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The abundance of unconventional low-permeability
gas in North America suggests that the extreme ratio of gaseous heating
value cost to liquid hydrocarbon heating value cost could persist for an
extended period of time. Therefore, both operators and pumping service companies
have real incentives to develop and optimize these systems.
Bakken_multi_pads
The parade of rig
conversions in the Marcellus Shale to run on liquefied natural gas (LNG)
continues. First EQT, then CONSOL switching to duel-fuel LNG/diesel
engines.
After EQT and CONSOL, Seneca Resources started to convert drilling rigs
to run on 100% LNG (see Seneca Boasts First 100% LNG-Powered Drill Rig
in Marcellus).
You may now add Antero Resources to the club.
Antero recently converted the first of three rigs in West Virginia to
run on 100% natural gas engines manufactured (as they were for Seneca)
by General Electric. The engines will run on LNG, propane or even dry "field
gas" that comes from the well itself. Kewl. From the Antero/GE press release:
CONSOL Switching
to Dual Fuel Drilling Rigs in Marcellus/Utica
In the near future, drilling and fracking at CONSOL Energy drill sites
will be powered by dual fuel technology using LNG (liquefied natural gas)
and diesel fuel. You may recall MDN reported on CONSOL’s experimentation
with dual fuel technology at two different locations last year (see CONSOL
Orders Additional 3 Dual Fuel Generators for 2nd Rig).
Linde, the company providing CONSOL with dual fuel technology to run
the generators and other drilling equipment, issued a press announcement
yesterday which says, in essence, that CONSOL has decided to go “all in”
and start using Linde’s dual fuel solutions throughout all of their drilling
operations in the Marcellus and Utica Shale:
Second Seneca
100% LNG-Powered Drilling Rig Goes Online
MDN recently told you about Seneca Resources, the first Marcellus driller
to convert a drilling rig to run on a 100% liquefied natural gas (LNG) engine,
a rig they now use for drilling in Lycoming County, PA (see this MDN story).
Seneca has just completed the conversion of a second 100% LNG-powered rig
and uses it for drilling in Forest, Elk, Jefferson and McKean counties in
PA.
Stands to reason the company that makes the engine would want to crow
about it, and sure enough they now have. General Electric is the manufacturer
of the Jenbacher J320 turbocharged natural gas engine, and they issued this
press release yesterday about their innovative new engine being used by
Seneca:
Seneca Boasts First 100% LNG-Powered Drill Rig in Marcellus
EQT was the first driller in the Marcellus Shale to convert a drilling
rig to run on electricity produced by LNG, or “liquefied natural gas” (see
this MDN story). CONSOL has also been experimenting with converting some
of their rigs to use LNG too (see this MDN story). You may now add a third
driller to the list: Seneca Resources. Seneca is the gas drilling arm of
National Fuel Gas Company.
Yesterday, Seneca
announced they are converting two of their rigs to run on LNG. But unlike
EQT and CONSOL which mix LNG with diesel fuel in a blend, Seneca is using
100% LNG to power their rigs—a first for drilling rigs in the Marcellus
Shale. Seneca says they’ve already converted one rig that’s now in operation,
a second rig will be finished in November, and a third rig is coming later
this year. Seneca also says someday they’d like to use the gas coming out
of the ground to power the rig that’s drilling it. Cool.
GE’s 1-megawatt Jenbacher J320 turbocharged natural gas engines.
The Jenbacher units were combined with Ensign Drilling-designed rig packages
to provide all the electricity needed by each drilling rig. The J320 represents
GE’s first U.S. Environmental Protection Agency certified technology for
mobile and stationary drilling applications.
CONSOL Orders
Additional 3 Dual Fuel Generators for 2nd Rig
CONSOL Energy has ordered an additional three dual fuel electrical generator
conversions at a second drilling rig in the Marcellus Shale. MDN previously
reported that CONSOL was experimenting with three dual fuel generator conversions—blending
liquefied natural gas with diesel—at one location (see this MDN story).
Looks like the experiment is going well enough that CONSOL has ordered another
three conversions for a different location.
EQT Converts
2nd Drilling Rig in WV Marcellus to Run on LNG
EQT was the first driller in the Marcellus to convert electrical generators
used at a drilling site to burn liquefied natural gas, or LNG (see this
MDN story). EQT announced yesterday they’ve commissioned a second drilling
rig, located in West Virginia (as was the first converted rig) to be converted
to the new LNG technology.
Linde Says Early Results from LNG/Diesel Generators Promising
Drilling rigs for shale gas use a lot of electricity to power the equipment—so
much electricity each drill site uses enough generators to power an entire
town. Drillers make their own electricity rather than draw from the local
power grid. Almost all electrical generators at well sites are powered by
diesel engines. But a few enterprising companies are offering alternatives
to diesel. Hey, why not use natural gas to power those engines, since you’re
drilling for natural gas!
Linde North America is one of those enterprising companies. CONSOL Energy’s
gas division is experimenting with a dual-fuel technology that combines
liquefied natural gas (LNG) with diesel, blending them together, a technology
being pioneered by Linde. CONSOL is currently testing it with three generators
in the Marcellus, and according to Linde and CONSOL, the early results are
promising.
DUAL-FUEL CAT CONVERSIONS
Nabors Offshore
- 16 cyl CAT 399 dual fuel http://www.energyconversions.com/picturescat.htm
EQT Converts Marcellus Drilling Rigs to Run on LNG
Drilling rigs take a lot of horsepower to run, and the engines that
run them are big and use a lot of fuel. That fuel is typically diesel,
and the emissions may (or may not) cumulatively contribute to air pollution
if there are enough drilling rigs in a particular region. At least that’s
the contention of the federal EPA.
EQT, in a public relations coup, is the first to start converting its
Marcellus Shale drilling rigs from running on diesel to running on liquefied
natural gas (LNG). LNG has a couple of advantages: it costs about 40% less
than diesel, and it pollutes less when burned. EQT’s first conversion is
a rig operating in northern West Virginia.
Baker Hughes
converts a fleet of its Rhino hydraulic fracturing units to bifuel pumps
The use of natural gas over diesel is becoming more widespread, likely
due to the cost benefits associated with fuel switching, according to a
Nov. 28 analyst report from GHS Research. GHS referenced Baker Hughes' Nov.
26 announcement that it would convert a fleet of its Rhino hydraulic fracturing
units to bifuel pumps as a way to improve operational efficiency, lower costs
and reduce health, safety and environment impacts.
The new pumps use a mixture of gas and diesel, reducing diesel use by
up to 65 percent with no loss of hydraulic horsepower. The converted fleet,
which meets all U.S. Environmental Protection Agency emissions standards,
can also reduce a number of emissions including nitrogen oxides, carbon dioxide
and particulate matter.
Baker Hughes first converted a small fleet of its units in Canada; the
success Baker Hughes saw with this endeavor prompted to company to convert
an entire fleet in the United States. The company is converting several
more fleets of Rhino trucks to Rhino Bifuel equipment. Baker Hughes also
has a test program in Oklahoma, where a number of light-duty vehicles have
been converted to natural gas
Cabot used a mobile pressure pumping unit provided by FTSI, which was
then retrofitted with a dynamic gas blending kit from Caterpillar. This
system allows diesel to be substituted with natural gas during high-pressure
pumping operations and is compatible with field gas, compressed natural
gas, and liquefied natural gas.
Cabot joins the likes of Apache (NYSE: APA ) , which in January
became the first energy exploration and production company to power a full
hydraulic fracturing operation using natural gas-burning engines at its
Granite Wash operations in Oklahoma. By switching to natural gas, Apache
said it expects to reduce fuel costs by roughly 60%, while also lowering
emissions.
Apache and Cabot's successful efforts in using cleaner-burning natural
gas are a promising development for the oil and gas industry, which is constantly
under fire for its alleged neglect of the environment. Not only is using
natural gas a cost-effective solution for hydraulic fracturing operations,
but it is an innovative way to utilize the nation's abundant supply of the
fuel, while also minimizing greenhouse gas emissions.
Halliburton, Schlumberger and Baker Hughes.
The abundance of unconventional low-permeability gas in North America
suggests that the extreme ratio of gaseous heating value cost to liquid
hydrocarbon heating value cost could persist for an extended period of time.
Therefore, both operators and pumping service companies have real incentives
to develop and optimize these systems.
Baker Hughes converts fracking units to bifuel pumps
The new pumps reduce diesel use by up to 65 per cent whilst maintaining
hydraulic horsepower
Texas-based oilfield services company Baker Hughes this week announced
that it has converted a fleet of hydraulic fracturing units to bifuel pumps
compatible with natural gas, in order to increase the cost efficiency of
operations and reduce the environmental risk of unconventional oil and gas
extraction.
Baker Hughes subsidiary Baker Hughes Oilfield Operations has converted
a fleet of Rhino hydraulic fracturing units to bifuel pumps, the company
said in a statement on Monday. The new pumps are powered by natural gas
and diesel, reducing diesel use by up to 65 per cent whilst maintaining hydraulic
horsepower, Baker Hughes claims. The converted fleet can also reduce nitrogen
oxide, carbon dioxide and particulate matter emissions.
The conversion was made following successful results from a similar
initiative by the oilfield service company in Canada. Baker Hughes is in
the process of converting several more fleets of Rhino trucks for bifuel
usage. The firm is following the ranks of a number of oil and gas operators
in the Marcellus Shale which have converted several drilling rigs to support
natural gas as a fuel.
"Baker Hughes has seen excellent results with this initiative," said
Mike Davis, Baker Hughes' president of Pressure Pumping for US land. "The
environmental benefits are significant. We're reducing emissions from the
engines driving the stimulation pumps and less fuel is needed to keep our
pumps going. In addition, this has the added value of improving job
site safety by eliminating re-fueling demands during operations."
Baker Hughes’s new Rhino units were recently used in a hydraulic fracturing
job in the Eagle Ford Shale for energy firm Cheyenne Petroleum Company.
The company claims the 65 per cent cut in diesel fuel consumption can help
the oil company achieve significant cost reductions
The abundance of unconventional low-permeability gas in North America
suggests that the extreme ratio of gaseous heating value cost to liquid
hydrocarbon heating value cost could persist for an extended period of time.
Therefore, both operators and pumping service companies have real incentives
to develop and optimize these systems.
The technologies required to retrofit large diesel engines so that they
can operate on a combination of natural gas and diesel has been in use
for a number of years in midstream and upstream applications. Until recently,
however, engines that power hydraulic fracturing pumps have not had the
attention in this area that other fixed-footprint power sources have received.
Historically, a number of limiting conditions have combined to slow
the acceptance and implementation of natural gas as a fuel in hydraulic
fracturing operations:
The logistics associated with delivering a clean and predictable
supply of natural gas to a given fracturing fleet in a temporary, remote
location raise challenges.
The logistics associated with distributing the fuel safely in and among
a multitude of heavy vehicles that are constantly being repositioned during
the stimulation and completion operations cause concerns. Though such logistics
might seem minor, the ramifications of failure are so large that extreme
measures must be taken to ensure system integrity and safety during a wide
range of unpredictable conditions.
In a 24-hour period of use, fracturing pumps typically cycle through
many different combinations of speeds and loads. The implication is that
the ratio of natural gas to diesel injected into the system must be instantaneously
varied to allow the development of the required torque during these periods
of changing loads and engine speeds.
Regulatory tightening of new off-road diesel engine criteria in the
U.S. (a progressive series of tiered standards mandating increased reduction
of noxious gases and particulate matter) may have temporarily diverted attention
from dual-fuel service efforts until the last two to three years.
The recent move toward implementation was initially driven by several
operators and their service companies who recognized that the huge differential
in the normalized cost of diesel and natural gas would likely be a long-term
condition. In addition, public demand for more environmentally friendly fossil
fuels suggested that any substitutionary use of natural gas could conceivably
offset the burning of heavier hydrocarbons.
Natural Gas Sources
Several sources of natural gas can be used in dual-fuel service. Liquefied
natural gas (LNG) is an option involving onsite storage at -260 F and a
vaporization unit. Approximately 1.6 gallons of LNG are required to produce
the energy equivalent of 1 gallon of diesel fuel (129,400 BTU).
Compressed natural gas (CNG) is an alternative, which is typically stored
in mobile tube trailers at about 3,600 psi. The pressure must be reduced
to a usable range, and no vaporization equipment is required.
The cost to convert to dual fuel is a challenge since a significant
expense is associated with the installation of the conversion kits.
On a comparative energy basis, approximately 4 gallons of CNG
are required to produce the same amount of energy as 1 gallon of diesel.
Local field gas can be used if it has been properly conditioned with respect
to removal or reduction of water, hydrogen sulfide (H2S) and other impurities.
While field gas has the distinct advantage of limited transport cost, approximately
1,000 gallons (133 cubic feet) of pipeline gas is required to produce the
energy equivalent of 1 gallon of diesel.
Dual-System Operation
With current dual-fuel systems, natural gas is introduced into the engine
through fumigation of the intake airstream. Depending on speed and load,
substitution ratios as high as 60 percent can be achieved. Gas initially
flows from its localized source, and its pressure is subsequently regulated
to near zero at the engine intake. It is directed past a gas shutoff valve,
heat exchanger, low-pressure variable regulator, throttle body and finally
to the intake manifold.
A typical frac fleet can use anywhere from 1.0 to 3.0 million standard
cubic feet (MMSCF) for a day’s operations, depending on the total hydraulic
horsepower present and the number of hours spent pumping. Current commodity
pricing of natural gas per unit of heating value is approximately 15 to 20
percent of the price of No. 2 off-road diesel.
From a purely fiscal standpoint, the extra cost of planning, infrastructure
and implementation of dual-fuel services can make sense even if the differential
(cost/unit of heating value) between the two fuels is as low as 40 percent.
Dual-fuel systems are required to demonstrate that they meet the certification
standards of the engines on which they are installed. In the U.S., regulatory
requirements mandate that new, large, off-road engines manufactured in or
after 2015 (EPA Tier 4F) demonstrate even further reductions of nitrogen
oxides (NOx), particulate matter and non-methane hydrocarbons (NMHC).
Dual-fuel systems often require additional exhaust catalysts (depending
upon the particular regulatory tier), and such incremental upgrades will
likely be required to achieve the ultra-low emissions required by Tier 4F
regulation.
Application of Dual-Fuel Engines
Dual-fuel scenarios in fracturing fleets are currently most applicable
when a fleet is dedicated long-term to a specific play and/or particular
operator. Engine conversion kits have significant capital cost associated
with their installation, and to take advantage of the potential cost savings,
a consistent source of natural gas should be available at each pad that
a given pumping fleet will occupy. However, if gas is not available for a
series of fracturing treatments, the dual-fuel units can run on 100 percent
diesel fuel.
Halliburton Dual-Fuel
Service in Hydraulic Fracturing Pumps
Using natural gas to power the frac spread by Doug Walser, Pinnacle,
a Halliburton Business Line
March 27, 2013
From an efficiency standpoint, acquiring conversion kits and building
up the extra infrastructure required may not make sense if dual-fuel services
are used only sporadically. In addition to the cost of installing conversion
kits, a typical fleet must carry auxiliary equipment and distribution infrastructure
on a separate truck or trailer. Maximizing the overall value of dual-fuel
processing requires that the operator’s supply chain management focus on
the specifics of ensuring 100-percent or near-100-percent use of the dedicated
equipment.
Along this line, the industry trend toward smaller hydraulic fracturing
footprints is most consistent with the use of clean and dry field or pipeline
gas. Though LNG and CNG are all part of the mix of options available to
operators, they require more tractors and trailers on location and, by implication,
more square footage of pad space.
The abundance of unconventional low-permeability gas in North America
suggests that the extreme ratio of gaseous heating value cost to liquid
hydrocarbon heating value cost could persist for an extended period of time.
Therefore, both operators and pumping service companies have real incentives
to develop and optimize these systems.
About the author:
Doug Walser has extensive (31 years) Permian Basin, Mid-Continent, Appalachia,
Rockies and South Texas experience with Dowell Schlumberger; The Western
Company of North America; BJ Services; and Pinnacle, a Halliburton business
line. He has specialized in the calibration of three-dimensional fracture
modeling via a number of methods. Recently, he has specialized in the examination
and comparison of the various emerging resource plays in North America, and
more specifically, plays with liquid hydrocarbons. He has written 14 papers
and holds three patents in his areas of interest. He can be reached at doug.walser@pinntech.com.
DGB-Modified 3512Cs
dual fuel for Citadel Drilling and Tycrop Pressure Trailers
Caterpillar Oil & Gas has disclosed new customers for its 3512C engines
outfitted for natural gas-diesel duel fuel operation with the manufacturer’s
own Dynamic Gas Blending kits. The operators are Citadel Drilling for upwards
of a dozen drill rigs and Tycrop, for 20 trailers carrying 3512C-powered
well stimulation gear.
Citadel is building “Technically Advanced AC Triple” drilling rigs to
comprise a fleet of 12 to 14 units over the course of the next five to six
years, Caterpillar says.
“The first three Cat DGB units have been delivered and tested and are
slated to be field operational by the end of June 2014 on Citadel’s first
rig,” Caterpillar reports. Three Cat 3512C modules each with rated power of
1,kilowatts (1,476 brake horsepower) at 1200 rpm, will be used to power each
of the Citadel land drilling rigs.
Compressed Natural Gas or Field Gas
“Our customers will save in excess of $50,000 per month in fuel savings
by utilizing our rigs equipped with the cost-effective Cat DGB power and
CNG or field gas supply,” Citadel CEO Dan Hoffarth says in the Caterpillar
announcement. “The Cat DGB solution has operational consistency and a fantastic
support team in Finning Canada and is, in my opinion, the dual fuel leader
in the industry,” he said.
“Citadel Drilling just experienced the most trouble free start-up and
generator syncing process in our electrical/automation providers’ history.
The engines were put online, synced and power shared better than any project
we have been associated with,” Hoffarth said.
Diesel Displacement Up to 70%
For Tycrop, Cat reports an initial order for 3512C engines with DGB for
20 equipment trailers. Each engine will provide 2,500 horsepower at 1,900
rpm of rated power and will be manufactured in an ATAAC – air-to-air-after-cooled
– configuration. The engines for Tycrop will also feature Product Link,
a Caterpillar telematics solution for comprehensive engine management.
“The Dynamic Gas Blending kit,” Caterpillar says, “automatically adjusts
to changes in incoming fuel quality and pressure allowing engines to run
on a wide variety of fuels, from associated gas to vaporized LNG with no
loss of performance integrity. It maintains diesel performance levels with
up to 70% replacement of diesel with gas, accepts up to 55% inerts and can
be applied to existing engines with EPA certification.”
Finning Canada Got It Done
“No customer input or gas analysis is needed during operation, and no
recalibration is required when the equipment is moved or the gas supply changes.”
Cat credits its dealer Finning Canada for leading the Citadel and Tycrop
sales efforts and said that Finning Canada will support the companies’
dual fuel work.
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ND Drilling Rigs Saturday July 18 2015 And fracing
units:
http://www.patenergy.com/drilling/rigs/
Patterson Drilling Rigs 10 in ND 1000 1500 and 2000+ hp
Abraxas, 1
Armstron, 1
Burlington RES, 4
Continental, 10
Denbury, 1
Enerplus Res, 1
EOG Resources, 3
Marathon Oil, 1
Newfield PROD, 1
Oasis, 3
Petro Hunt, 2
QEP Energy, 2
Sinclair, 1
Slawson, 1
SM Energy, 4
Whiting, 8
WPX Energy Williston, 1
XTO Energy, 9
Zavanna, 1 AES, 1
Canelson, 1
Craig, 2
Cyclone, 4
Ensign, 1
Extreme, 1
Frontier, 1
H & P(Helmerich & Payne), 9
Nabors, 25
Patterson, 10
Pioneer, 2
Precision, 4
Raven, 1
Sidewinder, 1
Stoneham, 1
Trinidad, 2
True, 1
Unit, 5
North Dakota NABORS
AC SCR
TOTAL MECH
<1000 hp 1 1
2 7 4
<1400 HP 11 41
6 1 48
>2000 hp 1 49
12 1 62 1
PACE-X RIGS
17 SOME WITH 3512 DUAL FUEL CAT AVAILABLE UP TO 4 3516 CATS
COMPLETION AND PRODUCTION SERVICES
ROCKIES 69 FRAC CREWS
10 TRUCKS 56
http://www.patenergy.com/# PATTERSON DRILLING COMPANY AND PRESSURE
PUMPING
North Dakota 13
Universal Pressure Pumping, Inc. and Universal Well Services, Inc.
are subsidiaries of Patterson-UTI Energy, Inc.
Sidewinder
drilling HAS 3 RIGS IN BAKKEN SLAWSON IS THINKING LNG FOR ITS DRILLING
RIG
http://www.sidewinderdrilling.com/rig-fleet
H&P http://www.hpinc.com/drilling/business-segments/us-land
North Dakota 239 22,000 AC (FlexRig3) 750,000
North Dakota 255 22,000 AC (FlexRig3) 750,000
North Dakota 256 22,000 AC (FlexRig3) 750,000
North Dakota 257 22,000 AC (FlexRig3) 750,000
North Dakota 258 22,000 AC (FlexRig3) 750,000
North Dakota 259 22,000 AC (FlexRig3) 750,000
North Dakota 272 18,000 AC (FlexRig4) 500,000
North Dakota 293 20,000 AC (FlexRig4) 600,000
North Dakota 294 20,000 AC (FlexRig4) 600,000
North Dakota 295 20,000 AC (FlexRig4) 600,000
North Dakota 309 18,000 AC (FlexRig4) 500,000
North Dakota 316 18,000 AC (FlexRig4) 500,000
North Dakota 317 18,000 AC (FlexRig4) 500,000
North Dakota 320 18,000 AC (FlexRig4) 500,000
North Dakota 324 18,000 AC (FlexRig4) 500,000
North Dakota 325 18,000 AC (FlexRig4) 500,000
North Dakota 329 20,000 AC (FlexRig4) 600,000
North Dakota 353 18,000 AC (FlexRig4) 600,000
North Dakota 386 22,000 AC (FlexRig3) 750,000
North Dakota 392 22,000 AC (FlexRig3) 750,000
North Dakota 438 22,000 AC (FlexRig3) 750,000
North Dakota 446 22,000 AC (FlexRig3) 750,000
North Dakota 448 22,000 AC (FlexRig3) 750,000
North Dakota 449 22,000 AC (FlexRig3) 750,000
North Dakota 454 22,000 AC (FlexRig3) 750,000
North Dakota 456 22,000 AC (FlexRig3) 750,000
North Dakota 457 22,000 AC (FlexRig3) 750,000
North Dakota 471 22,000 AC (FlexRig3) 750,000
North Dakota 492 22,000 AC (FlexRig3) 750,000
North Dakota 515 25,000 AC (FlexRig5) 750,000
North Dakota 516 25,000 AC (FlexRig5) 750,000
North Dakota 517 25,000 AC (FlexRig5) 750,000
North Dakota 524 25,000 AC (FlexRig5) 750,000
North Dakota 535 25,000 AC (FlexRig5) 750,000
North Dakota 640 22,000 AC (FlexRig3) 750,000
UNIT DRILLING RIGS IN NORTH DAKOTA ALL HAVE 3-3512C CATS 1500
hp
EXCEPT ONE WHICH HAS 2-379TAs 1000 hp
http://unitdrilling.com/Operations.html
SHOWS 12 RIGS IN NORTH DAKOTA
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Range Resources and FTS
International Use Clean-Burning Natural Gas to Power Equipment for Hydraulic
Fracturing August 04, 2015 WASHINGTON COUNTY, Pa. (PRWEB)
Range Resources and FTS International have successfully partnered on an
initiative to use clean-burning natural gas from producing gas wells to power
an entire pressure pumping fleet, yielding several environmental benefits.
Range Resources and FTS International (FTSI) have successfully partnered
on an initiative to use clean-burning natural gas from producing gas wells
to power an entire pressure pumping fleet, yielding several environmental
benefits. To date, FTSI has completed 15 wells and a total of 365 stages
for Range Resources using this fleet.
FTSI's new fleet uses a technology called dual fuel, where the pressure
pumping engines operate on a mixture of natural gas and a small portion of
diesel. The dual fuel engines can displace up to 65 percent of the diesel
fuel traditionally used to operate pressure pumping equipment.
The benefits of this technology include:
Reduced air emissions for a cleaner environment, due to a reduction in
diesel usage
Reduced truck traffic when field gas at or near the well site is used (reduces
transportation of diesel fuel to site)
Reduced costs, as natural gas can be a less expensive fuel option than
diesel, providing potential cost savings for the industry and for energy
consumers
Range Resources Executive Vice President and Chief Operating Officer Ray
Walker commented, "In today's environment, improving operational efficiencies
is critical. This growing technology not only allows Range to improve our
well economics but it allows for the use of a clean burning fuel. Advances
like these are how we as an industry have been able to reduce emissions
from natural gas production by 38% since 2005, according to the EPA."
FTSI CEO Greg Lanham said, "We are pleased to offer this technology in
a dedicated fleet to Range Resources. This solution is not only environmentally
conscious, but also helps us be more operationally efficient, delivering
exceptional uptime and reliability during hydraulic fracturing operations.
FTSI is privileged to work with market leaders like Range that are early
adopters of this type of technology."
Range Resources Corporation is a leading independent oil and natural gas
producer with operations focused in Appalachia and the Midcontinent region
of the United States. The Company pursues an organic growth strategy targeting
high return, low-cost projects within its large inventory of low risk, development
drilling opportunities. The Company is headquartered in Fort Worth, Texas.
More information about Range can be found at http://www.rangeresources.com.
FTS International (http://www.ftsi.com) is the largest private well completion
service company in North America. The company provides well completion services,
including pressure pumping, wireline and reservoir optimization technologies.
Exploration and production companies use FTSI's products, services and expertise
to enhance recovery rates from oil and gas wells, primarily in unconventional
plays.
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Halliburton introduces
new refracturing service
7/29/2015
Halliburton announced today the launch of ACTIVATE Refracturing Service,
a collaborative workflow that leverages subsurface insight, expertise and
breakthrough diversion technology to recover bypassed reserves from unconventional
wells more predictably and repeatedly.
Generating more predictable results from refraced wells is creating a paradigm
shift on how Halliburton targets shale/tight formation field development.
Operators can now increase their ability to build a balanced portfolio with
production distributed across new wells, infills and refracs in order to drive
down the cost per BOE break-even point of their specific assets. With ACTIVATE
Service, Halliburton can help operators increase their ultimate recovery
and bookable reserves.
In basins where Halliburton has delivered ACTIVATE Service, operators are
seeing on average an 80% increase in EUR per well, 66% reduction in cost per
BOE from refractured wells compared to new wells, and a potential of up to
a 25% increase in the oil recovery factor with a balanced portfolio.
The ACTIVATE Service leverages multiple Halliburton products, such as its
AccessFrac Stimulation Service, FiberCoil Tubing Service, FracInsight Service,
Pressure Sink Mitigation Solution (PSM) and Pinnacle’s Integrated Sensor Diagnostics
(ISD) to obtain subsurface insight and bring together the needed expertise
to make refracs more reliable and predictable.
“Our customers can be confident that Halliburton’s ACTIVATE Service has
shown that it can help deliver their projects at a lower cost per BOE, and
that we are helping reduce the unpredictability that has surrounded refracturing
projects in the past,” said Jim Brown, Halliburton’s president of the Western
Hemisphere.
“Given today’s commodity prices, adding more refracs to their unconventional
portfolios just makes sense and can help increase the profitability of the
operators’ assets.”
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