalo Calf Run, Doddridge County. It took the company 12 to
13 days to drill and fracture the well using a combination of
air and foam to drill, and water to fracture. The well was
5843 ft deep. The pit fluids were recirculated for dust
suppression.
A pit with the dimensions of 150 ft x 15 ft x 8 ft was built on a
30 percent grade and 3000 ft to the nearest stream. DNR
officials when sampling measured the pit size to be 156 ft x 13
ft.* The pit had a plastic liner but was not prelimed. 2300 BBLS
of water was hauled two miles to the drilling site from Buffalo
Calf, a local stream. Approximately 300 BBLS Of additives were
used during the operation. Total estimated pit volume when
discharged was 1700 BBLS. An aquifer producing a 1/4 inch stream
was encountered at 50 ft as well as a 1 1/2 inch aquifer at 230
ft. The amount of fresh water displaced into the pit from these
aquifers is unknown.
After flow back into the pit was completed the pit fluids settled
for 24 hours. Then the pit fluids, approximately 1700 BBLS, were
aerated and pH was adjusted using hydrated lime. Approximately
72 hours later an identical treatment procedure was repeated, 17
days later the pit fluids were land applied.
Union - Upshur
4. Union Drilling, Incorporated drilled well number 1941 in
the Banks District in Upshur County, West Virginia. It took
the company 14 to 15 days to drill and fracture the
well. A combination of air and foam was used to drill the
well. The fracturing process used was foam consisting of
water, sand, and nitrogen. Total well depth was 4350 ft.
Pit fluids were recirculated for dust suppression.
*This Chesterfield site had a pit failure. Due to unknown causes
the pit overflowed. Company personnel were able to build a
second pit downhill of the pit, approximately 180 ft
circumference, to catch the overflow while the first pit was
shored up.
14

-------
A pit approximately 80 ft x 40 ft x 6 ft-8 ft was constructed on
the downhill side of the well location. DNR officials when
sampling measured the pit size to be 144 ft x 54 ft,*116 1/2 ft x
33 1/2 ft, and 124 ft x 40 ft.** The nearest stream to the pit is
550 ft away, and feeds into the Little Kanawha River. The pit
was neither prelimed nor lined. 990 BBLS of water was piped from
the stream approximately 1600 ft to 1800 ft from the well.
Approximately 21 BBLS of additives was used during the operation.
Total estimated pit volume at the time discharge was 1200 BBLS.
A 1/2 inch fresh water aquifer was encountered at approximately
at 45 ft and again at 138 ft. Four quarts of drilling soap was
added for each 17 BBLS of water at a rate of 290 BBLS per day.
According to the well history submitted, drilling with foam
occurred 1-2 days.
Treatment began within 24 hours after flow back was completed.
Skimming, mixing, and pH adjustment was utilized at this site.
The pit fluids were land applied 22 days after treatment.
Cabot 2 Putnam
5. Cabot Oil & Gas drilled the Albertson-4 well in Putnam
County, West Virginia. It took the company 22-23 days to
drill and fracture the well. A combination of foam and
drilling fluids (muds) were used to drill the well. The
fracturing process used was foam. Total well depth was
5100 ft. Pit fluids were recirculated for dust suppression.
Two pits approximately 57 ft x 14 ft x 5 ft and 90 ft x 16 ft x 6
ft were constructed on moderate terrain. DNR officials when
sampling measured the pit sizes to 57 ft x 14 ft and 90 ft x 26
ft. The nearest stream to the well was 1/3 mile. Reinforced
plastic was used to line the pit, but preliming was not done.
1260 BBLS of water was hauled 1.2 miles from the Poca River to
the drilling site. Approximately 90 BBLS of additives were used
during the operation. Total estimated pit volume for both pits
at the time of discharge was 1470 BBLS. Fresh water was
encountered at approximately 196 ft. Amount of water displaced
into the pit from this fresh water aquifer was unknown.
Both pits were allowed to settle for 2 days prior to beginning
the treatment scheme. At that time, treatment consisted of
*This measurement was taken on the outer edge of the lip of pits
versus taking it from the water's edge.
**At 24-48 hours sample the size of the pit was 116-1/2 ft x
33-1/2 ft. Sometime between that sample and the 5-6 day sample
heavy rains occured there which substantially increased the pit's
size to 124 ft x 40 ft. However, by day 20-21 the water was back
to the original size.
15

-------
skimming, pH adjustment/ mixing, and aeration. Due to presence
of the circulated cement, only one of the pits required pH
adjustment. Pit fluids were land applied 8 days after treatment.
Cabot - Kanawha
6. No data was submitted on well number 3845 drilled by Cabot
Oil and Gas in Kanawha County, West Virginia since the pit was
empty when DNR officials arrived collect samples. Refer to
Attachment C for explanation.
Drilling Materials Used
Attachment A has a copy of a well history for the five drilling
sites. Included in the well histories are the names and amounts
of products used during the entire drilling operation. The names
of the products are such that except for the generic use
description not much is known about them.
Data
Tables 2 through 6 present the results of the 27 inorganics
analyzed by site and by treatment. These tables provide a
understanding of the efficiency of treatment by site. Table 7
lists the inorganics results by element and by treatment. Table
7 provides information on the inorganic effluent variability.
The organics, conventional, and nonconventional pollutant
analysis conducted by EPA contractors is presented on Table 8.
Table 9 lists all the organics compounds that were analyzed for
in the designated samples. Organic and conventional pollutant
results submitted by DNR and organic conventional pollutant
analyses conducted by their laboratories are listed in Table 10.
Well history and treatment cost information submitted by the
industry are found in Attachments A and B respectively.
16

-------
iJ/KEPCO-RITCHIE
TABLE 2

Sample No.
:87852
: 14246
: 14249


Stimulation
Raw Waste
6 days


Flowback
Untreated
Treated


Date: 9-13-84
Date: 9/13/84
Date: 9/19/84


ug/1
uq/1
uq/1

Calcium
6710000.
2470000.
3970000.
_ #
Magnesium
741000.
253000.
269000.
3.
Sodi urn
18200000.
5540000.
7950000.
".
Aluminum
1380.
15800.
8020.
.
Manganese
43200.
31500.
4000.
.
Cadmi urn
< 100.
< 100
< 100
7.
Vanadium
53.
63.
47.
R.
Boron
3810.
2230.
1700.
.
Bari urn
15400.
11000.
11900.
.
Beryl 1ium
< 10.
< 10.
< 10.
. ..
Lead
950.
< 500.
790.
12.
Molybdenum
< 200.
< 200.
< 200.
.
Tin
< 2000.
< 200.
< 2000.
.
Yitrium
< 100.
170*.
< 100.
.
Cobalt
< 100.
170.
< 100.
16.
Chromi um
< 40.
170.
50.
1 7
Copper
74.
50.
37.
>
Iron
480000.
393000.
41100.
.
Ni ckel
< 150.
< 150.
< 150.

Titanium
< 100.
< 100.
< 100.
21.
Zinc
900.
3140.
56.
,
Selenium
29.
21.
22.
.
Thai 1i um
23.
< 10.
< 10.

Si 1ver
< 1.
< 1.
< 1.
Zb.
Arsenic
143.
24.
44.

Ant imony
< 10.
< 10.
< 10.
•
Mercury
< 0.2
< 0.2
< 0.2
: 1425S
12 days
Treated
Date: 9/25/84
uq/1	
4030000.
274000.
8100000.
2720.
3130.
<	100.
<	40.
1530.
11200.
<	10.
500.
200.
200.
100.
100.
<	40.
<	20.
17800.
<	150.
<	100.
<	30.
24.
<	10.
<	1.
8.
<	10.
<	0.2
: 14254
Pit Discharge
Treated
Date: 9/25/84
ug/1	
3590000.
269000.
7230000.
3320.
3160.
< 100.
<	40.
1670.
11400.
<	10.
500.
200.
200.
100.
100.
<	40.
35.
21300.
<	150.
<	100.
<	30.
23.
<	10.
<	1.
9.
<	10.
<	0.2




TABLE 3




-BARBOUR







Sample No.
:87850
: 14260
: 14247
: 14257
: 14259
: 14252


Stimulati on
Raw Waste
4 days
6 days
21 days
Pit Discha


Flowback
Untreated
Treated
Treated
Treated
Treated


Date: 9/5/84
Date: 9/6/84
Date: 9/10/84
Date: 9/12/84
Date: 9/26/84
Date: 9/26


ug/1
ug/1
uq/1
uq/1
uq/1
ug/1

Calcium
6440000.
132000.
487000.
487000.
471000.
472000.

Magnesium
654000.
11700.
9280.
9420.
11000.
11300.

Sodi um
13700000.
258000.
567000.
573000.
556000.
555000.
i'.
A1umi num
576000.
14500.
1050.
641.
262.
447.

Manganese
135000.
6340.
905.
1060.
2310.
2370.

Cadmium
< 1000.
< 10.
< 10.
< 10.
< 10.
< 10.

Vanadi um
< 400.
8.
< 4.
< 4.
< 40.
< 4.
8.
Boron
3200.
214.
247.
239.
235.
252.
Q .
Bari um
86300.
861.
713.
702.
887.
906.

Beryl 11um
< 100.
3.
< 1.
< 1.
< 10.
< 1.

Leaa
< 5000.
132.
< 50.
< 50.
< 500.
< 50.
1<-.
Molybdenum
< 2000.
< 20.
< 20.
< 20.
< 20.
21.
13.
Tin
< 2000.
< 20.
< 200.
< 200.
< 200.
< 200.

Yi tri um
< 1000.
31.
< 10.
< 10.
< 10.
< 10.

Cobalt
< 1000.
108.
< 10.
< 10.
< 100.
< 10.

Chromi um
< 400.
18.
< 4.
< 4.
< 40.
< 4.
17.
Copper
1000.
66.
.3.
4.
< 20.
< 2.
1 °
Iron
2220000.
43400.
1960.
1310.
1720.
1820.

Ni ckel
< 1500.
28.
< 15.
< 15.
< 15.
< 15.

Titanium
< 1000.
< 10.
< 10.
< 10.
< 10.
< 10.
kl .
Zinc
3400.
323.
11.
7.
4.
6.
22.
Selenium
29.
< 5.
< 5.
< 5.
< 5.
< 5.

Thai 1ium
23.
< 10.
< 10.
< 10.
< 10.
< 10.

Si 1 ver
< 1.
< 1.
< 1.
< 1.
< 1.
< 1.
2-.
Arsenic
143.
13.
2.
< 2.
< 2.
< 2.
26.
Antimony
17.
< 10.
< 10.
< 10.
< 10.
< 10.

Mercury
2.0
0.3
< 0.2
< 0.2
< 0.2
4.
17

-------
CHESTERFIELD - DODDRIDGE
SAMPLE NO:
:87855
: 11231
Stimulation
Flowback
DATE: 8/10/81
-ifadi	
Raw Pit Wa.ste
Untreated
DATE: 8/30/81
	mil	
1.
CALCIUM
3770000.
705000
2.
MAGANESIUM
236000.
98500
3.
SODIUM
11800000.
2060000
4.
ALUMINUM
3090.
2690
5.
MANGANESE
29100.
17000
6.
CADMIUM
< 10.
< 100
7.
VANADIUN
< 20.
< 10
8.
BORON
3210.
1110
9.
BARIUM
5030.
1900.
10.
BERYLLIUM
< 1.
< 10
11.
LEAD
< 50.
< 500
12.
MOLYBDENUM
< 200.
< 200
13.
TIN
<2000.
<2000
11.
YITRIUM
<2000.
< 100
15.
COBALT
< 60.
< 100,
16.
CHROMIUM
< 11.
40
17.
COPPER
< 26.
20.
IB.
IRON
308000.
101000.
19.
NICKEL
11.
< 150
20.
TITANIUM
23-
< 100.
21.
ZINC
667.
667.
22.
SELENIUM
37.
< 5,
23.
THALLIUM
10.
< 10,
21.
SILVER
2.
< 1.
25.
ARSENIC
139.
11,
26.
ANTIMCNY
< 10.
< 10.
27.
MERCURY
< 0.2
< 0.
NES = not enouqh sample to analyze
0
:14258
5 days
Treated
DATE: 9/1/84
:87846
U dsys
Treated
DATE: 9/10/84
Ml/1	
:14256
21 days
Treated
DATE: 9/30/84
	
:11261
Pit Discharge
Tr*»at-fid
DATE: 9/20/81
-JilCl	
281000.
587000.
>80000.
562000.
31200.
83800.
62300.
80800.
555000.
1370000.
1010000.
1320000.
658.
109.
70"'.
550.
1050.
31 50.
2620.
3510.
< 10.
< 10.
< 10.
< 10.
< 4.
< 4.
< 1.
< 1.
266.
6 38.
462.
594.
512.
1170.
852.
1060.
< 1.
< 1.
< 1.
< 1.
< 50.
< 50.
< 50.
< 50.
< 20.
< 20.
< 20.
< 20.
< 20.
< 200.
< 200.
< 20.
11.
23.
13.
< 10.
< 10.
< 10.
< 10.
< 10.
5.
< 4.
< 4.
< 4.
7.
< 2.
< 2.
4.
956.
A 24.
1790.
1890.
< 15.
34.
18.
2<*.
11.
< 10.
10.
10
18.
< 3.
10.
8.
< 5.
< 5.
NE
-------
TABLE 5
UNION - UPSHUR
SAMFLE NO:
:87810
11250
: 11253
:8"»R#3
: 11263
: 8 7R6 3
Spudding
Raw Water
DATE: 8/11/81
	H3^i	
Raw Haste
Untreated
DATE: 8/27/81
—aadi	
2 days
Treated
DATE: R/29/81
_H3 C±	
7 days
Treated
DATE: 9/3/81
21 day3
Treated
Pit Discharge
Treated
DATE: 9/17/R1 DATE: "V17/P1
	H2£I_.
Ml/1
1.
CALCIUM
1900.
262000.
130000.
329000.
109000.
1610000.
2.
MAGNESIUM
718.
11000.-
172.
2560.
10100.
132000.
3.
SODIUM
1220.
139000.
168000.
122000.
838000.
5020000.
1.
ALUMINUM
381.
6920.
755.
37 10.
81.
790.
5.
MANGANESE
57.
3890.
5.
200.
5.
2290.
6.
CADMIUM
< 10.
<10.
<10.
< 10.
<10.
<100.
7.
VANADIUM
< 1.
< 1.
< 1.
< 1.
< 1.
< 10.
8.
BORDCN
10.
128.
1 17.
61.
02.
100.
9.
BARIUM
10.
1170.
1200.
1000.
787.
9 30.
10.
BERYLLIUM
< 1.
< 1.
< 1.
< 1.
< 1.
<100.
11.
LEAD
<50.
<50.
<50.
<50.
<50.
<500.
12.
MOLYBDENUM
<20.
<20.
<20.
<20.
<20.
<200.
13.
TIN
<20.
<20.
<200.
<200.
<200.
<200.
11.
YITRIUM
<20.
10.
<10.
< 10.
<10.
<100.
15.
COBALT
<10.
33.
<10-
< 1.
< 10.
<100.
16.
CHROMIUM
< 1.
< 1.
< 1.
< 1.
< 1.
< 10.
17.
COPPER
< 2.
< 2.
< 2.
< 2.
<20.
<200.
18.
IRON
1150.
19100.
16.
13.
11.
1300.
19.
NICKEL .
<15.
<15.
<15.
<15.0
<15.
<150.
20.
TITANIUM
<10.
<10.
< 10.
< 10.
< 10.
<100.
21.
ZINC
19.
66.
< 3.
< 3.
<30.
<300.
22.
SELENIUM
< 5.
< 5.
< 5.
< 5.
< 5.
12.
23.
THALLIUM
<10.
<10.
<10.
< 10.
<10.
< 10.
21.
SILVER
< 1.
< 1.
< 1.
< 1.
< 1.
< 1.
25.
ARSENIC
< 2.
1.
3.
< 2.
< 2.
151.
26.
ANTIMONY
<10.
<10.
< 10.
< 10.
< 10.
< 10.
27.
MERCURY
0.9
< 0.2
0.8
0. 5
< 0.2
< 0.2

-------
TABLE 6
CABOT - PUTNAM
SAMPLE NO:
:07853
Prior to
Spudding
DATE: 9/3/81
	M3£i	
:87818
Surface
Ca3tir.g
DATE: 9/12/81
	BlCl	
:8706<»
Stimulation
Flowhack
DATE: 9/21/81
		
1.
CALCIUM
70900.
1880000.
129000
2.
MAGNESIUM
19700.
632000.
101000
3.
SODIUM
23600.
1670000.
1090000
1.
ALUMINUM
3610.
1610000.
2230
5.
MANGANESE
2110.
33600.
5850
6.
CADMIUM
< 10.
< 1000.
< 100
7.
VANADIUM
5.
3000.
< 10
8.
BORON
65.
3990.
701
9.
BARIUM
115.
182000.
1030
10.
BERYLLIUM
2.
< 100.
< 10
11.
LEAD
< 50.
12800.
9750
12.
MOLYBDENUM
< 20.
< 2000.
< 200
13.
TIN
91.
< 2000.
< 200
11.
YITRIUM
11.
< 1000.
< 100
15.
COBALT
51.
1000.
110
16.
CHROMIUM
5.
1700.
1910
17.
COPPER
18.
1900.
160
18.
IRON
35700.
1120000.
91600
19.
NICKEL
115.
1700.
1100
20.
TITANIUM
< 10.
91700.
< 100
21.
ZINC
216.
29100.
5590
22.
SELENIUM
< 5.
30.
15
23.
THALLIUM
< 10.
< 10.
< 10
21.
SILVER
< 1.
< 1.
2
25.
ARSENIC
< 2.
123.
151
26.
ANTIMONY
< 10.
< 10.
< 10
27.
MERCURY
< 0.2
0.1
< 0
NES
= not enough sample to analyze
:11218
:87857
:87R12
:8786 2
Raw ifaste	3 days
Untreated Treated
DATE: 9/21/81 DATE: 27/81
	US.Lk	H9/1.	
920000.
1250000
39200.
38900
2190000.
33B0000
2160.
I860
1910.
960
< 100.
< 100
< 10.
< 10
311.
311
1120.
2330
< 10.
< 10
510.
< 500
< 200.
< 200
<2000.
<2000
< 100.
< 100
< 100.
< 100
62.
75
16.
50
29100.
18 300
< 150.
< 150
< 100.
< 100
210.
110
21.
NES
< 10.
NES
< 1.
NES
17.
NES
< 10.
NES
< 0.2
NES
7 dsys	Pit Discharge
Treated	Treated
DATE:10/1/81 DATE: 10/1/81
_hh1L		
1210000.
1080000
12300.
35500
3130000.
3710000
918.
852
2000.
781
< 100.
< 10
< 10.
6
180.
225
2300.
2220
< 10.
< 1
510.
283
< 200.
71
< 200.
<200
< 100.
< 10
< 100.
< 10
7190.
22
< 20.
17
13100.
11 100
2930.
< 15
< 100.
15
130.
121
NES
NES
NES
NES
NES
NES
NES
NES
NES
NES
NES
NES

-------
ft) CALCIUM
TABLE 7
ANALYSIS OF MAJOR PARAMETERS - 5 PIT SAMPLING PROJECT
EPA/W.VA DNR/W.VA INDUSTRY
uq/1
Stimulation
Flowback
uq/1
Raw waste
Untreated
uq/1
2-4 days
Treated
uq/1
5-7 days
Treated
uq/1
11-12 days
Treated
uq/L
20-21 days
Treated
1 - p
6710000
2470000
N/A
3970000
403000/3590000*
I C J - B
6440000
132000
487000
4B7000
N/A
3 - U
N/A
262000
430000
329000
N/A
;h - D
705000
3770000
N/A
201000
587000
: - p
429000
920000
1250000
1210000/1080000*
N/A
N/A
47 1000/472000*
409000/1610000*
4R0000/562000*
N/A
(2) MAGNESIUM
J - R
741000
253000
N/A
269000
274000/269000*
N/A
I 5 J - B
654000
11700
9290
9420
N/A
11000/11300*
J - U
N/A
14000
172
2560
N/A
10100/132000*
:h - D
2J6000
90500
N/A
31200
83000
62300/80800*
: - P
101000
39200
38900
42300/35500
N/A
N/A
(3) SODIUM
J - R
J - B
0 - U
Ch - D
C - P
18200000
13700000
N/A
1 1B00000
1090000
5540000
258000
<•39000
2060000
2190060
N/A
567000
46R000
N/A
33*0000
7950000
573000
U22000
555000
3130000/3710000*
8100000/9230000*
N/P.
N/A
1370000
N/A
N/A
556000/555000*
B3HO00/5020000*
1040000/1320000
N/A
•The Eirst number is from a sample taken directly from the pit. The second number Is from a sample taken tram the
discharged effluent.

-------
TABLE 7 (Continued)
uq/1 ug/1 tiq/1	uq/1	ug/1	ug/1
Stimulation Raw Haste 2-4 days	5-7 days	11-12 days	20-21 days
Flowback Untreated Treated	Treated	Treated	Treated
(4) ALUMINUM
to
NJ
J - R
1380
15800
N/A
B020
2720/3320*
N/A
J - B
576000
14500
1050
64 1
N/A
262/407*
U - U
N/A
6920
755
3710
N/A
81/790*
Ch - D
3090
2690
N/A
658
409
707/550*
c - p
2230
2160
1860
948/852*
N/A
N/A
(5) MANGANESE






J - F
43200
31500
N/A
0000
3130/3160*
N/A
J - B
135000
6340
905
1060
N/A
2310/2370*
U - U
N/A
3880
5
209
N/A
5/2290*
Ch - D
29400
17000
N/A
1050
3150
2620/3510*
C - P
5850
1910
960
2000/7R0*
N/A
N/A
(6) CADMIUM
J - R
<100
<100
N/A
< 100
<100/<100*
N/A
J - B
<1000
<10
<10
<10
N/A
<10/<10*
U - U
N/A
<10
<10
< 10
N/A
<10/<100*
Ch - D
<10
<100
N/A
<10
<10
<10/<10*
C - P
<100
<100
< 100
<100/< 10
N/A
N/A
(7) VANADIUM
J - R
53
63
N/A
47
<40/<40*
N/A
ffi
1
*
<400
8
<4
<4
N/A
<4 0/<4 *
u - u
N/A
<4
<4
<4
N/A
<4/<40*
Ch - D
20
<40
N/A
<4
<4
<4/<4 *
C - P
<40
<40
<40
<40/6*
N/A
N/A
~The first number is from a sample taken directly from the pit. The second number is from a sample t=iken from the
discharged effluent.

-------
TABLE 7 (continued)
uq/1
Stimulation
Flowback
uq/1
Raw Wa3te
Untreated
uq/1
2-4 days
Treated
uq/l
5-7 days
Treated
uq/1
11-12 days
Treated
uq/l
20-21 days
Treated
(9) BOFCN
J - R
3810
2230
N/A
1700
1530/1670*
N/A
J G J - B
3 200
214
247
23<*
N/A
235/252*
U - U
N/A
12P
117
64
N/A
42/100*
Ch-D
3210
iino
N/A
266
648
4 62/594*
C - P
701
3«1
311
1B0/225*
N/A
N/A
19) BARIUM
J - R
15400
11000
N/A
11900
11200/11400*
N/A
J - B
86300
861
713
702
N/A
887/906*
0 - U
N/A
1170
1200
1000
N/A
787/930*
Ch-D
5030
1900
N/A
512
1170
852/1060*
C - P
1030
14 20
2330
2300/2220*
N/A
N/A
(10) BERYLLIUM
J - R
<10
<10
N/A
<10
<10/<10*
N/A
J - B
<100
3
<1
< 1
N/A
<10/<1*
0 - U
N/A
<1
<1
< 1
N/A
<1/100*
Ch-D
<1
<10
N/A
< 1
<1
<1/<1*
C - P
<10
<10
<10
< 10/< 1*
N/A
N/A
(11) LEAD
J - R
950
<500
N/A
790
<500/
-------
uq/l
Stimulation
Flowback
TABLE 7 (continued)
uq/l ug/1	uq/l
Raw Waste 2-1 days	5-7 days
Untreated Treated	Treated
ug/1
11-12 days
Treated
ug/l
20-21 days
Trea ted
(12) MOLYBDENUM
J - R
<200
<200
N/A
<200
<200/<200*
N/A
J - B
<2000
<20
<20
<20
N/A
<20/21*
0 - U
N/A
<20
<20
<20
N/A
<20/<200*
Ch - D
<200
<200
N/A
<20
<20
< 20/<20*
C - P
<200
<200
<200
<200/7 1*
N/A
N/A
(13) TIN
to
J -	R
3 t	3
0 -	U
C -	D
C -	P
<2000
<2000
N/A
<2000
<200
<200
<20
<20
<2000
<2000
N/A
<200
<200
N/A
<2000
<2000
<200
<200
<20
<200/<200*
<200/<200*
N/A
N/A
<200
N/A
N/A
<20U/<200*
<200/<200*
<200/<20*
N/A
(14) YITRIUM
J - R
<100
170
N/A
<100
<100/<10f>*
N/A
J 6 J - B
<1000
31
< 10
< 10
N/A
<10/<10*
U - U
N/A
40
<10
<10
N/A
<10/<100*
Ch - D
60
<100
N/A
11
23
13/<10*
C - P
< 100
<100
<100
<100/<10*
N/A
N/A
(15) COBALT
J - R
<100
170
N/A
<100
<100/<100*
N/A
J - B
<1000
108
< 10
< 10
N/A
<100/<10*
U - U
N/A
33
< 10
< 10
N/A
<10/<100*
Ch - D
14
<100
N/A
< 10
<10
<10/<4•
C - P
110
< 100
< 100
< 100/<10*
N/A
N/A
•The first number is from a sample taken directly from the pit. The secor.d number is from a sample taken from the
discharged effluent.

-------
TABLE 1 (continued)
uq/1
Stimulation
Flowback
ug/1
Raw Waste
Untreated
uq/1
2-4 rlays
Treated
uq/1
5-7 days
Treated
ug/1
11-12 days
Treated
uq/1
20-21 days
Treated
(16) CHRCMIUM
J - R
<40
170
N/A

-------
TABLE 1 (continued)

uq/1
uq/1
uq/1
uq/1
uq/1
uq/1

Stimulation
Paw Waste
2-4 days
5-f days
11-12 days
20-21 days

Flowback
Untreated
Treated
Treated
Treated
Trested
(20) TITANIUM






J - R
< 100
<100
N/A
<100
<100/<100*
N/A
J * J - B
<1000
<10
< 10
<10
N/A
<10/<10*
U - U
N/A
<15
<15
<10
N/A
<10/<100*
Ch - D
23
¦100
N/A
11
<10
<10/<10*
C - P
<100
<100
<100
< 100/15*
N/A
N/A
(21) ZINC






J - P
900
3110
N/A
30/<56*
<30/30*
N/A
J - B
3100
323
11
7
N/A
4/6*
U - U
N/A
66
<3
<3
N/A
<30/<300*
Ch - D
667
64 4
N/A
19
<3
10/fl*
C - P
5590
2U0
1U0
130/12**
N/A
N/A
(22) SELENIUM
J - R
29
21
N/A
22
24/23*
N/A
J - B
29
<5
<5
<5
N/A
<5/5
U - U
N/A
<5
<5
<5
N/A
<5/4 2*
Ch - D
37
<5
N/A
<5
<5
N/A/<5*
C - P
15
21
N/A
N/A
N/A
N/A
(23) THALLIUM
J - P
23
10
N/A
10
10/10*
N/A
J - B
23
<10
<10
< 10
N/A
< 10/<10*
U - U
N/A
<10
<10
< 10
N/A
< 10/<10*
Ch - D
<10
<10
N/A
< 10
<10
N/A/<10*
C - P
< 10
<10
N/A
N/A
N/A
N/A
~The first number is from a sample taken directly from the pit. The second number is from a sample taken trom the
discharged effluent.

-------
(24) SILVER
TABLE 7 (continued)
uq/1
Stimulation
Flowback
ug/1
Raw waste
Untreated
uq/1
2-4 days
Treated
uq/1
5-7 days
Treated
uq/1
11-12 days
Treated
uq/1
20-21 d*ys
Treated
J -
R
< 1 <
N/A
<1
<1/<1*
N/A
J -
B
<1 <
< 1
<1
N/A
<1/<1*
u -
U
N/A <
<1
< 1
N/A
<1/<1*
Ch
- D
2 <
N/A
<1
< 1
N/A/<10*
C -
P
2 <
N/A
N/A
N/A
N/A
(2 5) ARSENIC
J - R
143
24
N/A
44
0/9*
N/A
J - B
143
13
<2.
<2
N/A
<2/<2*
0 - U
N/A
4
3
<2
N/A
<2/151.
Ch - D
139
11
N/A
<2
2.
N/A/<2*
C - P
15«
17
N/A
N/A
N/A
N/A
-o
(26) ANTIMONY
J - P
<10
<10
N/A
<10
<1f»/<10*
N/A
J - B
17.
<10
<10
< 10
N/A
<10/<10*
U - U
N/A
<10
<10
<10
N/A
<10/<10*
Ch - D
<10
<10
N/A
22
< 10
N/A/<10*
C - P
<10
<10
N/A
N/A
N/A
N/A
127) MERCURY
J - R
<0. 2
<0.2
N/A
<0.2
10.2/00.2* N/A
J - B
2.0
0-3
<0. 2
<0. 2
N/A <0.2/4.6*
U - U
N/A
<0. 2
o.n
0.5
N/A <0.2/<0.2*
Ch - D
<0. 2
<0. 2
N/A
N/A
0.9 N/A/<0.2*
C - P
<0. 2
<0. 2
N/A
N/A
N/A N/A
~The first
number is from a
sample take directly from
the pit.
The second number is
from a sample taken from the
discharqed
effluent.



-------
TABLE 8
ERA'S ORGANICS AND CONVENTIONAL DATA


2 - • days
S - 7 days
11 - 12 lays
20 - 21 diys
Pit
Untreated
Settling
Settllnq
Settli-H
Sp*t J t-a
Hunber/Ndme
Pit Fluids
Treated
Treated
?r*a*:pi

1. .1 - R
POD 2
370
264
—


COL)
3*00
30 SO
•-


CN
<0.02
<0.02
•-


CtG
96
1R
—


1SS
• IS
1600
-•


fhenolics
0* 09*
0. 137
--


Acetone
2690 uq/1
6169 uq/1
7«67 uq/1;


n - c,.
322 ug/1
Toluene: 132 uq/1
11«•39 uq/1*


U - C,4
13 uq/1
• •
--


h - c,.
200 ug/1
Phenyl: 7> uq/1
102 uq/1
12S uq/-


1S1
--
--


P*cy»ene
17
••
••


2. J - B





POD i
*9
	\\\
—


COD
261
SO
--


CN
0.01
<0.02
--


C6G
13
12
••


1SS
IS
3S
--


Fhenolics
<1.0
0.013
--

M*»t Interred
Acetone
836 uq/1
3220 uq/1
2236 uq/1

priority
Toluene
S2S uq/1

2S uq/1
*-C,0 31 uq/1
33 uq/1

pa! 1 «it a-t s
	
coo
OJ
OCG
1SS
Phenolic*
Acetone
Methylene Chloride
Ch
r?	
290
<0.02
9
28
0.006
3269 uq/1
2781 uq/1
IodJ
"TO	
• 300
<0.02
19
72
0.079
129 uq/1
¥9 uq/1
•7 uq/1
25 uq/1
~Ti	
3*0
<0.02
11
• S
<0.005
1630 aq/1
1689 ug/1
H-C30: 21 aq/X
46
•6 5
<0.02
10
IS
0.022
Acetate 3777 iq/1
Toluene 1299 uq/1
COD
O)
Ot G
1SS
Pbenollca
¦aphthalane
»-C,.
»-c.»
»-C,0
feor^
COD
CN
06 G
tss
Phenollea
Phenol
*-C,»
P-C« »
"T33	
2200
<0.02
7
2S0
0.057
2* uq/1
268 uq/1
11 uq/1
Acetone: 1959« u}/l
Taluene: 52# u^/l
38 uq/1
100 uj/1	*0 uq/1
Acetane 10357 oq/1 7601 uq/1
¦ana discharge
28

-------
TABLE 9
LIST OF THE ORGANIC COMPOUNDS
ANALYZED IN SELECTED SAMPLES
1.
ACENAPHTHENE
19.
BIS (2-CHLOROETHOXY) METHANE
37. DIBENZOFURAN
2.
ACENAPHTHYLENE
20.
BIS (2-CHLOROISOPROPYL) ETHER
38. DIBENZOTHIOPHENE
3.
ACETONE
21.
BIS (2-ETHYLHEXYL) PHTHALATE
39. DIBROMOCHLOROMETHANE
4.
ACROLEIN
22.
BIS (2-CHLOROETHYL) ETHER
40. DICHLORODIFLUOROMETHANE (NR)
5.
ACRYLONITRILE
23.
BROMODICHLOROMETHANE
41. DIETHYL ETHER
6.
ALPHA-TERPINEOL
24.
BROMOFORM
42. DIETHYL PHTHALATE
7.
ANTHRACENE
25.
BROMOMETHANE
43. DIMETHYL PHTHALATE
8.
B-NAPHTHYLAMINE
26.
BUTYL BENZYL PHTHALATE
44. DIPHENYL ETHER
9.
BENZENE
27.
CARBAZOLE
45. DIPHENYLAMINE
10.
BENZIDINE
•
00
CSJ
CARBON TETRACHLORIDE
46. ETHYLBENZENE
11.
BENZO(A)ANTHRACENE
29.
CHLOROBENZENE
47. FLUORANTHENE
12.
BENZO(A)PYRENE
30.
CHLOROETHANE
48. FLUORENE
13.
BENZO(B)FLUORANTHENE
31.
CHLOROFORM
49. HEXACHLORO-1,3-BUTADIENE
14.
BENZO(GHI)PERYLENE
32.
CHLOROMETHANE
50. HEXACHLOROBENZENE
15.
BENZO(K)FLUORANTHENE
33.
CHRYSENE
51. HEXACHLOROCYCLOPENTADIENE
16.
BENZOIC ACID
34.
DI-N-BUTYL PHTHALATE
52. HEXACHLOROETHANE
17.
BIPHENYL
35.
Dl-N-OCTYL PHTHALATE
53. HEXANOIC ACID
18.
BIS (CHLOROMETHYL) ETHER (NR)
36.
DI BENZO(A,H)ANTHRACENE
54. INDENO(1,2,3-CD)PYRENE

-------
TABLE 9 (continued)
55.
IS0PH0R0NE
77.
PHENOL
99.
1,4-DICHL0R0BENZENE
56.
METHYLENE CHLORIDE
78.
PYRENE
100.
2-BUTAN0NE
57.
N-DECANE (N-C10)
79.
STYRENE
101.
2-CHL0R0ETHYLVINYL ETHER
58.
N-DOCOSANE (N-C22)
80.
T-l ,3-DICHL0R0PR0PENE
102.
2- CHLORONAPHTHALENE
59.
N-DODECANE (N-C12)
81.
TETRACHLOROETHENE
103.
2-CHLOROPHENOL
60.
N-EICOSANE (N-20)
82.
TOLUENE
104.
2-METHYL-4.6-DINITR0PHEN0L
61.
N-HEXACOSANE (N-C26)
83.
TRANS-1,2-DICHLOROETHENE
105.
2-METHYLPYRIDINE
62.
N-HEXADECANE (N-C16)
84.
TRICHLOROETHENE
106.
2-NITROPHENOL
63.
N-NITROSODI-N-PROPYLAMINE
85.
TRICHLOROFLUOROMETHANE (NR)
107.
2,3,6-TRICHLOROPHENOL
64.
N-NITROSODIMETHYLAMINE
86.
VINYL CHLORIDE
108.
2,4-DICHL0R0PHEN0L
65.
N-NITROSODIPHENYLAMINE
87.
1,1-DICHLOROETHANE
109.
2,4-DIMETHYLPHENOL
66.
N-OCTACOSANE (N-C28)
88.
1,1-DICHLOROETHENE
110.
2,4-DINITROPHENOL
67.
N-OCTADECANE (N-C18)
89.
1,1,1-TRICHLOROETHANE
111.
2,4-DINITROTOLUENE
68.
N-TETRACOSANE (N-C24)
90.
1,1,2-TRICHLOROETHANE
112.
2,4,5-TRICHLOROPHENOL
69.
N-TETRADECANE (N-C14)
91.
1,1,2,2-TETRACHLOROETHANE
113.
2,4,6-TRICHLOROPHENOL
70.
N-TRIACONTANE (N-C30)
92.
1,2-DICHLOROBENZENE
114.
2,6-DINITROTOLUENE
71.
NAPTHALENE
93.
1,2-DICHLOROETHANE
115.
3,3'-DICHLOROBENZIDINE
72.
NITROBENZENE
94.
1,2-DICHLOROPROPANE
116.
4-BR0M0PHENYL PHENYL ETHER
73.
P-CYMEME
95.
1,2-DIPHENYLHYDRAZINE
117.
4-CHL0R0-3-METHYLPHEN0L
74.
P-DIOXANE
96.
1,2,3-TRICHLOROBENZENE
118.
4-CHL0R0PHENYL PHENYL ETHER
75.
PENTACHLOROPHENOL
97.
1,2,4-TRICHLOROBENZENE
119.
4-NITR0PHEN0L
76.
PHENANTHRENE
98.
1,3-DICHLOROBENZENE



-------
TABLE 10
SUMMARY OF CONVENTIONAL AND ORGANIC DISCHARGE DATA
DNR DATA OP PIT EFFLUENTS
Pit Number:	'	I	J	'	i
County:	l • H	J-B	u - u	-h - B	c - P
Treatment System:	N/M/A/S*	N/K/A/S*	N	N/*/A/S»	l»/«l/A/R*
(20 iay3)	(21 days)	(8 days)	<21 days)	<7 lays)
Effluent characteristics:
BODS, mq/l
COD, mq/l
IOC, mq/l
Dissolved Solids mg/1
Total Suspended Solids, mq/l
Total Phenolic Materials, ug/1
Oil £ Greass, «q/l
pH, s.U
Conductivity, whoa/ca
Dissolved Oxyqen, mq/l
Acidity, mq/l
Chloride, mq/l
fltgeuls-toelxati;	
Benzene, uq/1
toluene, uq/1
Ethylbenzene, uq/1
p-xylene, uq/1
•-xylene, uq/1
o-xylene, uq/1
Diethyl Phthalate, uq/1
Bis|2-ethylhexyl) Phthalate, uq/1
Di-n-Butyl Phalate, uq/1
Acetone, uq/1
Phenol, uq/1
196
232i
876
• 0969
7,1
2000
1.5
6.8
52400
1.6
5
25250
Hot analyzed
•
25250
125
•N/N/A/S » neutralization, nixing, aeration, lettlini
Dioasuy Test	LCS0"95K Low
Acute Toxicity
B5
267
29 3
3168
70
150
4.0
7. 1
1990
3.0
1
1880
Sample was not
analyzed for
organic pollu-
tants
1840
»
No toxicity
demonstrated
28
264
25
178 39
121
100
<1
6.6
27700
4.8
11000
6.6
14.0
2. 4
1.7
10. 3
6. 3
Not analyzel
Not analyzed
IT50«13. 251
Very Hlqh
Acute Toxicity
212
1073
760
6688
71
tooo
2
6.9
9680
5.1
4
3450
1727
700
19860
513
160
2.5
6.8
29800
3.0
3.0
11200
16.6
• 29
2.3
3.9
8.7
4.7
4.0
20.3
6.9
Not analyzed
V3t analyzed
LC50»85* Low
Acute Toxi-
city
16
Not analyz
7600
37.9
LC50-12.75
Very Acute
Toxicity
Concentrations of iron In the effluents from pit Nos. 3 and 5 were relatively hiqh compared with the preriischar^e ettluer
limitation for iron of 7 nq/1. Nate, however, that this effluent limitation was not In effect durlnq these pit treat-
ability studies. Hlqh concentrations of lroi may be responsible (at lesst partly) for the very hiirh acute toxicity ot th
effluents.
orqanic analysis for Ha. 1 and 2343 were carried out by DNR laboratory and for No. 3 and 5 were carried out by in
EPA contractor	'

-------
DISCUSSION
Effluent Characterization
When discussing the site selection process for this project, it
was mentioned that the two main limiting factors were the lack of
money for sampling analysis and sample collection time. These
affected the scope of the project. Instead of each participating
company having two or three drilling sites, only one site was
included in the study. The result was that there was no
systematic variation of treatment schemes or operational
differences, thus there was no accurate means to objectively
compare sites. Treatment effectiveness could only be assessed by
comparing differences in the pollutant levels of the untreated
effluent to the final discharge effluent from site to site. Too
many variables were introduced between locations to make
definitive statements about the results. However, since the
purpose of this project was to perform a preliminary evaluation
of the effluent produced from the air drilling technology, it was
within the purview of this project to receive a full range of
possible pollutant concentrations due to operational and site
variations. The project's intent was to also give an indication
of the pollutant parameters that may have to be monitored.
Indices would be determined from resulting trends that occur from
the organic, inorganic, conventional, and nonconventional
pollutant analysis.
For example, one of the major operating differences noted is the
amount of HC1 and KC1 used at a given site (which affected the
final chloride content in the treated effluent.) None of the
existing treatment methods adequately removed or even
significantly lowered the chloride level.
Guidelines need to be established pertaining to the treatment
scheme to better define when oil skimming is conducted and
whether a sheen is allowed for land application. As described by
one of the DNR sampling personnel, oil sheen was another
important variable between the sites. At several sites the slick
was considered severe enough by the sampling personnel that
sampling was aborted.
The trace carbon chained organic priority pollutants are assumed
to be the result of soluble hydrocarbons from oil and grease in
the pit fluids. The presence of acetone and toluene are being
attributed to the degradation (i.e. redox potential) of various
unknown complex organic carbon chain compounds present in
the pit fluids when treatment begins.
Metals are contributed to the effluent by the drill cuttings,
bentonite (when used), cement and any other mineral or clay used
during the drilling operations. The metals found in these items
by themselves are not to be considered detrimental to the
environment until the pH of the pit fluids are significantly
lowered to pH range of 1 to 3 units. This occurs because of the
32

-------
assortment of acids and stimulation fluids used. Acidic fluids
are known to dissolve metals thereby changing their ionic state
to a bioavailable form. Also, the metals can be accumulated in a
stable state and then can potentially become bioavailable (i.e.
barium) inside the organism. That is why the amount of lime used
and the length of time the pH is maintained is so important to
these pit fluids. The neutralization process can reverse the
previously mentioned chemical reaction thereby "dropping" the
metals out of the tested effluent.
Although the protocol and the laboratory handling of the raw data
and final results for the toxicity tests (aquatic bioassays)
conducted need to be reexamined before future testing is done,
the toxicity tests results did reveal that there are some unknown
toxicants at three of the five sites that still need to be
researched. Refer to page 53 for a detailed discussion of
toxicity testing conducted.
Based on this project, differences between air drilling and mud
drilling include:
1.	Overall the volume of the fluids used and produced with
air drilling as well as the size of the earthen pits are
much less. However this fact is not only a function of
the drilling medium used but the depth of the well.
2.	Weighting agents such as barite (which normally
comprised approximately 60 to 90 percent of a mud system)
are not used in air drilling. Air drilling does use
foamants and defoaments that might not have to be used with
mud drilling. However, there are instances, where an
operator air drilling may have to use drilling fluids
because of drilling conditions.
3.	Generally, the number of additives used during air drilling
is considerably less because the drilling operation (as a
function of depth and underlying geological formations) is
simpler. Few drilling complications are usually encountered
as a result.
Organics Pollutant
As shown in Table 8, untreated and treated samples were analyzed
for organic priority pollutants and a few Section C organics.
The table only lists the names and amounts of those chemicals
detected. Only those compounds detected by the EPA 1624 and 1625
methods are listed in Table 8. The entire list of organics that
were tested for is shown on Table 9. Other non-priority
pollutant chemicals may be present but until more information is
collected on some of the specific surfactants, foamants,
defoamants, and stimulation fluids, no conclusions can be drawn.
This point is mentioned because the toxicity data provided by the
state (which will be discussed later) showed that 3 out of 5 pits
contained some unknown toxicant. As will be discussed, it is
33

-------
possible that the toxicity directly correlates with the amount of
chloride ions present, and are not due to priority organics.
Of the organics detected, the presence of acetone and toluene is
interesting because it appears to be a byproduct of the treatment
and degradation process. At first it was thought that since
acetone is a common laboratory solvent, that the samples could
have become contaminated in the laboratory during sample
analysis, from various glassware used. As a result, it thought
this occurrence accounted for the presence of acetone. However,
the contracting laboratory was contacted and subsequently told
the Agency that it was not the case with these samples. Later,
EPA agreed with the laboratory when it was further observed that
the detection of acetone not only occurred during the treatment
process at four of the five sites, but that the appearance of
acetone in samples was not random as it should have been if
contaminated from the glassware. Trends were actually observed.
According to studies conducted by EPA's ORD laboratory in
Cincinnatti and the Office of Emergency and Remedial Response*,
the amount of acetone generated from these sites should not in
themselves be a concern, however just the fact that these
compounds are being made during the treatment of these pits
should be researched further. The carbon chain compounds are
attributed to the presence of residual oil mixed into the pit
fluids after skimming. The data is presented in Tables 8 and 10.
Inorganic Pollutants
As stated, 27 inorganic elements were tested for this study.
Tables 5-6 present the results by site, while Tables 7 present
the results by element. Tables 2-6 present overall treatment
efficiency by site, while Table 7 is used to determine the range
of detected individual elements by site and treatment. Of the 27
elements tested (of which 24 were metals) tested, As, Ba, Bo, Ca,
Cu, Fe, Mg, Mn, Na, and Zn, consistently appear in the untreated
effluent in elevated amounts. After treatment, elevated levels
of all these elements still appear except for As, Cu, and Zn. As
and Zn appear to be treated prior to discharge.
Several existing effluent limitation guidelines such as the Coal
Mining, Ore Mining and Dressing, and Metal Finishing Point Source
Categories all rely heavily on the effectiveness of lime and
settle treatment methods to remove metals. Metal removal
efficiency, when using lime and settling techniques is dependent
on the amount of lime added (how high the pH is raised), the
characteristics of the effluent being treated (quantities of
pollutants present), the length of time that the elevated pH is
*EPA 1984. Technical Background Document to Support Rulemaking
Pursuant to CERCLA Section 102. Prepared by Rockwell
International Corp. Volume I: August 10.
34

-------
maintained, the length of the settling period, and external
factors such as weather conditions and runoff.
Conventional and Nonconventional Pollutants
Results of the conventional and nonconventional tests are
presented on Tables 8 and 10. Ranges for BOD, COD, TOC, TSS,
dissolved solved solids and oil and grease for the treated
effluent at the five sites are 28-212 mg/1 (BOD5 - Table 10),
14-320 mg/1 (BOD5-Table 8), 264-2325 mg/1 (COD - Table 10), 50-
3050 mg/1 (COD-Table 8), 25-876 mg/1 (TOC-Table 10), 70-753 mg/1
(TSS-Table 10, 35-1-0 mg/1 (TSS-Table 8), 6688-40968 mg/1
(dissolved solids - Table 10, 1-4.5 mg/1 (oil and grease - Table
10), 10-18 mg/1 (oil and grease-Table 8) respectively.
It is general knowledge that elevated chloride (greater than 1000
ppm CI) will interfere with BOD35 and COD tests. Since all five
sites had discharged chloride ranging from 1800 ppm to 25,000
ppm, concern was raised as to its effect on the BOD35 and COD
test results. As a result of the concern about chloride
interference, EPA's contractor conducted a side experiment to
determine the effects of chloride on the BOD35 test. From the
information supplied by the industry it was determined that the
two main chloride contributors during the drilling process were
from the additives HC1 and KC1 that are used to fracture the
well. Moreover, it was concluded the KC1 seems to be the factor
most concern since three of the five sites that used KC1 in the
drilling process not only had the highest chloride levels, but
also appeared to have the most toxic effluent. The toxicity of
the effluent can not be categorically correlated to the presence
of chloride from KCL but it is a significant possibility.
Therefore, the contractor chose to use KCL to set up the BOD35
tests with 1,000 ppm CI, 5,000 ppm CI, 10,000 ppm CI, 20,000 ppm
CI, and 30,000 ppm CI.
A glucose/glutamic acid BOD35 standard was also set up as the
control. Between laboratories, the BOD35 result that should be
recorded from this standard is 200 + 36. The results of the
experiment produced are presented in Table 11.
35

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Results - Effects of CI on BOD
Concentration
BOD 3 5
Percent
Suppression
Control
1000 ppm CI
5000 ppm CI
195
129
114
108
102
18
0%
33.9%
41.%
44.6%
47.7%
90.8%
10,000 ppm CI
20,000 ppm CI
30,000 ppm CI
TABLE 11
This experiment was a simple series of CI concentrations giving
an indication of the percent suppression that can be expected.
More data points are definitely needed to determine statistical
significance but the trend is obvious. The COD test used for
this study have been corrected for chloride content according to
this data. The COD results presented on Table 8 adjusted for
high chloride levels.
Toxicity Tests (Aquatic Bioassays)
Summary results from toxicity tests conducted on all five pit
fluid effluents are listed on Table 10. The protocol used and
the types of tests done are shown in Attachment F. As previously
stated, the information provided on the toxicity tests (aquatic
bioassays) conducted have been useful in showing possible HC1 and
KC1 usage trends between sites as well as showing that the
components of air drilling effluents are not totally understood.
However, the use of these tests results is limited because both
the test protocol and the laboratory handling of the data need
refinement. Information that could be used to determine whether
the results provided are valid was not submitted. This study is
not determining whether the results are valid, it is just stating
that future studies should include the information listed below.
This additional information is not only important for acceptance
of the test procedure and results but will provide additional
information on the tested effluent.
o Range finders and definitive tests should be conducted.
o DO and pH meaturements should be taken during the test (or
at a minimum when the test begins and ends).
o State whether aeration had to be utilized, is so, why.
36

-------
o The numbers of animals per test per replication should
be listed.
o Raw data showing percent mortality per concentration
per replicate should be provided.
o Control mortality data and the allowable percentage should
be provided before repeating the test.
o Quality assurance factors (for example reference toxicant
test results) should be provided.
o Documentation that GLP (Good Laboratory Practices) are
utilized is necessary.
o Rationale as to why the species used was chosen (i.e.
most sensitive species, indigenous species, availability) is
needed.
o Rationale behind using carbon absorption in some of
the experiments is needed.
o Statistical method(s) used to calculate the LC50 should
be referenced. State whether methods included Abbots
correction.
o Any observations, such as turbity and an oil sheen, that
could have affected the final results of the tests should be
included.
As previously stated, these are suggestions that would increase
the confidence of submitted toxicity test results as well as
provide additional information on the tested effluent. ITD is
interested in toxicity data if it can be used to better
characterize an effluent such as that produced from the air
drilling technology.
Treatment Costs
Even with the assumption that the industry supplied data from the
five wells more than adequately reflects the true cost of
treatment; the costs ranged from $1300 to $2,500 per site for the
program participants. Thus, average treatment costs account for
approximately 0.5 percent of the total cost (using $250,000 as
the average air drilling costs). This cost leaves room for
either improving the treatments presently being tested or allows
room for other move extensive treatment technologies to be
considered.
37

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CONCLUSIONS
Although this five site project was a successful collaboration
between the EPA, West Virginia's DNR, and the participating oil
and gas companies drilling in West Virginia, more data is still
required to complete an effluent characterization of wastes
produced from air drilling technology. This study attempted to
collect as much information as possible on all aspects of the
drilling operation and effluent through sample analysis and
questionnaires. On this point, the project was successful
because of the cooperation of all interested parties. However,
it is considered an unfortunate but uncontrollable happenstance
that budgetary constraints restricted the scope of the project.
The effectiveness of the treatment methods currently used to
other technological treatment methods is not possible since other
treatments were not evaluated. Some organic priority pollutants
and Attachment C compounds were detected in the treated effluent,
although the extent to which they are of concern could not be
determined. Elevated metals levels and high chloride levels were
demonstrated. Toxicity tests performed on the effluent indicated
that there are one or more waste components in the effluent
(either individual products, inefficient treatment process, or
down-hole contamination) that exhibit significant concern. This
finding warrants further research to isolate the cause.
Although the study was successful in providing preliminary
toxicity and effluent characterization information, a more
comprehensive effort is required for definitive analysis. All of
West Virginia pits have to be drained in order to reclaim.
38

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ATTACHMENT A

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Permit No. 47-085-7015
well Operator Kepco, Inc.
Well No. «v.w
Location	m
wr
Name, Title, and Telephone No.
of Person Completing Form:
Martin Puskar, Kepco, Inc., 436 Blvd of Allies
Pittsburgh, Pa. 15219
(412) 391-7760	:
WASTE PIT SAMPLING PROGRAM
WELL HISTORY
Date	Activity or Milestone Event	Additive/Quant.
8-20-84
Beqan Clearing Brush for Location
8-25-84
Began Building Pit
R-27-84
Finish Buildign Pit
B-28-84
Move in Drilling Rig - Spud Well
8-29-84
Drilling @ 610' - Dusting Hit Fresh Water @ 778' 55 gal AP50 Soap
8-30-84
Cement 1800 8 5/8" casing Bentonite Gel 1000#
Bulk Cement 350 sks
Calcium Chloride 1000#
8-31-84
Drilling @ 2488' - Dusting
9-1-84
Drilling @ 3638' - Dusting - Shut Down - Holiday
9-5-84
Drilling @ 5039' - Dusting
9-6-84
TD Well @ 5995", Cemented 4V casing Bulk Cement 183 sks
Pozmix A .182 sks
Bentonite Gel 600#
Salt 1748#
Flocele 91#
9-12-84
PERFORATED & FRACTURED - 2200 BBL of fresh water used.
MATERIALS:
HCL Acid 2000 gal., 15-N 80 gal., AQF-1 40 gal., WG-12 1700#,
KCL 17000#, 20/40 Sand - 950 sks, 80/100 sand - 50 sks., Nitrogen
375,000 SCF
Water was
trucked from nearby stream. Fracture zones were Rhinestreet Shale,
Alexander, Benson & Riley.
9-13-84 thru 9-18-84 Service Rig swabbed well, had a slight film of oil on pit.
A-1

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Well Operator 	re.Pro tmp
Well No. wv-?^
Location P-jf-rhio PrMinf-y, fly	
Name, Title, and Telephone No.
of Person Completing Form:
PneVa^ Vopz-o ( Tnr f	y^
nf	'IK", Pi ¦!-¦>-ct-mrgVi P3 Tj?1Q
	1Q1-T7Rn	_
WASTE PIT SAMPLING PROGRAM
PIT HISTORY
Date	Activity or Milestone Event	Additive/Quant.
8-25-84
Begin Building Pit

8-27-84
Finished Building Pit
500 BBL. Fresh Water
8-28-84
thru 9-6-84 Well Being Drilled
55 gal. AP-50 Soap
9-12-84
Well Fracked

9-13-84
Well Flowing Back after Frac

9-13-84 thru 9-16-84 Service Rig Swabbing Well
- Pit Adjustment -
9-16-84	Ph Adjustments	1400 # Hydrated Lime
9-16-84	Mixed Pit with 3" Pump Vol. - 1700 BBLS. - 8 Hrs.
9-17-84	Aeration of Pit with 3" Pump Vol. - 17CO BBLS. ~ 8 Hrs.
9-25-84	Pit Discharged - Vol. - 17 UU BBLS. - 6 Hrs.
Pit Approx. 40' wide X 100' long 3-4' deep
Pit constructed on slope of 4-6% to East
Nearest Stream approx. 3000 Ft.
A-2

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WELL/PIT HISTORY SUMMARY SHEET	Permit No.	47-085-7015
Name, Title, Telephone of
Person Completing Form:
Martin Puskar, Kepco, Inc. 436 Blvd.
DRILLING of the Allies, Pittsburgh, Pa. 15219
Date drilling began 8-26-84 (412) 391-7760
Date drilling completed 9-5-84	
Quantity of fresh water brought to well site?	500 BBL.	
Source Stream	Distance from well site to source 3-5 Miles
Additives used (list with quantities):*
55 gal AP-50 Soap	Calcium Chloride 1000 #
Bentonite Gel
1600 #
Pozmix "A" 182 sks., Flocele 91#
Bulk Cement
533 sks.
Salt 1748 #
Fresh water encountered during drilling? X Yes 	No
Salt water encountered during drilling? 	Yes x No
FRACTURING/STIMULATION
Fracturing/stimulation dates: 	9-12-84	
Fracturing process used: Water frac with Nitrogen assist	
Fracturing/Stimulation chemicals used (list with quantities)
Acid - 2000 gal. 15% HCL	 Potassium Chloride 17000 #	
Gel 1700 # (WG-12)	Gel Breaker	40 # (GBW-3)
Non-Emulsifier - 80 gal. (15-N)	Nitrogen	375,000 SCF	
Surfactent Foamer 40 gal. (AQF-1) 2200 BBL Fzack Water Sand 1000 sks
Was this well acidized? 	Yes x	No
Type, concentration, and amount 	
PIT
Pit dimensions? 40' length, 100' width, 3-4' depth
Is the pit lined? 	Yes y No If yes, type of lining?	
Is the pit prelimed? 	Yes v No
If so, lime quantity	
Pit treatment (describe treatment process, amount of chemicals
used, how chemicals introduced):*
Trflafmcnf i nr-1 mi v-i ng aaratinn anH Ph mntrnl liging a V' pnmp and HyHrafpri
T-i 	- 14Pn a Hyrira+oH T-i mo iicpH				
Pit Liquid Volume - 1700 BBLS.
Pit treatment date(s):	tt,n, q-i%b^	
Was pit fluid recirculated for dust suppression? y Yes 	No
On what dates? b-29-84 thru q-s-84	
*If more space is required, please use back of form
A-3

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3V-35	Data I0-1S-B4		
(Rev 8-81)	Operator's
t si JBtsi ^Irgirtia w®11 Mo- W1-3S3	
^ipisinnd if ^Hinn	J i Bcndimkfti—
AJntSu jBrufebm *" No._47_-_£^	- 7015
WELL CFEWflCR'S KUUU'
OF
npTTJ/mr^ gatrrnRPc JtfC/OR STPiULftTING, OR PHYSICAL OtftNCE
WELL TYPE: Oil / Cm t / Liquid Injection / Waste Disposal /
(If "Gas," Production * / Underground Storage / Deep / Shallow y /)
LOCATION r Elevation: 1199.70 Watershed Bunnell Run		
District; Clay	COunty Ritchie	Quadrangle Pennaboro 7.5
COMPANY Kfpco. Inc.
MOBESS4V, »Wi. of th, MH>«. Titta. Pa 15219
BESIOWH) Igw r. T.. Sfimrf	
AEORESS Bex 1550 Clarkabure. WV 2630)
SURFACE CWEJt J. Hendtrahot «t. al.
ALuhfc&S 100 Victor Ave. Ant. 3 Davton. OH 45400
KD4SWL RIQCS OdNER J. Henderihot et. al.
AmxtaS 100 Victor Ave. Apt. 3 Dayton. OH 4S400
OIL AJ© GAS INSPECTOR FOR THIS WORK Sanur]
Heratnan AltllttSSBox 66 Snithville. WV 26 171
PERMIT ISSUED June 22. 1984
DRILLING COMMENCE)
August 28- 19B4
Uhni.TNC UfffliflVlJ September 5. 1964
ZF APPLICABLE: PLUGGING OF DRY HOLE ON
CONTINUOUS PROGRESSION FROM DRILLING OR
REWORKING. VERBAL PEJWISSICN OBTAINED
ON	
Caging
Tubing
Used in
Drilling
Left
in Well
Oorent
fill up
CU. ft.
Size
20-16



13-10"
20
0

9 5/8



8 5/8
1800
1800
350 ik
7



5 1/2



4 1/?
5990
5990
365 »ks
3



2



liners
used






(2DL0GICRL TAKET FCSMKTICK Rhineatreet Shale
Depth of completed well 3999 feet Rotary
ttater strata Oepth: Fresh 776 feet: Salt_
Q>al seam depths:	^ported	
CRN I10W DMA
Depth 5288
feet
Cable Tools_
feet
Zs coal being mined in the area? no
Riley	S877 5278
Producing formation shale. Alexander. Benaon. Pay rcne depth 4947 4634
Oil:
feet
Gas: Initial open flow_
Final open flow
94 1
_Mcf/d
Mef/d
Initial open flow 0 Bbl/d
Pinal open flow	0 Bbl/d
Tine of open flow between initial and final tests
Static rock pressure.
hoars
1650
psig(surface neasuranent) after 48
Uf applicable Ate to mltiple eorrpletixm—)
Secoiii producing formation pay sane depth
Gas: Initial open flow	Mcf/d Oil: Initial open flow
hours shut in
feet
Bbl/d
Final open flow_
_Mef/d Oil: Final open flow
Bbl/d
Tine of open flow between initial and final tests_
Static rock pressure	psiq (surface measurement) after_
hours
hours shut in
(Contime on reverse eide)
A-4

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torn IV-35
(REVERSE)
DETAILS Ct PDTOVOTD INTERVALS, FWCTURDC OR STWULMUC, PHYSICAL OtANGE, ETC.
Perforated 9-12-84 Perfco Wireline Co
*634 - 4649 Avg. Press 1930 psig Avg. Rate 24 BPH
4947 - 5002 Avg. Press 2300 psig Avg. Bate 26 BPH
5278 - 52B7 Avg- Press 2300 psig AVg. Bate 24 BPH
3677 - 5976 Avg. Pre** 2700 psig Avg. Bate 32 BPH
Fractured 9-12-84 Halliburton Service* - WaterFrac with litrogen Asaist.
let stage 17500 lbs. 20/40 sand
2nd stage 30000 lbs. 20/40 sand
3rd stage 25000 lbs. 20/40 sand
4th stage 22500 lbs. 20/40 sand, 5000 lbs. 60/100 sand.
HQ1 IDG
fowoton color hafd or soft
top rnr
BOTTOM RET
KHMWS
Including indication of all frt
and salt water, coal, oil and a
Red Bock and Shale
0
15

Sand
IS
95

Sandy Shale
95
165

Shale
165
215

Bed Bock
215
275

Shale
275
325

Sandy Shale
325
425

Shale
425
530

Sand
530
575

Shale and Bed Bock
575
678

Sand
678
700

Shale and Red Rock
700
1210
Fresh Water 9 778'
Sand
1210
1230

Sand end Shale
1230
1605

Sand
1605
1660

Sand and Shale
1660
2003

Big Line
2003
2042

Big Injun
2042
2197

Berea
2566
2571

5th Sand
2974
2987

Speechley
3516
3572

Riley
4634
4648

Benson
4946
5002

Alexander
5278
5288

Shale
528B
5999
Total Depth
(Attach aaparat* ihsats at tweeaaary)
Rg^rq. jnc. 	Chief Geologist
¦tor
gy: b-JjtXDt'S
Date: October 15. 1984
Note: Regulation 2.02(i) provides ae follous:
Tht ttrm 'log* or '«til log' jihalZ swan a tyaUmatic
.fr toiled geological record of all formations, including
mcuntered in the drilling of a u*2Z."
A-5

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yermit No. 47-001-2125
Well Operator T pnfcrpr;coc Tn^
Well NO.	3.1042	
L°C3tion 	Harbour County, WV	
Name, Title, ana Telephone No.
of Person Completing Form:
F.dward F. Summer field		
Permit tine; S. Reclamation Supervisor
nn41 47?-9403	;	
WASTE PIT SAMPLING PROGRAM
WELL HISTORY
Date	Activity or Milestone Event	Add itive/Quant.
8-9-84
Cleared area & started location and pit

8-17-84
Started Drilling - Spudded well
500 BBLS. Fresh Water
Drilling @ 164 Ft. - Hit Fresh Water	55 gal. AP 50 Soap
8-19-84
Dusting @ 865
Ft.


8-19-64
Cement 8 5/B"
@ 899.10 Ft.
265 sks. Bulk
Cement



Bentonite Gel
400#



Calcium Chloride
700#



Flocele
66#
8-20-84	Drilling @ 2000 FX. - Dusting
8-21-84
Drilling @ 4000 FT. - Dusting



8-22-84
TD Well @ 5550 - Cemented 4V casing
Bulk Cement
315
sks


Pozmix A
315
sks
Bentonite Gel, 25 sks.
Calcium Chloride 3318 #
Flocele	157 #
Flo-Chek-P	900 #
8-29-84	PERFORATED & FRACTURED - 1000BBLS. Fresh Water used
MATERIALS: Mod-202 20.2% Acid 1000 gal., AQF-1 40 gal., WG-12 150#, BA-2 20#
CLA-STA B 6^ gal., Ferechek 50#, Losurf-259 4 gal., HAI-60 2 gals.
20/40 Sand 805 sks., Nitrogen 395, 000 SCF
Water was trucked from nearby stream - Fracture Zones were Haverty & Elk
9-10-84	thru 9-13-84 Service Rig Swabbed Well
A-6

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- .1 fc .1 Enterprises. Inc.
Well NO. 	j-1042	
Location Rarhnur County. WV	
Name, Title, and Telephone No.
of Person Completing Form:
Mi-	F diinmprfipld	
Parmiffing fc Porlamatinn Supervisny
t> n Rnv 4Rr BupVtiannon. WV 26201
(304) 472-9403
WASTE PIT SAMPLING PROGRAM
PIT HISTORY
Pate	Activity or Milestone Event	Additive/Quant.
8-9-84	Pit Constructed
8-17-84	Drilling Began	500 BBLS. Fresh Water
8-18-84	Drilling Continued	55 gal AP-50 Soap
8-22-84	Drilling Completed
8-24-84	Well Tracked
9-4-84	Flow Well after Frac
9_9_84 **	Pit Treated - Ph Adjusted	1400 # Hydrated Lime
9-9-84	Mixing Pit - Turned over 2 times Vol.-1000 BBLS. -7 Hrs.
9-9-84	Aeration of Pit Volume - 1000 BBLS. — 5 Hrs.
9-26-84	Pit Discharged Volume - 1000 BBLS. - 8 Hrs.
.** - 3" Pump used in Pit Treatment, Mixing & Aeration
Pit approximately 100' long by 40' wide by 3'-4* deep.
Pit constructed on flat terrain 0-2% slope to the East.
500' to nearest stream (intermittent)

-------
WL LL/PIT HISTORY SUMMARY SHEET	Permit No. 47-001-2125 (j-1042)
Name, Title, Telephone of
Person Completing Form:
Edward F. Summerfield 472-9403
DRILLING	Permitting & Reclamation Supervisor
Date drilling began 8-17-84	
Date drilling completed 8-22-84	
Quantity of fresh water brought to well site? 	500 bbls.	
Source Stream Distance from well site to source 5 Miles
Additives used (list with quantities):*
55 gal. AP50 Soap		580 sks Bulk Cement	
Bentonite Gel 3718 #		Flocele 223 # - Pozmix "A" 315 sks
Calcium Chloride 700#
Fresh water encountered during drilling? X Yes 	No
Salt water encountered during drilling? 	Yes x No
FRACTURING/STIMULATION
Fracturing/stimulation dates: 8-28-84
Fracturing process used: Foam Frac with Nitrogen
Fracturing/Stimulation chemicals used (list with quantities)
AQF-1 40 gal. Ferechek
• ^
50#
WG-12 150# Losurf-259
4 gal
BA-2 20# 1000 BBLS. fluid -805 sks 20/40
sand
ClaSta-B 6 gal.
Was this well acidized? Yes X No

Type, concentration, and amount mod-202 20.2%, 1000 gal.

PIT
Pit dimensions? mn -t-o-r- length, 40' + or- width, 3_a_i_±arL___depth
Is the pit lined? 	Yes _x	No If yes, type of lining?	
Is the pit prelimed? 	Yes y No
If so, lime quantity 	
Pit treatment (describe treatment process, amount of chemicals
used, how chemicals introduced):*
Treatment included mixinp. aeration and Ph control using a .V' pump and 1400 #
of Hvdrated Lime-Pump Rate 12 Hrs. Pit turned over twice.	Pit liquid volume
1000 BBLS.		
Pit treatment date(s):	9-9-84	
Was pit fluid recirculated for dust suppression? x Yes 	No
On what dates? 8-17-84 thru 8-22-84	
*If more space is required, please use back of form
A-8

-------
JV-35	^ —"S	Date September 14.1984
(Rev 8-81)	Operator's
ghdz nf Pesi Piigtma "ell No. J-1042
^Brparlmrid vi ^imi Farm—
(Bit ant Gat J3h)ision ^ NO. 47 ~ OQl — 2l?<;
WEIL OPERATOR'S REPORT
OF
PFTT.T.TNG, fracturing and/or stimulating, or physical change
WELL TYPE: Oil / Gas* / Liquid Injection	/ Waste Disposal	/
(If "Gas," Production * / Underground Storage	/ Deep / Shallow x /)
LOCATION: Elevation; 1590	Watershed Gladv creek	
District; Glade	County Barbour	Cteadr angle westorviiu
COMPANY	JtJ Enterprises, Inc.	
^nnPF^S P.O. Box 48, Buckhannon, WV 26201
DESIGNATED V^KTr Richard Reddecliff	
ADDRESS ,p-0. Bo* 4e< Buckhannon, WV 26201
SURFACE ONER Vorlev S, Ruth Rpxroad	
ADDRESS 1174 Dale View Drive. McLean, Va. 22102
KlNiIKAL RIGHTS CWNEIR	Same as surface
ADDRESS	
OIL AND GAS INSPECTOR FOR THIS WORK Russell
Beall	ADDRESS P.O. Box 160. Philippi. WV
PERMIT ISSUED 8/6/84	26416
DRILLING C0M-ENCED 8/17/84	
DRILLING COMPLETED 8/22/84	
IF APPLICABLE: PLUGGING OF DRY HOLE ON
CONTINUOUS PROGRESSION FROM DRILLING OR
REWORKING. VERBAL PERMISSION OBTAINED
CJN	
GEOLOGICAL TARGET FORMATION	Haverty
Depth of caroleted well 5550	feet Rotary x / Cable Tools	
Kater strata 6ecrth: Fresh55,105,16%eet; Salt 0	feet
370-73	;—
Coal seam depths:	son-os .?7i-7^-7R3-B1; Is coal being mined in the area? No
OPEN FLOW DATA
Producing formation Haverty	Pay 2one depth 5216-5351 feet
Gas: Initial open flow	Mcf/d Oil: Initial open flow	Ebl/d
Combined Final open flow 1,032	Mcf/d	Final open flow	Bbl/d
Tire of open flow between initial and final tests 4 hours
Static rock pressure J850 psiq (surface measurement) after 96 hours shut in
(If explicable due to multiple completion—)
Second producing formation Elk	Pay zone depth 4126-42 feet
Gas: Initial open flw	_Mcf/d Oil: Initial open flow	Ebl/d
Final open flew	Kcf/d Oil: Final open flow	Ebl/d
Time of open flow between initial aid final tests	tours
Static rock pressure	psiq (surface measurement) after	hours shut in
. .	(Contirue on reverse tile)
Casing
Tubing
Used in
Drilling
Left
in Well
Cement
fill up
Cu. ft.
Size
20-16
CnnH.



13-10"
30
0
0 sks.
9 5/8



8 5/8
899.10
899.10
265 sks.
7



5 1/2



A 1/2
5437.10
5437.10
630 sks
3



2



Liners
used






5216-51 feet

-------
H'WI IV-35
(REVERSE)
DETAILS OF PERFORATED INTERVALS, FRACTURING OR STIMULATING, PHYSICAL CHANGE, ETC.
Haverty: Perforations: 5216-20 (10 holes) 5349-51 ( 7 holes)
Fracturing: 525 ska. 20/40 sand: 555 Bbls. fludi.
Elk: Perforations: 4126-30 (7 holes) 413B-42 ( 7 holes)
Fracturing: Foam frac: 2B0 sks. 20/40 sand: 500 gal acid:445 Bbls. fluid.
BOTTOM HOLE PRESSURE Pf-PwEXGLS j
t-60 +(0.0075 x 5437) ~ 459.7 - 560 X-53.35 x 560
(0.656)(4739)(0.9).1850x2-720.095.le50xl>10
¦29876 -0.000033 Pf»1850 x 2.72
(0.0000
Pf«2035 psi
HELL LOG
formation; COLOR HATO OR SOFT
TOP FEET
BOTTOM FEET
REMARKS
Including indication of all fre
and salt water, coal, oil and -
Top soil t sand
Sand
Coal
Sand t sandy shale
Coal
Sandy shale C sand
Coal
Sand
Coal
Sand
Coal
Sandy shale t sand
Coal
Sand t sandy shale
Red rock
Sandy shale t red rock
Sand t sandy shale
Little line
Sandy shale
Big Lime
Sand & sandy shale
Sandy 6hale
Elk
Sandy shale
Haverty
SarOy Shale
0
4
55
59
200
205
271
275
282
285
305
310
370
373
865
970
1115
1280
1290
1305
1385
3000
4126
4142
5216
5251
4
55
59
200
205
271
275
282
285
305
310
370
373
865
970
1115
1280
1290 -
1305
1385
3000
4126 -
4142
5216
5251
5550 T.
Gas ck 9 1610 No show
Gas ck 6 2630 No show
Gas ck e 2939 100/10-7" w/wa
4503 cu.ft.
Gas ck 8 2939 later 12/10-2"
144,000 cu.ft.
Gas ck ? 3400 2/10-2" w/water
144,000 cu.ft.
Gas ck @ 4024 2/10-2" w/water
144,000 cu.ft.
Gas ck § 4980 1/10-2" w/wate:
42,000 cu.ft.-
Gas ck P 5324 2/10-2" w/water
144,000 cu.ft.
Gas ck £ collars 4/10-2" w/w
84,000 cu.ft.
t
Gas ck after running 4V 28/11
w/water
223,000 cu.ft.
Damp ® 55'
¦l" stream g 105"
3S" stream @ 164"
(Attach separate sheets as necessary)
JfcJ Enterprises, Inc.
Well Operator
Robert DaMin-Geoloc'
Date:
9/14/84
Note: Regulation 2.0Z(i) provides as follous:
"The term 'log' or 'veil log' shall mean a systematic
detailed geological record of all formations, including
• • . -- am!, tfrn-ountererf £n the drilling of arvell\"
A-1 0

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Permit No. 47-017-3341	
Well Operator Chesterfield Bierqy Corp.
We 11 No. Plauger #4 Well	•
Location Buffalo Calf Run. Doddridge Co.
Name, Title, and Telephone No.
of Person Completing Form:
J. B. Dagley, Completion Supervisor
Chesterfield Biergy Corporation	
320 Professional Blda.. Clarksburg. WV 26301
WASTE PIT SAMPLING PROGRAM
WELL HISTORY
Date	Activity or Milestone Event	Add i t i ve /Quant.
8-17-84	Build Pit	
8-18-84	Move on rotary rig and spud well - fresh water @ 50' (1/4" stream)
	Drill to 508' (Hauled in 800 EBLS water from Buffalo Calf)
8-19-84	Drilling with air and foam 508' - 965' - (Used 300 BBLS water)
8-20-84	Drilling 965' to 1893' - Ran 1815.95' 8 5/8" OD casing. Cemented
	with 440 sacks. (Used 300 BBLS water and 60 gal, soap for drilling)
	Added 3% NACL to cement.	
8-21-84	Drilling 7 7/8" hole from 1893' - 2475' - Dusting	
8-22-84	Drilling 7 7/8" hole from 2475' - 3515' - Dusting
8-23-84	Drilling 7 7/8" hole from 3515* - 5040' -Dusting
8-24-84	Drilling 7 7/8" hole to 5843' - Ran well logs and ran 5810'
	4 1/2" OD 10.5# J-55 Casing. Cemented with 205 sacks 50/50 pozmix
cement. 982 LB salt and 38 sacks Gel added to cement. Conditioned
hole with 10 sacks Gel.
8-26-84	Hauled 1500 BBLS water from Buff ado Calf to storage tanks on
	location		
8-29-84	Well treatment - (Alexander-Benson) 500 BBLS fresh water	
	1000 gal. - 15^ HcL acid - 1 Gal HAI 60 inhibitor in acid.	
	1240 LB/ WG 12 Gelling Agent; 25 gal./15N Non Bnulsifier;	
	25 gal./ AQF-1 Foaming Agent; 250#/ Ferchek - Iron Control	
	Agent; 150#/BA-2 - Buffering Agent (PH Stabalizer); 50 gal./
A-1 1

-------
Permit No. «/-ui/-j-mi		
Well Operator Chesterfield Energy Corp
Well No. PI auger #4 Well		
Location Buffalo Calf Run Dnddririnp
Name, Title, and Telephone No.
of Person Completing Form:
J. B. Dagley, Completion Supervisor
Chesterfield Energy Corporation
320 Professional Building. Clarksburg
WASTE PIT SAMPLING PROGRAM
WELL HISTORY
Date	Activity or Milestone Event	Add i t i ve/Quant.
8-29-84 - Continued	
	CLA-5TA-B Clay Stabalizer; 10 gal./ Paracheck - Paraffin
	Inhibitor; 55 gal./ Parasperse - Paraffin Cleaner: 15000ft
	80/100 Frac Sand; 69000# 20/40 Frac Sand	
8-30-84	Flow well back - Service rig swab well	
8-31-84	Run 1 1/2" tubing in well and shut in.
A-1 2

-------
Well Operator Chesterfield Energy
Well No. Plauaer #4 Well	
Location Buffalo Calf Run. Clarksbrug
Name, Title, and Telephone No.
of Person Completing Form:
J. B. Dagley. Completion Supervisor
Chesterfield Energy Corporation
3?0 Professional Blda.. Clarksburg. WV
WASTE PIT SAMPLING PROGRAM
PIT HISTORY
Dat;e
Activity or Milestone Event
Additive/Quant,
8-17-84
Build Pit

8-18-84
Drilling

8-19-84
Drilling
300 BBLS water
8-20-84
Drilling
300 BBLS water
8-21-84 to
8-24-84
Drilling

8-29-84
Fracture well and start flow back

8-30-84
Flow well back into pit

8-31-84
PH adjustment and Aeration

9-3-84
PH adjustment and Aeration

9-20-84
Land Application Discharge


Pit Dimensions 150'X 15' X 8'
on 30% Grade
below location
3000' to nearest stream




A-13

-------
Name, Title, Telephone of
Person Completing Form:
J. B. Daqley	
DRILLING	304 - 623-5467	
Date drilling began 8-18-84
Date drilling completed 8-24-84	
Quantity of fresh water brought to well site? 800 BBLS	
Source stream Distance from well site to source 2 miles
Additives used (list with quantities):*
S6ap - 110 Gal.	 	
600 BBLS water	 		
10 sacks Ben ton i te	 		
Fresh water encountered during drilling? x Yes 	No
Salt water encountered during drilling? 	yes X No
FRACTURING/STIMULATION
Fracturing/stimulation dates: 	8-29-84	
Fracturing process used:
water frac

Fracturing/Stimulation chemicals used (list with
quantities):*
1240# WG12
25 Gal. AQF-1

1000 Gal. ACL acid
250# ferchek

25 Gal. 15N
150# BA-2

1 Gal. HAI60
50 Gal. GLA-STA B
(See bottom)
Was this well acidized?
Yes X No

Type, concentration, and
amount

PIT
Pit dimensions? 150	length, 15	width, 8	depth
Is the pit lined? x Yes 	No If yes, type of lining? plastic
Is the pit prelimed? 	Yes x No
If so, lime quantity 	
Pit treatment (describe treatment process, amount of chemicals
used, how chemicals introduced):*
Drilling pits are treated for ph and adjusted with hydrated lime. Hie pit is
then circulated and aeration by turning the pit over twice, and discharges
are done by land application method.		
Pit treatment date(s):	R_3i_fl4	
Was pit fluid recirculated for dust suppression? x Yes 	No
On what dates? 	8-21-84 to 8-24-84		
*If more space is required, please use back of form
Treatment chemicals	84,000# Sand
10 gal paracheck	1500 BBLS Water
55 gal parasperse
A-1 4

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Permit No. 47-097-2664	
Well Operator union Drilling, inc.
Well NO. 1941	
Location Banks District. Upshur Co.
Name, Title, and Telephone No.
of Person Completing Form:
Joseph C. Pettev	
Vice President of Production	
(304) 472-4610	
WASTE PIT SAMPLING PROGRAM
ViELL/PIT HISTORY
Date	Activity or Milestone Event	Additive/Quant.
08-07-84 to Constructed well location and pit. Pit
08-08-84	size approximately HU' long, 4U' wide
and 6' to 8' deep. The pit is located
on the downhill side of the well loca-
	tion. The nearest stream is 550 feet	
away. The well location is in an open
	field with a slight grade ending in a	
small stream feeding into the left branch
of Little Kanawha River
08-12-84	Move rig on location and prepare to
start drilling operations
08-13-84	Began drilling operations - Drilling on
air - No additives. No rain.
08-14-84
No rain. Drilled through ground water

at 45' - began drilling on foam. For

each 17 BBL fresh water 4 quarts of

drilling soap is added induced at a

rate of 290 BBL of fresh water per day.

Fresh water obtained from the nearest

stream. Drilled through ground water
at 138'.
08-15-84	No rain. Ran 1099.93 feet of 8-5/8" casing

and cemented with 175 cubic feet of standard

cement. 75 cubic feet poz mixture, 700#

calcium, 150 cubic feet of 2% gel, casing

cement back to ground surface. Fresh water

in tanks for mixing cement. Rig sat for 8

hours to allow cement to harden.
08-16-84
No rain - drilling on air - no additives -

water taken from pit for dust control as

needed.
00
i ^
r*H
1
00
o
No rain - drilling on air - no additives -
water taken from pit for dust control as
needed.
A-15

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WASTE PIT SAMPLING PROGRAM
WELL/PIT HISTORY
Date	Activity or Milestone Event	Additive/Quant.
08-18-84	It rained .22 of an inch. Completed	
drilling hole and logged hole - ran
4V 4214.15 feet of casing in hole and	
cemented with 410 cubic feet of standard
	cement, 400 sks. calcium, 39if of A-10	
gypseal to each 100// of cement, 51 hit
D-7 Gilsonite added to each 100it of
cement. Fresh water supplied from tanks
	on location. Before cementing pumped	
500 gallons of 15% hydrochloric acid down
hole.
08-19-84	Just a trace of rain. Hove drilling rig
off location
08-20-84	No rain. Hauled frac tanks to location.
08-21-84	No rain. Filled frac tanks with fresh
water from nearest 6tream.
08-22-84	No rain. No activity.
Well Operator Union Drilling, Inc.
Well No. 1941	
Location Banks District, Upshur Co.
Name, Title, and Telephone No.
of Person Completing Form:
Joseph C. Pettev	
Vice President of Production
(3041 472-4610		
08-23-84	Rained .46 of an inch. Spread 4 bags of
Bregoil sponge absorbent around location
.	and pit to absorb and oil.	
08-24-84	No rain. Begin restoration process.	
08-25-84	No rain. Perforated well and pumped 500	
gallons of 15% Hydrochloric acid downpipe.
	Fractured well with 90,000ft of sand, 70 gallon
J-16, 6,000it KCL potassium chloride and
	 920,000 SCF Nitrogen.	
08-26-84	No rain. Blowing well into pit. Mostly nitrogen.
08-27-84	No rain. Added 12 bags of hydrated lime to pit.
08-28-84	Rained .08 of an inch. No activity.	
A-1 6

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Permit No. 47-097-2664
Well Operator Union Drilling, Inc.
Well No. 1941		
Location Banks District, Upshur Co.
Name, Title, and Telephone No.
of Person Completing Form:
¦Infigph C- Pettev	
Vice President of Production	
(304) 472-4610	
WASTE PIT SAMPLING PROGRAM
WELL/PIT HISTORY
Activity or Milestone Event	Additive/Quant.
08-29-84
No
rain.
No activity
08-30-84
Rained 1
.52 inches. No activity
08-31-84
Rained .
02 of an inch. No activity
09-01-84
No
rain.
No activity
09-02-84
No
rain.
No activity
09-03-84
Rained .
25 of an inch. No activity
09-04-84
Rained .
57 of an inch. No activity
09-05-84
Rained .
02 of an inch. No activity
09-06-84
No
rain.
No activity.
09-07-84
No
rain.
Fog until noon. No activitv
09-08-84
No
rain.
Fog until noon. No activity
09-09-84
No
rain.
Fog until rioon. No activity
09-10-84
No
rain.
Foe until noon. No activitv
09-11-84
No
rain.
Foe until noon. No activitv
09-12-84
No
rain.
For until noon. No activitv
09-13-84
No
rain.
Foe until noon. No activitv
09-14-84
Rained .
31 of an inch. No activitv
09-15-84
Rained .
58 of an inch. Set pum> to pump nnrn pit.
09-16-84
No
rain.
Foe until noon. No activitv
09-17-84
No
rain.
Pumpine oit to displacp pit
09-18-84
No
rain.
Restoring location
A-17

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renin t nu . h /-uy	.	
Well Operator Union Drilling, Inc.
Well No. 1941		
Location Banks District, Upshur Co.
Name, Title, and Telephone No.
of Person Completing Form:
Joseph C. Pettey	
Vice President of Production	
(304) 472-4610	
WASTE PIT SAMPLING PROGRAM
WELL/PIT HISTORY
Date	Activity or Milestone Event	Additive/Quant.
09-19-84	No rain. Restoring location	
09-20-84	No rain. Hydroseeding location	
A-18

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WELL/PIT HISTORY SUMMARY SHEET
DRILLING
Date drilling began 08-13-84
permit No. 47-097-2664	
Name, Title, Telephone of
Person Completing Form:
Joseph C. Pettey	
Vice President of Production
(304) 472-461U	
Date drilling completed 08-18-84
Quantity of fresh water brought to well site? 990 BBL Approximately
Source stream	 Distance from well site to source 1600' to 1800'
Additives used (list with quantities):*
Biodegradable drilling soap		73 quarts - approximately	
Fresh water encountered during drilling? X Yes 	No
Salt water encountered during drilling? 	Yes X No
FRACTURING/STIMULATION
Fracturing/stimulation dates: 08-25-84	
Fracturing process used: Foam (water, sand and nitrogen)	
Fracturing/Stimulation chemicals used (list with quantities):*
J-16	 70 gallon	
KCL Potassium Chloride		600 pounds	
Was this well acidizea? 	Yes X No
Type, concentration, and amount 1000 gallon 15% hydrochloric acid used
^	before cementing and atter perforating.
Pit dimensions? 60' length, 40' width, 6' to 8' depth
Is the pit lined? 	Yes X No If yes, type of lining?	
Is the pit prelimed? 	Yes X No
If so, lime quantity 	
Pit treatment (describe treatment process, amount of chemicals
used, how chemicals jrtroduced):*
Introduced 12 bags of hydrated lime to pit on 08-27-84 by pump and circulated.
Pit treatment date(s):	
Was pit fluid recirculated for dust suppression? X Yes 	No
On what dates? 08-16-84 and 08-17-84
*If more space is required, please use back of form
A-19

-------
Data ftiignst	
(Rev 8-81)	Operator's
^Slair of jESrai Virginia 1,0•	1 - *941
Pf?«rtminl of gimf Farm Reta F. Clark »1
®il ani • 4"7 - 09"? - 2664
HELL OPERATOR'S REPORT
OF
DRILLING. FRACTURING AND/OR STr-rJLMTJG. OR PHYSICAL GU.'JCE
WELL TVFE: Oil	/ Gas x / Liquid Injection / Waste Disposal	/
(If "Gas," Production / Underground Storage / Deep	/ Shallow x /)
LOCATION: Elevation: 2083' Watershed Left Fork of Little Kanawha River
District:	Banks	County Upshur Quadrangle Rock Cave
QCMPANY Union DrilHng.Inr.	
¦ADDRESS P.O.Drawer 40. Buckhannon. VfV 26201
DESIGWI^D AGDJT	Joseph C. Vanzant.Jr.
ADDRESS P.O.Drawer 40. Buckhannon. WV 26201
SURFACE CTsNP Jerry t Brent Galyean	
ADDRESS Washington & Broad, Charleston,HV 2530i
MESDWL RIGHTS 0KNTO 8ee attacftnent	
ADDRESS	
OIL AND G^S INSPECTOR FOR THIS WORK	
Phil Tracy &nr,Tr^cg Forest Fest. ,Apts. , Elkins
PEP-MIT ISSUED	7/26/B4	m 262'
. DRILLING ~O.'-D-E-JCED 8/13/84	
DRILLING CCi-FLEXES B/1B/64	
IF APPLICABLE: PLCGGIivG OF DRY HOLE ON
CONTINUOUS PROGRESSION FROM DRILLING OR
REWORKING. VERBAL PERMISSION OBTAINED
CM	
GEOLOGICAL TARGET FORMATION	Benson	Depth' 4000' feet
Depth of carpleted well 4350'	feet Rotary xx / Cable Tools	
Water strata Septh: Fresh 1 138' feet; Salt none feet
Cbal sean depths; 983/66	 Zs coal being mined in the area? no
OPEN FLOW DATA
Producing formation	Riley, Benson	Pay zone depth 4116'	feet
Gas: Initial open flow 25 Mcf/d Oil: Initial open flow	Bbl/d
Final open flow 1517	Mcf/d	Final open flow	Bbl/d
Tire of open flow between initial and final tests 2 hours
Static rock pressure	950* psig (surface ireasurerent) after 24 hours shut in
(If applicable due to imltiple completion—)
Second producing formation	Pay zone depth	feet
Gas: Initial open flew	Mcf/d Oil: Initial open flew	Ebl/d
Final open flex 	Mcf/d Oil: Final open flow	i	Ebl/d
Tine of open flo^ between initial and final tests	hours
Static rock pressure	psig (surface measurerent) after hours shut in
'(Centime on reverse side)
A-20
Caging
Tubing
Used in
Drilling
Left
in Well
Cerent
fill up
Cu. ft.
Size
20-16



13-10"
22.00'
J2.0IV

9 5/8



8 5/8
1099.93'
1099.93'
310 cf
7



£ 1/2
1

4 1/2

4214.15'
562 cf
3



2
1

Liners
used







-------
rCTM IV-35
(P.EV53E)
DETAILS CK PETOiVJTD r.TES>.7,LS, rRACTJRITJG OR srrjVJCJC, PHYSICAL CJATJCE, rrc.
B.J. Hughes - 2 stage Fonn Frac - 6/25/84
3770/3802 - Riley - 45,000* sand, 150 Bbls water, and 440,000 scf nitrogen
4112/16 - Benson - 45,0000 sand, 180 Bbls water and 480,000 scf nitrogen
WELL LOG
FORMATION COLOR HARD OR SOFT
TOP rETT
BOTTOM FEZT
KS'APXS
Including indication of all fres:
and salt water, coal, oil and ca:
Sand & Shale
Coal
Sand Shale
Blue Monday
Big Line
Injun
Squaw
4th Sand
5th Sand
Bayard
Lower Bayard
Warren
Bradford
Riley
Benson
0
983
986
1522
1592
1668
1838
2185
2256
2300
2408
2632
3430
3748
4084
983
986
1522
1575
1668
1838
1860
2202
2277
2352
2436
2650
3436
3809
4116
4350'
1/2" stream water 6138'
T.D. 6/10ths thru 1"
25 mcf
(Attach separate sheets as necessary)
UNION DRII.T.TKn.TMr.
Hell Operator	-o
-r&L
Date: Joseph C. Pettev. v
-------
304-472-4610
nmi 1 IKin IMP Drawer40	DRILLING CONTRACTORS
UKILLINLl, IINU. Buckhannon. WV 26201 PRODUCERS OF OIL AND GAS
SUPPLEMENT TO FORM IV-35 WELL NO. 1941
Lease No. 1650	1/2 Interest
Elsie Young, Agent
79 South Florida Street
Buckhannon,wv	26201
Lease No. 1650	1/2 Interest
John R. Morris,	Agent
P.O.Box 629
Parkersburg,WV	26102
Lease No. 1652	100% Interest
Reta F. Clark
66 Smithfield Street
Buckhannon, WV	26201
A-2 2

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rermit no. *t/-U/9-ll 18	
Well Operator Cabot Oil & Gas
We 11 No. Albertson //4
Location Putnam Co., W. Va.	
Name, Title, and Telephone No.
of Person Completing Form:
David G. McCluskey	
District Drilling Superintendent
304-347-1600 	-
WASTE PIT SAMPLING PROGRAM
WELL HISTORY
Ddjte	Activity or Milestone Event	Additive/Quant.
8-2-84
Began clearing brush for location

8-8-84
Began building pit

8-9-84
Finishing building pit
Trucked 630 bhls FrfiRh U,-T"
9-1-84
Spudded well & set 16" conductor
6 sks Class A near
9-3-84
Drilling 0 326' Hit FW @ 196'

9-4-84
Set 514* of 11-3/4" CSG
300 sks Class A neat
3% CaC12
k# Flocele/sack
9-5-84
Drilling @ 1080' on Foam
1 BBL of Soap
9-6-84
Drilling @ 1600' on Foam

9-7-84
Drilling @ 1800' on Fluid
2///BBL starch & 3% kcl
9-10-84
Drilling @ 2090' on Fluid
II II
9-11-84
Set 2150' of 8-5/8" csg
600 sks Class A neat
3% CaC12 & .75% CFR-2
k# Flocele/sack
9-12-84
Drilling @ 2626' Dusting
50 bbls of GeL
9-16-84
TD well @ 5100' & Ran 5V CSG
145 sks 50-50 P0Z mix
10% salt 10#/sack Gilsonite
95 sks Class A & .75% CFR-2
9-22-84
Perforated & Frac'd well (Oriskany Formation)-
Materials
- 500 gal 28% HCL w/cla-sta (.5 gal/1000 gals), 150 sks 20/40 sand, 3% kcl
5///100 gal Fe control, 1 gal/1000 gal FR 28LC, 1
gal/1000 gal Lo Surf 259, 247 MCFIN2
9-22 thru 9-23 Flowed well back
A-2 3

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Well Operator Cabot Oil & Gas
Well NO. Alberts™ U
Location Putnam Co.. W. Va.
Name, Title, and Telephone No.
of Person Completing Form:
David G. McCluskey
District Drilling Superintendent
304-347-1600

WASTE PIT SAMPLING PROGRAM
PIT HISTORY
D«jte
Activity or Milestone Event Additive/Quant.
8-8-84
Began building pit Added 630 bbls utr.
8-9-84
Finishing building pit
9-1 thru 9-16
Well being drilled
9-22-84
Well fractured & started flowback
9-23-84
Preliminary evaluation of location
including vater testing, determination
of disposal method, etc.
9-24-84
Skimming of pits and adjustment of
pH by blending/circulation of pits.
Chemical additives not required since
pH was elevated on one pit attributable
to the presence of circulated cement.
9-25-84
Two volume mixing with submerged discharge,
1470 bbls - 5 hrs.-15 min.
Two volume aeration with elevated discharge
1470 bbls - 5 hrs.-15 min.
10-1-84	Discharge by land application
1470 bbls - 8 hrs.-35 min. @ 120 gpm
'	Water vas trucked from nearby stream (1.2 miles)
Pit dimensions 57'xl4'x5' & 90'xl6'x6'
	Nearest stream - 1/3 mile	
Moderate terrain
A-24

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»vtLL/fii nj.Si.UKX £>UMPIAKX bttLfc'J.	Permit NO. 47-U79-111B	
Name, Title, Telephone of
Person Completing Form:
David G. McCluskev	
DRILLING	District Drilling Superintendent
« - ^ •11 • u o i a/ 304-347-1600
Date drilling began 9-1-84	
Date drilling completed 9-16-84	
Quantity of fresh water brought to well site? 1260 bbls	
Source Poca River Distance from well site to source 1.2 miles
Additives used (list with quantities):*
1 bbl 50AP - 1260# Starch	 995 sks Class "A". 145 sks 50-50 POZ mix
6,000// Kcl	 225// Flocele, 50 bbls of eel. 1450// Gilsonite
	 525// CFR-2, 2,700# CaC12, 145// salt
Fresh water encountered during drilling? X Yes 	No
Salt water encountered during drilling? X Yes 	No
FRACTURING/STIMULATION
Fracturing/stimulation dates: 9-22-84	
Fracturing process used: 	FOAM FRAC
Fracturing/Stimulation chemicals used (list with quantities):*
500 gal 28% Hcl	100// Fe control agent
15,000// 20/40 sand		20 gal FR 28 LC 20 gal LP Sorf 259
247,000 SCF N.		3,300// Kcl	
40 gal Cla STA
Was this well acidized? 	Yes X No
Type, concentration, and amount N/A
57'	14'	5.0'
Pit dimensions? 90* length, 16'	width, 6.0'	depth
Is the pit lined? X Yes 	No If yes, type of lining?Reinforced Plastic
Is the pit prelimed? 	Yes X No
If so, lime quantity N/A	
Pit treatment (describe treatment process, amount of chemicals
used, how chemicals introduced):*
Pits were skimmed, pH _ad j us ted bv blending/circulation nf	rhpm-iral
additives not required since pH elevated on one pit due to the presence of
circulated cement. Total Liquid Volume «= 1470 bbls.	
Pit treatment date(s): 9/24/84 - 9/25/84	
Was pit fluid recirculated for dust suppression? x Yes 	No
On what dates? 9/12/84 - 9/16/84	
*If more space is required, please use back of form
A-25

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ATTACHMENT B

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Permit No. 085-7015		
Well Operator Kenr.o	
Wel1 No- gg-'m	
Well Location IMtrMe County
Name, Title, Telephone No.
of Person Completing Form:
Charles T. Krushansky	
TKC. Inc.. 44 Baltimore Street.
Uestnver. Uest Virginia	26505
304/291-5960
WASTE PIT STUDY
ENGINEERING COST QUESTIONNAIRE
I. MANPOWER COSTS FOR PIT TREATMENT
*
Please describe each treatment task, skill level required for
each task, number of manhours required for each task in Table 1.
TABLE 1. MANPOWER REQUIREMENTS
Task/Activity	Skill Level	Manhours
The treatment of this drill pit	(1) Technician 	18	10
included mixing, aeration, and	(1) Technician	18	10
ph adjustment.
(1) Supervisor
18
10

Travel	(1) Technician	3	l*s
(1)
Technician
3
ih
(1)
Supervisor
3
Ik
(1) Comp. Rep.	6	3
Mixing and aeration was
performed using a 3 inch
trash pump. Hydrated lime
was used as the catalyst
for ph adjustment.
TOTAL:	
Labor $ 975.
Supv.	975.
Comp. Rep. 270.
$ 2220.
B-1

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Permit No. 085-7015
For each of the Skill Levels described in Table 1, please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
TABLE 2. MANPOWER COSTS
Skill Level	Hourly Salary	Includes Benefits?
Technician	$ 15 per hour	yes
Technician	$ 15 per hour	yes
Supervisor	$ 30 per hour	yes
Company Representative	$ 30 per hour	yes
B-2

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Permit No. 108-7015
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are usiny may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of. total delivered purchase cost.
TABLE 3. EQUIPMENT COSTS
Equipment
Description
Total Del.
Purchase
Cost (S)
Installation
Cost (% of
Purchase Cost)
Annualized
Cost (%)
(1) 3 inch pump
$15 per hour
vith suction and 28 hrs. x $15 = 420
discharge lines
($1,400)
(2) Vehicle for tech. $15 per hour
($3,200)
32.5 x $15 = 487.50
(3) Vehicle for Supv. $15 per hour
($9,400)
32.5 x $15 ¦= 487.50
(4) Vehicle for Comp. $15 per hour
Rep. ($9,400) 9 x $15 - 135.00
TOTAL COST FOR EQUIPMENT - $1,530.
B-3

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Permit No. 085-7015
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
. Hydrated Lime	19 bags (1400 lbs.1	$145	
B-4

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Permit No. 085-7015
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, $200/yd3 or §l,000/pit.

B. What engineering costs or consultant costs are associated
with pit construction? Again, please indicate units.
$45 per hour for dozer, supervisor and vehicle
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
$3,895 or $2.29 per barrel	
Man hour cost $2,220.
Equipment cost 1,530.
Chemical	145.
Total cost for treatment and discharge - $3,895.
Estimated 1,700 barrels
$3,895 divided by 1,700 barrels ¦ 2.29 per barrel
B-5

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Permit No. 001-2125	
Well Operator J & J Enterprises
Well No. j 1Q42	__
Well Location Barbour County
Name, Title, Telephone No.
of Person Completing Form:
Charles T. Krushansky	
TKT- Tnr. . 44 Baltimore Street,
Westover. West Virginia 26505
304/291-5960
WASTE PIT STUDY
ENGINEERING COST QUESTIONNAIRE
IMANPOWER COSTS FOR PIT TREATMENT
Please describe each treatment task, skill level required for
each task, number of manhours required for each task in Table 1.
TABLE 1. MANPOWER REQUIREMENTS
Task/Activity	Skill Level	Manhours
The treatment of this drill pit
(1)
Technician
12
8
included mixing, aeration, and
(1)
Technician
12
8
ph adiustment
(1)
Supervisor
12
8

(1)
Company Rep.
3
3
Travel
(1)
Technician
2
2

(1)
Technician
2
2

(1)
Supervisor
2
2

(1)
Company Rep.
3
3
Mixing and aeration was
performed using a 3 inch
trash pump. Hydrated lime
was used as the catalyst
for ph adjustment.
TOTAL:
Labor $ 720.
Supv.	720.
Comp. Rep. 180.
$1620.
B-6

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Permit No.
001-2125
For each of the Skill Levels described in Table 1, please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
Skill Level
TABLE 2. MANPOWER COSTS
	Hourly Salary	
Includes Benefits?
Technician
$ 15 per hour
yes
Technician
15 per hour
yes
Supervisor
30 per hour
yes
Company Representative
30 per hour
yes
B-7

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Permit No. 001-2125
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are using may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of total delivered purchase cost.

TABLE 3.
EQUIPMENT COSTS

Equipment
Description
Total Del.
Purchase
Cost ($)
Installation
Cost (% of
Purchase Cost)
Annuali zed
Cost (%)
m 1 l'nrti pump
$15 per hour


with suction and
20 x $15 = $300


discharge lines
($1,400)
• Vehicle for Tech.
$15 per hour


($3,400) 	,24 x $15 = $360

(3)
Vehicle for Supv.
$15 per hour

($9,400)
24 x $15 = $360

(4)
Vehicle for Comp.
$15 per hour

Rep. ($9,400)
6 x $15 = $ 90
TOTAL COST FOR EQUIPMENT - $1,110.
B-8

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Permit No. 001-2125
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
foydrated Lime	5 bags (250 lbs.)	$25	
B-9

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Permit No. 001-2125
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, S200/yd3 or 51,000/pit.
$1,500
B. What engineering costs or consultant costs are associated
with pit construction? Again, please indicate units.
	$45 per hour for dozer, supervisor and vehicle	
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
	$2,755 or $2,75 per barrel	
Man hour cost $1,620.
Equipment cost $1,110.
Chemical	$ 25.
Total cost for treatment and discharge - $2,755
Estimated 1,000 barrels
$2,755 divided by 1,000 barrels = 2.75 per barrel
B-l 0

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WASTE PIT STUDY
ENGINEERING COST QUESTIONNAIRE
I_5	MANPOWER COSTS FOR PIT TREATMENT
Permit No. 47-097-2664
Well Operator Union Drilling. Inc.
Well No. 1941
Well Location Banks District, Upshur
Name, Title, Telephone No.	Co.
of Person Completing Form:
Joseph C. Pettey
Vice President of Production
(304) 472-4610	
Please describe each treatment task, skill level required for
each task, number of manhours required for each task in Table 1.
TABLE 1. MANPOWER REQUIREMENTS
Task/Activity	Skill Level	Manhours
The treatment of this drill site and	
drill pit includes mixing, skimming	
and pH adjustment	
	Laborer	21	
	Supervisor	24	
Mixing was performed using a 2" trash pump, with hvdratP^ Hm*. used as the
catalyst for pH adjustment.	
B-1 1

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Permit No. 47-097-2664
For each of the Skill Levels described in Table 1, please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
TABLE 2. MANPOWER COSTS
Skill Level	Hourly Salary	Includes Benefits?
$32 per hour with water pump/truck yes	
$220 per day with truck	yes
Laborer
Supervisor
B-1 2

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Permit No. 47-097-2664
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are using may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of total delivered purchase cost.
TABLE 3. EQUIPMENT COSTS
Total -Del. Installation
Equipment Purchase Cost (% of Annualized
Description	Cost (S)	Purchase Cost)	Cost (%)
(1) 2" pump with suction and discharge lines and fittings	
$1,400.00
(1) 1982 GMC 3/4 ton vehicle for Laborer
$10,688.62
(1) 1984 GMC 3/4 ton vehicle for supervisor
$10,063.15
B-13

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Permit No. 47-097-2664
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
Bregoil sponge absorbant	4 Bags	S17ft.nn	
Hydrated Lime	12 Bags 0 2.95/Bag	35.40	
B-1 4

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Permit No. 47-097-2664
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, S200/yd3 or $l,000/pit.
$l,500.00/pit
B. What engineering costs or consultant costs are associated
with pit construction? Again, please indicate units.
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
Cost Summary:
Labor	$ 890.00
Supervisor
660.00
Pit 1200 BBL
Materials
163.40
$1.57/BBL
10% Contingencies
171.30

Total
$1,884.70

B-15

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47-097-2664
RETA CLARK #1
WVG01941
DATE
DESCRIPTION
QUANTITY
RATE
AMOUNT
08-08-64
Supervisor
0.50
220.00/Day
$ 110.00
08-24-f84
Keegas - Misc. Products
1.00
128.00/Job
128.00
08-27-84
Lime
12.00
2.95/Each
35.40
09-04-84
Labor - Pump Vater (W/Pump)
17.00
32.00/Hr.
544.00
09-04-84
Supervisor
1.00
220.00/Day
220.00
09-15-84
Labor - Set Pump
6.00
15.00/Hr.
90.00
09-15-84
Supervisor
0.50
220.00/Day
110.00
09-17-84
Labor - Pump Vater (W/Pump)
8.00
32.00/Hr.
256.00
09-17-84
Supervisor
1.00
220.00/Day
220.00



Total
$1,713.40
+10% 171.34
$1,884.74
B-1 6

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Permit No. 47-017-3341	
Well Operator Chesterfield Energy Corp.
Well No. PI auger #4 Well	
Well Location Buffalo Calf Run.Doddridq
Name, Title, Telephone No.
of Person Completing Form:
Jeffrey W. Nelson. V.P.	
Keeqas Corp.	;	
Clarksbrug. WV 26301"	
WASTE PIT STUDY
ENGINEERING COST QUESTIONNAIRE
I., MANPOWER COSTS FOR PIT TREATMENT
Please describe each treatment
each task, nurr.Der of manhours
task, skill level
required for each
required for
task in Table 1
TABLE 1. MANPOWER REQUIREMENTS

Task/Act iv i ty
Skill Level
Manhours
The treatment of this drilling pit
(1) Technician
20
Included geration and ph adjustment
(1) Technician
20
Hydrated lime was used as the
(1) Supervisor
20
catalyst for ph adjustment
(1) Company Sup.
1
travel
(1) Technicial
2

(1) Technicial
2

(1) Supervisor
2

(1) Company Sup.
2
Discharge of the drilling pit was
done land application

(1) Technicial
10

(1) Technicial
10

(1) Supervisor
10

(1) Company Sup.
1
Travel
(1) Technicial
2

(1) Technicial
2

(1) Supervisor
2

(1) Company Sup.
2
B-17

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Permit No. 47-017-3341
For each of the Skill Levels described in Table 1, please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
TABLE 2. MANPOWER COSTS
Skill Level	Hourly Salary	Includes Benefits?
Technician	$15 per hour	yes	
Technician	$15 per hour	yes	
Supervisor	$30 per hour	yes
Company Rep.	$30 per hour	yes
B-1B

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Permit No. 47-017-3341
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are using may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of!total delivered purchase cost.
TABLE 3.	EQUIPMENT COSTS
Total Del.	Installation
Equipment Purchase	Cost (% of Annualized
Cost (S)	Purchase Cost) Cost (%)
(1) 3 inch
1800

pump with suction
and discharge lines
50.00 per day

gasoline 30

@ 1.40
192

(1) 1980 C	6000	450
3/4 ton vehicle 15.00 per hour
for technicians
(1) 1983 Ford	8000	450
3/4 ton vehicle 15.00 per hour
for Supervisor
B-19

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Permit No. 47-017-3341
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
Hydrated Lime	35 bags (1750)	3.20/#50 Bag
Tbtal	112
Delivery	(1) 3/4 ton vehicle 	
	i> 26. per hour	
Time 4 hr.	$104
B-20

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Permit No. 47-017-3341
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, $200/yd3 or $l,000/pit.
$2>000/pit with plastic liner
Pit
1,500.00
"liner
500.00
$2,000.00
B. What engineering'costs or consultant costs are associated
with pit construction? Again, please indicate units.
Supervisor	I Dav	S1 SO.00	
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
Supervisor	34 hrs. @ $30 per hr.=$l ,020.00	
Technician
68 hrs.
@ $15
per
hr .=
1.020.00
Company Sup.
6 hrs.
C° $30
per
hr .=
180.00
Equip.




1.092.00
Chemical




216.00
Total	$3,528.00
Pit size	1,700 bbl
Cost per barrell	$ 2.07
B-21

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WASTE PIT STUDY
ENGINEERING COST QUESTIONNAIRE
Ij MANPOWER COSTS FOR PIT TREATMENT
Permit No. 47-097-2664
Well Operator Union Drilling. Inc.
Well No. 1941
Well Location Banks District, Upshur
Name, Title, Telephone No.	Co.
of Person Completing Form:
Joseph C. Pettey	
Vice President of Production
(304) 472-4610	
Please describe each treatment task, skill level required for
each task, number of manhours required for each task in Table 1.
TABLE. 1. MANPOWER REQUIREMENTS
Task/Activity	Skill Level	Manhours
The treatment of this drill site and	
drill pit includes mixing, skimming	
and pH adjustment	
	Laborer	2J	
	Supervisor	24	
Mixing was performed using a 2" trash pump, with hvdrat-prf 1-fmp used as the
catalyst for pH adjustment.	
B-22

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Permit No. 47-097-2664
For each of the Skill Levels described in Table 1, please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
TABLE 2. MANPOWER COSTS
Skill Level	Hourly Salary	Includes Benefits?
Laborer	$32 per hour with water pump/truck yes
Supervisor	$220 per day with truck.	yes	
B-23

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Permit No. 47-097-2664
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are usiny may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of total delivered purchase cost.
TABLE 3. EQUIPMENT COSTS
Total Del. Installation
Equipment Purchase Cost (% of Annualized
Description	Cost (S)	Purchase Cost)	Cost (%)
(1) 2" pump with suction and discharge lines and fittings	
$1,400.00
(1) 1982 GMC 3/4 ton vehicle for Laborer
$10,688.62
(1) 1984 GMC 3/4 ton vehicle for supervisor
$10,063.15
B-24

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Permit No. 47-097-2664
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
Bregoll sponge absorbant	4 Bass	SI 7R_nn	
*
Hydrated Lime	12 Bags C° 2.95/Bag	35.40	
B-25

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Permit No. 47-097-2664
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, $200/yd3 or 51,000/pit.
$1,500.00/pit
B. What engineering costs or consultant costs are associated
with pit construction? Again, please indicate units.
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
Cost Summary:
Labor	$ 890.00
Supervisor	660.00 	 	Fit 1200 BBL
Materials
163.40
S1.57/BBL

10% Contingencies
171.30


Total
$1,884.70


B-26

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47-097-2664
RETA CLARK 01
WVG01941
DATE
DESCRIPTION
QUANTITY
RATE
AMOUNT
O8-0B-B4
Supervisor
0.50
220.00/Day
$ 110.00
08-24-84
Keegas - Misc. Products
1.00
128.00/Job
128.00
08-27-64
Lime
12.00
2.95/Each
35.40
09-04-B4
Labor - Pump Water (W/Pump)
17.00
32.00/Hr.
544.00
09-04-84
Supervisor
1.00
220.00/Day
220.00
09-15-84
Labor - Set Pump
6.00
15.00/Hr.
90.00
09-15-84
Supervisor
0.50
220.00/Day
110.00
09-17-84
Labor - Pump Water (W/Pump)
8.00
32.00/Hr.
256.00
09-17-84
Supervisor
1.00
220.00/Day
220.00



Total
$1,713.40
+10% 171.34
$1,884.74
B-27

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rermit no. 
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Permit No. 47-079-1118
For each of the Skill Levels described in Table lr please
indicate hourly salary (indicate if hourly salary includes
benefits) in Table 2.
TABLE 2. MANPOWER COSTS
Skill Level	Burdened Rate	Total Cost
Supervisor	kOh g $30.00	$1215.00
2--Man Crew	62'-j g $30.00	$1875.00
B-29

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Permit No. 47-079-11 ib
II. EQUIPMENT COSTS FOR PIT TREATMENT
In Table 3, list all equipment required for pit treatment.
Although the equipment you are using may not be new, please
indicate the Total Delivered Purchase Cost for each item. (This
replacement cost or "new" cost will be used to estimate current
on-site costs.) Total Delivered Purchase Costs for all rented
or leased equipment should also be included, but please indicate
rental equipment by an asterisk (*) by the Equipment Descrip-
tion. Installation costs should be indicated as a percentage
of total delivered purchase cost.
TABLE 3. EQUIPMENT COSTS
Equipment
Description
Total Del.
Purchase
Cost (S)
Installation
Cost (% of
Purchase Cost)
Annuali zed
Cost (%)
F-250 Ford 4WD
Equipped with winch,
utility top, tools,
test kits, 2 trash
pumps, lime hopper.
oil booms, safety
equipment, etc.
Treatment
2 trucks @ 2 days @ $100.00/dav
$400.00
Discharge
1 truck @ 1 day @ $100.00/day
$100.00
B-30

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Permit No. 47-079-1118
III. CHEMICAL COSTS FOR PIT TREATMENT
In Table 4, list chemical costs (and any other special non-
reusable materials and associated costs). Indicate quantity and
price per quantity for each entry.
TABLE 4. CHEMICAL COSTS
Chemical	Quantity	Price/Quantity
No chemicals required for pH adjustment	
Other expendables including vehicular	
mileage charges, test reagents, sorbent	
materials, pump gasoline, per diem, etc.	S??Q. ?s
B-31

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Permit No. 47-07S-1113
IV. PIT EXCAVATION COSTS (GIVE DOLLAR VALUES)
A. What are the pit site preparation and excavation costs?
Indicate units, for example, S200/yd3 or $l,000/pit.
$1,000/Pit x 2 Pits = $2.000	
$500/Pit Liner x 2 Pit Liners s $1.000	
B. What engineering costs or consultant costs are associated
with pit construction? Again, please indicate units.
206 Plan - $50.00	
Construction Foreman	5 hrs. x $30/hr. ¦= $150	
C. What engineering costs or consultant costs are associated
with pit treatment and pit fluid disposal? Indicate units.
From Tables 2, 3, & 4	Total Cost $3.819.25	
Pit size - 1470 bbls 			 	
Cost per barrel = $2.60
B-32

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ATTACHMENT C

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V; Cabot Oil & Gas Corporation of West Virginia
'Ji
1100 crrv center west
POST OFFICE BOX 628
CHARLESTON. W V* 2S322
TELEPHONE 304/347-1600
October 17, 1984
David M. Flannery, Esquire
Robinson & McElwee
P.O. Box 1791
Charleston, Wv 25326
Dear Dave:
Please forgive the delay 1n getting this letter to you.
It 1s indeed unfortunate that our C. G. Stowers #1 Well 1n Kanawha
County had to be withdrawn from the Six Well Analysis Program.
Our Investigation of the removal of the water from the pit reveals the
following:
1.	No pit Integrity problems had been experienced and
there was no evidence of a pit leak.
2.	The pit water was not transported to our disposed
well.
3.	A contract vacuum truck driver working over the
weekend of the Labor Day Holiday commented to our
drilling foreman that he had problems finding enough
water to fill "the frac^Jank on the location. While
the driver did not say he had pumped water from the
pit, which was estimated to be less than 70 bbls, we
suspect the pit water was pumped Into the frac tank.
Since no Cabot employees were present when the water was removed from
the pit we cannot say with certainty what actually happened. However, we do
feel that Item #3 above 1s the most reasonable conclusion.
Sincerely,

Fred H. Shelton,
Safety and Environmental Supervisor
FHS/taa
C-1

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ATTACHMENT D

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07/26/84
OIL AND GAS
GENERAL PERMIT
GENERAL RESPONSIBILITIES OF PARTICIPANTS IN 15 WELL STUDY
Well Operator Responsibilities
1.	Take samples, treat pits and conduct operations in
accordance with the attached instructions.
2.	Discharge pits in accordance with demonstration
guidelines.
3.	Coordinate with the District Inspector of DNR in the
delivery of samples.
4.	Provide well history and pit history in accordance with
later instructions from the Pit Waste Group.
DNR Responsibilities
1.	Furnish sample containers, fixatives and sampling
instructions.
2.	Deliver samples to laboratory.
3.	Perform all sample analysis.
4.	Provide copy of laboratory analysis to Pit Waste Group.

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Sampling and Operating Instructions
Well No. 	
		 Company
Treatment Method #1
(pH Adjustment)
Pit History
Sampling
1. Prior to spudding
Take a representative sample of
water brought to site in advance of
drilling by making a composite of
samples taken at various locations
and depths within the pit or tank.
Two of the samples shall be of
water and material on the surface
of the pit or tank and two of the
samples shall be taken with the
sample bottle submerged. The
composite sample shall be 1 gallon
in size.
2. During drilling of
holes for all surface,
mine, and intermediate
casings.
Take "mud log" samples every 50
feet of well hole and make a
composite sample by combining 1
tablespoon from each sample into a
single container.
Immediately upon comple-
tion of the cementing of
the last string of cas-
ing prior to production
casing.
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallon
in size.
4. During drilling of pro-
duction casing
Take " mud log" samples every 50
feet of well hole and make a com-
posite sample by combining 1
tablespoon from each sample into a
single container.
D-2

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5. Immediately upon comple- Take a representative, sample of
tion of the cementing of water in the pit by making a
final production casing composite of samples taken at at
various locations and depths within
the pit. Eight of the samples
shall be of water and material on
the surface of the pond and eight
of the samples shall be taken with
the sample bottle submerged. The
composite sample shall be 4 gallon
in 6ize.
6. During stimulation flow- Take 3 "mud log" samples and corn-
back	bine total contents of sample into
a single composite sample. The
first sample shall be taken at 1/4
of flowback, the second at 1/2 of
flowback and the third at 3/4 of
flowback.
7. Immediately upon comple-
tion of stimulation
flowback
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallon
in size.
8. Adjust pH in pit to
between 8 and 10. Do
not aerate or mechani-
cally mix the pit
except to the extent
necessary to adjust pH
No sampling required other than
to field test for pH. To make sure
that pH is between 8.0 and 10, take
6 to 8 individual pH field test
measurements.
9. After 24 hours but no
later than 48 hours
after completion of
pH adjustment
Take eight samples of water from
the surface of the pond and make a
composite sample for analysis.
Similarly, take eight samples of
water from the middle depth of the
pit and make a separate composite
sample for analysis. Similarly,
take eight samples of water from
the bottom of the pit and make
D-3

-------
another composite sample for
analysis. The result of this
sampling will be 3 composite
samples of 2 gallons each.
10. After 5 days but no	Take -eamples as outlined in step 9.
later than 6 days
after completion of
pH adjustment
11. After 10 days but no	Take samples as outlined in step 9.
later than 11 days
after completion of
pH adjustment
12. After 20 days but no	Take samples as outlined in step 9.
later than 21 days
after completion of
pH adjustment
13. After 21 days following Take effluent samples in the begin-
completion of initial	ning of discharge, middle of dis-
pH adjustment, pit con- charge and at the end. Do not com-
tents shall be disposed posite these 3 grab samples. Each
of in accordance with sample should be 1 gallon,
demonstration guidelines
including, where neces-
sary, additional adjust-
ment of pH to insure pH
between 8 and 10
D-4

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Sampling and Operating Instructions
Well No. 	
	 Company
Treatment Method #2
(pH Adjustment and Mechanical Aeration)
Pit History	Sampling
1. Prior to spudding	Take a representative sample of
water brought to site in advance of
drilling by making a composite of
samples taken at various locations
and depths within the pit or tank.
Two of the samples shall be of
water and material on the surface
of the pit or tank and two of the
samples shall be taken with the
sample bottle submerged. The
composite sample shall be 1 gallon
in size.
2. During drilling of holes Take "mud log" samples every 50
for all surface, mine, feet of well hole and make a com-
and intermediate casings posite sample by combining 1 table-
spoon from each sample into a
single container.
3. Immediately upon comple- Take a representative sample of
tion of the cementing of water in the pit by making a com-
the last string of casing posite of samples taken at
prior to production cas- various locations and depths within
ing.	the pit. Two of the samples shall
be of water and material on the
surface of the pond and two of the
samples shall be taken with the
sample bottle submerged. The
composite sample shall be 1 gallon
in size.
4. During drilling of pro- Take "mud log" samples every 50
duction casing	feet of well hole and make a com-
posite sample by combining 1
tablespoon from each sample into a
single container.
D-5

-------
tablespoon from each sample into a
single container.
Immediately upon com-
pletion of the cement-
ing of final production
casing
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallons
in size.
During stimulation
flowback
Take 3 "mud log" samples and com-
bine total contents of sample into
a single composite sample. The
first sample shall be taken at 1/4
of flowback, the second at 1/2 of
flowback and the third at 3/4 of
flowback.
Immediately upon com-
pletion of stimulation
flowback
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallons
in size.
Adjust pH in pit be-
tween 8.0 and 10. Do
not aerate the pit
except to the extent
necessary to adjust pH
No sampling required other than to
field test for pH. Before sampling
for pH, the pit content should be
turned over twice to insure thor-
ough mixing. To make sure that pH
is between 8.0 and 10, take 6-8
individual measurements.
D-6

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9. After 24 hours but no
later than 48 hours
after completion of
mixing for pH adjust-
ment
Take eight samples of water from
the surface of the pond and make a
composite sample for analysis.
Similarly, take eight samples of
water from the middle depth of the
pit and make a separate composite
sample for analysis. Similarly,
take eight samples of water from
the bottom of the pit and make
another composite sample for
analysis.
The result of this sampling will be
3 composite samples of 2 gallons.
10. After 5 days but no	Take samples as outlined in step 9.
later than 6 days after
completion of mixing
for pH adjustment
11. After 10 days but no Take samples as outlined in step 9.
later than 11 days
after completion of
mixing for pH adjust-
ment
12. After 20 days but no Take samples as outlined in step 9.
later than 21 days
after completion of
mixing for pH adjust-
ment
13. After 21 days follow-
ing completion of mix-
ing for pH adjustment,
pit contents shall be
disposed of in accord-
ance with demonstration
guidelines including,
where necessary, addi-
tional adjustment of
pH to insure pH between
8.0 - 10.
Take effluent samples in the begin-
ning of discharge, middle of dis-
charge and at the end. Do not com-
posite these 3 grab samples. Each
sample should be 1 gallon.
D-7

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Sampling and Operating Instructions
Well No.
Company
Treatment Method #3
(pH Adjustment, Mechanical Mixing and Mechanical Aeration)
Pit History
Sampling
Prior to spudding
Take a representative sample of
water brought to site in advance of
drilling by making a composite of
samples taken at various locations
and depths within the pit or tank.
Two of the samples shall be of
water and material on the surface
of the pit or tank and two of the
samples shall be taken with sample
bottle submerged. The composite
shall be 1 gallon in size.
During drilling of
holes for all surface,
mine, and intermediate
casings
Take "mud log" samples every 50
feet of well hole and make a com-
posite sample by combining 1 table-
spoon from each sample into a
single container.
3.
Immediately upon com-
pletion of the cement-
ing of the last string
of casing prior to pro-
duction casing.
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallons
in size.
4. During drilling of pro- Take "mud log" samples every 50
duction casing	feet of well hole and make a
composite sample by combining 1
D-8

-------
tablespoon from each sample into a
single container.
5. Immediately upon com-
pletion of the cement-
ing of final production
casing
Take a representative sample of
water in the pit by making a com-
posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallons
in size.
6. During stimulation	Take 3 "mud log" samples and com-
flowback	bine total contents of sample into
a single composite sample. The
first sample shall be taken at 1/4
of flowback, the second at 1/2 of
flowback and the third at 3/4 of
flowback.
7. Immediately upon com- Take a representative sample of
pletion of stimulation water in the pit by making a com-
flowback	posite of samples taken at various
locations and depths within the
pit. Eight of the samples shall be
of water and material on the
surface of the pond and eight of
the samples shall be taken with the
sample bottle submerged. The
composite sample shall be 4 gallons
in size.
8. Adjust pH in pit be-
tween 8.0 and 10. Do
not aerate the pit
except to the extent
necessary to adjust pH
The pit content should be turned
over twice to insure thorough mix-
ing. To make sure that pH has been
raised to 8.0 - 10, take eight sam-
ples from various locations within
the pit and make a 2 gallon compos-
ite sample.
D-9

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9. Accomplish mechanical
aeration with a pump
having the outlet
(fitted with a nozzle)
of the discharge hose
above the level of the
pit water by using other
means including but not
limited to floating aer-
ator, diffuse at the
outlet of the discharge
hose, etc. Continue
aeration until the pit
content is turned over
twice
After completing aeration, take
eight samples from various loca-
tions within the pit and make a 2
gallon composite sample for anal-
ysis.
10. After 24 hours but no
later than 48 hours
after completion of
aeration
Take eight samples of water from
the surface of the pit and make a
composite sample for analysis.
Similarly, take eight samples of
water from the middle depth of the
pit and make a separate composite
sample for analysis. Similarly,
take eight samples of water from
the bottom of the pit and make
another composite sample for
analysis.
The result of this sampling will be
3 composite samples of 2 gallons
each.
11. After 5 days but no	Take samples as outlined in step
later than 6 days	10.
after completion of
aeration
12. After 10 days but no Take samples as outlined in step
later than 11 days	10.
after completion of
aeration
D-1 0

-------
13. After 20 days but no Take samples as outlined in step 9.
later than 21 days
after completion of
aeration
14. After 21 days follow-
ing completion of aer-
ation, pit contents
shall be disposed of
in accordance with
demonstration guide-
lines including, where
necessary, additional
adjustment of pH to
insure pH between 8.0
and 10
Take effluent samples in the begin-
ning of discharge, middle of dis-
charge and at the end. Do not com-
posite these 3 grab samples. Each
sample should be 1 gallon.
D-11

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ATTACHMENT E

-------
METALS AND ORGANICS
WASTE PIT SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
SAMPLING KIT CONTENTS
1. Each Metals and Organics test kit contains three separate
boxes of test materials for ultimate shipment to three
different laboratories, plus some general test equipment.
The sample containers in each box must be filled and
returned to the same box for shipment to the appropriate
laboratory.
An inventory of each box is presented below. Please check
the contents of each box prior to sampling. If any material
is missing, broken, or if you have any questions about the
sampling procedure or Sampling Questionnaire, call Kerri
Kennedy at 703-471-6300 (no collect calls).
Some of the sample bottles contain a strong acid or base, or
powdered or pelletized preservatives. DO NOT POUR THE CON-
TENTS OF THE PROVIDED SAMPLE BOTTLES OUT AND AVOID ANY
CONTACT WITH THE CONTENTS.
The S3 box is a small styrofoam ice chest surrounded by
cardboard containing:
o Two 1-liter brown glass bottles with teflon-lined screw
caps, labeled with SCC number and "GRAB-EXTRACTABLE
ORGANICS" and "GRAB-EXTRACTABLE ORGANICS DUPLICATE"
o Two 40-ml VOA vials with rubber septum top, labeled with
SCC number and "V3-VOA UNPRESERVED" and "V-4 VOA UNPRE-
SERVED (duplicate)"
o One small plastic bag for ice
o Packing materials
o Organics Traffic Report form
The CENTEC box is a small styrofoam ice chest surrounded by
cardboard containing;
o One 1-pint clear glass bottle with teflon-lined screw cap,
labeled with SCC number and "-0-0H PHENOLS"
o One 16-oz rectangular plastic bottle with screw cap,
labeled with SCC number and "-CN CYANIDE"
o One 32-oz brown glass bottle with screw cap, labeled with
SCC number and "OIL AND GREASE"
E-1

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METALS AND ORGAN ICS	2
WASTE PIT SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
o One 16-oz round plastic bottle with screw cap, labeled
with SCC number and "TSS, BOD, COD"
o One small plastic bag for ice
o Packing materials
The Versar box is a small cardboard box containing;
o One 16-oz screw top plastic bottle in a ziploc bag. The
bottle is labeled with SCC number and "Ml METALS-TASK I
(plasma only)"
o Metals Traffic Report form
In addition to these three boxes, your test kit should
conta in:
o One pH kit
o One pair of plastic gloves to protect you while taking
samples. THESE GLOVES MUST BE WORN FOR ALL SAMPLING
ACTIVITIES.
O One 1/2-gal wide mouth jug for taking samples
o One 2-1/2 gal wide mouth jug with wire handles for
compising damples
o Metals and Organics pit Waste Sampling Procedure and
Sampling Questionnaire (this form)
Again, if any material is missing, broken, or you have
questions about the sampling procedure, call Kerri Kennedy
at (703) 471-6300 (no collect calls) or Eli McCoy at
301-348-2107.
SELECT SAMPLE POINTS
2. Select three sample points in the pit, as evenly spaced as
possible from the cuttings return line to the farthest end
of the pit (see example). Record the location of sample
points on the attached Sampling Questionnaire. Record all
other requested information. Please indicate measurement
units. Where gross approximations are used, note with an
asterisk (*).
E-2

-------
(Tear off and discard this sheet after sampling)
EXAMPLE DIAGRAM:
3
U">e
©
rOcyWv
80«t
v
\
^ v.. x
\\T\ 'y^
ftOft
\ \ \ \ v	¦ ""f
v*\\<§>
kvw : (T> ©(£? o-o.He"^Wae scwplec**.-
. Indicates atprmtaauon US®.	^	rf. p^..
E-3

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METALS AND ORGANICS	4
WASTE PIT SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
SAMPLING PROCEDURE
3.	At the first sample point, submerge the capped 1/2-gallon
jug 4 to 6 inches below the fluid surface. Turn the jug on
its side, uncap the jug and allow it to completely fill. Cap
the jug while it is still submerged. Be careful not to stir
up silt from the bottom or to suck surface material into the
sample. "(If either of these happens, rinse the jug out with
pit fluids at this location, then move across the pit to an
equivalent site and repeat the sampling procedure. Note any
change in sample location on the diagram.)
4.	Pour the 1/2-gallon sample into the 2-1/2 gallon jug and
cap.
5.	Follow Step 3 and Step 4 for the second and third sample
points, consolidating each 1/2-gallon sample into the 2-1/2
gallon jug. The 2-1/2 gallon jug will be about 2/3 full when
all three samples have been added to it.
6.	Once all three 1/2 gallon samples are composited into the
2-1/2 gallon jug, carefully swirl the jug to stir the con-
tents. EX) NOT SHAKE THE JUG—SWIRL IT TO STIR.
7.	Check the pH of the sample in the 2-1/2 gallon jug. Take a
small strip of the Alkacid Test strip and dip one end into
the sample and withdraw it. Match the resulting color on
the test strip to the color chart and read the pH value
associated with that color. Record the pH on the Sampling
Questionnaire.
8.	Pour samples from the jug into the supplied containers
(EXCEPT the 40 ml vials with septa or rubber caps) allowing
about 10 percent air space above the liquid. Tightly cap
each bottle after you fill it from the 2-1/2 gallon jug.
Record the Sample Number from each bottle on the Sampling
Questionnaire (they should all be the same). Be careful to
return each filled sample bottle to the box it came from for
shipment to the appropriate laboratory.
9.	The two 40-ml vials with septums or rubber-lined caps must
be completely filled with absolutely no air in the vial. To
accomplish this, pour fluids from the 2-1/2 gallon jug into
each vial until it is totally full with the meniscus (fluid
surface) bulging slightly above the vial top. Carefully
slide the rubber part of the cap over the meniscus and seal
the vial. After the vial is sealed, check it for bubbles.
If there are any bubbles, repeat the process until you are
sure the sample is air-free. Record the sample number from
each vial on the Sampling Questionnaire.
E-4

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METALS AND ORGANICS	5
WASTE PIT SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
10.	The 1/2 gallon jug and 2-1/2 gallon jug may now be disposed
of.
11.	Recheck to make sure that the appropriate sample bottles are
returned to the box for each laboratory. The inventory
under Item 1 of this procedure should be used to check the
contents of each box.
SHIPPING INSTRUCTIONS
12.	Immediately ice down the contents o the S^ and CENTEC
boxes by putting ice in the provided twist-top bags and then
settling the ice down over the sample bottles. IX) NOT USE
LOOSE ICE—USE THE ENCLOSED PLASTIC BAG FOR ICING DOWN THE
SAMPLES. Please be sure the bottles are adequately packed
to prevent breakage during shipping—you may have to use the
provided packing materials in addition to the ice. Please
provide adequate ice to allow the samples to reach the
analytical laboratory well preserved.
The S^ and CENTEC samples must be shipped on ice to arrive
at the analytical laboratories within 24 hours of sampling.
SUSAN HANCOCK AT EPA SAMPLE CONTROL CENTER (703-557-504 0)
MUST BE CONTACTED UPON SHIPMENT OF EACH SAMPLE. IF SHE IS
UNAVAILABLE, JIM KING AT THE SAME TELEPHONE NUMBER MAY BE
NOTIFIED.
When you call Susan, identify yourself, then give her the
samples by company and well location, sample number(s), and
shipping identification numbers (Airbill number, etc.).
13.	Complete the EPA Traffic Report and pack the Metals Traffic
Report with the Versar sample, and the Organics Traffic
Report with the S^ samples. Pack the forms so they will
stay dry during shipping. Follow directions on the back of
those forms regarding who keeps what copy of the Traffic
Reports.
14.	Complete the Sampling Questionnaire and return it to CENTEC
at the address on the Questionnaire.
15.	The metals sample (Versar box) may be accumulated at a
central point designated by Eli McCoy with metals samples
from other testing for shipment once a week to Versar.
AGAIN, SUSAN HANCOCK MUST BE NOTIFIED UPON SHIPPING.
E-5

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METALS AND ORGANICS
WASTE PIT SAMPLING
QUESTIONNAIRE
MAIL COMPLETED FORM TO:
CENTEC Corp.
11260 Roger Bacon Drive
Reston, VA 22090
Attn: K. C. Kennedy
Permit No.: 	
Well Operator:		
Well No.:			
Well Location: Co. Dist.
Sampling Date/Time:	
Sample Nos. from Metals Traffic
Report: 	
Air Temp. 	 °F
PIT CONDITION AT SAMPLING (Check One):
	 Immed. upon completion of stimulation flowback
	 24-48 hrs. after pit treatment
	 5-6 days after pit treatment
	 10-11 days after pit treatment
	 20-21 days after pit treatment
	 Other, describe: 	
PIT TREATMENT PRIOR TO-SAMPLING (Check applicable treatment)
	 None
	 pH adjustment only
	 pH adjustment, mixing (2 pit volumes)
	 pH adjustment, mixing (2 pit volumes) and aeration
< 2 pit volumes)
	 Other, describe: 	 	
SAMPLING PERSONNEL (List any company or agency representatives
present during sampling):
Name	Affiliation	Address	Telephone #
SAMPLE pH 	
SAMPLING DIAGRAM—Please show location of cuttings return line,
pit dimensions, pit depth (to cuttings) across profile,
oil/grease or foam film on pit surface, location of sample
points, and any unusual site or sample conditions:
h*-		H
I IT
	it
	I
* Indicates approximation

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METALS ONLY	1
PIT WASTE SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
GENERAL INSTRUCTIONS FOR EACH SAMPLE
1. Your test kit contains two forms (this one and a Metals
Traffic Report), one plastic snap-top Sample Collection Cup
(approximately 125 ml) and one 16 oz plastic Metals Sample
Bottle (containing acid). The 16 oz bottle should arrive
in and be returned in a sealed ziploc bag. Both forms must
be completed during sampling. This form (the Sampling
Questionnaire) will be sent to CENTEC in the enclosed
envelope. The Metals Traffic Report form will be shipped
per instructions on the back of the form.
The enclosed containers are prelabeled and precleaned. They
are ready for receiving samples. The Metals Sample Bottle
contains a small amount of strong acid for preserving the
samples. DO NOT POUR THE ACID OUT AND AVOID ANY CONTACT
WITH IT. The snap-top bottle not containing acid will be
used to collect the samples. Do not open the sample bottles
until you are ready to fill them.
Plastic gloves to protect you while taking samples are
provided in the test kit. FOR SAFETY REASONS, THEY MUST BE
WORN FOR ALL SAMPLE TAKING AND HANDLING ACTIVITIES.
A pH kit is also provided in the test kit (see Step 7.)
If any material in your test kit is missing or broken, or if
you have questions about the sampling procedure, call Kerri
Kennedy at (703) 471-6300 (no collect calls) or Eli McCoy at
304-348-2107.
SELECTING SAMPLING POINTS
2. Select three sample points in the pit, as evenly spaced as
possible, starting from the cuttings return line to the .
farthest end of the pit (see example diagram below). Record
the location of sample points on the attached Sampling
Questionnaire. Record all other requested information.
Please indicate measurement units (pounds, feet, or what-
ever). Where gross approximations are used, note with an
asterisk (*).
EXAMPLE DIAGRAM:
Indicates	KlSfBL '
E-7
0 © G2	"ttVR a&nryle
Ou> cjooc Iftrc+V-, o£ pl+

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METALS ONLY	2
PIT WASTE SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
SAMPLING PROCEDURE
3.	At the first sample point, submerge the capped Sample
Collection Cup 4 to 6 inches below the fluid surface. Turn
the bottle on its side, uncap the bottle and allow it to
completely fill. Cap the bottle while it is still sub-
merged. Be careful not to stir up silt from the bottom of
the pit or to suck surface material into the sample. (If
either of these happens, rinse the bottle out with pit
fluids at this location, then move across the pit to an
equivalent site and repeat the sampling procedure. Note any
change in sample location on the diagram.)
4.	Pour the sample into the 16 oz Metals Sample Bottle and
cap.
5.	Using the same Sample Collection Cup, follow Step 3 and
Step 4 for the second and third sample points, pouring each
sample into the Metals Sample Bottle. The Metals Sample
Bottle will be almost full when all three samples have been
added to it.
6.	Dispose of the used Sample Collection Cup.
7.	Check the pH of the sample in the 16 oz bottle. Take a
small strip of the Alkacid Test strip and dip one end into
the sample and withdraw it. Match the resulting color on
the test strip to the color chart and read the pH value
associated with that color. Record the pH on the Sampling
Questionnaire.
8.	Complete the Sampling Questionnaire and mail it in the
enclosed self-addressed envelope to CENTEC Corp., 11260
Roger Bacon Drive, Reston, Virginia 22090, Attention:
K. C. Kennedy.
PLEASE DIRECT ALL QUESTIONS ABOUT SAMPLING PROCEDURE OR TEST
KIT MATERIALS TO KERRI KENNEDY 703-471-6300. NO COLLECT
CALLS.
E-8

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METALS ONLY	3
PIT WASTE SAMPLING QUESTIONNAIRE
SAMPLING PROCEDURE AND EXAMPLE
(Tear off and discard this sheet after sampling)
SHIPPING INSTRUCTIONS
9.	Replace the tightly-capped Metals Sample Bottle in the
ziploc bag and seal it for shipping.
10.	Complete the Metals Traffic Report and keep it with the
sample (but NOT inside the ziploc bag). Samples for metals
analysis will be accumulated at a central point designated
by Eli McCoy for shipment to Versar once a week (pread-
dressed shipping label is enclosed in test kit). Be sure to
follow the instructions on the back of the Metals Traffic
Report for sending copies of the report to EGD Sample
Control Center and to Versar (the analytical laboratory).
11.	Once a week, ship metals samples to Versar. CALL SUSAN
HANCOCK AT 703-557-5040 (OR JIM KING IN SUSAN'S ABSENCE) TO
NOTIFY HER OF THE SHIPMENT. IDENTIFY YOURSELF TO SUSAN,
THEN GIVE HER THE SAMPLES (BY COMPANY AND WELL LOCATION),
SAMPLE NUMBERS, AND SHIPPING IDENTIFICATION NUMBERS.
SUSAN HANCOCK MUST BE NOTIFIED UPON SHIPPING.
E-9

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METALS ONLY
PIT WASTE SAMPLING
QUESTIONNAIRE
MAIL COMPLETED FORM TO:
CENTEC Corp.
11260 Roger Bacon Drive
Reston, VA 22090
Attn: K. C. Kennedy
Co.
Dist
Pe rm i t No.: 	
Well Operator:
Well No.:	)
Well Location: 	 	
Sampling Date/Time:	
Sample Nos. from Metals Traffic
Report: 		
Air Temp.	°F
PIT CONDITION AT SAMPLING (Check One):
	 Immed. upon completion of stimulation flovback
	 24-48 hrs. after pit treatment
	 5-6 days after pit treatment
	 10-11 days after pit treatment
	 20-21 days after pit treatment
	 Other, describe: 	
PIT
TREATMENT PRIOR
None
TO SAMPLING (Check applicable treatment)
pH adjustment only
pH adjustment, mixing
pH adjustment, mixing
(2 pit volumes)
Other, describe: 	
(2
(2
pit
pit
volumes)
volumes)
and aeration
SAMPLING PERSONNEL (List any company or agency representatives
present during sampling):
Name
Affiliation
Address
Telephone #
SAMPLE pH 	
SAMPLING DIAGRAM—Please show location of cuttings return line,
pit dimensions, pit depth (to cuttings) across profile,
oil/grease or foam film on pit surface, location of sample
points, and any unusual site or sample conditions:
H*	—ft	
I IT
	ft
	I
* Indicates approximation
E-1 0

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ATTACHMENT F

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Oil And Gas Bioassay Results
Twenty-four toxicity tests were conducted as part of a study of the treatment
and disposal of oil and gas pit fluids. Static bioassays using Fathead Minnows
were conducted on these wastes at various stages of field treatment. Screening
tests (in which the minnows are exposed only to 100% effluent for 24 hours) were
performed approximately 1, 5, 10, and 20 days after field treatment of pit wastes.
Although no LC50 can be'determined, these tests do indicate the degree of toxicity.
A carbon adsorption test was performed when pit fluids demonstrated toxicity one
day post-treatment. For this test one liter of pit wastes was placed into five
beakers. Each beaker then received 0, 500, 750, 1,000, or 1,200 mg of activated
carbon. These containers were incubated for five days at 25°C. After incubation
the carbon was removed from the beakers, five fish were added to each, and mor-
talities were recorded for a 24-hour period. "Full" bioassays were performed on
composite samples collected during the discharge of the pit fluids. Five concentra-
tions (1002, 562, 32%, 18%, and 10% pit wastes) were tested for 96 hours. Mortali-
ties were recorded and an LC50 was determined. The results of these bioassays are
presented below:
J & J Enterprises, Well #J-1042, Barbour County, Permit #0012125
24-48 hours after field treatment - no toxicity demonstrated.
5-6	days post-treatment - no toxicity demonstrated.
10-11	days post-treatment - no toxicity demonstrated.
20-21	days post-treatment - no toxicity demonstrated.
Pit Discharge - LC50 = 85%
J & J Enterprises, Well #WK-3G3, Ritchie County, Permit #47-085-7015
24-48 hours after field treatment - 100% mortality.
Carbon adsorption test - 100% mortality in all pit wastes, with
and without carbon.
8 days post-treatment - 100% mortality.
10-11 days post-treatment - 100% mortality.
Pit Discharge - LC50 = 13.25%
Union Drilling, Well #1941, Upshur County, Permit #47-097-2664
24-48 hours after field treatment - 100% mortality.
Carbon adsorption - 100% mortality in all pit wastes, with and
without carbon. When these solutions were diluted 50%, all
fish survived in carbon treated wastes; 20% mortality observed
in the zero-carbon pit fluid.
5-6 days post-treatment - 70% mortality.
11 days post-treatment - no toxicity demonstrated.
20-21 days post-treatment - no toxicity demonstrated.
Pit Discharge - LC50 = 75%
F-1

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Oil and Gas Bioassay Results
Page 2
Chesterfield Energy, Doddridge County, Permit #47-017-3341
24-48 hours post-treatment - no toxicity demonstrated.
5-6 days post-treatment - no toxicity demonstrated.
20-21 days post-treatment - no toxicity demonstrated.
Discharge - no toxicity demonstrated.
Cabot Oil and Gas, Albertson #4, Putnam County
24-48 hours post-treatment - 100% mortality.
5-6 days post-treament - 100% mortality.
Carbon adsorption - 100% mortality in all pit wastes,
carbon treated or not:
Discharge - LC50 = 12.75%
In summary, two wells - J & J Enterprises #J-1042 and Chesterfield
Energy - were essentially non-toxic throughout the treatment period. The
J & J well, however, did demonstrate slight toxicity during the 96 hour
test. Two wells displayed extreme toxicity throughout the study - J & J
Enterprises #WK353 and Cabot Oil and Gas Albertson #4. These had final
LC50's of 13.25% and 12.75%, respectively. Union Drilling's Well #1941
demonstrated a decrease in toxicity as treatment progressed. The initial
tests were extremely toxic, however, by the eleventh day of field treatment
no toxicity was displayed. The final bioassay was only slightly toxic (LC50 - 75%).
F-2

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STATE OF WEST VIRGINIA
DEPARTMENT OF NATURAL RESOURCES
CHARLESTON 25306
IN D. ROCKEFELLER IV
Govarnor
November 26, 1984
WILLIS H. HERTIG. JR.
Director
RONALD R. POTESTA
Deputy Director
Mr. David Flannery, Esquire
Robinson & McElwee
P. 0. Box 1791
300 Energy Center
Charleston, West Virginia 25326
Dear Dave:
Enclosed is a copy of the proposed protocal for sampling for further
bioassay work. Let me know if you have comments. If I don't here from you,
I'll have it sent out December 7, 1984, and I hope that date selection is just
an innocent coincidence.
Sincerely yours.
DIVISION OF WATER RESOURCES
Laidley Eli McCoy, Ph. D.
Assistant to the Chief
LEM/cIs
Enclosure
cc: Bill Brannon
Janice Fisher
F-3

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Protocal for Bioassay Sampling
Forty-efght hours prior to discharge the company should follow theses
procedures:
1.	Contact Water Resources Biology Section (phone: 318-5929,
Janice Fisher, Section Leader). Biologists will evaluate
their work load and decide whether or not the bioassay
can be accepted.
2.	If the Biology Section is unable to perform the bioassay,
the company may proceed with the discharge. No sampl-
ing other than that required by the interim guidelines
will be necessary.
3.	Company collects samples as 3 groups during discharge
then composites them. DNR will provide sample container
to companies. A supply will be sent to the DNR District
offices and can be dropped off by the inspector or picked
up by the company.
Minimum sample volume is 1j gallons. Sample label should
provide the following information: Name of company. Well
number, date and time of collection, permit number, and
location (county or nearest town). Samples should be
preserved on ice.
5. Sample should be delivered to the Charleston Lab no later
than 72 hours after collection. Weekend deliveries are
to be avoided. If possible, notify the Biology Section of
the estimated time of arrival.
F-4

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PRELIMINARY report
I. LABORATORY BIOASSAY PROCEDURES
Bioassays were conducted using fathead minnows (Pimephales prom&las)
for 24 hours. Since the treatment process involved raising the pH of the
wastewater to 8-10. treated fluids had to be neutralized before the bioassay
was conducted. In cases where this was not done, the fish died immediately
upon entering the test chamber. The bioassays were not aerated.
II. INSTREAM BIOASSAY PROCEDURES
Instream bioassays were conducted using fathead minnows, acclimated to
the stream temperature. The test chambers were clear plastic jars with
screening at both ends to allow stream water to flow through. The chambers
rested on the bottom in shallow pools, so that they were completely
submerged. The tests were conducted for 24 hours.
III. WASTE TREATMENT PROCEDURES
In most cases, hydrated lime was used to raise the pH of the pit
fluids to a pH between 8 and 10. The fluids then had to settle for at
least 24 hours. At this point, the fluids could be withdrawn from the pit
and either land applied or metered to a stream. The device used to with-
draw the fluids from the pit had to provide a means of withdrawing fluids
from below the surface of the pit (skimming) and a means of preventing the
discharge of bottom sludge.
IV. COMMENTS ON BIOASSAY RESULTS
1.	Definition of LC50: The LCgn of a test solution is the per cent
of the full strength solution which results
in death to 50% of the fish in 24 hours.
For example, LC50 = 20% indicates that, in a
solution of 20% pit water and 80% dilution water,
50% of the fish would die in 24 hours. The lower
the LC50, the more toxic the test solution.
2.	All bioassays were conducted on pit fluids after stimulation, except
where noted. Thus, the fluids contained both drilling fluids and
stimulation fluids.
3.	Note that treatment decreased the toxicity of the fluids where
treated and unt _ :ed fluids were testeJ.
4.	Also note that in many cases, the exhibited toxicity was produced
by either oxygen depletion during the bioassay or failure to adjust
the pH of the fluid before the bioassay.
5.	Many of the low LCsq's (i.e., more toxic pit fluids) resulted from
the pits of one company. The Division is trying to determine whether
this is caused by perhaps an additive used only by this company, or
a stimulation method, or the geographic area, or any other factor.
F-5

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PRELIMINARY REPORT
BIOASSAY RESULTS ON OIL AND GAS DRILLING
AND STIMULATION WASTE FLUIDS IN WEST VIRGINIA
1. LABORATORY BIOASSAYS
Well Name
Treated
L£so
Comments
Davis
No
8%

Davis
Yes
25%
Oxygen depletion during bioassay
Chesterfield
No .
22%

Chesterfield
Yes
m
Oxygen depletion during bioassay
Kepco
No
26%

Kepco
Yes
28%

Drennan
No
11%
Dry hole, not stimulated, drilling fluids
Drennan
Yes
50%
II II II II II II
Kaiser
No
22%

Stonewood
Yes
--
100% survival
Alamco
Yes
--
100% survival
Borg-Warner 1
Yes
--
100% survival
Borg-Warner 2
Yes
—
100% survival
Borg-Warner 3
Yes
—
100% survival
Elk Lick
Yes
—
100% survival
Devers
Yes
90S
pH not adjusted before bioassay
Wood
Yes
87%

Henderson
Yes
75%

Frog Run
Yes
73%
Oxygen depletion during bioassay
Hal stead
Yes
49%

Dodd
Yes
37%

Haddox Run
Yes
25%

Bartram
Yes
13%
Sodium hydroxide used to raise pH of pit
Eagleland
Yes
23%

INSTREAM BIOASSAYS



Bartram
Yes
No deaths
Burnside
Yes
No deaths
Eagleland
Yes
Deaths
occurred in both upstream control and

downstream test chambers. Stream received


mine
draii
Elk Lick
Yes
No deaths
WVDNR, DWR March 14
, 1984



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