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Natural Gas Pipeline Leaks and Emissions Andy Greenspon HEJC March 18, 2015 Natural Gas vs. CO2 •  Natural gas: primarily methane CH4. •  Global average atmospheric levels: –  CO2 ~ 400 ppm = 400,000 ppb. –  CH4 ~ 1,800 ppb = 0.45% of CO2 levels. •  Lifespans: –  CO2: centuries –  CH4: decades (half life of 7 years in atmosphere) –  Natural gas is a much more potent greenhouse gas than CO2 •  ~20-‐25 Rmes more over the long term (100 years). •  ~72 Rmes more over a 20 year horizon. Natural gas producRon and atmospheric methane levels. •  Methane levels have steadily risen since the start of the industrial revoluRon in 1750. •  Leveled oﬀ in the early 2000s. •  Started rising again in the late 2000s (due to the natural gas boom??) U.S. natural gas producRon and pipelines Natural gas producRon and distribuRon compressor staRons Pipeline infrastructure is vast and distributed – companies control many diﬀerent geographic regions and diﬀerent types of pipes (material, age, size, miles of piping). Unaccounted for natural gas •  Gas distribuRon companies in 2011 reported releasing 69 billion cubic feet of natural gas to the atmosphere. –  Almost enough to meet the state of Maine’s gas needs for a year. –  Equivalent to ~33.3 million metric tons of CO2. •  Equivalent to CO2 emissions of ~ 6-‐7 million automobiles. –  Reference: CO2 emissions in 2014: 32.3 billion metric tons •  Natural gas released contributes equivalent of only ~0.1% of total CO2 emissions. •  Natural gas unaccounted for in 2000-‐2011: –  U.S.: 2.6 trillion cubic feet –  Massachuse]s: 99 -‐ 227 billion cubic feet of natural gas –  Natural gas distribuRon systems (main pipelines and smaller distribuRon networks and mains): 19% of total CH4 emissions from natural gas systems. Conversion factor assumpRons: –  1 billion cubic feet CH4 = 19,300 metric tons CH4 –  1 metric ton CH4 = 25 metric tons CO2 equivalent –  1 billion cubic feet CH4 = 482,500 metric tons CO2 equivalent newable
chigan,
y, Camdminisder, CO.
ment of
Energy
bridge,
eley, CA.
ersity of
onmen-
supplere those
the U.S.
espond-
This study presents a first effort to systematically compare published CH4 emissions
estimates at scales ranging from devicelevel (>10 3 g/year) to continental-scale
atmospheric studies (>1013 g/year). Studies
known to us that (i) report measurementbased emissions estimates and (ii) compare
those estimates with inventories or established emission factors (EFs) are shown in
the first chart.
Studies that measure emissions directly
from devices or facilities (“bottom-up” studies) typically compare results to emissions
factors (EFs; e.g., emissions per device).
Large-scale inventories are created by multiplying EFs by activity factors (e.g., number
of devices).
Studies that estimate emissions after
atmospheric mixing occurs (“atmospheric”
studies) typically compare measurements to
emissions inventories, such as the U.S. Envi-
Atmospheric natural gas measurements vs. claimed emissions factors Brandt, et al. (2014). Ratios with common baseline (EPA GHGI)
Ratios as published
1015
1014
1013
1012
12
10
1011
1010
0
1
2
3
4
5
6
7
8
109
Scale of measurement
National or continental
Multi-state
Regional or air basin
Facility
Device or component
6
10
Downloaded from www.sciencemag.org on March 15, 2015
akage
other
techUnited
mateasurenvenl CH4
ors as
epenumber
e for a
gional
ssions
f typissessshow
large
al-to-
Underestimation—Device to Continent
Emissions magnitude (g CH4/year)
bridge
rbons carer fosstries.
rming
ompoG use
recent
e benlarge
uction
pheric
th the
•  Emissions factor (EF): esRmated emissions per device. •  Inventory: EF x number of devices •  RaRo >1 indicates emissions are larger than expected from emissions factor or inventory claimed. Summary of studies: •  Emissions are overall underesRmated. •  State and regional studies predict larger Ratio: measured/inventory or measured/EF [unitless]
underesRmaRon than naRonal studies. •  NaRonal studies, which average outliers be]er, suggest 1.25-‐1.75 Rmes the Inventories and emissions factors consistently underestimate actual measured CH emissions across
emissions than expected from the scales. Ratios >1 indicate measured emissions are larger than expected from EFs or inventory. Main graph
compares results to the EF or inventory estimate chosen by each study author. Inset compares results to
green house gas inventory of the EPA. regionally scaled common
(17), scaledC
toH
region
study and (in some cases)
under
Challenge: adenominator
]ribuRng eofmissions to themsector
ulRple 4
examination. Multiple points for each study correspond to different device classes or different cases measured in a single study.
nitions of error(bar
bounds vary between studies. (US,a
United
Can, Canada;
potenRal sDefi
ources anthropogenic nd States;
natural). SC, South Central; Petrol. and Pet., petroleum; SoCAB, South Coast Air Basin; LA, Los Angeles; DJ, DenverAttribution
Attributed to oil and gas or
measured at facillity
Attributed to energy indust.
or not attributed
103
0.01
(6): US
(5): US + Can
(8): US energy
(13): US energy
0.1
1.0
(6): SC-US
(9): SC-US
(6): SC-US, NG + Petrol.
10
(12): SoCAB I
(1): UT
(12): SoCAB II
(7): all sources
100
1000
(2): SoCAB
(2): SoCAB, NG + Pet.
(10): LA county
(3): DJ basin
(25): DJ basin
(14): Gas plants
(26): Production + HF
(18): Compressor
(15): Gas plants
(21): Gas plants, other
(16): Distribution
4
Julesberg; UT, Utah; HF, hydraulic fracturing). See SM for figure construction details.
Reported gas leaks in Massachuse]s Grade 1 – hazardous Grade 2 – potenRally hazardous Grade 3 – non-‐hazardous Companies ofen ignore grade 3 leaks. But in aggregate they can make signiﬁcant contribuRons to CH4 emissions. To quantify the fraction of the observed ΔCH4 that was due to
Nahant (NHT)] measurement stations (black points) in Boston, and the surNG emissions, we compared ratios of C2H6 and CH4 measured
rounding area, overlaid on a map of the number of housing units with NG
in the atmosphere and NG pipelines serving the region. Ethane
per square kilometer (14). The 90-km radius circle delineates the ∼18,000is a significant component of NG, whereas microbial CH4 sources,
2
km land area for which CH4 emissions and the NG loss rate were calculated.
such as landfills, sewage, and wetlands, produce little or no C2H6
The magenta and purple contours enclose 50% of the average footprint
(15). Because Boston has no geologic CH4 seeps, no oil and gas
(sensitivity area) of the BU and COP afternoon measurements, respectively.
production
or refining, and low rates of biomass burning, there
The two city sites are difficult to distinguish at this scale because the horizontal distance between them is ∼2 km. The influence area is ∼80% larger
are no known significant sources of C2H6 in the region other
for COP than BU because the former station is higher. See SI Appendix, Table
than
NG.
Methane
concentrations
in Boston were consistently elevated
S2, for additional
measurement
site location Housing
information.
Measurement
sites
units
Ethane concentrations were measured with a laser spectrom-
QuanRtaRve study of gas leaks in the Boston area background (Fig. 2 and SI Appendix, Figs. S1 and S2) and
•  over
Atmospheric CforH34 mo
c(Fig.
oncentraRons easured (15) at
BUpattern
in 3the
winter
of
and
followed
aeter
distinct
daily
A fall
andand
C, and
SI m
Ap-2012–13
1
mo
in
the
late
spring
of
2014
(SI
Appendix,
Fig.
S6).
Covariances
pendix, Fig. S16), associated with growth and decay of the
Methane Concentrations in the Boston Atmosphere
conRnuously from CSHep and2fluctuated
012 o Aug 2013 at four CH t
observations
planetary between
boundary atmospheric
layer. Concentrations
over short were deAtmospheric CH concentrations were measured continuously
from Fig.
the daily
slopes
of a linear model
that minimizes χ
timescalestermined
(SI Appendix,
S1) due
to small-scale
atmospheric
locaRons: from September 2012 through August 2013 at two locations near
(16)
of heterogeneous
5-min median sources
afternoon
dataurban
(Fig. environ4 and SI Appendix,
circulations
and
in the
the urban center [Boston University (BU) and Copley Square
sectionconcentrations
S2.1). The median
ofhigher
the daily
slopes of
atmospheric
CH
ment. • 
Methane
in
winter
than
the
Two urban cwere
enters: Bless
U awith
nd Cseason
opley (COP)] and two locations outside of Boston [Harvard Forest
versus
2.6but
(2.5,
2.8) varied
% during
the
cool
and 1.6
other seasons
at CH
bothwas
sites,
ΔCH
season
(HF) and Nahant (NHT)] (Fig. 1 and SI Appendix, Table S2
and2). The
1.7) l%
during afternoon
the warm
season,
obtained
with
at from
BU Hdays
(Fig.
average
annual
values
of B
ΔCH
•  (1.4,
Two ocaRons outside oston: arvard section S1). Background concentrations in air flowing into
coefficient
of determination
0.7539.3)
(∼50%
andthe
COP awere
45.9 (37.3,
58.5) ppb and (R
30.5) >
(23.6,
ppb,of the days).
city were estimated by randomly sampling from a range (5th
to
respectively
(Fig.average
2), reflecting
different
altitudes
(30
The
C HN
and
CH sampling
ratio in the
NG flowing
into the
Forest and ahant 35th) of lower percentiles of CH measurements from two
andup-215 region
m, respectively;
SItwo
Appendix,
Table measurement
S2). All errorsperiods was
during the
atmospheric
wind stations (HF or NHT, depending on the direction ofreported
simthroughout
thethe
paper
aresampling 95% confidence
intervals.
2.7
±- 
0.0%
in
fall and
winter
of 2012–2013
and
Random over 48 2.4h ±p0.1%
eriods to ulated air trajectories; SI Appendix, section S3.1), averagedUncertainties
over
(Fig.
2) were
calculated
through
a bootin spring
ΔCH of
in the
2014,
determined
from
hourly
gas quality data
strap
background
af- (17, 18) (SI
a 48-h moving window, to capture synoptic-scale variability
andanalysis
get main
background concentraRons fromthat
the included
three
pipelinesconcentrations
that serve
the and
region
42.5
0
with NG km−2
4000
2
50 km
4
6
4
2
500
2
HF
BU
NHT
COP
4
100
4
2
2
10
6
4
41.5
4
6
4
42.0
Latitude
43.0
43.5
Study Boundary
BU 50% influence contour
COP 50% influence contour
4
0
measurements
ternoon hourly,
daily,Figs.
and seasonally
CH4S2.2).
remove possible
influences
of −70.5
small nearby sources (SI Appendix,
−72.5
−71.5
Appendix,
S7 and S8,averaged
and section
The quotient of the
(SI
Appendix,
section
S3.3).
were
calculated
by
subtracting
section S3.3). Values
of
ΔCH
C2H6 and CH4 ratios in the atmosphere and pipeline demon4
Longitude
background from urban concentrations. Hourly average ΔCH4
strates that NG contributed 98 (92, 105) and 67 (59, 72) % of the
Contribution of NG to Elevated CH4 Concentrations
Fig. 1. data
Location
of aggregated
two city [Boston
(BU), 29-m(11–16
height; hCopley
were
intoUniversity
daily afternoon
EST, 16–21 h
ΔCH4 in Boston in the cool and warm seasons, respectively.
Square (COP), 215-m height] and two peripheral [Harvard Forest (HF);
To on
quantify
theresult
fraction
the observed
due tothe relative
4 that wasabout
UTC)
means
to
remove
autocovariance
and
focus
the
analysis
This
is of
insensitive
to ΔCH
assumptions
Nahant (NHT)] measurement stations (black points) in Boston, and the surH
and
CH
measured
NG
emissions,
we
compared
ratios
of
C
2
6
4
4
contribution of the three pipelines that supply the region and
of well-mixed
atmospheric
conditions.
roundingperiods
area, overlaid
on a map of
the number of
housing units with NG
in the atmosphere and NG pipelines serving the region. Ethane
per square kilometer (14). The 90-km radius circle delineates the ∼18,000is a significant component of NG, whereas microbial CH4 sources,
loss rate were calculated.
km2 land area for which CH4 emissions and the NG4
such as landfills, sewage, and wetlands, produce little or no C2H6
The magenta and purple contours enclose 50% of the average footprint
(15). Because
geologic CH4 seeps, no oil and gas
(sensitivity area) of the BU and COP afternoon
respectively.
A measurements,BU
B Boston has noCOP
production or refining, and low rates of biomass burning, there
The two city sites are difficult to distinguish at this scale because the horizontal distance between them is ∼2 km. The influence area is ∼80% larger
are no known significant sources of C2H6 in the region other
for COP than BU because the former station is higher. See SI Appendix, Table
than NG.
S2, for additional measurement site location information.
Ethane concentrations were measured with a laser spectrometer (15) at BU for 3 mo in the fall and winter of 2012–13 and
1 mo in the late spring of 2014 (SI Appendix, Fig. S6). Covariances
Methane Concentrations in the Boston Atmosphere
between atmospheric C2H6 and CH4 observations were deAtmospheric CH4 concentrations were measured continuously
termined from the daily slopes of a linear model that minimizes χ2
from September 2012 through August 2013 at two locations near (16) of 5-min median afternoon data (Fig. 4 and SI Appendix,
the urban center [Boston University (BU) and Copley Square
section S2.1). The median of the daily slopes of atmospheric C2H6
(COP)] and two locations outside of Boston [Harvard Forest versus CH4 was 2.6 (2.5, 2.8) % during the cool season and 1.6
SON DJF Table
MAM S2
JJAand
ANN
SON DJF MAM JJA ANN
t al. (2015). (HF) and Nahant (NHT)] (Fig. 1 and SI Appendix,
(1.4, 1.7) % during the warm season, obtained McKain, from daysewith
2
sectionFig.
S1).
Background
concentrations
in
air
flowing
into
the
coefficient
determination
(R right
) > 0.75
of and
the for
days).
2. Average (±95% confidence intervals) afternoon (11–16 h EST)aCH
y axis)
and ΔCH4 (blue;
y axis)(∼50%
by season
the whole year at
4 (black; leftof
city were
randomly sampling from a range (5th to
(A) estimated
BU and (B) by
COP.
The average C2H6 and CH4 ratio in the NG flowing into the
1880
120
∆CH4 (ppb)
100
80
20
40
60
2000
1960
CH4 (ppb)
∆CH4 (ppb)
1920
120
100
80
20
40
60
1960
1920
1880
CH4 (ppb)
2000
•  Values of ΔCH calculated by subtracRng background from urban concentraRons. •  Hourly average ΔCH data aggregated into daily afernoon means (11-‐16 h EST). MAM
JJA
ANN
DJF
MAM
JJA
ANN
MAM
JJA
ANN
SON
DJF
MAM
JJA
ANN
0
1
2
3
•  Leak rate corresponds to ~300,000 m1944
etric tons of natural gas leaked over the | www.pnas.org/cgi/doi/10.1073/pnas.1416261112
2012-‐2013 year studied — about 2.7 % of all natural gas delivered to the region of study. -  7.5 million metric tons CO2 equivalent or CO2 emissions from ~1.5 million passenger vehicles. -  Gas valued aANN
t $90 million and could heat 200,000 homes in a year. SON DJF MAM JJA
•  (±95%
State and intervals)
federal authoriRes previous esRmate: 1.1 % obyf nsector,
atural nd annual average
confidence
(A) optimized
CH emissions
in total and from
NG, (B) NG consumption
and (C)gas was being ed from CH concentration observations from the BU and COP sites together. (B) Consumption categories are electric power, residential
lost tofo industrial,
leaks fvehicle
rom fuel,
a rand
ange oand
f sources in (SIthe area, including homes, businesses, nd other, which is comprised
pipeline
distribution use
Appendix,
section
3.2.1).
and electricity generaRon faciliRes. org/cgi/doi/10.1073/pnas.1416261112
et al.
•  If correct, Boston area would be contribuRng 9% of U.S. mMcKain
ethane from natural gas – implies naRonal esRmate is also low. Nat. Gas Loss Rate (%)
200
3
Fig. 5. Seasonal and annual average (±95% confidence intervals) (A) optimized CH4 emission
NG loss rates, derived from CH4 concentration observations from the BU and COP sites togeth
and commercial, and other, which is comprised of industrial, vehicle fuel, and pipeline and d
McKain, et al. (2015). 4
4
SO
2
0
SON
DJF
1
600
400
200
0
DJF
C
Nat. Gas Loss Rate (%)
800
Nat. Gas Consumption (g CH4 m−2 yr−1)
15
10
0
SON
4
C
Elec Power
Res & Com
Other
RaRo of C2H6 to CH4 determines proporRon of natural gas contribuRon to CH4 emissions 20
25
30
B
Total
Nat Gas
5
CH4 Emissions (g m−2 yr−1)
A
SON
4
0
5
QuanRtaRve study of gas leaks in the Boston area 0
10
Nat. Gas Consu
(23). Emissions of NG in our study area are equal to ∼8% of US
emissions attributed to distribution, transport, and storage, and
∼23% of national emissions from distribution alone, a notably
higher fraction than the ∼3% of US residential and commercial
CH4 Emiss
nalysis makes no assumptions about the relative
emissions of specific NG-consuming sectors or
ses (SI Appendix, section S3.2.1), which could
e very different loss rates than the aggregate
Primary cause of natural gas leaks – old infrastructure •  Cast iron and bare steel: –  Leak 18 Rmes more gas than plasRc pipes. –  Leak 57 Rmes more gas than protected steel. •  In 2012, Massachuse]s had: –  5,482 miles of leak-‐prone mains. –  194,326 miles of leak-‐prone service lines. 2013 MassachuseAs State Rank for Pipeline Material Rank Item 2 Most miles of cast iron service lines 3 Most miles of cast iron mains 4 Most miles of bare steel service lines 9 Most miles of bare steel mains 6 Most miles of pipeline from cast iron and bare steel New England Gas Main Milesb
New England Gas Service
Linesb
17
-1%
-1%
-1%
-2%
-3%
-3%
8%
-4%
185
-5,637
-2%
-5%
-2%
-11%
-13%
-19%
448%
-5%
8,813
Nstar Gas Main Miles
145
-3%
-2%
-2%
-2%
-3%
-2%
-3%
-3%
716
-4%
Lack of incenRves to repair “minor” leaks Table 6: Replacement rates for leak-prone pipeline in Massachusetts, by company, 2004-2012
17
Nstar Gas Service Lines
Wakefield Municipal Gas & Light
Main Miles
Wakefield Municipal Gas & Light
Service Lines
Westfield Gas & Electric Main
Miles
Westfield Gas & Electric Service
Company
Name
Lines
• 
9,303
-2%
-4%
-2%
-3%
-4%
-4%
-5%
26,514
11
Leakprone
529
Pipeline
Replaced
15
Since
2004
493
-1%
-3%
-4%
-1%
-1%
-9% rate -4%
Replacement
-3%
37
0%
-4%
-4%
-1%
-4%
-7%
-8%
-2%
-4%
-2%
-2%
-2%
-5%
-4%
-1%
-10%
2005
14%
2006
-7%
2007
-6%
2008
-8%
2009
-6%
2010
-4%
2011
-4%
2012
-5%
Leak1,463
prone
Pipeline
42
Remaining
in
2012
1,543
Massachusetts - Main Miles
Berkshire Gas - Main Miles
Massachusetts - Service
Berkshire
Gas - Service Lines
Lines
Blackstone
Gas - Miles
Main Miles
National- Main
1,293
23
-3%
-2%
-3%
-73%
0%
251%
-2%
-2%
-2%
-2%
-3%
-2%
-3%
-3%
-4%
-4%
5,571
115
1,088
28,419
220,944
-3%
-2%
0%
-5%
-3%
-4%
0%
-3%
-3%
-2%
0%
-3%
-2%
-3%
0%
-2%
-2%
-4%
0%
-4%
-4%
-3%
0%
3%
-2%
0%
100%
-4%
-5%
-4%
0%
-3%
3,864
194,326
093,705
Blackstone
Gas - Service Lines
National- Services
02,036,032
0%
-10%
0%
4%
0%
-2%
0%
-2%
0%
-4%
0%
-35%
0%
-4%
0%
-12%
02,568,279
Source: Staff analysis of PHMSA’s Cast and Wrought Iron and Bare Steel Pipeline Inventory, available at: http://opsweb.phmsa.dot.gov/pipeline_replacement/cast_iron_inventory.asp and
http://opsweb.phmsa.dot.gov/pipeline_replacement/bare_steel_inventory.asp
respectively.
Boston Gas - Main Milesa,b
496
-1%
-2%
-1%
-1%
-2%
-3%
-2%
-3%
2,997
Notes: According to PHMSA officials, changes in replacement rates are generally due to three factors: (1) pipeline replacement, (2) acquisition of or selling off part of a distribution pipeline, or (3) changes in pipeline
classification due to updated information
or recordkeeping.
a,b
BostonbyGas
- Service
Lines
6,609
-2%in 2010.
13%
-1%
-2%
-3%
-5%
-3%
-3%
90,523
a Owned
National
Grid. Essex
Gas was merged
into Boston Gas
b Participating in Massachusetts’ Targeted Infrastructure Replacement Program. Fitchburg Gas & Electric applied in 2011.
In many states, gas companies pass on the cost of lost gas to customers. 16
–  MassachuseAs customers lost $640 million to $1.5 billion from 2000-‐2011 due to leaked gas. • 
Replacing old pipes signiﬁcant capital. 189 requires -1%
-2%
-2% upfront -3%
-3%
-5%
Colonial Gas - Main Milesa,b
cColumbia
Gas is a subsidiary of NiSource.
-19%
-17%
253
–  33 states, including Massachuse]s, have infrastructure replacement programs. 1,078
26%
1%
-6%
-8%
-6%
-3%
-10%
-10%
4,466
–  But sRll li]le incenRve to accelerate pipeline replacement so long as companies can sRll pass b,c
Columbia Gas
- Main
344
-5%lost gas. -5% -4%
-4%
-3%
-2%
-4%
-4%
979
costs oMiles
n to customers for Colonial Gas - Service Linesa,b
• 
-3%
-3%
-3% established -3%
-3% limits -3% on -4%
Only two states, P13,907
ennsylvania a-4%
nd Texas, have the a46,622
mount companies can charge customers for l-1%
ost gas. Essex Gas - Main Miles
23
-2%
-4%
-1%
-3%
-6%
1%
-3%
111
Columbia Gas - Service Linesb,c
a,b
• 
– GasTexas: 2010 to 2533
012 gas -1%
companies their o-2%
f leak-‐prone service lines a,b
Essex
- Service Lines
4% reduced -2%
-2% inventory -3%
-3%
-3%
4,433 by 55 percent (
101,790 l
ines). Fitchburg Gas & Electric - Main
b
Miles– 
21 period, -83%
433%
-3%
-3%
-3% reduced -3%
-3% leak-‐prone -4%
66 service In this same Rme gas companies in Massachuse]s their Fitchburg Gas & Electric lines by just 4 p-490
ercent (8,278 lines). -8%
Service Linesb
-6%
-14%
-9%
-8%
119%
-6%
-8%
3,379
As of 2013, only ﬁ6 ve states a0%
ll non-‐hazardous leaks t-2%
o be repaired 0% required -2%
-3%
-3%
0%
0%
58 within a certain Rmeframe. City of Holyoke Service Lines
1,127
-2%
-4%
-2%
-2%
-5%
-3%
-7%
-10%
2,557
City of Holyoke Main Miles
Methods to detect and reduce pipeline leaks •  Include all emissions sources in inventory for possible leaks, including: –  downstream of customer meters –  industrial faciliRes –  residenRal and commercial serngs. •  Improve sampling protocols and develop more comprehensive leak surveys. –  negaRve unaccounted for gas volumes by companies indicate calculaRng or reporRng errors –  infrequent high emission events are under-‐sampled. –  small leaks require more sensiRve equipment to detect •  Replace old mains and service lines sooner rather than later. New MA law to promote repair of pipeline infrastructure •  Passed in July 2014: An act relaRve to natural gas leaks –  Grade 1 (hazardous) leaks must be repaired unRl hazard is eliminated. –  Grade 2 (potenRally hazardous) leaks required to be repaired within a year. –  Grade 3 (non-‐hazardous) leaks must be reevaluated. –  Gas companies accountable for plans to remove leak-‐prone infrastructure. •  What’s sRll missing: –  Ratepayers sRll pay the cost of lost gas. –  Grade 3 leaks don’t actually have to be repaired on any Rmetable. –  No requirement to acRvely replace old cast iron and bare steel pipes without leaks. OpRmism for the future? •  Based on EPA assumpRons, Massachuse]s residents stand to realize $156 million in net beneﬁts over 10 years from the companies parRcipaRng in MA infrastructure replacement program. •  State law requires Massachuse]s to reduce GHG emissions to 25 percent below 1990 levels by 2020. •  By 2010, Massachuse]s had already succeeded in reducing methane emissions from the natural gas distribuRon system by 14 percent below 1990 levels. New pipeline proposal through MA/NH – 2018? •  Capacity to transport up to 2.2 billion cubic feet of natural gas per day from wells in Pennsylvania to markets in the Northeast. •  Co-‐locaRng with exisRng right of way uRlity corridors. •  65 and 90 % of aﬀected landowners in MA and NH respecRvely have not granted permission to enter their land for surveying purposes. -  Possible eminent domain authority to pursue access to those denied properRes if pipeline wins a cerRﬁcate from federal regulators. QuesRons?