analysis of michigan department of environmental quality high

Transcription

ANALYSIS OF MICHIGAN DEPARTMENT
OF ENVIRONMENTAL QUALITY HIGH VOLUME
HYDRAULICALLY FRACTURED WELL
COMPLETIONS AND APPLICATIONS
FARWatershed.com
respectmyplanet.org
March 28, 2014
Clockwise from top left: Pioneer 1-3HD1, Excelsior 1-25HD1, Garfield 1-25HD1, Beaver Creek 1-23HD1.
Table of Contents
GENERAL HF INFORMATION ................................................................................................................. 3
Drilling and Completion ........................................................................................................................... 3
Drilling .................................................................................................................................................. 3
Completion............................................................................................................................................ 4
Formation Characteristics ......................................................................................................................... 4
Conventional & Unconventional .......................................................................................................... 4
Permeability & Porosity ........................................................................................................................ 5
Interstitial Gas & Adsorbed Gas ........................................................................................................... 5
Natural Fractures ................................................................................................................................... 5
Formation Pressures .............................................................................................................................. 5
Induced Pressure ....................................................................................................................................... 6
Water ......................................................................................................................................................... 6
High Volume & Large Volume ............................................................................................................ 6
Consumptive Use of Water ................................................................................................................... 7
Chemicals.................................................................................................................................................. 7
Proppants .................................................................................................................................................. 7
WELLS ON THE HVHF CHART ............................................................................................................... 8
Large Volume Wells ................................................................................................................................. 8
Utica/Collingwood ................................................................................................................................ 8
A-1 Carbonate ....................................................................................................................................... 9
High Volume Wells ............................................................................................................................... 10
Antrim ................................................................................................................................................. 11
Dundee ................................................................................................................................................ 11
Niagaran .............................................................................................................................................. 12
Black River (VanWert) ....................................................................................................................... 12
SUMMARY ................................................................................................................................................ 13
ANALYSIS OF MDEQ HIGH VOLUME HYDRAULICALLY FRACTURED WELL
COMPLETIONS AND APPLICATIONS
This paper addresses the list of high volume hydraulically fractured wells published by the
Michigan Department of Environmental Quality, Office of Oil, Gas and Minerals, (MDEQOOGM) on its website dated March 18, 20141, attached as Appendix A. When you look at the
list of 58 HVHF wells on the MDEQ list, you may assume that all of them involve the use of
millions of gallons of water and toxic chemicals at extremely high pressure to complete. This is
not the case, and the differences are significant enough to warrant better understanding. An
overall comparison of the factors discussed in this paper as they pertain to the wells on the
MDEQ chart is contained in Appendix D, and you can skip right to it if you want to know the
“what” of the differences between the wells—but if you want to know the “why” for the
differences, we have attempted to give some basic descriptions of the contributing factors. The
source papers linked to the paper afford in depth education on many of these for anyone seeking
deeper understanding.
GENERAL HF INFORMATION
Drilling and Completion
To start with the basics, hydraulic fracturing (HF) is not a drilling technique. It is a completion
technique. It is defined by the MDEQ as a well completion operation that involves pumping fluid
and proppant into a target formation to create or propagate artificial fractures, or enhance natural
fractures, for the purpose of improving the deliverability and production of hydrocarbons.2
Each well has two phases: the drilling of the well (which does not involve fracturing but does
involve the use of water and/or other fluids), and the completion of the well (which may involve
fracturing, and the use of water and/or other fluids, and may include additional chemicals).
Drilling
Drilling fluid or “mud” is a very important component of the drilling process. The main
functions of drilling fluids include providing hydrostatic pressure to prevent formation
fluids from entering into the well bore, keeping the drill bit cool and clean during drilling,
carrying out drill cuttings, and suspending the drill cuttings while drilling is paused and when the
drilling assembly is brought in and out of the hole. The drilling fluid used for a particular job is
selected to avoid formation damage and to limit corrosion.3 The wells on the MDEQ chart will
not all be drilled using the same kind of drilling fluid. The components of the fluid can
sometimes be found in the well summary contained in the MDEQ well file (Page 60 of the
Kohler-Kendall well file is a good example4), or may be available through a Freedom of
Information Act request to the MDEQ.
1
http://www.michigan.gov/documents/deq/High_Volume_Hydraulic_Fracturing_Activity_DATA_TABLE_423436_7.pdf
2
http://www.michigan.gov/documents/deq/Supervisor_of_Wells_Insruction_1-2011_428260_7.pdf
3
http://en.wikipedia.org/wiki/Drilling_fluid#Dispersed_systems ; http://www.aesfluids.com/ ;
https://www.rigzone.com/training/insight.asp?insight_id=291&c_id=24
4
http://ww2.deq.state.mi.us/GeoWebface/GeoWebface/WF/031/60170_WF.pdf
Completion
The completion phase of an HF well is the stage when the hydraulic fracturing occurs.
Completion sometimes involves perforating the horizontal section of the pipe and the cement
casing installed in a well with explosive charges contained in a perforating gun, then injecting
fluid and proppant under pressure into the formation through the openings (perforations), to
create fractures in the rock or enhance naturally occurring fractures already present. The amount
of pressure necessary to create or enhance fractures and the type of fluid used varies greatly,
depending on the characteristics of the formation being accessed. Some HF wells have horizontal
sections which are “open hole” and do not involve creating perforations.
The key differences between the completion techniques used on the listed wells discussed here
are




Induced pressure
Composition and amount of chemicals
Amount of proppant
Volume of water
All of these factors vary, depending on the formation characteristics.
Formation Characteristics
Geologic formation characteristics and the way gas and oil are deposited within them dictate
completion techniques.5 For this reason, we group the wells and applications according to the
targeted geological formation. To get a sense of how deep the target formation is, see the
Stratigraphic Map attached as Appendix B. The way hydrocarbons have been deposited in the
formation, the physical structure of the formation rock, and the depth of the formation all affect
the method of completion indicated to extract the hydrocarbon.
Conventional & Unconventional
The term “conventional” or “unconventional” describes the way gas or oil is situated in the
formation. It does not describe the method of removing it. Conventional natural gas is generally
held as a pocket of gas beneath a rock layer with low permeability and flows freely to the surface
once the well is drilled. By contrast, unconventional natural gas is more difficult to extract
because it is trapped in rock with very low permeability. Unconventional natural gas does not
flow freely to the surface once the well is drilled. Three common types of unconventional gas
include: (1) coalbed methane, which is sourced from within a coal seam or in the surrounding
rock; (2) tight natural gas, which is found in low- porosity sandstones and carbonate reservoirs;
and (3) shale gas, which is trapped in the pore space of shale rocks.6 Of the formations for the
wells on the MDEQ chart, the Utica, Collingwood, Antrim, and A-1 Carbonate formations are
5
6
http://web2.geo.msu.edu/geogmich/Oil&gas.html
http://www.pacinst.org/wp-content/uploads/sites/21/2013/02/full_report35.pdf
termed unconventional: the Black River (Van Wert), Niagaran and Dundee are termed
conventional. 7,8,9
Permeability & Porosity
Permeability is a measurement of how easily fluid flows through rock. Fluid flow is much easier
in rock with higher permeability. The values of high, moderate, and low permeability assigned to
a rock formation are defined on the basis of both the formation permeability and the reservoir
fluid viscosity.10 When you see the terms “low permeability” it generally means it will be more
difficult to remove the hydrocarbon from the rock than in formations defined as “high
permeability”. Porosity of a rock is a measurement of its ability to hold a fluid. Mathematically,
porosity is the open space in a rock divided by the total rock volume (solid + space or holes).
Porosity is normally expressed as a percentage of the total rock which is taken up by pore space.
For example, a sandstone may have 8% porosity. This means 92 percent is solid rock and 8
percent is open space containing oil, gas, or water.11
Interstitial Gas & Adsorbed Gas
Interstitial gas refers to gas stored in the pore spaces of the rock: sometimes referred to as “free
gas”. Adsorbed gas has adhered to organic particles present in the rock. Completion techniques
will vary depending on whether gas is interstitial or adsorbed.
Natural Fractures
Fractures may be referred to as “natural fractures” to distinguish them from induced fractures-as
the name implies, natural fractures are already present in the rock. In some reservoirs, natural
fractures improve production. In other cases, natural fractures can complicate reservoir
stimulation. The Antrim is naturally fractured and its fractures can be enhanced with relatively
low pressure. While some natural fractures exist in the Utica, no natural fractures are observed in
the core samples from the Collingwood.12,13
Formation Pressures
Generally speaking the deeper the formation, the greater the pressure encountered. The term
“bottom hole pressure” means either the pressure present at the bottom of the well, or at the top
of the perforated interval. As fluid is released from the formation, pressure will change.
Formation pressure affects both drilling and completion.
7
http://phx.corporate-ir.net/External.File?item=UGFyZW50SUQ9MTMzMjM5fENoaWxkSUQ9LTF8VHlwZT0z&t=1
http://certmapper.cr.usgs.gov/data/noga95/prov63/text/prov63.pdf ;
http://bradfordgordon.com/pdf/USGSMichiganCore8_22.pdf
9
https://www.ugcenter.com/US-Shales/Unconventional-Action-Pops-Southeastern-Michigan_86565: request article from
[email protected]
10
http://petrowiki.org/Fracturing_high-permeability_formations
11
http://www.geomore.com/porosity-and-permeability-2/
12
http://msue.anr.msu.edu/uploads/235/29659/OilGasnews_June_2013.pdf, Encana Oil and Gas Outlines Utica Collingwood Play
13
http://digitalcommons.mtu.edu/cgi/viewcontent.cgi?article=1311&context=etds
8
All of the characteristics discussed above will affect the level of pressure, amount and type of
fluid, and the amount of proppant used to hydraulically fracture a formation and complete a well.
Induced Pressure
The pressure at which fluid is pumped into the well during completion varies, depending on all
of the formation characteristics discussed above. For the wells in the formations we concern
ourselves with here, the greatest pressure is utilized for wells into the Utica Collingwood.
Sustained pressure of 9200 psi, and peaks at over 10,000 psi, were used to complete Encana's
State Beaver Creek 1-23 HD1 well in May of 2013.14 Nine days were needed to fracture 33
stages.15
In comparison, the Antrim Shale has very different formation characteristics than the
Collingwood. As a result, the pressure used during completion is much lower. Completion
pressures between 800 and 1800 psi, depending on depth and location, are used in typical Antrim
wells. Antrim wells can be completed in one day and typically require 2-5 stages.16 There is only
one Antrim well on the MDEQ’s HVHF chart because typical Antrim wells are not high volume.
Why such a pressure disparity between the Antrim and the Collingwood? The Collingwood has
low permeability and has little or no natural fracturing. The Antrim on the other hand, is
considered a naturally, un-conventional shale due to an extensive natural fracture network.
Simply put, less pressure is needed to expand the Antrim's natural fractures than is needed to
create new cracks in the Collingwood. Formation depth also plays a role in pressure. Total
measured depth (TMD17) of wells that exceed 20,000 feet, will require much more pressure
during hydraulic fracturing than a 1500 ft. vertical well simply because more friction must be
overcome.
Water
High Volume & Large Volume
MDEQ-OOGM states that hydraulic fracturing has been occurring in Michigan for about 50
years18. It does not say that high volume or large volume hydraulic fracturing has been occurring
in Michigan for 50 years, and this is an important distinction.
“High Volume” is defined by MDEQ as a well that is completed using over 100,000 of any
liquid: water, brine, foam, acid, or gels.
“Large Volume”, on the other hand, means using more than 100,000 gallons of water per day
over a consecutive 30 day period (100,000 gallons of water over 30 days=3,000,000 gallons) to
complete a well. Only operators intending to use a large volume water withdrawal for well
14
http://www.respectmyplanet.org/public_html/documents/BeaverCreek.Completion_Program_.pdf
http://www.respectmyplanet.org/public_html/documents/CompletionReport.BeaverCreek_.pdf
16
http://www.geo.mtu.edu/svl/LINGO/reports/42931_LINGO_Antrim_Play_Handbook.pdf
17
Total Measured Depth=Vertical + Horizontal length of wellbore
18
http://www.michigan.gov/documents/deq/deq-FINAL-frack-QA_384089_7.pdf
15
completion are required to utilize the Water Withdrawal Assessment Tool (WWAT) in
accordance with Supervisor of Wells Instruction 1-201119.
Also note that there is no reporting requirement for the amount of fresh water withdrawn for
drilling the well: only completing the well. Wells going into deep formations, or with long lateral
wellbores, may use from 300,000 to more than 1,000,000 gallons20 of fresh water to drill the well
which should be included in water withdrawal analysis.
Consumptive Use of Water
The water used for gas and oil extraction is 100% consumptive,21 meaning none of it is returned
to the hydrological cycle. There is no requirement in Michigan to recycle the water used for gas
and oil extraction.
Chemicals
What is in completion fluids? The answer varies greatly, depending on what formation a well is
being completed in. In the Antrim formation, many hundreds of wells have been completed with
nitrogen foam. In the A-1 Carbonate, acid stimulation is common. In the Utica / Collingwood,
fresh water mixed with an array of chemical constituents is used. Some of these chemicals are
highly toxic, and may also be classified as endocrine disruptors or carcinogens.22 Encana has
posted the chemical constituents utilized in six of the wells completed to date on the FracFocus
website23, and MDEQ has Material Safety Data Sheets posted for some of those. Some of the
chemicals are listed as “proprietary” and their names are not disclosed.24 Slickwater or slick
water fracturing is a method or system of hydraulic fracturing which involves adding chemicals
to water to increase the fluid flow. Fluid can be pumped down the wellbore as fast as 100
bbl25/min. to fracture the shale. Without using slickwater the top speed of pumping is around 60
bbl/min.26
Proppants
A proppant is a solid material designed to keep an induced hydraulic fracture open, during or
following a fracturing treatment. All of the wells considered in this paper utilized sand as a
proppant. The size of the sand particles are described in terms of mesh size, and the size range of
the proppant is very important. Typical proppant sizes are generally between 8 and 140 mesh
(106 µm - 2.36 mm), for example 16-30 mesh (600 µm – 1180 µm), 20-40 mesh (420 µm - 840
µm), 30-50 mesh (300 µm – 600 µm), 40-70 mesh (212 µm - 420 µm) or 70-140 mesh (106 µm 212 µm). When describing frac sand, the product is frequently referred to as simply the sieve cut,
i.e. 20/40 sand.27 Crystalline silica, in the form of sand (“frac sand”), plays a major role in the
hydraulic fracturing process."Frac sand" is a high-purity quartz sand with very durable and very
19
http://www.michigan.gov/documents/deq/Supervisor_of_Wells_Insruction_1-2011_428260_7.pdf
http://www.shalegaswiki.com/index.php/Amount_of_Water_Used
21
http://nrconservation.msu.edu/uploads/files/105/MSUE_BulletinWQ62_WaterWithdrawalsandWaterUseinMichigan.pdf
22
http://democrats.energycommerce.house.gov/sites/default/files/documents/Hydraulic-Fracturing-Chemicals-2011-4-18.pdf
23
http://www.fracfocusdata.org/DisclosureSearch/
24
http://www.michigan.gov/deq/0,4561,7-135-3311_4111_4231-262172--,00.html
25
Bbl=barrel. One barrel = 42 gallons
26
http://www.waytogoto.com/wiki/index.php/Slickwater
27
http://www.horiba.com/scientific/products/particle-characterization/applications/frac-sand/
20
round grains.28 In the United States there are two preferred types of frac sand - Ottawa (white)
and Brady (brown), the former found mostly in the St. Peter sandstone formations spanning
north-to-south from Minnesota to Missouri and east-to-west from Illinois into Nebraska and
South Dakota. This quartz silica sand is the highest quality available.29
Not all of the completion records filed with the MDEQ for the wells discussed here contain
proppant information. The Encana Beaver Creek 1-23 HD1 well used an unprecedented
18,707,700 pounds of sand to complete.30 This is the largest reported use of proppant by any
well on the HVHF list.
WELLS ON THE HVHF CHART
Large Volume Wells
Utica/Collingwood
34 out of the 58 wells listed on the MDEQ HVHF chart target either the Utica or the
Collingwood formations, or both, and Encana Oil & Gas (USA) Inc. (Encana) is the operator on
29 out of the 34. The Utica is a shale formation lying just above the Collingwood, which is
sometimes classified as a carbonate formation. Both formations are often permitted together as a
target formation by MDEQ-OOGM. All of the permits listed for this formation are located in
Cheboygan, Missaukee, Kalkaska, Crawford and Roscommon counties. The first production
from the Utica/Collingwood was in 2011, from the Excelsior 1-13 HD1 well in Kalkaska
County. Although the Encana Pioneer and Kohler Kendall wells were completed earlier, neither
well has a pipeline installed to the well and both are temporarily abandoned. Since November of
2011, the six Encana wells producing from this formation have not yielded stellar results in
comparison with other plays in North America31, but it’s too soon to tell what the overall
production curve will look like. Production figures are available for these wells at
respectmyplanet.org.32
Encana has used, and proposes to use, significantly larger amounts of water to complete its
Utica/Collingwood wells than any other producer in any other formation to date (For a list of
the Encana wells and water use See Appendix C).
All of the Encana wells completed or proposed on the MDEQ chart in this formation are Large
Volume and have used, or propose to use, more than 3,000,000 gallons of water. The latest
applications filed by Encana for its BRCA wells in Kalkaska County estimate using 35,280,000
gallons of water per well33.
28
http://geology.com/articles/frac-sand/
http://fracdallas.org/docs/sand.html
30
http://www.respectmyplanet.org/public_html/documents/CompletionReport.BeaverCreek_.pdf
31
http://www.eia.gov/oil_gas/natural_gas/data_publications/eia914/eia914.html
32
Go to respectmyplanet.org, click on a well from the map or the legend, click on homepage, click on production.
33
http://www.respectmyplanet.org/public_html/documents/A130152.pdf
29
Only 5 wells listed on the chart for the Utica/Collingwood were not drilled by Encana:
Well Name
Lucas 1-13 HD1
State Norwich 1-6 HD1
State Richfield 1-34 HD1
Yonkman 1-29 HD1
State Garfield/Tiger 1-14
Completion
Drilled but not hydraulically fractured.
Litigation is pending over alleged faulty pipe
couplings.34
Drilled, not completed. Dry Hole.35.
Drilled and completed with 4,811,940 gals.
slickwater. Failed to produce. Plugged.36
Drilled. Not Completed. Plugged. 37
Drilled and completed using 210,000 gals.
slickwater. The well did not produce and is
temporarily abandoned.38
A-1 Carbonate
Carbonate formations tend to be extremely heterogeneous, with complex porosity and
permeability variations, barriers, and irregular flow paths.39 There have been incidents of
“kicks”, i.e. high pressure gas pockets, encountered in the formation40, as well as hydrogen
sulfide (sour gas) in the A-1. The formation has not been widely explored.
There appear to be two primary ways to complete Michigan A-1 Carbonate wells: matrix acid
stimulation and acid fracturing.39 The amount of water and specific chemicals being used vary
greatly from well to well.
Of the 12 wells listed in the MDEQ chart for the A-1, only two are Large Volume wells:
Well Name
Sherwood 1-22 HD1
Merten 1-24 HD1
34
Completion
Drilled. Not completed. Est. 3 million gallons
water41
Drilled and completed. No completion data
available to date. Est. 3 million gallons water.42
Atlas Resources LLC v McJunkin Red Man Corp., U.S. District Court, Western District, 1:12-cv-00041-JTN
36
37
38
39
https://www.slb.com/~/media/Files/resources/mearr/num8/51_63.pdf
40
http://ww2.deq.state.mi.us/GeoWebface/GeoWebface/WF/011/41728_WF.pdf;
41
42
35
High Volume Wells
A-1 Carbonate
The remaining 10 wells listed in A-1 are high volume wells (or may have been if they were
completed).
Well Name
Schultz 1-36 HD1
Schick 1-7 HD1
David’s Acres 1-19 HD1
Cronk1-24 HD1
Wiley 1-18 HD1
St. Orange &Christenson 1-21 HD1
Riley 1-22 HD1
Walker 11-25 HD1
State Wheatland & Reinelt
Swanson Trust 1-1 HD1
Rich et al. 11-33 HD1
Completion
Drilled and Completed w/acid and 154,600
gals. Water. Shut In since May 2012.43
Drilled. Not completed. Plugged44.
Partially drilled. Not completed. Plugged45
Drilled and Completed w/ 231,450 gals gel &
44,000 gals. 15% HCL. Plugged.46
Drilled and Completed.1.42 million gallons
water w/acid & gel. Plugged.47
Drilled and Completed. Used 645,834 water
with BTEX constituents. Plugged.48
Drilled and Completed w/ 10,487,650 scf
Nitrogen & 93,198 gals. HCI.49 Application to
plug well filed 2/3/2014.
Drilled and Completed.50 2,600,270 gallons
water used to complete51
Drilled. Est. water withdrawal: 1 million
gallons52
Not drilled. Est. water withdrawal 2.1 million
gallons53
Not drilled. Est water withdrawal 2.75 million
gallons54
It can be seen that the completion techniques employed in the A-1 Carbonate do not approach the
volume and scale of the water withdrawal and/or fluid utilized in the Utica Collingwood.
43
45
46
47
48
49
http://www.respectmyplanet.org/public_html/documents/Riley_Completion_Report.pdf
50
51
http://www.respectmyplanet.org/public_html/documents/21-151-60808-01-00-2182014_115914_AM-373Whiting_Petroleum.pdf
52
53
54
http://www.respectmyplanet.org/public_html/documents/Whiting.RichA140014_.pdf
44
However, producers continue to experiment with HF fluid ingredients ( including BTEX
constituents), and water withdrawal volumes continue to increase for A-1 completion.
Antrim
The Antrim formation, located throughout Michigan, is presently only commercially productive
in the northern part of the State, and predominantly produces natural gas. To date, Antrim
exploration and production has centered on Otsego, Montmorency, Alpena, Alcona, Oscoda,
Antrim and Manistee Counties. The Antrim shale was one of the first shale gas productions in
the United States, coming online in 1926.55 Significant development occurred in the Antrim in
the 1980’s56. The majority of the “12,000 wells” the MDEQ states have been hydraulically
fractured in Michigan are in the Antrim shale. A particular characteristic of this formation is
that a considerable amount of formation water is produced initially with the gas.57 You will note
from the Stratigraphic Map (Appendix B) this formation is significantly shallower than either the
Utica/Collingwood or the A1 Carbonate58 (500 to 2000 feet ).
In 2011, respectmyplanet.org undertook an examination of well file records for Antrim wells. To
date, 1,670 files have been reviewed. Of these, 59.4% (992) used water, and 40.6% (678) used
nitrogen or nitrogen foam to complete. Of the wells that used water, the average consumption
was 11,457 gallons59.
The MDEQ chart lists one high volume well completed in the Antrim: the Soper 1-25 HD1,
completed by Cimarex Energy Co. in 2008. This well used 1.8 million gallons of water, failed to
produce, and was plugged.60 From the records reviewed in the respectmyplanet.org Antrim Well
Project, this well is an exception to common completion techniques employed in the Antrim.
MDEQ lists pending HV applications for two additional wells into the Antrim by O.I.L. Energy
Corp. Both wells estimate +/-185,000 of water to be used for completion in the application
files.61
Dundee
The Dundee is a rather shallow formation throughout the basin and ranges from surface outcrops
to 4300 feet deep.62, exhibiting high permeability and high porosity.63 It is the most prolific oil
producing unit in the Michigan Basin, with more than 375 million barrels of oil produced to
date64. It is also gas bearing in the northern part of the Lower Peninsula. It is the target
formation for many brine disposal wells.65 The Dundee is also a current target for geological
sequestration of Carbon Dioxide (CO2). 62
55
http://repository.tamu.edu/bitstream/handle/1969.1/ETD-TAMU-2009-12-7481/AGRAWAL-THESIS.pdf
http://www.mogpef.org/Exploration/GeologicalFormationsinMichigan.aspx
57
http://custom.cengage.com/regional_geology/data/Geo_Michigan_Watermarked.pdf
58
Stratigraphic Map, Appendix B
59
Request a copy of the Antrim Well Report at [email protected]
60
61
http://www.respectmyplanet.org/public_html/documents/OIL.Antrim_AppA130164_.pdf
http://www.respectmyplanet.org/public_html/documents/OILAntrimAppA130165.pdf
62
http://www.mrcsp.org/userdata/Articles/eg09007.pdf
63
http://www.michigan.gov/documents/deq/GIMDL-OFR866_302614_7.pdf
64
http://aapgbull.geoscienceworld.org/content/90/11/1787.abstract
65
http://digitalcommons.mtu.edu/cgi/viewcontent.cgi?article=1327&context=etds
56
Completion of Dundee wells is not typically high volume. The single HVHF well listed by the
MDEQ in the Dundee is for Jordan Development’s State Jerome and Starnes 15-8 HD1 in
Midland County.66 The lateral portion of the well is about 3500’ and will also use open hole
completion. The well has been drilled but no completion records have been filed so it is
undetermined whether this well is actually high volume or not. No other completed wells or
pending applications on the MDEQ High Volume chart are targeting the Dundee.
Niagaran
Development in Kalkaska, Grand Traverse and Otsego counties in this formation began in
earnest in 1970. The decade of the 1970s produced around 225 million barrels of oil and almost
874 billion cubic feet of gas in Michigan, and most of this production was from the Niagaran
reefs.67 The first horizontal well in Michigan was drilled into this formation in 1984.68
MDEQ lists one high volume well in the Niagaran formation completed in 2010 by Merit
Energy Company: the Hubbel 2-22 HD1. MDEQ records indicate that this well was completed
using a combination of water, hydrochloric acid and nitrogen foam. Total fluid is noted at
216,968 gallons.69 The well was open hole for the lateral portion of 2,143 feet. No other
completed wells or pending applications on the MDEQ High Volume chart are targeting
the Niagaran.
Black River (Van Wert)
The Black River formation is below the Utica/Collingwood. This formation produces both oil
and gas. Gas produced from the Black River Group is predominantly “dry”. The formation has
low permeability and low porosity. Development in this formation is focused in south central
Michigan.70
Six wells listed on the MDEQ HVHF list target the Black River formation. One is plugged, two
are producing and three have yet to be drilled or completed:
Well Name
Kelly et al. 1-26 HD1
McNair 1-26 HD1
Arno 1-25 HD1
Arno/Timmons 1-24 HD1
66
Completion
Well completed with 228,291 gals. gelled
water. Producing.71
Well completed with 17,405 NE Acid72 &
350448 PPG gel.73
Producing.74
Well not drilled as of August 201375
Well not drilled as of August 201376
http://www.respectmyplanet.org/public_html/documents/Jordan.Dundee60718_.pdf
http://custom.cengage.com/regional_geology/data/Geo_Michigan_Watermarked.pdf
68
http://bradfordgordon.com/pdf/USGSMichiganCore8_22.pdf
69
http://www.respectmyplanet.org/public_html/documents/60041_wf_with_water_summary.pdf
70
http://www.michigan.gov/documents/deq/GIMDL-GGTBR_302379_7.pdf
71
72
http://www.weatherford.com/Products/EngineeredChemistry/AcidAdditives/Surfactants/
73
http://www.chemeor.com/downloads/PB_Cerogel%20PPG_906-p1.pdf
74
75
http://www.respectmyplanet.org/public_html/documents/Arno.File_.pdf
67
Stiverson & French 1-25 HD1
Burns A1-23 HD1
Well Plugged. Drilled in September 2013. Dry
Hole77
Well not drilled as of December 201378
SUMMARY
Of the 58 wells listed on the MDEQ chart, 23 have been drilled and completed, 9 have been
drilled but not completed, and the rest have not been drilled or completed as of this date. Of the
23 that have been drilled and completed, 8 are currently producing.
The wells completed and proposed by Encana Oil & Gas (USA), Inc. into the Utica/Collingwood
formation are the longest (TMD now approaching 4 miles), and are using the largest volume of
fresh water, as well as the most varied and toxic array and volume of chemicals in Michigan to
date. Wells targeting the A-1 Carbonate formation are utilizing ever increasing volumes of water
as well as many of the same chemicals associated with Utica/Collingwood completions. Wells
currently being completed in other formations do not approach those numbers, as can be seen
from the comparisons contained in this report (Appendix D).
We hope you’ve found this paper helpful in differentiating between the formations being
accessed and the corresponding completion techniques being employed in the wells listed on the
MDEQ’s HVHF chart. Please contact us with any questions or feedback you may have via email
to [email protected] or [email protected] .
76
http://www.respectmyplanet.org/public_html/documents/Continental.Arno2_.pdf
78
http://www.respectmyplanet.org/public_html/documents/60674.Muzyl2_.pdf
77
HIGH VOLUME HYDRAULICALLY FRACTURED WELL COMPLETION ACTIVE PERMITS AND APPLICATIONS
(AS OF 3/18/2014)
HIGH VOLUME (>100,000 gallons) HYDRAULIC FRACTURING SINCE 2008 - ACTIVE PERMITS
#
Company Name
BEACON EXPLORATION AND PRODUCTION CO LLC
CIMAREX ENERGY CO
ENCANA OIL AND GAS USA INC
MERIT ENERGY COMPANY
ATLAS RESOURCES LLC
ATLAS RESOURCES LLC
COUNTRYMARK RESOURCES INC
TIGER DEVELOPMENT LLC
DEVON ENERGY PRODUCTION COMPANY LP
CONTINENTAL RESOURCES INC
ALTA ENERGY OPERATING LLC
COUNTRYMARK ENERGY RESOURCES LLC
Well Name
SCHULTZ
SOPER
PIONEER
HUBBEL
STATE NORWICH
STATE KOEHLER & KENDALL
LUCAS
KELLY ET AL
STATE EXCELSIOR
STATE GARFIELD & TIGER
CRONK
STATE EXCELSIOR
WILEY
SCHICK
MCNAIR ET AL
STATE EXCELSIOR
STATE EXCELSIOR
STATE RICHFIELD
RILEY
STATE GARFIELD
DAVID'S ACRES, LLC
ARNO
ARNO & TIMMONS
WESTERMAN
Well No
1--36
1-25 HD1
1-3 HD1
2-22 HD1
1-6 HD1
1-27 HD1
1-13 HD1
1-26 HD1
1-13 HD1
1-14
1-24 HD1
1-25 HD1
1-18 HD1
1-7HD1
1-26 HD1
2-25 HD1
3-25 HD1
1-34 HD1
1-22 HD1
1-25 HD1
1-19 HD1
1-25 HD1
1-24 HD1
1-32 HD1
County
SANILAC
OSCEOLA
MISSAUKEE
MONTMORENCY
MISSAUKEE
CHEBOYGAN
KALKASKA
HILLSDALE
KALKASKA
KALKASKA
GLADWIN
KALKASKA
GLADWIN
CLARE
HILLSDALE
KALKASKA
KALKASKA
ROSCOMMON
OCEANA
KALKASKA
OGEMAW
HILLSDALE
HILLSDALE
KALKASKA
Pilot Boring
NA
ACOW
59919
NA
NA
60133
60138
NA
60357
NA
60379
NA
60451
60525
60536
NA
NA
60559
60574
NA
60581
NA
NA
60600
Comments
well completed Feb. 2012
well completed Aug. 2008
well completed Feb 2010
well completed June. 2010
well not hydraulically fractured to date.
well completed Oct 2010
well not hydraulically fractured to date.
well completed Sept. 2011
well completed Nov 2011
Well completed Oct. 2013
well completed April/May 2012
well completed May/June 2012
well not hydraulically fractured
well completed August 2012
Well completed Dec. 2012/May 2013
Well completed Dec. 2012
permit for horizontal well
No completion records on file
Target formation
A1 Carbonate
Antrim
Utica-Collingwood
Niagaran
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Collingwood
A1 Carbonate
Utica-Collingwood
A1 Carbonate
A1 Carbonate
Utica-Collingwood
Utica-Collingwood
Collingwood
A1 Carbonate
Utica-Collingwood
A1 Carbonate
Utica-Collingwood
25 60606
26
27
28
29
30
31
ROSETTA RESOURCES OPERATING LP
MUZYL OIL CORPORATION
STATE MENTOR
1-17 HD1
CHEBOYGAN
STATE ORANGE & CHRISTENSEN
YOUNKMAN
STATE BEAVER CREEK
STIVERSON & FRENCH
STATE ROSCOMMON
BURNS
1-21 HD1
1-29 HD1
1-23 HD1
1-25 HD1
1-7 HD1
A1-23 HD1
IONIA
MISSAUKEE
CRAWFORD
HILLSDALE
ROSCOMMON
HILLSDALE
34N 3W 17
NA
permit for horizontal well (60562)
6N 6W 21
21N 8W 29
25N 4W 11
6S 2W 24
21N 4W 17
6S 2W 23
60614
00581
60620
NA
60670
NA
Well completed June 2013
well completed May 2013
32 60686
33 60718
STATE GARFIELD
1-23 HD1
JORDAN DEVELOPMENT CO. LLC
15-8 HD1
STATE JEROME & STARNES
STATE EXCELSIOR
KALKASKA
25N 6W 26
60685
1-14 HD1
MIDLAND
KALKASKA
8N 1W 8
27N 6W 24
60717
NA
34 60746
35 60747
36 60748
STATE EXCELSIOR
1-12 HD1
KALKASKA
27N 6W 24
STATE EXCELSIOR
1-11 HD1
KALKASKA
27N 6W 24
37 60749
STATE EXCELSIOR
2-14 HD1
KALKASKA
38 60750
STATE EXCELSIOR
2-12 HD1
39 60755
ROSETTA RESOURCES OPERATING LP
40
41
42
43
44
45
46
47
48
49
50
51
52
SWANSON TRUST
STATE EXCELSIOR
STATE EXCELSIOR
STATE EXCELSIOR
MERTEN
WALKER
SHERWOOD
STATE OLIVER
STATE EXCELSIOR
STATE OLIVER
STATE OLIVER
STATE EXCELSIOR
STATE WHEATLAND & REINELT
STATE PIONEER
STATE NORWICH
BLACK RIVER CONSERVATION ASSN.
STATE CUSTER AND MUNN
RICH ET AL
1-1 HD1
3-12 HD1
4-12 HD1
5-12 HD1
1-24 HD1
11-25 HD1
1-22 HD1
3-13 HD1
4-25 HD1
2-13 HD1
1-13 HD1
5-25 HD1
11-7 HD1
3-4 HD1
3-12 HD1
1-9 HD1
D2-6
11-33 HD1
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
Permit #
59112
59173
59979
60041
60161
60170
60198
60212
60360
54696
60380
60389
60452
60526
60537
60545
60546
60560
60575
60579
60582
60587
60588
60601
60615
60617
60621
60662
60672
60674
60765
60766
60767
60788
60809
60811
60818
60819
60820
60821
60822
60826
60848
53 60891
54 60892
55 60922
56 60930
UNION GAS OPERATING COMPANY
WHITING OIL AND GAS CORPORATION
GEOSOUTHERN OPERATING LLC
O I L ENERGY CORP.
Well Type
Oil
Gas
Gas
Oil
Dry Hole
Oil
Not available
Oil
Gas
Gas
Dry Hole
Gas
Gas
Other
Oil
Gas
Gas
Gas
Oil
Gas
Other
Location
Location
Location
Well Status
Shut-in
Plugging complete
Temporarily abandoned
Producing
Producing
Producing
Plugging complete
Producing
Plugging complete
Plugging complete
Producing
Producing
Producing
Plugging complete
Well complete
Well Complete
Plugging complete
Permitted Well
Permitted Well
Drilling complete
Utica-Collingwood
Location
Permitted Well
YES
A1 Carbonate
Utica
Utica-Collingwood
Utica-Collingwood
Dry Hole
NA
Gas
Dry Hole
Location
location
Well complete
Plugging complete
Well Complete
Plugging complete
Permitted Well
Permitted Well
NO
NO
NO
NO
YES
NO
Utica-Collingwood
Location
Permitted Well
YES
No completion records on file
Dundee
Location
Drilling complete
NO
Utica-Collingwood
Location
Permitted Well
YES
NA
Utica-Collingwood
Location
Permitted Well
YES
NA
Utica-Collingwood
Location
Permitted Well
YES
27N 6W 24
NA
Utica-Collingwood
Location
Permitted Well
YES
KALKASKA
27N 6W 24
NA
Utica-Collingwood
Location
Permitted Well
YES
MUSKEGON
KALKASKA
KALKASKA
KALKASKA
9N 14W 1
27N 6W 24
27N 6W 24
27N 6W 24
15N 17W 24
12N 15E 25
4N 3E 23
26N 6W 1
26N 6W 1
26N 6W 1
26N 6W 1
26N 6W 1
13N 14E 7
24N 7W 3
25N 6W 36
27N 5W 28
29N 7W 6
12N 15E 4
60754
NA
NA
NA
60787
60808
60804
NA
NA
NA
NA
NA
60825
NA
NA
NA
NA
60927
A1-Carbonate
Location
Permitted Well
YES
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
A1-Carbonate
A1-Carbonate
A-1 Carbonate
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Location
Location
Location
Location
Location
Location
Location
Location
Location
Location
Location
Location
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
YES
YES
YES
NO
NO
YES
YES
YES
YES
YES
YES
Location
Location
Location
Location
Location
Permitted Well
Permitted Well
Permitted Well
Permitted Well
Permitted Well
OCEANA
SANILAC
LIVINGSTON
KALKASKA
KALKASKA
KALKASKA
KALKASKA
KALKASKA
SANILAC
MISSAUKEE
KALKASKA
KALKASKA
ANTRIM
SANILAC
Wellhead T R S
12N 15E 36
17N 10W 25
24N 7W 3
29N 1E 22
24N 6W 6
35N 2W 33
26N 8W 13
6S 2W 26
27N 6W 24
25N 6W 14
19N 1W 24
26N 6W 1
18N 2W 18
19N 3W 7
6S 2W 26
26N 6W 1
26N 6W 1
22N 1W 27
15N 18W 22
25N 6W 36
22N 4E 19
6S 2W 25
6S 2W 24
28N 8W 29
permit for directional well
A1 Carbonate
Utica-Collingwood
Utica-Collingwood
Utica-Collingwood
Antrim
A-1 Carbonate
HIGH VOLUME (>100,000 gallons) HYDRAULIC FRACTURING PROPOSALS - ACTIVE APPLICATIONS
#
App #
1 A130152
2 A130164
Company Name
O I L ENERGY CORP.
Well Name
BLACK RIVER CONSERVATION ASSN.
STATE CUSTER AND BGC
Well No
6-9 HD1
C3-31
County
KALKASKA
ANTRIM
Wellhead T R S
27N 5W 28
29N 7W 6
Pilot Boring
NA
NA
target formation
Utica-Collingwood
Antrim
comments
application for horizontal well
application for a directional well
Confidential
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
NO
YES
YES
YES
YES
NO
YES
STRATIGRAPHIC
SUCCESSION
IN LOWER
PENINSULA
OF MICHIGAN
DOMINANT LITHOLOGY
Basin Center
u
.~
Quaternary
Pleistocene Glacial Drift
'"
u
<II
Mesozoic
Jurassic
~
?Kimmeridgian?
~
Conemaugh
:< ------- - ---Pennsylvanian
~
ro
?Pottsville?
w
*
...J
Mississippian
Michigan Dept. of Environmental Quality
Geological Survey DIvision
Harold Fitch, State Geologist
and
Grand River Formation
~~
Saginaw Formation
E~~~~::::~~~=~=~l __~arma Sand2~o~,~
___ _ ________
____ _
Bayport Limestone
Grand Rapids Group
Meramecian
Michigan Formation
Stratigraphic Nomenclature Project Committee:
Dr. Paul A . Catacosinos, Co-chairman
Mark S. Wollensak, Co-chairman
1-+_____
Osagian
~ f - - - - - - I::=::::::::;~~;l:'i:~
Kinderho okian
.'!!
~
Marshall Sandstone
Principa l Authors:
Dr. Paul A. Catacosinos
Dr. William Harrison III
Robert Reynolds
Dr. Dave BWestjohn
Mark S. Wollensak
Coldwater Shale
Sunbury Shale
Berea Sandstone
Bedford Shale
Antrim Shale Chautauquan
'"
...J
Senecan
2000
Traverse Formation Traverse Limestone
Traverse Group Erian Devonian
Bell Shale
~
'0
Dundee Limestone
~f------
Lucas Formation Detroit River Group Amherstburg Form. Sylvania Sandstone BOi s Blanc Formation Ulsterian
Garden Island Formation
Bass Islands Dolomite
Sand
Salina G Unit
Cayugan
Glacial
Salina F Unit
Salina E Unit
Salina D Unit
Salina C Shale
Salina 8 Unit
{
Niagaran
Salina Group (Gray Niagaran) Lockport
(While Niagaran) Dolomite
Manistique Limestone
Burnt Bluff Formation
Cabot Head Shale Alexandrian
Till/Gravel
limestone
Salina A-2 Carbonate Salina A-2 Evaporite RuH Formation (Salina A-I Carbonate) Guelph Dolomite (Salina A-I Evaporite)
.
.
(Brown Niagaran!
Cain Formation Salina A-O Carbonate)
Silurian Clay or Silt
Sandy Limestone Shaley Limestone
Limestone Bedded
Dolomite
Sandy Dolomite
Niagara
Group
Cataract Group Manitoulin Dolomite
Shaley Dolomite
Sandstone-Coarse
Sandstone-Fine
Sandstone-Cross Bedded
Queenston Shale
Sandstone-Bedded
Richmond Group
Cincinnatian
Calcareous Sandstone
Utica Shale
Shaley Sandstone
Collingwocd Shale
Shale
<D
Ordovician
~
~
Trenton Formation
Arenaceous Shale
Mohawkian
Black River Forma tion
Fosler Formation
Canadian
Dolomitic Shale
Anhydrite
Basement Rocl<s
Tre mpealeau Formation
Coal Bed
Franconia Formation
Franconian
!B
Galesville Sandstone
'"
...J
Dresbach ian Prairie du Chien
Group
Gypsum
Trempealeaun
Cambrian Calcareous Shale
Glenwood Formation
Bruggers Sandstone/St. Peler Sandstone
Chazyan
,--------- --- .... _- ... _---- ..
Munising Group
-~--
Chert
.. ..
Glauconite
GG
Mt. Simon Sandstone
Pre-Mt. Simon Clastics
Middle Proterozoic Eon
Breccia Eau Claire Formation Bentonite
Fossils
~---. -----~.--~-~.~--~-----
Precambrian Crystalline Basement
Unconformity
X X X X
f f f f
Appendix C
Large Volume Water Withdrawal for Hydraulic Fracturing in Deep Shale Formations by
Encana Oil & Gas (USA), Inc.
(as of March 20, 2014)
Kalkaska, Crawford, Missaukee, Cheyboygan & Roscommon Counties, Michigan
Proposed and Actual Water Removal in Gallons
Actual water removal reported for completed wells:
60170
59979
60360
60389
60545
60546
60579
60621
60601
Koehler-Kendall
Pioneer 1-3
Excelsior 1-13
Excelsior 1-25
Excelsior 2-25
Excelsior 3-25
Garfield 1-25
Beaver Creek 1-23
Westerman 1-32
3,256,596
6,720,000
5,840,000
8,481,635
12,592,096
21,112,194
12,539,639
15,810,735
12,636,294*
2010
2010
2011
2011
2012
2012
2012
2013
2013
Wells permitted but not yet drilled:
60606
60748
60747
60750
60746
60749
60765
60766
60767
60819
60822
60821
60820
60818
60672
60686
60891
60892
60848
Mentor 1-17
Excelsior 1-11
Excelsior 1-12
Excelsior 2-12
Excelsior 1-14
Excelsior 2-14
Excelsior 3-12
Excelsior 4-12
Excelsior 5-12
Excelsior 4-25
Excelsior 5-25
Oliver 1-13
Oliver 2-13
Oliver 3-13
Roscommon 1-7
Garfield 1-23
Norwich 3-12
BRCA 1-9
Pioneer 3-4
est. 4, 200,000
est 23,100,000
est 23,100,000
est 23,100,000
est 23,100,000
est 23,100,000
est 23,100,000
est 23,100,000
est 23,100,000
est 18,900,000
est 18,900,000
est 31,500,000
est 31,500,000
est 31,500,000
est 16,800,000
est 10,600,000
est 25,200,000
est 35,280,000
est 25,200,000
Wells applied for, permits pending:
A130152
BRCA 6-9
TOTAL:
est 35,280,000
568,649,189 GALLONS
*2,130,576 from Kalkaska and Mancelona Municipal Water as per Bill Duley, MDEQ Geologist 11/7/2013
Appendix D
Summary of Completion Factors for MDEQ Chart of HVHF Wells in Michigan as of January 23, 2014
Utica Collingwood Wells
Permit #
60560
54696/
60170
Well Name
Richfield 1-34 HD1
Garfield & Tiger 1-14
Koehler-Kendall
Completion Fluid
4,811,940 gals slickwater
210,000 gals slickwater
Chemicals
See below1
See below2
Not Reported
59979
60360
60389
60545
60546
60579
60621
60601
Pioneer 1-3
Excelsior 1-13
Excelsior 1-25
Excelsior 2-25
Excelsior 3-25
Garfield 1-25
Beaver Creek 1-23
Westerman
Not reported
See below3
See below3
See below4
See below4
See below5
Not Reported
See below6
Proppant
3,875,300 lbs silica
Not reported
2,840,000 #20/40 mesh; 241,810 # 30/50 mesh
423,277 40/70 mesh
1,300,000 100 mesh; 2,580,000 40/70 mesh
1,100,000 40/70 mesh;2,580,000 20/40 mesh
1,870,000# 40/70 mesh; 3,440,000# 20/40 mesh
988,164# Ottawa sand
8,827,623# Ottawa sand
9,668,100# Ottawa sand
18,707,700# Premium White
10,333,000# silica7
The remaining wells on the MDEQ list permitted to target the Utica Collingwood formations have not been completed to date.
1
Hydrochloric acid, Hexamethylenetetramine, Phenol / formaldehyde resin, Trimethylbenzene, Ethanol , Heavy aromatic petroleum naphtha, Naphthalene, Poly(oxy-1,2-ethanediyl), alpha-(4nonylphenyl)-omega-hydroxy-, branched, Tributyl tetradecyl phosphonium chloride, Ammonium salt, Ammonium chloride, Hydrotreated light petroleum distillate, Paraffinic solvent, Methanol,
Ethoxylated nonylphenol, Sodium perborate tetrahydrate http://www.fracfocusdata.org/DisclosureSearch/SearchResults.aspx
2
Hydrochloric acid 7.5%, Hydrotreated light petroleum distillate, Tributyl tetradecyl phosphonium chloride, Ammonium chloride, Ammonium salt. 9-Octadecenanide alcohols, Isopropanol,
http://www.michigan.gov/documents/deq/Permit_54696_MSDS_439389_7.pdf
3
Hydrogen chloride, Ethoxylated Nonylphenol, Glycol Ethers, Isopropyl Alcohol, Propargyl Alcohol, Tar bases, quinoline derivs, benzyl chloride-quaternized, 2,2-dibromo-3-nitrilopropionamide,
Ammonium Sulfate, Ammonium Chloride, Ethoxylated alcohol blend, Ethoxylated oleylamine, Hydrotreated light distillates Hydrotreated light distillates, Polyacrylamide, Propylene glycol, 2Butoxyethanol, 2-Ethylhexanol, Cocamidopropyl Dimethylamine, Coconut oil, Dodecylbenzenesulfonate sopropanolamine, Epichlorohydrin, Methanol, Isopropyl Alcohol, Monoethanolamine,
Dimethyl-1,3-Propanediamine, Cocoamidopropyl-N,N-dimethyl-N-2-h ydroxypropylsulfobetainE, Naphthalene, Phosphoric Acid, Poly(Oxy-1,2-Ethanediyl)Alpha.-Hydro-.Omega.-Hydroxy-, MonoC8-10-Alkyl Ethers, Phosphates, Polyethylene glycol trimethylnonyl ether, Sodium Metabisulfite, Solvent Naptha (Petroleum), Sulfamic Acid, Aluminum,Titanium and Iron oxides, 2 undisclosed
proprietary elements http://www.fracfocusdata.org/DisclosureSearch/StandardSearch.aspx
4
Hydrochloric acid, Hydrotreated light petroleum distillate, Tributyl tetradecyl phosphonium chloride, Ammonium chloride, Trimethylbenzene, Ethanol, Heavy aromatic petroleum naphtha,
Naphthalene, Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-, branched, Methanol, Propargyl Alcohol, http://www.fracfocusdata.org/DisclosureSearch/StandardSearch.aspx
5
Hydrochloric acid, Hydrotreated light petroleum distillate, Tributyl tetradecyl phosphonium chloride, Ammonium chloride, Trimethylbenzene, Ethanol, Heavy aromatic petroleum naphtha,
Naphthalene, Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-, branched, Methanol, Propargyl Alcohol, Guar Gum, Sodium Persulfate
http://www.fracfocusdata.org/DisclosureSearch/StandardSearch.aspx
6
15% FE Acid, Heavy aromatic petroleum naphtha, Trimethylbenzene, Tributyl tetradecyl phosphonium chloride, Hydrotreated light petroleum distillate, Guar Gum, Methanol, Propargyl Alcohol,
Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-, branched, Sodium persulfate, Ammonium chloride, Naphthalene, FracTracers
http://www.michigan.gov/documents/deq/60601_Westerman_1-32_MSDS_426422_7.pdf ; http://www.respectmyplanet.org/public_html/documents/Encana_-_Westerman_1-32HD1_Chemical_Disclosure_%281%29.pdf
7
http://www.respectmyplanet.org/public_html/documents/Westerman_01-32_HD-1_-_Chemical_Additive_Usage.pdf
A-1 Carbonate Wells
Permit #
59112
60380
60452
60615
60575
60809
60788
Well Name
Schultz 1-36
Cronk 1-24 HD1
Wiley 1-18 HD1
Christenson 1-21 HD1
Riley 1-22 HD1
Walker 11-25 HD1
Merten 1-24 HD1
Completion Fluid
154,600 gals water
231,450 Linear gel &
44,000 gals 15% HCI
1,420,939 gals water
645,834 gals water
93,198 gals. HCI
2,600,270 gals water
Not Reported to Date
Chemicals
Proppant
26,000 gals 10% HCI 175,000 sand
See below8
See below9
See below10
See below11
See below12
Not reported to date
593,400# unspecified proppant
1,308,602# unspecified proppant
Amount not specified on completion report
No proppant noted on completion report
Silica sand. Amount not specified.
Not Reported to date
The remaining wells permitted to target the A-1 Carbonate formation have not been completed to date.
Antrim Well
Permit #
59173
Well Name
Soper 1-25 HD1
Completion Fluid
1,800,000 slickwater
Chemicals
Proppant
No MSDS on file at MDEQ None noted on completion report
Dundee Well
The single well on the HVHF list for this formation, the Jerome & Starnes 15-8 HD1, has been drilled and completed but no completion record is
available.
8
Hydrochloric Acid, Guar Gum, Resin, Petroleum Distillates,Methanol, Parafinic Petroleum Distillates, Poly (Oxyethylene) Nonylphenol Ether, Citric Acid, Acrylic Polymers, 1-Butoxy-2-Propanol,
2-Butoxyethanol, Enzyme solution, Boric Acid (H3BO3), Methyl Borate, Ethylene Glycol, Potassium Carbonate, Isopropanol, Glutaraldehyde, Sodium Carbonate, Polyoxyalkylenes, Didecyl
Dimethyl Ammonium Chloride, Hemicellulase Enzyme , Calcium Chloride, Ethanol, Quaternary Ammonium Compound, Fatty Acids, Ammonium Persulfate, Olefin, Propargyl Alcohol, Potassium
Hydroxide , http://www.fracfocusdata.org/DisclosureSearch/SearchResults.aspx
9
Hydrochloric Acid, Guar Gum, Hexamethylenetetramine, Phenol / formaldehyde resin, Ethylene glycol, Tributyl tetradecyl phosphonium chloride, Hydrotreated light petroleum distillate,
Monoethanolamine borate, Acetic Acid, Methanol, Sodium persulfate, Sodium perborate tetrahydrate, Alcohols, C12-16, ethoxylated, Ammonium chloride, Sodium chloride, Sodium Sulfate, & three
proprietary ingredients, http://www.fracfocusdata.org/DisclosureSearch/SearchResults.aspx
10
Xylene, Ethel Benzene, Toluene, Monoethanolamine borate, Ethylene glycol, Monobutyl ethel, Isopropanol, Crotonaldehyde, Acetaldehyde, Methanol, Hydrotreated light petroleum distillate,
Aldol,Ethanol, Heavy aromatic petroleum naphtha, Naphthalene, Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-, branched, 1,2,4 Trimethylbenzene, Tributyl tetradecyl
phosphonium chloride, Sodium persulfate & 6 confidential ingredients, , http://www.fracfocusdata.org/DisclosureSearch/SearchResults.aspx
11
Hydrochloric acid , Dodecylbenzene sulfonic acid, Isopropynol, Tributyl tetradecyl phosphonium chloride, Ammonium salt, Carbohydrates, Hemicellulase enzyme, Methanol, Propargyl alcohol,
Inner salt of alkyl amines, Sodium chloride, Paraffinic solvent Paraffinic solvent, Ethanol, Heavy aromatic petroleum naphtha, Naphthalene, Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omegahydroxy-, branched, Isopropanol, Nitrogen http://www.michigan.gov/documents/deq/60575_Riley_HD1_MSDS_420613_7.pdf
12
Hydrochloric Acid, Guar Gum, Acetic anhydride, Methyl Borate, Dipropylene glycol monomethylether, Ethanol, Heavy aromatic petroleum naphtha, Naphthalene, Poly(oxy-1,2-ethanediyl), alpha(4-nonylphenyl)-omega-hydroxy-, branched, Ethylene glycol, 1,2,4 Trimethylbenzene, Ammonium salt, Citric Acid, Tributyl tetradecyl phosphonium chloride, Propylene glycol, Sodium chloride,
Methanol, & 11 confidential ingredients. http://www.fracfocusdata.org/DisclosureSearch/SearchResults.aspx
Niagaran Well
Permit #
60041
Well Name
Hubbel 2-22 HD1
Completion Fluid
Chemicals
216,000 water; 968 additives See below13
Proppant
177,000# 20/40 premium white
Black River Wells
Permit #
60212
60537
Well Name
Kelly et al, 1-26 HD1
McNair 1-26 HD 1
Completion Fluid
228,291 gals. gelled water
17,405 NE Acid &
350,448 gals PPG gel.
Chemicals
See below14
See below15
Proppant
None noted in completion report
None noted in completion report
The remaining wells on the MDEQ list permitted to target the Black River formation have not been completed to date.
13
Monoethanolamine borate, Ethylene glycol, 2-Monobromo-3-nitrilopropionamide, 2,2 Dibromo-3-nitrilopropionamide, 2-Bromo-2-nitro-1,3- propanediol, Acetic acid, Carbohydrates,
Hemicellulase enzyme, Methanol, Propargyl alcohol, Ethanol, Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-,branched
Naphthalene 1,2,4 Trimethylbenzene , Heavy aromatic petroleum naphtha, Heavy aromatic petroleum naphtha, Isopropanol. Guar Gum & 1 proprietary ingredient,
http://www.michigan.gov/deq/0,4561,7-135-3311_4111_4231-262172--,00.html
14
Ethylene glycol, Ammonium Persulfate, 2,2 Dibromo-3-nitrilopropionamide, Polyethylene Glycol Mixture, Isopropyl Alcohol, Glycol Ethers, & 2 proprietary ingredients,
http://www.michigan.gov/documents/deq/KELLEY_MSDS2011_11_02_367756_7.pdf
15
Glycol Ethers, Isopropyl Alcohol, Isopropynol, Hydrocarbons, Hydrochloric Acid, Cupric Sulfate, Copper, Methanol, Ethylene Glycol, & 2 proprietary ingredients
http://www.michigan.gov/documents/deq/McNair_ET_AL_1-26_HD1_MSDS_401458_7.pdf

analysis of michigan department of environmental quality high

Transcription

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