40 CFR 98.233 - Calculating GHG emissions.

Code of Federal Regulations, 2013 CFR

2013-07-01

... group, and sub-basin category), where gas wells are vented to the atmosphere to expel liquids... produced liquids from onshore petroleum and natural gas production facilities (including stationary liquid... wellhead gas-liquid separator before liquid transfer to storage tanks. Calculate flashing emissions with a...

40 CFR 98.233 - Calculating GHG emissions.

Code of Federal Regulations, 2014 CFR

2014-07-01

... group, and sub-basin category), where gas wells are vented to the atmosphere to expel liquids... produced liquids from onshore petroleum and natural gas production facilities (including stationary liquid... wellhead gas-liquid separator before liquid transfer to storage tanks. Calculate flashing emissions with a...

40 CFR 98.233 - Calculating GHG emissions.

Code of Federal Regulations, 2012 CFR

2012-07-01

...), where gas wells are vented to the atmosphere to expel liquids accumulated in the tubing, a recording... onshore petroleum and natural gas production facilities (including stationary liquid storage not owned or... emissions from onshore production storage tanks using operating conditions in the last wellhead gas-liquid...

Cryo-delivery Systems for the Co-transmission of Chemical and Electrical Power

NASA Astrophysics Data System (ADS)

Grant, Paul M.

2006-04-01

We present a novel concept for the simultaneous transport of chemical power in the form of natural gas or hydrogen in a cryogenic state along with the simultaneous transmission of electrical power over via superconductivity. This concept could impact future efforts to tap and deliver methane from distant geographic resources over conventional pipelines with part of the chemical potential energy converted directly to electricity at the wellhead and the remaining gas cooled cryogenically to increase volumetric density and provide the necessary support of a superconducting cable housed within the same packaging. As the fossil reserve becomes depleted, nuclear power plants would be constructed at the former remote wellhead sites to co-generate electricity and cryocooled hydrogen, the latter replacing natural gas and also serving to operate the already installed superconducting electrical service line.

METHANE EMISSIONS FROM THE NATURAL GAS INDUSTRY VOLUME 13: CHEMICAL INJECTION PUMPS

EPA Science Inventory

The 15-volume report summarizes the results of a comprehensive program to quantify methane (CH4) emissions from the U.S. natural gas industry for the base year. The objective was to determine CH4 emissions from the wellhead and ending downstream at the customer's meter. The accur...

METHANE EMISSIONS FROM THE NATURAL GAS INDUSTRY VOLUME 6: VENTED & COMBUSTION SOURCE SUMMARY

EPA Science Inventory

The 15-volume report summarizes the results of a comprehensive program to quantify methane (CH4) emissions from the U.S. natural gas industry for the base year. The objective was to determine CH4 emissions from the wellhead and ending downstream at the customer's meter. The accur...

METHANE EMISSIONS FROM THE NATURAL GAS INDUSTRY VOLUME 11: COMPRESSOR DRIVER EXHAUST

EPA Science Inventory

The 15-volume report summarizes the results of a comprehensive program to quantify methane (CH4) emissions from the U.S. natural gas industry for the base year. The objective was to determine CH4 emissions from the wellhead and ending downstream at the customer's meter. The accur...

METHANE EMISSIONS FROM THE NATURAL GAS INDUSTRY VOLUME 7: BLOW AND PURGE ACTIVITIES

EPA Science Inventory

The 15-volume report summarizes the results of a comprehensive program to quantify methane (CH4) emissions from the U.S. natural gas industry for the base year. The objective was to determine CH4 emissions from the wellhead and ending downstream at the customer's meter. The accur...

40 CFR 98.236 - Data reporting requirements.

Code of Federal Regulations, 2013 CFR

2013-07-01

... each gas, for all absorbent desiccant dehydrators combined. (5) For well venting for liquids unloading... gas emitted from produced oil sent to atmospheric tanks: (i) For wellhead gas-liquid separator with... atmosphere, expressed in metric tons CO2e for each gas, for all wellhead gas-liquid separators or storage...

40 CFR 98.236 - Data reporting requirements.

Code of Federal Regulations, 2012 CFR

2012-07-01

... each gas, for all absorbent desiccant dehydrators combined. (5) For well venting for liquids unloading... gas emitted from produced oil sent to atmospheric tanks: (i) For wellhead gas-liquid separator with... atmosphere, expressed in metric tons CO2e for each gas, for all wellhead gas-liquid separators or storage...

40 CFR 98.236 - Data reporting requirements.

Code of Federal Regulations, 2014 CFR

2014-07-01

... each gas, for all absorbent desiccant dehydrators combined. (5) For well venting for liquids unloading... gas emitted from produced oil sent to atmospheric tanks: (i) For wellhead gas-liquid separator with... atmosphere, expressed in metric tons CO2e for each gas, for all wellhead gas-liquid separators or storage...

40 CFR Table W - 4 of Subpart W of Part 98-Default Total Hydrocarbon Emission Factors for Underground Natural Gas...

Code of Federal Regulations, 2014 CFR

2014-07-01

... Population Emission Factors—Storage Wellheads, Gas Service Connector 0.01 Valve 0.1 Pressure Relief Valve 0.17 Open Ended Line 0.03 Population Emission Factors—Other Components, Gas Service Low Continuous... Bleed Pneumatic Device Vents 2 2.35 1 Valves include control valves, block valves and regulator valves...

40 CFR Table W - 4 of Subpart W of Part 98-Default Total Hydrocarbon Emission Factors for Underground Natural Gas...

Code of Federal Regulations, 2013 CFR

2013-07-01

... Population Emission Factors—Storage Wellheads, Gas Service Connector 0.01 Valve 0.1 Pressure Relief Valve 0.17 Open Ended Line 0.03 Population Emission Factors—Other Components, Gas Service Low Continuous... Bleed Pneumatic Device Vents 2 2.35 1 Valves include control valves, block valves and regulator valves...

Critique of analyses of natural gas pricing alternatives

DOE Office of Scientific and Technical Information (OSTI.GOV)

Lemon, R.

The Administration has predicted that deregulation would add $210 billion to gas producers' profits over the next eight years; by contrast, a study done for the Natural Gas Supply Committee by Edward Erickson concludes that deregulation would mean a $126 billion savings to consumers over the same period. This article examines the analyses done in the past year by nine organizations. By examining the assumptions and projections of each analysis on wellhead prices, gas supplies, retail gas prices, and alternative energy costs and mixes, an attempt is made to explain divergent projections of the costs of energy under the threemore » alternative natural-gas-pricing scenarios: continuance under FPC's Opinion 770-A; National Energy Plan (NEP); and deregulation of new gas.« less

Simulating the effect of hydrate dissociation on wellhead stability during oil and gas development in deepwater

NASA Astrophysics Data System (ADS)

Li, Qingchao; Cheng, Yuanfang; Zhang, Huaiwen; Yan, Chuanliang; Liu, Yuwen

2018-02-01

It is well known that methane hydrate has been identified as an alternative resource due to its massive reserves and clean property. However, hydrate dissociation during oil and gas development (OGD) process in deep water can affect the stability of subsea equipment and formation. Currently, there is a serious lack of studies over quantitative assessment on the effects of hydrate dissociation on wellhead stability. In order to solve this problem, ABAQUS finite element software was used to develop a model and to evaluate the behavior of wellhead caused by hydrate dissociation. The factors that affect the wellhead stability include dissociation range, depth of hydrate formation and mechanical properties of dissociated hydrate region. Based on these, series of simulations were carried out to determine the wellhead displacement. The results revealed that, continuous dissociation of hydrate in homogeneous and isotropic formations can causes the non-linear increment in vertical displacement of wellhead. The displacement of wellhead showed good agreement with the settlement of overlying formations under the same conditions. In addition, the shallower and thicker hydrate formation can aggravate the influence of hydrate dissociation on the wellhead stability. Further, it was observed that with the declining elastic modulus and Poisson's ratio, the wellhead displacement increases. Hence, these findings not only confirm the effect of hydrate dissociation on the wellhead stability, but also lend support to the actions, such as cooling the drilling fluid, which can reduce the hydrate dissociation range and further make deepwater operations safer and more efficient.

30 CFR 250.1626 - Tubing and wellhead equipment.

Code of Federal Regulations, 2010 CFR

2010-07-01

... 30 Mineral Resources 2 2010-07-01 2010-07-01 false Tubing and wellhead equipment. 250.1626 Section... GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Sulphur Operations § 250.1626 Tubing and wellhead equipment. (a) No tubing string shall be placed into service or continue to be used unless such...

Environmental regulations and energy for home heating

DOE Office of Scientific and Technical Information (OSTI.GOV)

Cohen, A.S.; Fishelson, G.; Gardner, J.L.

1975-01-01

A cost/benefit study of environmental policies supports banning coal as an urban fuel. In an analysis of the Chicago area a coal ban resulted in costs exceeding benefits in only 16 of 172 square miles. In 54 areas benefits were double costs. Benefits include improved air quality, health, and savings on cleaning supplies, and showed no income or racial preferences. As coal use declines, natural gas and oil will increase in demand and price. Two methods for increasing natural gas price would be Federal deregulation of wellhead gas and a fuel policy allowing price increases in response to local shortages.more » (DCK)« less

Radon-222 content of natural gas samples from Upper and Middle Devonian sandstone and shale reservoirs in Pennsylvania—preliminary data

USGS Publications Warehouse

Rowan, E.L.; Kraemer, T.F.

2012-01-01

Samples of natural gas were collected as part of a study of formation water chemistry in oil and gas reservoirs in the Appalachian Basin. Nineteen samples (plus two duplicates) were collected from 11 wells producing gas from Upper Devonian sandstones and the Middle Devonian Marcellus Shale in Pennsylvania. The samples were collected from valves located between the wellhead and the gas-water separator. Analyses of the radon content of the gas indicated 222Rn (radon-222) activities ranging from 1 to 79 picocuries per liter (pCi/L) with an overall median of 37 pCi/L. The radon activities of the Upper Devonian sandstone samples overlap to a large degree with the activities of the Marcellus Shale samples.

US energy industry financial developments, 1993 first quarter

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1993-06-25

Net income for 259 energy companies-- including, 20 major US petroleum companies-- rose 38 percent between the first quarter of 1992 and the first quarter of 1993. An increased level of economic activity, along with colder weather, helped lift the demand for natural gas. crude oil, coal, and electricity. The sharp rise in the domestic price of natural gas at the wellhead relative to the year-ago quarter was the most significant development in US energy during the first quarter. As a consequence of higher natural gas prices, the upstream segment of the petroleum industry reported large gains in income, whilemore » downstream income rose due to higher refined product demand. Increased economic activity and higher weather-related natural gas demand also led to improvements in income for the rate-regulated energy segment. However, declining domestic oil production continued to restrain upstream petroleum industry earnings growth, despite a moderate rise in crude oil prices.« less

Conclusions and Recommendations Regarding the Deep Sea Hybrid Power Systems Initial Study

DTIC Science & Technology

2010-06-01

proton-exchange membrane fuel cells ( PEMFC ) powered with hydrogen and oxygen, similar to that used on proven subsurface vessels; (2) fuel-cells...AND STORAGE OPTIONS CONSIDERED FOR INITIAL STUDY NO. NOMENCLATURE DESCRIPTION 1 PWR Nuclear Reactor + Battery 2 FC1 PEMFC + Line for surface O2...Wellhead Gas + Reformer + Battery 3 FC2 PEMFC + Stored O2 + Wellhead Gas + Reformer + Battery 4 SV1 PEMFC + Submersible Vehicle for O2 Transport

Environmental Impact of Natural Gas Hydrate Production

NASA Astrophysics Data System (ADS)

Max, M. D.; Johnson, A. H.

2017-12-01

Unmet conventional energy demand is encouraging a number of deep energy importing nations closer to production of their potentially very large Natural Gas Hydrate (NGH) resources. As methane and other natural gases are potent greenhouse gases, concerns exist about the possible environmental risks associated NGH development. Accidental of natural gas would have environmental consequences. However, the special characteristics of NGH and production models indicate a very low environmental risk from the reservoir to the deepwater wellhead that is much lower than for conventional deepwater gas. NGH is naturally stable in its solid form in the reservoir and shutting in the gas can be achieved by stopping NGH conversion and gas production in the reservoir. Rapid shut down results in re-crystallization of gas and stabilization of the reservoir through NGH reformation. In addition, new options for innovative technologies have the potential to allow safe development of NGH at a fraction of the current estimated cost. Gas produced from NGH is about the same as processed conventional gas, although almost certainly more pure. Leakage of gas during transport is not a production issue. Gas transport leakage is a matter for best practices regulation that is rigorously enforced.

Study of alternatives to the Natural Gas Policy Act of 1978

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1981-11-01

This report presents the results of the Department of Energy's review of natural gas policies. Its purpose is to define and evaluate alternatives to current policy which deregulate the US natural gas market. The review was initiated in March of 1981 for three reasons. First, natural gas plays a critical role in US energy markets, accounting for 25 percent of US energy use. Second, oil and gas market conditions have changed considerably since current natural gas policies were established in 1978. Indeed, in recognition of these changes, Congress modified national policy on gas use during the budget reconciliation process. Third,more » the Administration is committed to evaluating whether the costs of massive Federal intervention into the operation of markets outweigh the benefits. This study focuses on the wellhead and incremental pricing provisions of the Natural Gas Policy Act of 1978 (NGPA). It seeks to quantify the costs and benefits of alternative natural gas strategies. Specifically, the study evaluates the impacts of proposals to modify the NGPA on: efficiency of natural gas markets; oil import levels and energy security; supply, demand, and price of natural gas; performance of the US economy; and consumer wellbeing. The consequences of current and alternative gas policies under mid-range assumptions about future conditions are presented in Chapters II-V. Substantial uncertainty, however, surrounds the future course of the US natural gas market.« less

Petroleum dynamics in the sea and influence of subsea dispersant injection during Deepwater Horizon.

PubMed

Gros, Jonas; Socolofsky, Scott A; Dissanayake, Anusha L; Jun, Inok; Zhao, Lin; Boufadel, Michel C; Reddy, Christopher M; Arey, J Samuel

2017-09-19

During the Deepwater Horizon disaster, a substantial fraction of the 600,000-900,000 tons of released petroleum liquid and natural gas became entrapped below the sea surface, but the quantity entrapped and the sequestration mechanisms have remained unclear. We modeled the buoyant jet of petroleum liquid droplets, gas bubbles, and entrained seawater, using 279 simulated chemical components, for a representative day (June 8, 2010) of the period after the sunken platform's riser pipe was pared at the wellhead (June 4-July 15). The model predicts that 27% of the released mass of petroleum fluids dissolved into the sea during ascent from the pared wellhead (1,505 m depth) to the sea surface, thereby matching observed volatile organic compound (VOC) emissions to the atmosphere. Based on combined results from model simulation and water column measurements, 24% of released petroleum fluid mass became channeled into a stable deep-water intrusion at 900- to 1,300-m depth, as aqueously dissolved compounds (∼23%) and suspended petroleum liquid microdroplets (∼0.8%). Dispersant injection at the wellhead decreased the median initial diameters of simulated petroleum liquid droplets and gas bubbles by 3.2-fold and 3.4-fold, respectively, which increased dissolution of ascending petroleum fluids by 25%. Faster dissolution increased the simulated flows of water-soluble compounds into biologically sparse deep water by 55%, while decreasing the flows of several harmful compounds into biologically rich surface water. Dispersant injection also decreased the simulated emissions of VOCs to the atmosphere by 28%, including a 2,000-fold decrease in emissions of benzene, which lowered health risks for response workers.

Petroleum dynamics in the sea and influence of subsea dispersant injection during Deepwater Horizon

PubMed Central

Gros, Jonas; Socolofsky, Scott A.; Dissanayake, Anusha L.; Jun, Inok; Zhao, Lin; Boufadel, Michel C.; Reddy, Christopher M.; Arey, J. Samuel

2017-01-01

During the Deepwater Horizon disaster, a substantial fraction of the 600,000–900,000 tons of released petroleum liquid and natural gas became entrapped below the sea surface, but the quantity entrapped and the sequestration mechanisms have remained unclear. We modeled the buoyant jet of petroleum liquid droplets, gas bubbles, and entrained seawater, using 279 simulated chemical components, for a representative day (June 8, 2010) of the period after the sunken platform’s riser pipe was pared at the wellhead (June 4–July 15). The model predicts that 27% of the released mass of petroleum fluids dissolved into the sea during ascent from the pared wellhead (1,505 m depth) to the sea surface, thereby matching observed volatile organic compound (VOC) emissions to the atmosphere. Based on combined results from model simulation and water column measurements, 24% of released petroleum fluid mass became channeled into a stable deep-water intrusion at 900- to 1,300-m depth, as aqueously dissolved compounds (∼23%) and suspended petroleum liquid microdroplets (∼0.8%). Dispersant injection at the wellhead decreased the median initial diameters of simulated petroleum liquid droplets and gas bubbles by 3.2-fold and 3.4-fold, respectively, which increased dissolution of ascending petroleum fluids by 25%. Faster dissolution increased the simulated flows of water-soluble compounds into biologically sparse deep water by 55%, while decreasing the flows of several harmful compounds into biologically rich surface water. Dispersant injection also decreased the simulated emissions of VOCs to the atmosphere by 28%, including a 2,000-fold decrease in emissions of benzene, which lowered health risks for response workers. PMID:28847967

Water Resources and Natural Gas Production from the Marcellus Shale

USGS Publications Warehouse

Soeder, Daniel J.; Kappel, William M.

2009-01-01

The Marcellus Shale is a sedimentary rock formation deposited over 350 million years ago in a shallow inland sea located in the eastern United States where the present-day Appalachian Mountains now stand (de Witt and others, 1993). This shale contains significant quantities of natural gas. New developments in drilling technology, along with higher wellhead prices, have made the Marcellus Shale an important natural gas resource. The Marcellus Shale extends from southern New York across Pennsylvania, and into western Maryland, West Virginia, and eastern Ohio (fig. 1). The production of commercial quantities of gas from this shale requires large volumes of water to drill and hydraulically fracture the rock. This water must be recovered from the well and disposed of before the gas can flow. Concerns about the availability of water supplies needed for gas production, and questions about wastewater disposal have been raised by water-resource agencies and citizens throughout the Marcellus Shale gas development region. This Fact Sheet explains the basics of Marcellus Shale gas production, with the intent of helping the reader better understand the framework of the water-resource questions and concerns.

Modeling the Buildup of Annular Pressure in Cased and Uncased Annuli of Faulty Wellbores

NASA Astrophysics Data System (ADS)

Lackey, G.; Rajaram, H.

2017-12-01

Structurally sound wellbores are essential to oil and gas production, natural gas storage, and carbon dioxide sequestration operations. Wellbore integrity is easily assessed at the wellhead by the presence of pressure or gas flow in the outer annuli of a well, as it indicates the uncontrolled vertical migration of fluids outside the production casing. This phenomenon is typically referred to as sustained casing pressure (SCP), sustained annular pressure, or surface casing vent flow. Of particular concern is the buildup of pressure in the surface casing annulus. If the surface casing is sealed at the wellhead and cement is not brought into the bottom of the casing, annular pressure that builds induces gas migration when the fluid and entry pressure of the formation at the bottom of the surface casing is exceeded. Multiple incidents of stray gas migration from oil and gas operations have contaminated water wells in Colorado, Pennsylvania, and Ohio through this mechanism. Natural gas escaping the #25 Standard Senson well at the Aliso Gas storage facility in California, the largest accidental release of greenhouse gases in US history, also followed this pathway. Previous studies have modeled the buildup of SCP in faulty wells with fully-cased annuli that are isolated from the surrounding formation. However, the majority of onshore oil and gas wells in the US are constructed with uncased outermost annuli that are hydraulically connected to the surrounding subsurface. In this study, we adapt current approaches of modeling SCP to include the regulation of annular liquid level by formation fluid pressure, dissolution of gas into the annular liquids, the transport of aqueous gas by crossflow into deep formations, and gas migration away from the well, when the entry pressure of the formations or fractures along the uncased annulus is exceeded, to compare the buildup behavior of SCP in both uncased and fully-cased annuli. We consider well construction and subsurface geology representative of the Wattenberg Field in Colorado and interpret observations of sustained casing pressure collected by the Colorado Oil and Gas Conservation Commission. We demonstrate that the potential negative consequences of integrity loss are much greater for an uncased well than for fully-cased well.

Modelling and optimization of a wellhead gas flowmeter using concentric pipes

NASA Astrophysics Data System (ADS)

Nec, Yana; Huculak, Greg

2017-09-01

A novel configuration of a landfill wellhead was analysed to measure the flow rate of gas extracted from sanitary landfills. The device provides access points for pressure measurement integral to flow rate computation similarly to orifice and Venturi meters, and has the advantage of eliminating the problem of water condensation often impairing the accuracy thereof. It is proved that the proposed configuration entails comparable computational complexity and negligible sensitivity to geometric parameters. Calibration for the new device was attained using a custom optimization procedure, operating on a quadri-dimensional parameter surface evincing discontinuity and non-smoothness.

Impact of exploratory offshore drilling on benthic communities in the Minerva gas field, Port Campbell, Australia.

PubMed

Currie, D R; Isaacs, Leanne R

2005-04-01

Changes to benthic infauna caused by exploratory gas drilling operations in the Minerva field were examined experimentally using a BACI (before, after, control, impact) design. Analysis of 72 x 0.1 m2 Smith-McIntyre grab samples obtained from one pre-drilling and three post-drilling periods yielded a diverse fauna consisting of 196 invertebrate species and 5035 individuals. Changes to benthic community structure were assessed using ANOVA and nonmetric multidimensional scaling (MDS). The abundances of two common species (Apseudes sp. 1 and Prionospio coorilla) decreased significantly at the well-head site immediately after drilling. The size of these reductions in abundance ranged between 71% and 88%, and persisted for less than 4 months after drilling. A third common species (Katlysia sp. 1) increased in abundance 200 m east of the well-head following drilling. Most species occurred at densities too low to be analysed individually and so were pooled at higher taxonomic levels. Changes in the abundance of species aggregated by phylum varied, but significant declines in the most abundant phyla (Crustaceans and Polychaetes) of 45-73% were observed at all sites within a 100 m radius of the well-head following drilling. In most cases these changes became undetectable four months after drilling following species recruitments. MDS ordinations confirm that drilling related changes to benthic community structure are most pronounced at stations located closest to the well-head. Additionally, the ordinations indicate that modified communities persist at the well-head for more than 11 months following exploratory drilling.

Appraisal of transport and deformation in shale reservoirs using natural noble gas tracers

DOE Office of Scientific and Technical Information (OSTI.GOV)

Heath, Jason E.; Kuhlman, Kristopher L.; Robinson, David G.

2015-09-01

This report presents efforts to develop the use of in situ naturally-occurring noble gas tracers to evaluate transport mechanisms and deformation in shale hydrocarbon reservoirs. Noble gases are promising as shale reservoir diagnostic tools due to their sensitivity of transport to: shale pore structure; phase partitioning between groundwater, liquid, and gaseous hydrocarbons; and deformation from hydraulic fracturing. Approximately 1.5-year time-series of wellhead fluid samples were collected from two hydraulically-fractured wells. The noble gas compositions and isotopes suggest a strong signature of atmospheric contribution to the noble gases that mix with deep, old reservoir fluids. Complex mixing and transport of fracturingmore » fluid and reservoir fluids occurs during production. Real-time laboratory measurements were performed on triaxially-deforming shale samples to link deformation behavior, transport, and gas tracer signatures. Finally, we present improved methods for production forecasts that borrow statistical strength from production data of nearby wells to reduce uncertainty in the forecasts.« less

The Value of Renewable Energy as a Hedge Against Fuel Price Risk: Analytic Contributions from Economic and Finance Theory

DOE Office of Scientific and Technical Information (OSTI.GOV)

Bolinger, Mark A; Wiser, Ryan

2008-09-15

For better or worse, natural gas has become the fuel of choice for new power plants being built across the United States. According to the Energy Information Administration (EIA), natural gas-fired units account for nearly 90% of the total generating capacity added in the U.S. between 1999 and 2005 (EIA 2006b), bringing the nationwide market share of gas-fired generation to 19%. Looking ahead over the next decade, the EIA expects this trend to continue, increasing the market share of gas-fired generation to 22% by 2015 (EIA 2007a). Though these numbers are specific to the US, natural gas-fired generation is makingmore » similar advances in many other countries as well. A large percentage of the total cost of gas-fired generation is attributable to fuel costs--i.e., natural gas prices. For example, at current spot prices of around $7/MMBtu, fuel costs account for more than 75% of the levelized cost of energy from a new combined cycle gas turbine, and more than 90% of its operating costs (EIA 2007a). Furthermore, given that gas-fired plants are often the marginal supply units that set the market-clearing price for all generators in a competitive wholesale market, there is a direct link between natural gas prices and wholesale electricity prices. In this light, the dramatic increase in natural gas prices since the 1990s should be a cause for ratepayer concern. Figure 1 shows the daily price history of the 'first-nearby' (i.e., closest to expiration) NYMEX natural gas futures contract (black line) at Henry Hub, along with the futures strip (i.e., the full series of futures contracts) from August 22, 2007 (red line). First, nearby prices, which closely track spot prices, have recently been trading within a $7-9/MMBtu range in the United States and, as shown by the futures strip, are expected to remain there through 2012. These price levels are $6/MMBtu higher than the $1-3/MMBtu range seen throughout most of the 1990s, demonstrating significant price escalation for natural gas in the United States over a relatively brief period. Perhaps of most concern is that this dramatic price increase was largely unforeseen. Figure 2 compares the EIA's natural gas wellhead price forecast from each year's Annual Energy Outlook (AEO) going back to 1985 against the average US wellhead price that actually transpired. As shown, our forecasting abilities have proven rather dismal over time, as over-forecasts made in the late 1980's eventually yielded to under-forecasts that have persisted to this day. This historical experience demonstrates that little weight should be placed on any one forecast of future natural gas prices, and that a broad range of future price conditions ought to be considered in planning and investment decisions. Against this backdrop of high, volatile, and unpredictable natural gas prices, increasing the market penetration of renewable generation such as wind, solar, and geothermal power may provide economic benefits to ratepayers by displacing gas-fired generation. These benefits may manifest themselves in several ways. First, the displacement of natural gas-fired generation by increased renewable generation reduces ratepayer exposure to natural gas price risk--i.e., the risk that future gas prices (and by extension future electricity prices) may end up markedly different than expected. Second, this displacement reduces demand for natural gas among gas-fired generators, which, all else equal, will put downward pressure on natural gas prices. Lower natural gas prices in turn benefit both electric ratepayers and other end-users of natural gas. Using analytic approaches that build upon, yet differ from, the past work of others, including Awerbuch (1993, 1994, 2003), Kahn and Stoft (1993), and Humphreys and McClain (1998), this chapter explores each of these two potential 'hedging' benefits of renewable electricity. Though we do not seek to judge whether these two specific benefits outweigh any incremental cost of renewable energy (relative to conventional fuels), we do seek to quantify the magnitude of these two individual benefits. We also note that these benefits are not unique to renewable electricity: other generation (or demand-side) resources whose costs are not tied to natural gas would provide similar benefits.« less

Effect of Inlet and Outlet Flow Conditions on Natural Gas Parameters in Supersonic Separation Process

PubMed Central

Yang, Yan; Wen, Chuang; Wang, Shuli; Feng, Yuqing

2014-01-01

A supersonic separator has been introduced to remove water vapour from natural gas. The mechanisms of the upstream and downstream influences are not well understood for various flow conditions from the wellhead and the back pipelines. We used a computational model to investigate the effect of the inlet and outlet flow conditions on the supersonic separation process. We found that the shock wave was sensitive to the inlet or back pressure compared to the inlet temperature. The shock position shifted forward with a higher inlet or back pressure. It indicated that an increasing inlet pressure declined the pressure recovery capacity. Furthermore, the shock wave moved out of the diffuser when the ratio of the back pressure to the inlet one was greater than 0.75, in which the state of the low pressure and temperature was destroyed, resulting in the re-evaporation of the condensed liquids. Natural gas would be the subsonic flows in the whole supersonic separator, if the mass flow rate was less than the design value, and it could not reach the low pressure and temperature for the condensation and separation of the water vapor. These results suggested a guidance mechanism for natural gas supersonic separation in various flow conditions. PMID:25338207

40 CFR 60.756 - Monitoring of operations.

Code of Federal Regulations, 2010 CFR

2010-07-01

... owner or operator seeking to comply with § 60.752(b)(2)(ii)(A) for an active gas collection system shall... temperature measurements at each wellhead and: (1) Measure the gauge pressure in the gas collection header on... the landfill gas on a monthly basis as provided in § 60.755(a)(5); and (3) Monitor temperature of the...

40 CFR 60.756 - Monitoring of operations.

Code of Federal Regulations, 2011 CFR

2011-07-01

... owner or operator seeking to comply with § 60.752(b)(2)(ii)(A) for an active gas collection system shall... temperature measurements at each wellhead and: (1) Measure the gauge pressure in the gas collection header on... the landfill gas on a monthly basis as provided in § 60.755(a)(5); and (3) Monitor temperature of the...

30 CFR 250.433 - What are the diverter actuation and testing requirements?

Code of Federal Regulations, 2012 CFR

2012-07-01

..., DEPARTMENT OF THE INTERIOR OFFSHORE OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Oil and Gas Drilling Operations Diverter System Requirements § 250.433 What are the diverter actuation and.... (a) For drilling operations with a surface wellhead configuration, you must actuate the diverter...

30 CFR 250.431 - What are the diverter design and installation requirements?

Code of Federal Regulations, 2011 CFR

2011-07-01

... ENFORCEMENT, DEPARTMENT OF THE INTERIOR OFFSHORE OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Oil and Gas Drilling Operations Diverter System Requirements § 250.431 What are the diverter... wellhead configurations and at least 12 inches for floating drilling operations; (b) Use dual diverter...

30 CFR 250.433 - What are the diverter actuation and testing requirements?

Code of Federal Regulations, 2011 CFR

2011-07-01

... ENFORCEMENT, DEPARTMENT OF THE INTERIOR OFFSHORE OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Oil and Gas Drilling Operations Diverter System Requirements § 250.433 What are the diverter...-test the vent lines. (a) For drilling operations with a surface wellhead configuration, you must...

30 CFR 250.433 - What are the diverter actuation and testing requirements?

Code of Federal Regulations, 2014 CFR

2014-07-01

..., DEPARTMENT OF THE INTERIOR OFFSHORE OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Oil and Gas Drilling Operations Diverter System Requirements § 250.433 What are the diverter actuation and.... (a) For drilling operations with a surface wellhead configuration, you must actuate the diverter...

30 CFR 250.433 - What are the diverter actuation and testing requirements?

Code of Federal Regulations, 2013 CFR

2013-07-01

..., DEPARTMENT OF THE INTERIOR OFFSHORE OIL AND GAS AND SULPHUR OPERATIONS IN THE OUTER CONTINENTAL SHELF Oil and Gas Drilling Operations Diverter System Requirements § 250.433 What are the diverter actuation and.... (a) For drilling operations with a surface wellhead configuration, you must actuate the diverter...

Regulation, competition in natural gas industry

DOE Office of Scientific and Technical Information (OSTI.GOV)

O`Neill, R.P.; Whitmore, C.S.

1995-08-01

Conventional regulatory and rate-making tools are not adequate to deal with today`s natural-gas market, according to Richard P. O`Neill and Charles S. Whitmore of the Federal Energy Regulatory Commission in Washington, D.C. {open_quotes}Competitive market forces can substitute for many activities that traditionally have been regulated,{close_quotes} say O`Neill and Whitmore. {open_quotes}However, market-based solutions are only effective if traditional regulations is replaced by institutions that foster competition.{close_quotes} The transition to the era of open access to the transmission network, and thus to wellhead competition, started in the mid-1980s. More recently, change has also occurred in the industry`s communication and control activities. Pipelinesmore » now make more use of electronic communication and control, which will spread into pricing and capacity-release markets. Current trends and new policies for greater gas use make forecasting as difficult now as it has been for the past 20 years. O`Neill and Whitmore conclude that development of efficient institutions, therefore, should be the most important task of regulatory bodies.« less

Convergence of natural gas and electricity industries means change, opportunity for producers in the U. S

DOE Office of Scientific and Technical Information (OSTI.GOV)

Dar, V.K.

1995-03-13

The accelerating deregulation of natural gas and electricity distribution is the third and most powerful wave of energy deregulation coursing through North America. The first wave (1978--92) provided the impetus for sculpting competitive markets in energy production. The second (1986--95) is now breaking to fashion competitive bulk logistical and wholesale consumption markets through open access on and unbundling of gas pipeline and storage capacity and high voltage transmission capacity. The third wave, the deregulation of gas and electric retail markets through open access and nondiscriminatory, unbundled local gas and electric distribution tariffs, began in the early 1990s. It will gathermore » momentum for the next 5 years and crest at the turn of the century, affecting and molding almost $300 billion/year in retail energy sales. The transformation will have these strategic implications: (1) the convergent evolution of the gas and electric industries; (2) severe margin compression along the energy value chain from wellhead to busbar to the distribution pipes and wires; and (3) the rapid emergency of cyberspace retailing of energy products and services. The paper discusses merchant plants, convergence and producers, capital flows, producer federations, issues of scale, and demand, margins, and value.« less

NORM Management in the Oil & Gas Industry

NASA Astrophysics Data System (ADS)

Cowie, Michael; Mously, Khalid; Fageeha, Osama; Nassar, Rafat

2008-08-01

It has been established that Naturally Occurring Radioactive Materials (NORM) accumulates at various locations along the oil/gas production process. Components such as wellheads, separation vessels, pumps, and other processing equipment can become NORM contaminated, and NORM can accumulate in sludge and other waste media. Improper handling and disposal of NORM contaminated equipment and waste can create a potential radiation hazard to workers and the environment. Saudi Aramco Environmental Protection Department initiated a program to identify the extent, form and level of NORM contamination associated with the company operations. Once identified the challenge of managing operations which had a NORM hazard was addressed in a manner that gave due consideration to workers and environmental protection as well as operations' efficiency and productivity. The benefits of shared knowledge, practice and experience across the oil & gas industry are seen as key to the establishment of common guidance on NORM management. This paper outlines Saudi Aramco's experience in the development of a NORM management strategy and its goals of establishing common guidance throughout the oil and gas industry.

Geopressured-geothermal test of the EDNA Delcambre No. 1 well, Tigre Lagoon Field, Vermilion Parish, Louisiana: analysis of water an dissolved natural gas. Final report

DOE Office of Scientific and Technical Information (OSTI.GOV)

Hankins, B.E.; Karkalits, O.C.

1978-09-01

The Edna Delcambre et al. No. 1 gas well, shut-in since June 1975, was made available for the project. Two geopressured sand-bed aquifers were tested: sand No. 3 at a depth of 12,900 feet and sand No. 1 at a depth of 12,600 feet. Each aquifer was subjected to flow tests which lasted approximately three weeks in each case. Water samples were obtained during flow testing of the two geopressured aquifers. The water contained 11.3 to 13.3% dissolved solids. Several radioactive species were measured. Radium-226 was found to be approximately 10 times more concentrated than the average amount observed inmore » surface waters. No appreciable amount of heavy metals was detected. Recombination studies at bottom-hole conditions indicate the solubility of natural gas per barrel of water to be about 24 SCF. The methane content was 93 to 95%, and the gas had a heating value in the range of 1020 to 1070 Btu/cu.ft. During the flow tests, the gas/water ratio at the well-head was observed to be 45 to 88 SCF/Bbl water produced. (MHR)« less

Designing and implementing science-based methane policies

NASA Astrophysics Data System (ADS)

George, F.

2017-12-01

The phenomenal growth in shale gas production across the U.S. has significantly improved the energy security and economic prospects of the country. Natural gas is a "versatile" fuel that has application in every major end-use sector of the economy, both as a fuel and a feedstock. Natural gas has also played a significant role in reducing CO2 emissions from the power sector by displacing more carbon intensive fossil fuels. However, emissions of natural gas (predominantly methane) from the wellhead to the burner tip can erode this environmental benefit. Preserving the many benefits of America's natural gas resources requires smart, science-based policies to optimize the energy delivery efficiency of the natural gas supply chain and ensure that natural gas remains a key pillar in our transition to a low-carbon economy. Southwestern Energy (SWN) is the third largest natural gas producer in the United States. Over the last several years, SWN has participated in a number of scientific studies with regulatory agencies, academia and non-governmental entities that have led to over a dozen peer-reviewed papers on methane emissions from oil and gas operations. This presentation will review how our participation in these studies has informed our internal policies and procedures, as well as our external programs, including the ONE Future coalition (ONE Future). In particular, the presentation will highlight the impact of such studies on our Leak Detection and Repair (LDAR) program, designing new methane research and on the ONE Future initiatives - all with the focus of improving the delivery efficiency of oil and gas operations. Our experience supports continued research in the detection and mitigation of methane emissions, with emphasis on longer duration characterization of methane emissions from oil and gas facilities and further development of cost-effective methane detection and mitigation techniques. We conclude from our scientific and operational experiences that a performance-based methane mitigation policy like the ONE Future will lead to more operationally efficient and cost-effective reductions in methane emissions from the natural gas supply chain.

Wellhead with non-ferromagnetic materials

DOEpatents

Hinson, Richard A [Houston, TX; Vinegar, Harold J [Bellaire, TX

2009-05-19

Wellheads for coupling to a heater located in a wellbore in a subsurface formation are described herein. At least one wellhead may include a heater located in a wellbore in a subsurface formation; and a wellhead coupled to the heater. The wellhead may be configured to electrically couple the heater to one or more surface electrical components. The wellhead may include at least one non-ferromagnetic material such that ferromagnetic effects are inhibited in the wellhead. Systems and methods for using such wellheads for treating a subsurface formation are described herein.

Digital representation of oil and natural gas well pad scars in southwest Wyoming: 2012 update

USGS Publications Warehouse

Garman, Steven L.; McBeth, Jamie L.

2015-01-01

The recent proliferation of oil and natural gas energy development in the Greater Green River Basin of southwest Wyoming has accentuated the need to understand wildlife responses to this development. The location and extent of surface disturbance that is created by oil and natural gas well pad scars are key pieces of information used to assess the effects of energy infrastructure on wildlife populations and habitat. A digital database of oil and natural gas pad scars had previously been generated from 1-meter (m) National Agriculture Imagery Program imagery (NAIP) acquired in 2009 for a 7.7-million hectare (ha) (19,026,700 acres) region of southwest Wyoming. Scars included the pad area where wellheads, pumps, and storage facilities reside and the surrounding area that was scraped and denuded of vegetation during the establishment of the pad. Scars containing tanks, compressors, the storage of oil and gas related equipment, and produced-water ponds were also collected on occasion. This report updates the digital database for the five counties of southwest Wyoming (Carbon, Lincoln, Sublette, Sweetwater, Uinta) within the Wyoming Landscape Conservation Initiative (WLCI) study area and for a limited portion of Fremont, Natrona, and Albany Counties using 2012 1-m NAIP imagery and 2012 oil and natural gas well permit information. This report adds pad scars created since 2009, and updates attributes of all pad scars using the 2012 well permit information. These attributes include the origination year of the pad scar, the number of active and inactive wells on or near each pad scar in 2012, and the overall status of the pad scar (active or inactive). The new 2012 database contains 17,404 pad scars of which 15,532 are attributed as oil and natural gas well pads. Digital data are stored as shapefiles projected to the Universal Transverse Mercator (zones 12 and 13) coordinate system. These data are available from the U.S. Geological Survey (USGS) at http://dx.doi.org/10.3133/ds934.

NORM management in the oil and gas industry.

PubMed

Cowie, M; Mously, K; Fageeha, O; Nassar, R

2012-01-01

It has been established that naturally occurring radioactive material (NORM) may accumulate at various locations along the oil and gas production process. Components such as wellheads, separation vessels, pumps, and other processing equipment can become contaminated with NORM, and NORM can accumulate in the form of sludge, scale, scrapings, and other waste media. This can create a potential radiation hazard to workers, the general public, and the environment if certain controls are not established. Saudi Aramco has developed NORM management guidelines, and is implementing a comprehensive strategy to address all aspects of NORM management that aim to enhance NORM monitoring; control of NORM-contaminated equipment; control of NORM waste handling and disposal; and protection, awareness, and training of workers. The benefits of shared knowledge, best practice, and experience across the oil and gas industry are seen as key to the establishment of common guidance. This paper outlines Saudi Aramco's experience in the development of a NORM management strategy, and its goals of establishing common guidance throughout the oil and gas industry. Copyright © 2012. Published by Elsevier Ltd.

Lightweight Approaches to Natural Gas Hydrate Exploration & Production

NASA Astrophysics Data System (ADS)

Max, M. D.; Johnson, A. H.

2017-12-01

Lower-cost approaches to drilling and reservoir utilization are made possible by adapting both emerging and new technology to the unique, low risk NGH natural gas resource. We have focused on drilling, wellbore lining technology, and reservoir management with an emphasis on long-term sand control and adaptive mechanical stability during NGH conversion to its constituent gas and water. In addition, we suggest that there are opportunities for management of both the gas and water with respect to maintaining desired thermal conditions. Some of the unique aspects of NGH deposits allow for new, more efficient technology to be applied to development, particularly in drilling. While NGH-bearing sands are in deepwater, they are confined to depths beneath the seafloor of 1.2 kilometers or less. As a result, they will not be significantly above hydrostatic pressure, and temperatures will be less than 30 oC. Drilling will be through semi-consolidated sediment without liquid hydrocarbons. These characteristics mean that high capability drillships are not needed. What is needed is a new perspective about drilling and producing NGH. Drilling from the seafloor will resolve the high-pressure differential between a wellhead on the sea surface in a vessel and reservoir to about the hydrostatic pressure difference between the seafloor and, at most, the base of the GHSZ. Although NGH production will begin using "off-the-shelf" technology, innovation will lead to new technology that will bring down costs and increase efficiency in the same way that led to the shale breakthrough. Commercial success is possible if consideration is given to what is actually needed to produce NGH in a safe and environmentally manner. Max, M.D. 2017. Wellbore Lining for Natural Gas Hydrate. U.S. Patent Application US15644947 Max, M.D. & Johnson, A.H. 2017. E&P Cost Reduction Opportunities for Natural Gas Hydrate. OilPro. . Max, M.D. & Johnson, A.H. 2016. Exploration and Production of Oceanic Natural Gas Hydrate: Critical Factors for Commercialization. Springer International Publishing AG, 405pp.

GROUND WATER AND WELLHEAD PROTECTION

EPA Science Inventory

This document is for those responsible for delineating the boundaries of a wellhead protection area, identifying and evaluating potential contaminants, and identifying wellhead management options. t is divided into two parts: (1) Wellhead Protection Area (WHPA) Delineation and (2...

Footprint of Deepwater Horizon blowout impact to deep-water coral communities

PubMed Central

Fisher, Charles R.; Hsing, Pen-Yuan; Kaiser, Carl L.; Yoerger, Dana R.; Roberts, Harry H.; Shedd, William W.; Cordes, Erik E.; Shank, Timothy M.; Berlet, Samantha P.; Saunders, Miles G.; Larcom, Elizabeth A.; Brooks, James M.

2014-01-01

On April 20, 2010, the Deepwater Horizon (DWH) blowout occurred, releasing more oil than any accidental spill in history. Oil release continued for 87 d and much of the oil and gas remained in, or returned to, the deep sea. A coral community significantly impacted by the spill was discovered in late 2010 at 1,370 m depth. Here we describe the discovery of five previously unknown coral communities near the Macondo wellhead and show that at least two additional coral communities were impacted by the spill. Although the oil-containing flocullent material that was present on corals when the first impacted community was discovered was largely gone, a characteristic patchy covering of hydrozoans on dead portions of the skeleton allowed recognition of impacted colonies at the more recently discovered sites. One of these communities was 6 km south of the Macondo wellhead and over 90% of the corals present showed the characteristic signs of recent impact. The other community, 22 km southeast of the wellhead between 1,850 and 1,950 m depth, was more lightly impacted. However, the discovery of this site considerably extends the distance from Macondo and depth range of significant impact to benthic macrofaunal communities. We also show that most known deep-water coral communities in the Gulf of Mexico do not appear to have been acutely impacted by the spill, although two of the newly discovered communities near the wellhead apparently not impacted by the spill have been impacted by deep-sea fishing operations. PMID:25071200

APPARENT 85KRYPTON AGES OF GROUNDWATER WITHIN THE ROYAL WATERSHED, MAINE, USA

EPA Science Inventory

⁸⁵Kr activities were determined in 264 domestic and municipal wells from 2002-2004 in the Royal watershed (361 km²), Maine. Gas extraction for ⁸⁵Kr from wells was effected directly via a well-head methodology permitting efficient widespread analys...

Digital representation of oil and natural gas well pad scars in southwest Wyoming

USGS Publications Warehouse

Garman, Steven L.; McBeth, Jamie L.

2014-01-01

The recent proliferation of oil and natural gas energy development in southwest Wyoming has stimulated the need to understand wildlife responses to this development. Central to many wildlife assessments is the use of geospatial methods that rely on digital representation of energy infrastructure. Surface disturbance of the well pad scars associated with oil and natural gas extraction has been an important but unavailable infrastructure layer. To provide a digital baseline of this surface disturbance, we extracted visible oil and gas well pad scars from 1-meter National Agriculture Imagery Program imagery (NAIP) acquired in 2009 for a 7.7 million-hectare region of southwest Wyoming. Scars include the pad area where wellheads, pumps, and storage facilities reside, and the surrounding area that was scraped and denuded of vegetation during the establishment of the pad. Scars containing tanks, compressors, and the storage of oil and gas related equipment, and produced-water ponds were also collected on occasion. Our extraction method was a two-step process starting with automated extraction followed by manual inspection and clean up. We used available well-point information to guide manual clean up and to derive estimates of year of origin and duration of activity on a pad scar. We also derived estimates of the proportion of non-vegetated area on a scar using a Normalized Difference Vegetation Index derived using 1-meter NAIP imagery. We extracted 16,973 pad scars of which 15,318 were oil and gas well pads. Digital representation of pad scars along with time-stamps of activity and estimates of non-vegetated area provides important baseline (circa 2009) data for assessments of wildlife responses, land-use trends, and disturbance-mediated pattern assessments.

High-pressure jet cutters improve capping operations

DOE Office of Scientific and Technical Information (OSTI.GOV)

Abel, L.W.; Campbell, P.J.; Bowden, J.R. Sr.

1995-05-08

Advances in abrasive cutting technology have improved the methods for removing damaged equipment and preparing wellheads for capping. This technology, much of which was refined during well control operations in Kuwait in 1991, can improve the safety and efficiency of capping jobs by cutting wellheads or casing quickly and cleanly. The majority of well control jobs involve one of three types of capping operations: capping to a flange, capping by installing a wellhead, or capping to a casing stub. Capping operations are often the first major step in regaining control of the well during blowout intervention. Proper planning of amore » capping operation must take into account the mass flow rate, combustible nature of the flow, well bore geometry, and operations in the post-capping phase of the project. The paper discusses capping vehicles, tree removal, jet cutters, capping to a flange, capping to a stub, swallowing the stub, spin-on technique, capping on fire, stinging, offshore blowouts, firefighting, pollution control, intervention equipment, and rig removal.« less

Wellhead treatment costs for groundwater contaminated with pesticides: A preliminary analysis for pineapple in Hawaii

NASA Astrophysics Data System (ADS)

Leon-Guerrero, Ephraim D.; Loague, Keith; Green, Richard E.

1994-01-01

In Hawaii, trace concentrations of pesticides used in the production of pineapple were found in the groundwater supplies of Mililani Town in the Pearl Harbor Basin on the island of Oahu. Groundwater serves as the major source of drinking water and residents pay for wellhead treatment of the contaminated water, via their monthly water bill. The agricultural chemical users within the Pearl Harbor Basin do not include these wellhead treatment costs in their production costs. The agricultural industry benefits from using pesticides but does not pay the entire societal cost of using these chemicals. In this study we evaluate the specific financial cost of wellhead treatment, and not the economic value of groundwater. While wellhead treatment costs could conceivably be shared by several parties, this study focuses on the financial impact of the pineapple industry alone. This study factors annual wellhead treatment costs into annual pineapple production costs to measure the effect on annual financial return from pineapple production. Wellhead treatment costs are calculated from the existing granulated activated carbon (GAC) water treatment facility for Millilani Wells I and II. Pineapple production costs are estimated from previous cost of production studies. The inclusion of wellhead treatment costs produces different production-cost results, depending on the scale of analysis. At the local scale, the Mililani wellhead treatment costs can be factored into the production costs of the pineapple fields, which were probably responsible for contamination of the Mililani Wells, without causing a deficit in economic return. At the larger regional scale, however, the return from all of the pineapple grown in the Pearl Harbor Basin can not sustain the cost of wellhead treatmentfor the entire water supply of the basin. Recommendations point to the prevention of groundwater contamination as more cost-effective measure than wellhead treatment.

Preliminary Results from Downhole Osmotic Samplers in a Gas Tracer Injection Experiment in the Upper Oceanic Crust on the Eastern Flank of the Juan de Fuca Ridge.

NASA Astrophysics Data System (ADS)

de Jong, M. T.; Clark, J. F.; Neira, N. M.; Fisher, A. T.; Wheat, C. G.

2015-12-01

We present results from a gas tracer injection experiment in the ocean crust on the eastern flank of the Juan de Fuca Ridge, in an area of hydrothermal circulation. Sulfur hexafluoride (SF6) tracer was injected in Hole 1362B in 2010, during IODP Expedition 327. Fluid samples were subsequently collected from a borehole observatory (CORK) installed in this hole and similar CORKs in three additional holes (1026B, 1362A, and 1301A), located 300 to 500 m away. This array of holes is located on 3.5 My old seafloor, as an array oriented subparallel to the Endeavor Segment of Juan de Fuca Ridge. Borehole fluid samples were collected in copper coils using osmotic pumps. In addition to pumps at seafloor wellheads, downhole sampling pumps were installed in the perforated casing in the upper ocean crust. These downhole samplers were intended to produce a high-resolution continuous record of tracer concentrations, including records from the first year after tracer injection in Holes 1362A and 1362B. In contrast, wellhead samplers were not installed on these CORKs holes until 2011, and wellhead records from all CORKs have a record gap of up to one year, because of a delayed expedition in 2012. The downhole samples were recovered with the submersible Alvin in August 2014. SF6 concentrations in downhole samples recovered in 2014 are generally consistent with data obtained from wellhead samples. Of particular interest are the results from Hole 1362B, where a seafloor valve was opened and closed during various recovery expeditions. High resolution tracer curves produced from the 1362B downhole samples confirm that these operations produced an SF6 breakthrough curve corresponding to a classic push-pull test used to evaluate contaminant field locations in terrestrial setting. Complete analyses of downhole samples from these CORKs are expected to produce high-resolution breakthrough curves that will allow more precise analysis and modeling of hydrothermal flow in the study area.

Out of gas: Tenneco in the era of natural gas regulation, 1938--1978

NASA Astrophysics Data System (ADS)

Raley, David

2011-12-01

Federal regulation over the natural gas industry spanned 1938--1978, during which time both the industry and the nature of the regulation changed. The original intent of the law was to reform an industry stagnating because of the Depression, but regulation soon evolved into a public-private partnership to win World War II, then to a framework for the creation and management of a nationwide natural gas grid in the prosperous post-war years, and finally to a confused and chaotic system of wellhead price regulation which produced shortages and discouraged new production during the 1950s and 1960s. By the 1970s, regulation had become ineffective, leading to deregulation in 1978. The natural gas industry operated under the oversight of the Federal Power Commission (FPC) which set gas rates, regulated profits and competition, and established rules for entry and exit into markets. Over the course of four decades, the FPC oversaw the development of a truly national industry built around a system of large diameter pipelines. Tennessee Gas Transmission Company (later Tenneco) was an integral part of this industry. At first, Tenneco prospered under regulation. Regulation provided Tenneco with the means to build its first pipeline and a secure revenue stream for decades. A series of conflicts with the FPC and the difficulties imposed by the Phillips vs. Wisconsin case in 1954 soon interfered with the ambitious long-term goals of Tenneco CEO and president Gardiner Symonds. Tenneco first diversified into unregulated businesses in the 1940s, which accelerated as regulatory changes constrained the company's growth. By the 1960s the company was at the forefront of the conglomeration movement, when Tenneco included a variety of disparate businesses, including oil and gas production, chemicals, consumer packaging, manufacturing, shipbuilding, and food production, among others. Gas transmission became a minority interest in Tenneco's portfolio as newer and larger divisions overshadowed its former core business. The 1970s brought a renewed interest in natural gas and other energy resources as the nation faced chronic energy shortages. As the FPC loosened its low rate policy in the early 1970s to encourage production, Tenneco once again invested heavily in new pipelines and gas exploration, as well as more speculative ventures in Arctic gas, liquefied natural gas, synthetic fuels, and nuclear energy. By 1978, growing public and political support led to deregulation of natural gas, plunging Tenneco into a new era where market forces, not FPC oversight, impacted the gas industry. The deregulation of natural gas in 1978 removed the guaranteed rate of return from Tenneco's bottom line and exposed the weakness of Tenneco's conglomeration---the profitable pipeline had long been used to prop-up weaker businesses. The 1980s and 1990s were characterized by a gradual dissolution of Tenneco.

DOE Office of Scientific and Technical Information (OSTI.GOV)

Crawford, E.

Higher wellhead prices are not expected to bring on a significant increase in supplies of oil and natural gas from new outer continental shelf (OCS) reservoirs between now and 1982. Between 1982 and 1987, however, the situation should change: if 1987 prices range from $7.50 to $25 per barrel, supplies are expected to increase from two to 3.5 million barrels per day, respectively. These results from an Arthur D. Little Co. study are based on the assumption of continued OCS leasing and development, although uncertainties remain about the extent of recoverable reserves. For example, no indications of commercial hydrocarbons havemore » been found in the Gulf of Alaska for the three wells dug so far. In general a price of $20 per barrel is needed to make the risky exploration worthwhile for oil companies. (DCK)« less

Assessment of choke valve erosion in a high-pressure, high-temperature gas condensate well using TLA

DOE Office of Scientific and Technical Information (OSTI.GOV)

Birchenough, P.M.; Cornally, D.; Dawson, S.G.B.

1994-12-31

Many planned new developments in the North Sea will involve the exploitation of hostile high pressure, high temperature gas condensate reserves. The extremely high pressure letdown over the wellhead choke leads to very high flow velocities, and consequent risks of erosion damage occurring to the choke internals. In a recent study, measurements of erosion have been performed during an offshore well test under flowing conditions using advanced Thin Layer Activation techniques and scaled Laboratory tests.

Federal policies affecting the wellhead value of Prudhoe Bay crude oil. A report to the Alaska legislative council's subcommittee on oil and gas leasing and taxing policies, ninth Alaska state legislature

DOE Office of Scientific and Technical Information (OSTI.GOV)

Tussing, A.

1977-03-28

Markets for North Slope crude; FEA price ceilings and Prudhoe Bay crude oil prices; entitlements treatment of North Slope crude; and the question of exports and the long term oil supply picture are covered.

Hydraulic stimulation or low water injection in fractured reservoir of the geothermal well GRT-1 at Rittershoffen (France)?

NASA Astrophysics Data System (ADS)

Vidal, J.; Genter, A.; Schmittbuhl, J.; Baujard, C.

2016-12-01

In the Upper Rhine Graben, several deep geothermal projects, such as at Soultz-sous-Forêts (France) or Basel (Switzerland), were based on the Enhanced Geothermal System technology. The principle underlying this technology consists of increasing the low initial natural hydraulic performance of pre-existing natural fractures in the geothermal granitic reservoir via hydraulic and/or chemical stimulations. Hydraulic stimulation consists of injection of a large amount of water at a high flow rate to promote hydroshearing of pre-existing fractures. At Soultz-sous-Forêts and Basel, the maximum wellhead pressures were 16 MPa and 30 MPa respectively which induced larger magnitude seismic events of 2.9 and 3.4 respectively. Those specific induced seismicity events were felt by local population. At Rittershoffen (France), the geothermal well GRT-1 was drilled in 2012 down to a depth of 2.6 km and penetrates fractured sandstones and granite. The reservoir temperature reaches more than 160°C but the production flowrate was too low for an industrial project economically viable. Thus, the well was subjected to Thermal, Chemical and Hydraulic stimulations, which improved the injectivity index five-fold. During the hydraulic operation, a moderate volume of water was injected from the wellhead with a low pressure of 3 MPa. Approximately 300 microseismic events were detected during the hydraulic stimulations. Due to the low wellhead pressure during injection, no events were felt by nearby residents. The goal of the study was to assess the impact of the stimulation by comparing pre- and post-stimulation acoustic image logs. This comparison revealed minor modifications of almost all the natural fractures. However, not all of these fractures are associated with permeability enhancement. The most important permeability enhancement was observed on the originally permeable fault zone affecting the top of the granitic basement. In the Upper Rhine Graben, several deep geothermal projects, such as at Soultz-sous-Forêts (France) or Basel (Switzerland), were based on the Enhanced Geothermal System technology. The principle underlying this technology consists of increasing the low initial natural hydraulic performance of pre-existing natural fractures in the geothermal granitic reservoir via hydraulic and/or chemical stimulations. Hydraulic stimulation consists of injection of a large amount of water at a high flow rate to promote hydroshearing of pre-existing fractures. At Soultz-sous-Forêts and Basel, the maximum wellhead pressures were 16 MPa and 30 MPa respectively which induced larger magnitude seismic events of 2.9 and 3.4 respectively. Those specific induced seismicity events were felt by local population. At Rittershoffen (France), the geothermal well GRT-1 was drilled in 2012 down to a depth of 2.6 km and penetrates fractured sandstones and granite. The reservoir temperature reaches more than 160°C but the production flowrate was too low for an industrial project economically viable. Thus, the well was subjected to Thermal, Chemical and Hydraulic stimulations, which improved the injectivity index five-fold. During the hydraulic operation, a moderate volume of water was injected from the wellhead with a low pressure of 3 MPa. Approximately 300 microseismic events were detected during the hydraulic stimulations. Due to the low wellhead pressure during injection, no events were felt by nearby residents. The goal of the study was to assess the impact of the stimulation by comparing pre- and post-stimulation acoustic image logs. This comparison revealed minor modifications of almost all the natural fractures. However, not all of these fractures are associated with permeability enhancement. The most important permeability enhancement was observed on the originally permeable fault zone affecting the top of the granitic basement.

DOE Office of Scientific and Technical Information (OSTI.GOV)

Koen, A.D.

This paper reports that oil and gas companies in the US are curbing costs and redirecting spending to survive the worst decline of petroleum industry activity on record. Persistently weak US natural gas prices and shaky oil prices worldwide have put pressure on domestic companies to become low cost producers. Efforts to cut exploration and development costs have depressed activity in the US, one of the world's most mature oil and gas provinces. International E and D hot spots include the UK North Sea, Yemen, Thailand, Myanmar, Pakistan, and Latin America. Prospects in the Commonwealth of Independent States also continuemore » to generate considerable enthusiasm. Operators struggling to survive or searching for funds to spend on non-US prospects are trying to shuck noncore US assets. Other favored cost cutting strategies include reducing and restructuring debt, operating and administrative staffs, and internal organizations. Major integrated companies are able to add value by refocusing refining, petrochemical, or marketing operations. But independents must adapt operations close to the wellhead to become low cost producers. Whatever tactics are used to mitigate effects of low US activity, no domestic company --- from the largest integrated major to the smallest independent producer --- has proven to be immune from the downturn.« less

DOE Office of Scientific and Technical Information (OSTI.GOV)

Pallesen, T.R.; Braestrup, M.W.; Jorgensen, O.

Development of Danish North Sea hydrocarbon resources includes the 17-km Rolf pipeline installed in 1985. This one consists of an insulated 8-in. two-phase flow product line with a 3-in. piggyback gas lift line. A practical solution to design of this insulated pipeline, including the small diameter, piggyback injection line was corrosion coating of fusion bonded epoxy (FBE) and polyethylene (PE) sleeve pipe. The insulation design prevents hydrate formation under the most conservative flow regime during gas lift production. Also, the required minimum flow rate during the initial natural lift period is well below the value anticipiated at the initiation ofmore » gas lift. The weight coating design ensures stability on the seabed during the summer months only; thus trenching was required during the same installation season. Installation of insulated flowlines serving marginal fields is a significant feature of North Sea hydrocarbon development projects. The Skjold field is connected to Gorm by a 6-in., two-phase-flow line. The 11-km line was installed in 1982 as the first insulated pipeline in the North Sea. The Rolf field, located 17 km west of Gorm, went on stream Jan. 2. The development includes an unmanned wellhead platform and an insulated, two-phase-flow pipeline to the Gorm E riser platform. After separation on the Gorm C process platform, the oil and condensate are transported to shore through the 20-in. oil pipeline, and the natural gas is piped to Tyra for transmission through the 30-in. gas pipeline. Oil production at Rolf is assisted by the injection of lift gas, transported from Gorm through a 3-in. pipeline, installed piggyback on the insulated 8-in. product line. The seabed is smooth and sandy, the water depth varying between 33.7 m (110.5 ft) at Rolf and 39.1 m (128 ft) at Gorm.« less

WELLHEAD ANALYTIC ELEMENT MODEL FOR WINDOWS

EPA Science Inventory

WhAEM2000 (wellhead analytic element model for Win 98/00/NT/XP) is a public domain, ground-water flow model designed to facilitate capture zone delineation and protection area mapping in support of the State's and Tribe's Wellhead Protection Programs (WHPP) and Source Water Asses...

Estimation of methane emission from California natural gas industry.

PubMed

Kuo, Jeff; Hicks, Travis C; Drake, Brian; Chan, Tat Fu

2015-07-01

Energy generation and consumption are the main contributors to greenhouse gases emissions in California. Natural gas is one of the primary sources of energy in California. A study was recently conducted to develop current, reliable, and California-specific source emission factors (EFs) that could be used to establish a more accurate methane emission inventory for the California natural gas industry. Twenty-five natural gas facilities were surveyed; the surveyed equipment included wellheads (172), separators (131), dehydrators (17), piping segments (145), compressors (66), pneumatic devices (374), metering and regulating (M&R) stations (19), hatches (34), pumps (2), and customer meters (12). In total, 92,157 components were screened, including flanges (10,101), manual valves (10,765), open-ended lines (384), pressure relief valves (358), regulators (930), seals (146), threaded connections (57,061), and welded connections (12,274). Screening values (SVs) were measured using portable monitoring instruments, and Hi-Flow samplers were then used to quantify fugitive emission rates. For a given SV range, the measured leak rates might span several orders of magnitude. The correlation equations between the leak rates and SVs were derived. All the component leakage rate histograms appeared to have the same trend, with the majority of leakage rates<0.02 cubic feet per minute (cfm). Using the cumulative distribution function, the geometric mean was found to be a better indicator than the arithmetic mean, as the mean for each group of leakage rates found. For most component types, the pegged EFs for SVs of ≥10,000 ppmV and of ≥50,000 ppmV are relatively similar. The component-level average EFs derived in this study are often smaller than the corresponding ones in the 1996 U.S. Environmental Protection Agency/Gas Research Institute (EPA/GRI) study. Twenty-five natural gas facilities in California were surveyed to develop current, reliable, and California-specific source emission factors (EFs) for the natural gas industry. Screening values were measured by using portable monitoring instruments, and Hi-Flow samplers were then used to quantify fugitive emission rates. The component-level average EFs derived in this study are often smaller than the corresponding ones in the 1996 EPA/GRI study. The smaller EF values from this study might be partially attributable to the employment of the leak detection and repair program by most, if not all, of the facilities surveyed.

Combining microseismic and geomechanical observations to interpret storage integrity at the In Salah CCS site

NASA Astrophysics Data System (ADS)

Goertz-Allmann, Bettina P.; Kühn, Daniela; Oye, Volker; Bohloli, Bahman; Aker, Eyvind

2014-07-01

We present results from microseismic monitoring and geomechanical analysis obtained at the industrial-scale CO2 sequestration site at the In Salah gas development project in Algeria. More than 5000 microseismic events have been detected at a pilot monitoring well using a master event cross-correlation method. The microseismic activity occurs in four distinct clusters and thereof three clearly correlate with injection rates and wellhead pressures. These event clusters are consistent with a location within the reservoir interval. However, due to insufficient network geometry there are large uncertainties on event location. We estimate a fracture pressure of 155 bar (at the wellhead) from the comparison of injection pressure and injection rate and conclude that reservoir fracture pressure of the injection horizon has most likely been exceeded occasionally, accompanied by increased microseismic activity. Our analysis of 3-D ray tracing for direct and converted phases suggests that one of the event clusters is located at a shallower depth than the reservoir injection interval. However, this event cluster is most likely unrelated to changes in the injection activity at a single well, as the event times do not correlate with the wellhead pressures. Furthermore, this event cluster shows b-values close to one, indicating re-activated natural or tectonic seismicity on pre-existing weakness zones rather than injection induced seismicity. Analysis of event azimuths and significant shear wave splitting of up to 5 per cent provide further valuable insight into fluid migration and fracture orientation at the reservoir level. Although only one geophone was available during the critical injection period, the microseismic monitoring of CO2 injection at In Salah is capable of addressing some of the most relevant questions about fluid migration and reservoir integrity. An improved monitoring array with larger aperture and higher sensitivity is highly recommended, as it could greatly enhance the value of this technique. As such, real-time microseismic monitoring can be used to guide the injection pressure below fracture pressure, thus providing a tool to mitigate the risk of inducing felt seismicity and compromising seal integrity.

Reduction of Greenhouse Gas and Criteria Pollutant Emissions by Direct Conversion of Associated Flare Gas to Synthetic Fuels at Oil Wellheads

DOE Office of Scientific and Technical Information (OSTI.GOV)

Tan, Eric C; Zhang, Yi Min; Schuetzle, Dennis

This study describes the results of a 'well-to-wheel' life cycle assessment (LCA) carried out to determine the potential greenhouse gas and criteria pollutant emission reductions that could be achieved by converting associated flare gas directly to synthetic fuels at oil wellheads in the US and globally. A Greyrock Flare Gas-to-Fuels(TM) conversion process at an Ohio oil well was used as the base case for this LCA. The liquid fuel produced directly from associated gas is comprised primarily of premium synthetic diesel with a small amount of synthetic gasoline. In this LCA scenario, the synthetic diesel and synthetic gasoline are blendedmore » at 20 and 10 vol% with petroleum diesel and gasoline, respectively. While the synthetic diesel fuel can be used as is (100%), the 20 vol% synthetic diesel blend (with petroleum diesel) was found to significantly improve engine performance, increase fuel economy, and reduce emissions. The direct conversion of associated gas to synthetic diesel fuels globally could reduce emissions of CO2 and CH4 by up to 356 and 5.96 million metric tons/year, respectively, resulting in the reduction of greenhouse gases (GHGs) by about 113.3 and 92.2% (20 year global warming potential) and 73.8 and 50.7% (100 year global warming potential) for synthetic diesel and gasoline fuels when compared to petroleum-derived gasoline fuels, respectively. Likewise, diesel criteria emissions could be reduced globally by up to 23.3, 0.374, 42.4, and 61.3 million metric tons/year globally for CO, particulates, NOx, and hydrocarbons, respectively. The potential economic benefit of this approach is that up to 5.30 and 71.1 billion liters of synthetic fuels could be produced each year in the US and globally from associated gas, respectively.« less

Microbial Community Composition, Functions, and Activities in the Gulf of Mexico 1 Year after the Deepwater Horizon Accident

PubMed Central

Yergeau, Etienne; Maynard, Christine; Sanschagrin, Sylvie; Champagne, Julie; Juck, David; Lee, Kenneth

2015-01-01

Several studies have assessed the effects of the released oil on microbes, either during or immediately after the Deepwater Horizon accident. However, little is known about the potential longer-term persistent effects on microbial communities and their functions. In this study, one water column station near the wellhead (3.78 km southwest of the wellhead), one water column reference station outside the affected area (37.77 km southeast of the wellhead), and deep-sea sediments near the wellhead (3.66 km southeast of the wellhead) were sampled 1 year after the capping of the well. In order to analyze microbial community composition, function, and activity, we used metagenomics, metatranscriptomics, and mineralization assays. Mineralization of hexadecane was significantly higher at the wellhead station at a depth of ∼1,200 m than at the reference station. Community composition based on taxonomical or functional data showed that the samples taken at a depth of ∼1,200 m were significantly more dissimilar between the stations than at other depths (surface, 100 m, 750 m, and >1,500 m). Both Bacteria and Archaea showed reduced activity at depths of ∼1,200 m when the wellhead station was compared to the reference station, and their activity was significantly higher in surficial sediments than in 10-cm sediments. Surficial sediments also harbored significantly different active genera than did 5- and 10-cm sediments. For the remaining microbial parameters assessed, no significant differences could be observed between the wellhead and reference stations and between surface and 5- to 10-cm-deep sediments. PMID:26092461

Investigation of Natural Gas Fugitive Leak Detection Using an Unmanned Aerial Vehicle

NASA Astrophysics Data System (ADS)

Yang, S.; Talbot, R. W.; Frish, M. B.; Golston, L.; Aubut, N. F.; Zondlo, M. A.

2017-12-01

The U.S is now the world's largest natural gas producer, of which methane (CH4) is the main component. About 2% of the CH4 is lost through fugitive leaks. This research is under the DOE Methane Observation Networks with Innovative Technology to Obtain Reductions (MONITOR) program of ARPA-E. Our sentry measurement system is composed of four state-of-the-art technologies centered around the RMLDTM (Remote Methane Leak Detector). An open path RMLDTM measures column-integrated CH4 concentration that incorporates fluctuations in the vertical CH4 distribution. Based on Backscatter Tunable Diode Laser Absorption Spectroscopy and Small Unmanned Aerial Vehicles, the sentry system can autonomously, consistently and cost-effectively monitor and quantify CH4 leakage from sites associated with natural gas production. This system provides an advanced capability in detecting leaks at hard-to-access sites (e.g., wellheads) compared to traditional manual methods. Automated leak detecting and reporting algorithms combined with wireless data link implement real-time leak information reporting. Early data were gathered to set up and test the prototype system, and to optimize the leak localization and calculation strategies. The flight pattern is based on a raster scan which can generate interpolated CH4 concentration maps. The localization and quantification algorithms can be derived from the plume images combined with wind vectors. Currently, the accuracy of localization algorithm can reach 2 m and the calculation algorithm has a factor of 2 accuracy. This study places particular emphasis on flux quantification. The data collected at Colorado and Houston test fields were processed, and the correlation between flux and other parameters analyzed. Higher wind speeds and lower wind variation are preferred to optimize flux estimation. Eventually, this system will supply an enhanced detection capability to significantly reduce fugitive CH4 emissions in the natural gas industry.

Coupling Hydraulic Fracturing Propagation and Gas Well Performance for Simulation of Production in Unconventional Shale Gas Reservoirs

NASA Astrophysics Data System (ADS)

Wang, C.; Winterfeld, P. H.; Wu, Y. S.; Wang, Y.; Chen, D.; Yin, C.; Pan, Z.

2014-12-01

Hydraulic fracturing combined with horizontal drilling has made it possible to economically produce natural gas from unconventional shale gas reservoirs. An efficient methodology for evaluating hydraulic fracturing operation parameters, such as fluid and proppant properties, injection rates, and wellhead pressure, is essential for the evaluation and efficient design of these processes. Traditional numerical evaluation and optimization approaches are usually based on simulated fracture properties such as the fracture area. In our opinion, a methodology based on simulated production data is better, because production is the goal of hydraulic fracturing and we can calibrate this approach with production data that is already known. This numerical methodology requires a fully-coupled hydraulic fracture propagation and multi-phase flow model. In this paper, we present a general fully-coupled numerical framework to simulate hydraulic fracturing and post-fracture gas well performance. This three-dimensional, multi-phase simulator focuses on: (1) fracture width increase and fracture propagation that occurs as slurry is injected into the fracture, (2) erosion caused by fracture fluids and leakoff, (3) proppant subsidence and flowback, and (4) multi-phase fluid flow through various-scaled anisotropic natural and man-made fractures. Mathematical and numerical details on how to fully couple the fracture propagation and fluid flow parts are discussed. Hydraulic fracturing and production operation parameters, and properties of the reservoir, fluids, and proppants, are taken into account. The well may be horizontal, vertical, or deviated, as well as open-hole or cemented. The simulator is verified based on benchmarks from the literature and we show its application by simulating fracture network (hydraulic and natural fractures) propagation and production data history matching of a field in China. We also conduct a series of real-data modeling studies with different combinations of hydraulic fracturing parameters and present the methodology to design these operations with feedback of simulated production data. The unified model aids in the optimization of hydraulic fracturing design, operations, and production.

ESTIMATING FLOW AND FLUX OF GROUND-WATER DISCHARGE USING WATER TEMPERATURE AND VELOCITY. (R827961)

EPA Science Inventory

The nature of ground water discharge to a stream has important implications for nearby ground water flow, especially with respect to contaminant transport and well-head protection. Measurements of ground water discharge were accomplished in this study using (1) differences bet...

7 CFR 1410.6 - Eligible land.

Code of Federal Regulations, 2011 CFR

2011-01-01

... vegetation suitable for wetland restoration or wildlife habitat, as determined appropriate by the CCC, of... area, or any area determined eligible for CRP based on wetland or wellhead protection area criteria. A... permanent nature (such as a lake, pond, or sinkhole), or wetland; excluding such areas as gullies or sod...

Microbial Community Composition, Functions, and Activities in the Gulf of Mexico 1 Year after the Deepwater Horizon Accident.

PubMed

Yergeau, Etienne; Maynard, Christine; Sanschagrin, Sylvie; Champagne, Julie; Juck, David; Lee, Kenneth; Greer, Charles W

2015-09-01

Several studies have assessed the effects of the released oil on microbes, either during or immediately after the Deepwater Horizon accident. However, little is known about the potential longer-term persistent effects on microbial communities and their functions. In this study, one water column station near the wellhead (3.78 km southwest of the wellhead), one water column reference station outside the affected area (37.77 km southeast of the wellhead), and deep-sea sediments near the wellhead (3.66 km southeast of the wellhead) were sampled 1 year after the capping of the well. In order to analyze microbial community composition, function, and activity, we used metagenomics, metatranscriptomics, and mineralization assays. Mineralization of hexadecane was significantly higher at the wellhead station at a depth of ∼1,200 m than at the reference station. Community composition based on taxonomical or functional data showed that the samples taken at a depth of ∼1,200 m were significantly more dissimilar between the stations than at other depths (surface, 100 m, 750 m, and >1,500 m). Both Bacteria and Archaea showed reduced activity at depths of ∼1,200 m when the wellhead station was compared to the reference station, and their activity was significantly higher in surficial sediments than in 10-cm sediments. Surficial sediments also harbored significantly different active genera than did 5- and 10-cm sediments. For the remaining microbial parameters assessed, no significant differences could be observed between the wellhead and reference stations and between surface and 5- to 10-cm-deep sediments. Copyright © 2015, American Society for Microbiology. All Rights Reserved.

Natural gas-the missing link in the pricing chain can develop a life of its own

DOE Office of Scientific and Technical Information (OSTI.GOV)

Symonds, E.

When deputy treasury secretary R.T. McNamar addressed the May meeting of the National Foreign Trade Council in New York, he assured the assembled oilmen and bankers that further cuts of up to 20% should be expected in world oil prices. The puzzling feature is that the gas prices, which were for so long accused of undermining the oil market, are no longer brought into these discussions. Yet gas is the primary fuel over which governments have traditionally exercised the greatest control, and whose future movements must influence long-term world price levels as well as the near-term market for directly competitivemore » products such as heating and residual oils. On the domestic front, the latest of the gas industry's battle lines have been drawn around the long-lasting distortions of the 1954 ruling that the Federal Power Commission was obligated to devise and enforce as a method of controlling wellhead prices. As intended, gas then entered a long period of interstate sales below equilibrium prices, allowing it to capture one-third of the nation's energy market. But that share has now shrunk to approximately one-quarter of the market. This continuous decline was built into forecaster thinking during the long years of underpriced gas. The general assumption was that the decline in domestic supplies would be unbroken, and that prices would not be high enough to attract significant new supplies of supplemental gas. How far this assumption could be upset by decontrol remains an open question.« less

Performance evaluation of an advanced air-fuel ratio controller on a stationary, rich-burn natural gas engine

NASA Astrophysics Data System (ADS)

Kochuparampil, Roshan Joseph

The advent of an era of abundant natural gas is making it an increasingly economical fuel source against incumbents such as crude oil and coal, in end-use sectors such as power generation, transportation and industrial chemical production, while also offering significant environmental benefits over these incumbents. Equipment manufacturers, in turn, are responding to widespread demand for power plants optimized for operation with natural gas. In several applications such as distributed power generation, gas transmission, and water pumping, stationary, spark-ignited, natural gas fueled internal combustion engines (ICEs) are the power plant of choice (over turbines) owing to their lower equipment and operational costs, higher thermal efficiencies across a wide load range, and the flexibility afforded to end-users when building fine-resolution horsepower topologies: modular size increments ranging from 100 kW -- 2 MW per ICE power plant compared to 2 -- 5 MW per turbine power plant. Under the U.S. Environment Protection Agency's (EPA) New Source Performance Standards (NSPS) and Reciprocating Internal Combustion Engine National Emission Standards for Hazardous Air Pollutants (RICE NESHAP) air quality regulations, these natural gas power plants are required to comply with stringent emission limits, with several states mandating even stricter emissions norms. In the case of rich-burn or stoichiometric natural gas ICEs, very high levels of sustained emissions reduction can be achieved through exhaust after-treatment that utilizes Non Selective Catalyst Reduction (NSCR) systems. The primary operational constraint with these systems is the tight air-fuel ratio (AFR) window of operation that needs to be maintained if the NSCR system is to achieve simultaneous reduction of carbon monoxide (CO), nitrogen oxides (NOx), total hydrocarbons (THC), volatile organic compounds (VOCs), and formaldehyde (CH 2O). Most commercially available AFR controllers utilizing lambda (oxygen) sensor feedback are unable to maintain engine AFR within the required range owing to drift in sensor output over time. In this thesis, the emissions compliance performance of an AFR controller is evaluated over a 6-month period on an engine driving a gas compressor in an active natural gas production field. This AFR controller differentiates itself from other commercially available products by employing a lambda sensor that has been engineered against sensor drift, making it better suited for natural gas engine applications. Also included in this study are the controller's responses to transient loads, diurnal performance, adaptability to seasonal variations in ambient temperature, fuel quality variations (in wellhead gas), engine health considerations for proper AFR control, and controller calibration sensitivity when replacing lambda sensors. During the first three months of operation and subsequent diurnal tests, the controller's performance as a multi-point AFR control system was consistent, demonstrating appropriate AFR adjustments to variation in engine operation, over a wide range of ambient conditions, despite high consumption rate of engine lubrication oil. For the remainder the test, the high levels of lubrication oil consumption, compromised the ability to verify controller performance.

Natural gas: It's headed from surplus to shortage

DOE Office of Scientific and Technical Information (OSTI.GOV)

Parent, L.V.

1988-02-01

Reserve additions in the lower 48 states are not keeping up with the current rate of production, and deliverability surplus will soon become deliverability shortfall during periods of extended peak demand. Surplus deliverability will likely fade away, inasmuch as gas well completions are less than half of what they were when additions exceeded the current production rate of 16 tcf/year, and the outlook for a sharp increase in completions is bleak. Demand, lackluster before the recent cold weather, is likely to suffer some loss in markets where lower resid prices can switch loads back to oil. Year-end '87 price spikesmore » were a welcome relief to spot gas sellers, but low reside prices have already put a lid on what industrial users and power plants will pay. As an immature market struggles to develop structure in a quasi-deregulated environment, the Ferc is reduced to tinkering with the minutiae of Order 500, as it seeks to create a compromise that would be equally unsatisfactory to all. Canada is increasing its stake in the game. Canadian producers demonstrated their willingness to accept 1987's low price levels and be players. It will be another problem year for U.S. producers, as price relief for spot gas is more than offset by the Order 500 dilemma and drilling cost increases exceed wellhead price increases. Canadian gas will take a bigger piece of a desultory market. But pending shortfalls promise a better day for those with patience, stamina and deep pockets.« less

Improving Deliverability in Gas Storage Fields by Identifying the Timing and Sources of Damage Using Smart Well Technology

DOE Office of Scientific and Technical Information (OSTI.GOV)

J.H. Frantz Jr; K.G. Brown; W.K. Sawyer

2006-03-01

This report summarizes the work performed under contract DE-FC26-03NT41743. The primary objective of this study was to develop tools that would allow Underground Gas Storage (UGS) operators to use wellhead electronic flow measurement (EFM) data to quickly and efficiently identify trends in well damage over time, thus aiding in the identification of potential causes of the damage. Secondary objectives of this work included: (1) To assist UGS operators in the evaluation of hardware and software requirements for implementing an EFM system similar to the one described in this report, and (2) To provide a cost-benefit analysis framework UGS operators canmore » use to evaluate economic benefits of installing wellhead EFM systems in their particular fields. Assessment of EFM data available for use, and selection of the specific study field are reviewed. The various EFM data processing tasks, including data collection, organization, extraction, processing, and interpretation are discussed. The process of damage assessment via pressure transient analysis of EFM data is outlined and demonstrated, including such tasks as quality control, semi-log analysis, and log-log analysis of pressure transient test data extracted from routinely collected EFM data. Output from pressure transient test analyses for 21 wells is presented, and the interpretation of these analyses to determine the timing of damage development is demonstrated using output from specific study wells. Development of processing and interpretation modules to handle EFM data interpretation in horizontal wells is also a presented and discussed. A spreadsheet application developed to aid underground gas storage operators in the selection of EFM equipment is presented, discussed, and used to determine the cost benefit of installing EFM equipment in a gas storage field. Recommendations for future work related to EFM in gas storage fields are presented and discussed.« less

Assessing the reactivation potential of pre-existing fractures in the southern Karoo, South Africa: Evaluating the potential for sustainable exploration across its Critical Zone

NASA Astrophysics Data System (ADS)

Dhansay, Taufeeq; Navabpour, Payman; de Wit, Maarten; Ustaszewski, Kamil

2017-10-01

Understanding the kinematics of pre-existing fractures under the present-day stress field is an indispensable prerequisite for hydraulically increasing fracture-induced rock permeability, i.e. through hydraulic stimulation, which forms the basis of economically viable exploitation of resources such as natural gas and geothermal energy. Predicting the likelihood of reactivating pre-existing fractures in a target reservoir at particular fluid injection pressures requires detailed knowledge of the orientations and magnitudes of the prevailing stresses as well as pore fluid pressures. In the absence of actual in-situ stress measurements, e.g. derived from boreholes, as is mostly the case in previously underexplored ;frontier areas;, such predictions are often difficult. In this study, the potential of reactivating pre-existing fractures in a likely exploration region of the southern Karoo of South Africa is investigated. The orientations of the present-day in-situ stresses were assessed from surrounding earthquake focal mechanisms, implying c. NW-SE oriented maximum horizontal stress and a stress regime changing between strike-slip and normal faulting. A comparison with paleo-stress axes derived from inverted fault-slip data suggests that the stress field very likely did not experience any significant reorientation since Cretaceous times. Maximum possible in-situ stress magnitudes are estimated by assuming that these are limited by frictional strength on pre-existing planes and subsequently, slip and dilation tendency calculations were performed, assuming hydrostatic pore fluid pressures of c. 32 MPa at targeted reservoir depth. The results suggest that prevalent E-W and NW-SE oriented sub-vertical fractures are likely to be reactivated at wellhead pressures exceeding hydrostatic pore fluid pressures by as little as 2-5 MPa, while less prevalent sub-horizontal and moderately inclined fractures require higher wellhead pressures that are still technically feasible. Importantly, actual in-situ stress measurements are essential to test these theoretical considerations and to guide the design of safe and effective exploration linked to fracture manipulation, such as shale gas recovery.

Monitoring Volatile Organic Compounds (VOCs) in real-time on oil and natural gas production sites

NASA Astrophysics Data System (ADS)

Lupardus, R.; Franklin, S. B.

2017-12-01

Oil and Natural Gas (O&NG) development, production, infrastructure, and associated processing activities can be a substantial source of air pollution, yet relevant data and real-time quantification methods are lacking. In the current study, O&NG fugitive emissions of Volatile Organic Compounds (VOCs) were quantified in real-time and used to determine the spatial and temporal windows of exposure for proximate flora and fauna. Eleven O&NG sites on the Pawnee National Grassland in Northeastern Colorado were randomly selected and grouped according to production along with 13 control sites from three geographical locations. At each site, samples were collected 25 m from the wellhead in NE, SE, and W directions. In each direction, two samples were collected with a Gasmet DX4040 gas analyzer every hour from 8:00 am to 2:00 pm (6 hours total), July to October, 2016 (N=864). VOC concentrations generally increased during the 6 hr. day with the exception of N2O and were predominately the result of O&NG production and not vehicle exhaust. Thirteen of 24 VOCs had significantly different levels between production groups, frequently above reference standards and at biologically relevant levels for flora and fauna. The most biologically relevant VOCs, found at concentrations exceeding time weighted average permissible exposure limits (TWA PELs), were benzene and acrolein. Generalized Estimating Equations (GEEs) measured the relative quality of statistical models predicting benzene concentrations on sites. The data not only confirms that O&NG emissions are impacting the region, but also that this influence is present at all sites, including controls. Increased real-time VOC monitoring on O&NG sites is required to identify and contain fugitive emissions and to protect human and environmental health.

The recovered energy advantage; Unique new turboexpander makes use of pressure reduction

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1989-03-01

The oil and gas industry does not just produce energy. The industry also consumes large quantities of energy in transporting hydrocarbons to the customer. A convenient, inexpensive source of usable energy would represent a distinct economical advantage to any phase of the industry. Smaller, more flexible and more affordable turboexpanders offer just such an advantage at many application points from the wellhead to the customer. This paper describes the turboexpander, a simple machine in which fluid or gas at high pressure is expanded to achieve a lower pressure. The released energy drives a turbine wheel and generates power or mechanicalmore » work. A turbo charger on a gasoline or diesel engine is a common example of a turboexpander.« less

EPA MODELING TOOLS FOR CAPTURE ZONE DELINEATION

EPA Science Inventory

The EPA Office of Research and Development supports a step-wise modeling approach for design of wellhead protection areas for water supply wells. A web-based WellHEDSS (wellhead decision support system) is under development for determining when simple capture zones (e.g., centri...

Aspects of wellbore heat transfer during two-phase flow

DOE Office of Scientific and Technical Information (OSTI.GOV)

Hasan, A.R.; Kabir, C.S.

1994-08-01

Wellbore fluid temperature is governed by the rate of heat loss from the wellbore to the surrounding formation, which in turn is a function of depth and production/injection time. The authors present an approach to estimate wellbore fluid temperature during steady-state two-phase flow. The method incorporates a new solution of the thermal diffusivity equation and the effect of both conductive and convective heat transport for the wellbore/formation system. For the multiphase flow in the wellbore, the Hasan-Kabir model has been adapted, although other mechanistic models may be used. A field example is used to illustrate the fluid temperature calculation proceduremore » and shows the importance of accounting for convection in the tubing/casing annulus. A sensitivity study shows that significant differences exist between the predicted wellhead temperature and the formation surface temperature and that the fluid temperature gradient is nonlinear. This study further shows that increased free gas lowers the wellhead temperature as a result of the Joule-Thompson effect. In such cases, the expression for fluid temperature developed earlier for single-phase flow should not be applied when multiphase flow is encountered. An appropriate expression is presented in this work for wellbores producing multiphase fluids.« less

Of Detection Limits and Effective Mitigation: The Use of Infrared Cameras for Methane Leak Detection

NASA Astrophysics Data System (ADS)

Ravikumar, A. P.; Wang, J.; McGuire, M.; Bell, C.; Brandt, A. R.

2017-12-01

Mitigating methane emissions, a short-lived and potent greenhouse gas, is critical to limiting global temperature rise to two degree Celsius as outlined in the Paris Agreement. A major source of anthropogenic methane emissions in the United States is the oil and gas sector. To this effect, state and federal governments have recommended the use of optical gas imaging systems in periodic leak detection and repair (LDAR) surveys to detect for fugitive emissions or leaks. The most commonly used optical gas imaging systems (OGI) are infrared cameras. In this work, we systematically evaluate the limits of infrared (IR) camera based OGI system for use in methane leak detection programs. We analyze the effect of various parameters that influence the minimum detectable leak rates of infrared cameras. Blind leak detection tests were carried out at the Department of Energy's MONITOR natural gas test-facility in Fort Collins, CO. Leak sources included natural gas wellheads, separators, and tanks. With an EPA mandated 60 g/hr leak detection threshold for IR cameras, we test leak rates ranging from 4 g/hr to over 350 g/hr at imaging distances between 5 ft and 70 ft from the leak source. We perform these experiments over the course of a week, encompassing a wide range of wind and weather conditions. Using repeated measurements at a given leak rate and imaging distance, we generate detection probability curves as a function of leak-size for various imaging distances, and measurement conditions. In addition, we estimate the median detection threshold - leak-size at which the probability of detection is 50% - under various scenarios to reduce uncertainty in mitigation effectiveness. Preliminary analysis shows that the median detection threshold varies from 3 g/hr at an imaging distance of 5 ft to over 150 g/hr at 50 ft (ambient temperature: 80 F, winds < 4 m/s). Results from this study can be directly used to improve OGI based LDAR protocols and reduce uncertainty in estimated mitigation effectiveness. Furthermore, detection limits determined in this study can be used as standards to compare new detection technologies.

WHAEM: PROGRAM DOCUMENTATION FOR THE WELLHEAD ANALYTIC ELEMENT MODEL

EPA Science Inventory

The Wellhead Analytic Element Model (WhAEM) demonstrates a new technique for the definition of time-of-travel capture zones in relatively simple geohydrologic settings. he WhAEM package includes an analytic element model that uses superposition of (many) analytic solutions to gen...

Wellhead power production with a rotary separator turbine (RP 1196)

NASA Astrophysics Data System (ADS)

Cerini, D. J.; Record, J.

1982-12-01

A rotary-separator turbine was built with full flow capacity for a 500 F downhole temperature with a 850,000 lbm/hr production rate. The test system and results obtained in field tests are described. The preliminary design of a 10-megawatt wellhead power plant for the Roosevelt type resource is described. This system shows a specific power of .0013 kW hr per lbm, which is 20 percent greater than an optimized wellhead single stage flash plant. This is 26 percent greater than a central plant of 20 to 50 MW capacity when consideration is given to steam-gathering system pressure drop between the wells and central plant.

3DFEMWATER/3DLEWASTE: NUMERICAL CODES FOR DELINEATING WELLHEAD PROTECTION AREAS IN AGRICULTURAL REGIONS BASED ON THE ASSIMILATIVE CAPACITY CRITERION

EPA Science Inventory

Two related numerical codes, 3DFEMWATER and 3DLEWASTE, are presented sed to delineate wellhead protection areas in agricultural regions using the assimilative capacity criterion. DFEMWATER (Three-dimensional Finite Element Model of Water Flow Through Saturated-Unsaturated Media) ...

Deep-Sea Benthic Footprint of the Deepwater Horizon Blowout

PubMed Central

Montagna, Paul A.; Baguley, Jeffrey G.; Cooksey, Cynthia; Hartwell, Ian; Hyde, Larry J.; Hyland, Jeffrey L.; Kalke, Richard D.; Kracker, Laura M.; Reuscher, Michael; Rhodes, Adelaide C. E.

2013-01-01

The Deepwater Horizon (DWH) accident in the northern Gulf of Mexico occurred on April 20, 2010 at a water depth of 1525 meters, and a deep-sea plume was detected within one month. Oil contacted and persisted in parts of the bottom of the deep-sea in the Gulf of Mexico. As part of the response to the accident, monitoring cruises were deployed in fall 2010 to measure potential impacts on the two main soft-bottom benthic invertebrate groups: macrofauna and meiofauna. Sediment was collected using a multicorer so that samples for chemical, physical and biological analyses could be taken simultaneously and analyzed using multivariate methods. The footprint of the oil spill was identified by creating a new variable with principal components analysis where the first factor was indicative of the oil spill impacts and this new variable mapped in a geographic information system to identify the area of the oil spill footprint. The most severe relative reduction of faunal abundance and diversity extended to 3 km from the wellhead in all directions covering an area about 24 km2. Moderate impacts were observed up to 17 km towards the southwest and 8.5 km towards the northeast of the wellhead, covering an area 148 km2. Benthic effects were correlated to total petroleum hydrocarbon, polycyclic aromatic hydrocarbons and barium concentrations, and distance to the wellhead; but not distance to hydrocarbon seeps. Thus, benthic effects are more likely due to the oil spill, and not natural hydrocarbon seepage. Recovery rates in the deep sea are likely to be slow, on the order of decades or longer. PMID:23950956

30 CFR 250.517 - Tubing and wellhead equipment.

Code of Federal Regulations, 2010 CFR

2010-07-01

... evaluated every 30 days and the results submitted to the District Manager. (c) When the tree is installed..., a surface tubing head, a surface tubing hanger, and a surface christmas tree. (d) Wellhead, tree... and one surface safety valve, installed above the master valve, in the vertical run of the tree. (e...

30 CFR 250.518 - Tubing and wellhead equipment.

Code of Federal Regulations, 2013 CFR

2013-07-01

... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... otherwise evaluated every 30 days and the results submitted to the District Manager. (c) When the tree is... . . . you must equip . . . so you can monitor . . . (1) fixed platform wells, the wellhead, all annuli (A, B...

30 CFR 250.517 - Tubing and wellhead equipment.

Code of Federal Regulations, 2012 CFR

2012-07-01

... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... otherwise evaluated every 30 days and the results submitted to the District Manager. (c) When the tree is... . . . you must equip . . . so you can monitor . . . (1) fixed platform wells, the wellhead, all annuli (A, B...

30 CFR 250.518 - Tubing and wellhead equipment.

Code of Federal Regulations, 2014 CFR

2014-07-01

... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... otherwise evaluated every 30 days and the results submitted to the District Manager. (c) When the tree is... . . . you must equip . . . so you can monitor . . . (1) fixed platform wells, the wellhead, all annuli (A, B...

30 CFR 250.517 - Tubing and wellhead equipment.

Code of Federal Regulations, 2011 CFR

2011-07-01

... pressure integrity and is otherwise suitable for its intended use. (b) In the event of prolonged operations... Manager. (c) When the tree is installed, you must equip wells to monitor for casing pressure according to... platform wells, the wellhead, all annuli (A, B, C, D, etc., annuli). (2) subsea wells, the tubing head, the...

ANALYTIC ELEMENT MODELING FOR SOURCE WATER ASSESSMENTS OF PUBLIC WATER SUPPLY WELLS: CASE STUDIES IN GLACIAL OUTWASH AND BASIN-AND-RANGE

EPA Science Inventory

Over the last 10 years the EPA has invested in analytic elements as a computational method used in public domain software supporting capture zone delineation for source water assessments and wellhead protection. The current release is called WhAEM2000 (wellhead analytic element ...

The Deepwater Horizon Oil Spill: Ecogenomics of the Deep-Sea Plume

NASA Astrophysics Data System (ADS)

Hazen, T. C.

2012-12-01

The explosion on April 20, 2010 at the BP-leased Deepwater Horizon drilling rig in the Gulf of Mexico off the coast of Louisiana, resulted in oil and gas rising to the surface and the oil coming ashore in many parts of the Gulf, it also resulted in the dispersment of an immense oil plume 4,000 feet below the surface of the water. Despite spanning more than 600 feet in the water column and extending more than 10 miles from the wellhead, the dispersed oil plume was gone within weeks after the wellhead was capped - degraded and diluted to undetectable levels. Furthermore, this degradation took place without significant oxygen depletion. Ecogenomics enabled discovery of new and unclassified species of oil-eating bacteria that apparently lives in the deep Gulf where oil seeps are common. Using 16s microarrays, functional gene arrays, clone libraries, lipid analysis and a variety of hydrocarbon and micronutrient analyses we were able to characterize the oil degraders. Metagenomic sequence data was obtained for the deep-water samples using the Illumina platform. In addition, single cells were sorted and sequenced for the some of the most dominant bacteria that were represented in the oil plume; namely uncultivated representatives of Colwellia and Oceanospirillum. In addition, we performed laboratory microcosm experiments using uncontaminated water collected from The Gulf at the depth of the oil plume to which we added oil and COREXIT. These samples were characterized by 454 pyrotag. The results provide information about the key players and processes involved in degradation of oil, with and without COREXIT, in different impacted environments in The Gulf of Mexico. We are also extending these studies to explore dozens of deep sediment samples that were also collected after the oil spill around the wellhead. This data suggests that a great potential for intrinsic bioremediation of oil plumes exists in the deep-sea and other environs in the Gulf of Mexico.

Bull heading to kill live gas wells

DOE Office of Scientific and Technical Information (OSTI.GOV)

Oudeman, P.; Avest, D. ter; Grodal, E.O.

1994-12-31

To kill a live closed-in gas well by bull heading down the tubing, the selected pump rate should be high enough to ensure efficient displacement of the gas into the formation (i.e., to avoid the kill fluid bypassing the gas). On the other hand, the pressures that develop during bull heading at high rate must not exceed wellhead pressure rating, tubing or casing burst pressures or the formation breakdown gradient, since this will lead, at best, to a very inefficient kill job. Given these constraints, the optimum kill rate, requited hydraulic horsepower, density and type of kill fluids have tomore » be selected. For this purpose a numerical simulator has been developed, which predicts the sequence of events during bull heading. Pressures and flow rates in the well during the kill job are calculated, taking to account slip between the gas and kill fluid, hydrostatic and friction pressure drop, wellbore gas compression and leak-off to the formation. Comparison with the results of a dedicated field test demonstrates that these parameters can be estimated accurately. Example calculations will be presented to show how the simulator can be used to identify an optimum kill scenario.« less

Two-stream Convolutional Neural Network for Methane Emissions Quantification

NASA Astrophysics Data System (ADS)

Wang, J.; Ravikumar, A. P.; McGuire, M.; Bell, C.; Tchapmi, L. P.; Brandt, A. R.

2017-12-01

Methane, a key component of natural gas, has a 25x higher global warming potential than carbon dioxide on a 100-year basis. Accurately monitoring and mitigating methane emissions require cost-effective detection and quantification technologies. Optical gas imaging, one of the most commonly used leak detection technology, adopted by Environmental Protection Agency, cannot estimate leak-sizes. In this work, we harness advances in computer science to allow for rapid and automatic leak quantification. Particularly, we utilize two-stream deep Convolutional Networks (ConvNets) to estimate leak-size by capturing complementary spatial information from still plume frames, and temporal information from plume motion between frames. We build large leak datasets for training and evaluating purposes by collecting about 20 videos (i.e. 397,400 frames) of leaks. The videos were recorded at six distances from the source, covering 10 -60 ft. Leak sources included natural gas well-heads, separators, and tanks. All frames were labeled with a true leak size, which has eight levels ranging from 0 to 140 MCFH. Preliminary analysis shows that two-stream ConvNets provides significant accuracy advantage over single steam ConvNets. Spatial stream ConvNet can achieve an accuracy of 65.2%, by extracting important features, including texture, plume area, and pattern. Temporal stream, fed by the results of optical flow analysis, results in an accuracy of 58.3%. The integration of the two-stream ConvNets gives a combined accuracy of 77.6%. For future work, we will split the training and testing datasets in distinct ways in order to test the generalization of the algorithm for different leak sources. Several analytic metrics, including confusion matrix and visualization of key features, will be used to understand accuracy rates and occurrences of false positives. The quantification algorithm can help to find and fix super-emitters, and improve the cost-effectiveness of leak detection and repair programs.

Microbial enzymatic activity and secondary production in sediments affected by the sedimentation pulse following the Deepwater Horizon oil spill

NASA Astrophysics Data System (ADS)

Ziervogel, Kai; Joye, Samantha B.; Arnosti, Carol

2016-07-01

A large fraction of the spilled oil from the Deepwater Horizon (DwH) blowout in April 2010 reached the seafloor via sinking oil aggregates (oil snow) in a massive sedimentation that continued until late summer 2010 (;Dirty blizzard;). We measured heterotrophic microbial metabolic rates as well as porewater and sedimentary geochemical parameters at sites proximate to and distant from the wellhead to investigate microbial responses to the "Dirty Blizzard". Lipase activity and rates of bacterial protein production were highest and leucine-aminopeptidase activity was lowest in 0-2 cm sediment layers at the sites proximate to the wellhead. These results suggest that the presence of the oil snow stimulated benthic microbial enzymatic hydrolysis of oil-derived organic matter that was depleted in peptide substrates at the time of our sampling. The strong gradients in porewater DOC, NH4+, and HPO43- concentrations in the upper 6 cm of the sediments near the wellhead likewise indicate elevated heterotrophic responses to recently-sedimented organic matter. In addition to enhanced microbial activities in the 0-2 cm sediment layers, we found peaks of total organic carbon and elevated microbial metabolic rates down to 10 cm at the sites closest to the wellhead. Our results indicate distinct benthic metabolic responses of heterotrophic microbial communities, even three months after the ending of the "Dirty Blizzard". Compared to other deep-sea environments, however, metabolic rates associated with the recently deposited particulate matter around the wellhead were only moderately enhanced. Oil contaminants at the seafloor may therefore have prolonged residence times, enhancing the potential for longer-term ecological consequences in deep-sea environments.

Polycyclic Aromatic Hydrocarbon Distribution and Modification in the Sub-surface Plume Near the Deepwater Horizon Wellhead

NASA Astrophysics Data System (ADS)

Shiller, A. M.; Joung, D.; Wade, T.

2011-12-01

A significant concern associated with oil spills is the toxicity associated with the polycyclic aromatic hydrocarbon (PAH) component. Ratios of various PAH's have also been used as indicators of oil sources. During a late May/early June cruise, 57 samples for PAH analysis were collected in the vicinity of the Deepwater Horizon wellhead. Most samples were from the previously reported sub-surface oil plume, centered near 1100 m depth. PAH concentrations ranged up to 117 μg/L and rapidly diminished in the subsurface with distance from the wellhead. The Macondo well oil was observed to be rich in naphthalenes. Within a few km of the wellhead, the percentage of methyl-naphthalenes in the sub-surface plume was generally higher than in the source, suggesting preferential solubilization of this low molecular weight fraction. However, the percentage rapidly decreased away from the well also suggesting rapid destruction or removal of the naphthalenes. The pyrogenic index (Wang et al.) was <0.05 for all samples, indicating a petroleum origin. For a few samples, some other PAH ratios (e.g., MP/P and P/A ratios) suggested a combustion origin. However, these ratios also tended to vary both with percent methyl-naphthalenes and distance from the wellhead, suggesting anomalous ratios originating from solubilization/degradation effects. We also obtained a more limited set of surface water samples, generally avoiding the most contaminated areas as well as areas of oil burning. For these surface water samples, similar trends were observed as at depth, probably resulting from selective volatilization and photo-degradation. Overall, the data illustrate how environmental factors lead both to reduced concentrations and fractionation of the PAH's.

Temperature and Redox Effect on Mineral Colonization in Juan de Fuca Ridge Flank Subsurface Crustal Fluids

PubMed Central

Baquiran, Jean-Paul M.; Ramírez, Gustavo A.; Haddad, Amanda G.; Toner, Brandy M.; Hulme, Samuel; Wheat, Charles G.; Edwards, Katrina J.; Orcutt, Beth N.

2016-01-01

To examine microbe-mineral interactions in subsurface oceanic crust, we evaluated microbial colonization on crustal minerals that were incubated in borehole fluids for 1 year at the seafloor wellhead of a crustal borehole observatory (IODP Hole U1301A, Juan de Fuca Ridge flank) as compared to an experiment that was not exposed to subsurface crustal fluids (at nearby IODP Hole U1301B). In comparison to previous studies at these same sites, this approach allowed assessment of the effects of temperature, fluid chemistry, and/or mineralogy on colonization patterns of different mineral substrates, and an opportunity to verify the approach of deploying colonization experiments at an observatory wellhead at the seafloor instead of within the borehole. The Hole U1301B deployment did not have biofilm growth, based on microscopy and DNA extraction, thereby confirming the integrity of the colonization design against bottom seawater intrusion. In contrast, the Hole U1301A deployment supported biofilms dominated by Epsilonproteobacteria (43.5% of 370 16S rRNA gene clone sequences) and Gammaproteobacteria (29.3%). Sequence analysis revealed overlap in microbial communities between different minerals incubated at the Hole U1301A wellhead, indicating that mineralogy did not separate biofilm structure within the 1-year colonization experiment. Differences in the Hole U1301A wellhead biofilm community composition relative to previous studies from within the borehole using similar mineral substrates suggest that temperature and the diffusion of dissolved oxygen through plastic components influenced the mineral colonization experiments positioned at the wellhead. This highlights the capacity of low abundance crustal fluid taxa to rapidly establish communities on diverse mineral substrates under changing environmental conditions such as from temperature and oxygen. PMID:27064928

Spatial and temporal characteristics of elevated temperatures in municipal solid waste landfills.

PubMed

Jafari, Navid H; Stark, Timothy D; Thalhamer, Todd

2017-01-01

Elevated temperatures in waste containment facilities can pose health, environmental, and safety risks because they generate toxic gases, pressures, leachate, and heat. In particular, MSW landfills undergo changes in behavior that typically follow a progression of indicators, e.g., elevated temperatures, changes in gas composition, elevated gas pressures, increased leachate migration, slope movement, and unusual and rapid surface settlement. This paper presents two MSW landfill case studies that show the spatial and time-lapse movements of these indicators and identify four zones that illustrate the transition of normal MSW decomposition to the region of elevated temperatures. The spatial zones are gas front, temperature front, and smoldering front. The gas wellhead temperature and the ratio of CH 4 to CO 2 are used to delineate the boundaries between normal MSW decomposition, gas front, and temperature front. The ratio of CH 4 to CO 2 and carbon monoxide concentrations along with settlement strain rates and subsurface temperatures are used to delineate the smoldering front. In addition, downhole temperatures can be used to estimate the rate of movement of elevated temperatures, which is important for isolating and containing the elevated temperature in a timely manner. Copyright © 2016 Elsevier Ltd. All rights reserved.

Light rare earth element depletion during Deepwater Horizon blowout methanotrophy.

PubMed

Shiller, A M; Chan, E W; Joung, D J; Redmond, M C; Kessler, J D

2017-09-04

Rare earth elements have generally not been thought to have a biological role. However, recent work has demonstrated that the light REEs (LREEs: La, Ce, Pr, and Nd) are essential for at least some methanotrophs, being co-factors in the XoxF type of methanol dehydrogenase (MDH). We show here that dissolved LREEs were significantly removed in a submerged plume of methane-rich water during the Deepwater Horizon (DWH) well blowout. Furthermore, incubation experiments conducted with naturally methane-enriched waters from hydrocarbon seeps in the vicinity of the DWH wellhead also showed LREE removal concurrent with methane consumption. Metagenomic sequencing of incubation samples revealed that LREE-containing MDHs were present. Our field and laboratory observations provide further insight into the biochemical pathways of methanotrophy during the DWH blowout. Additionally, our results are the first observations of direct biological alteration of REE distributions in oceanic systems. In view of the ubiquity of LREE-containing MDHs in oceanic systems, our results suggest that biological uptake of LREEs is an overlooked aspect of the oceanic geochemistry of this group of elements previously thought to be biologically inactive and an unresolved factor in the flux of methane, a potent greenhouse gas, from the ocean.

Was the Deepwater Horizon Well Discharge Churn Flow? Implications on the Estimation of the Oil Discharge and Droplet Size Distribution

NASA Astrophysics Data System (ADS)

Boufadel, Michel C.; Gao, Feng; Zhao, Lin; Özgökmen, Tamay; Miller, Richard; King, Thomas; Robinson, Brian; Lee, Kenneth; Leifer, Ira

2018-03-01

Improved understanding of the character of an uncontrolled pipeline flow is critical for the estimation of the oil discharge and droplet size distribution both essential for evaluating oil spill impact. Measured oil and gas properties at the wellhead of the Macondo255 and detailed numerical modeling suggested that the flow within the pipe could have been "churn," whereby oil and gas tumble violently within the pipe and is different from the bubbly flow commonly assumed for that release. The churn flow would have produced 5 times the energy loss in the pipe compared to bubbly flow, and its plume would have entrained 35% more water than that of the bubbly flow. Both findings suggest that the oil discharge in Deepwater Horizon could have been overestimated, by up to 200%. The resulting oil droplet size distribution of churn flow is likely smaller than that of bubbly flow.

The helical screw expander evaluation project. [for geothermal wells

NASA Technical Reports Server (NTRS)

Mckay, R. A.

1977-01-01

A positive-displacement helical-screw expander of the Lysholm type has been adapted for geothermal service and successfully demonstrated in a 50 kW prototype power system. Evaluation of the expander by tests of a new model in a 1 MW power system under wellhead conditions in selected liquid-dominated geothermal fields is proposed. The objectives are to determine the performance characteristics of the expander and power system over a broad range of operating conditions and also to examine the concept of wellhead power plants. Throttling and fractionation of the fluids from the test wells is planned to simulate a wide range of wellhead pressures and steam fractions. Variation in the expander exhaust pressure is also planned. The investigation will include expander efficiency, corrosion, erosion, scale formation and control, and endurance testing. Interaction studies with the wells and an electric grid are also proposed.

Gras Dowr joins world`s FPSO fleet

DOE Office of Scientific and Technical Information (OSTI.GOV)

NONE

1997-05-05

The Gras Dowr, a floating production, storage, and offloading vessel (FPSD) for Amerada Hess Ltd.`s North Sea Durward and Dauntless fields, is one of the latest additions to the world`s growing FPSO fleet. The Gras Dowr, anchored in about 90 m of water, lies between the Durward (U.K. Block 21/16) and Dauntless (U.K. Block 21/11) fields, about 3.5 km from the subsea wellhead locations. The Gras Dowr`s main functions, according to Bluewater Offshore Production Systems Ltd., are to: receive fluids from well risers; process incoming fluids to separate the fluid into crude, water, and gas; store dry crude oil andmore » maintain the required temperature; treat effluent to allow for water discharge to the sea; compress gas for gas lift as a future option; provide chemical injection skid for process chemical injection; use a part of the produced gas for fuel gas, and flare excess gas; inject treated seawater into the injection wells; house power generation for process and offloading operation and utilities; offload to a tandem moored shuttle tanker including receiving liquid fuel from the same tanker; provide accommodations for operating and maintenance crews; allow helicopters landings and takeoffs; allow handling and storage of goods transported by supply vessels; moor a shuttle tanker; and control the subsea wells.« less

Monitoring Concept for CO2 Storage at the Pilot Site Ketzin, Germany

NASA Astrophysics Data System (ADS)

Wipki, Mario; Liebscher, Axel; Lüth, Stefan; Ivanova, Alexandra; Möller, Fabian; Schmidt-Hattenberger, Cornelia; Rippe, Dennis; Zimmer, Martin; Szizybalski, Alexandra

2016-04-01

Between 2008 and 2013, the German Research Centre for Geosciences - GFZ has injected more than 67 kt of CO2 at the Pilot Site in Ketzin, 25 km west of Berlin. The CO2 was stored in porous sandstones of the Upper Triassic Stuttgart Formation at a depth of 630 to 650 m. In more than a decade, GFZ has developed and tested an extraordinary multi-monitoring concept for onshore CO2 storages which mainly comprises the following methods: Time-lapse 3D seismic surveying is the most commonly used method for imaging and monitoring a CO2-plume in the deep underground before, during and after the injection phase. Such campaigns require high logistical and financial efforts and can be realised only to a limited extent. At Ketzin, for instance, 3D-seismic repeat surveys were acquired using several thousand surface acquisition points and lasting over two or three months. Alternative approaches include permanently buried seismic receivers. Geoelectric measurements in Ketzin are mainly applied by using a permanent downhole electrode installation (Vertical Electrical Resistivity Array = VERA) which has been implemented in three wells behind the well casings. Measurements between 590 m to 735 m are constantly carried out covering the vertical thickness of the entire CO2 storage horizon. Valuable results were achieved by a combination of inhole, crosshole and surface downhole measurements which has been carried out with appropriate acquisition geometries. For focused areas around monitoring wells, geoelectric methods may support and supplement information from seismic surveys. Borehole monitoring of pressure and temperature are generally indispensable for every underground gas storage type. In Ketzin, a remote monitoring system for all wells has been installed that constantly provides the operators with values for date, time, downhole and wellhead pressure, depth, and temperature. Moreover, all wellheads are checked weekly during onsite inspections. Samples for chemical analysis are taken in regular intervals from an observation well. With a total depth of 418 m, the well reaches the natural brine filled sandstones of the Triassic Exter Formation which represents the layer straight upon the caprock of the CO2 reservoir. Fluid samples are being analysed for stable carbon isotopes δ13C, dissolved organic carbon (DIC) and pH. Any significant intrusion of CO2 into this aquifer would cause distinct anomalies and trigger alarm conditions. Another regularly applied monitoring method in Ketzin is the measurement of soil CO2 flux. Natural CO2 flux is generated by the respiration of roots and soil organisms and the decomposition of organic matter. Both processes very much depend on the seasons respectively on the soil temperature. Outliers of the natural background range could indicate a leakage in the reservoir.

Arsenic-related water quality with depth and water quality of well-head samples from production wells, Oklahoma, 2008

USGS Publications Warehouse

Becker, Carol J.; Smith, S. Jerrod; Greer, James R.; Smith, Kevin A.

2010-01-01

The U.S. Geological Survey well profiler was used to describe arsenic-related water quality with well depth and identify zones yielding water with high arsenic concentrations in two production wells in central and western Oklahoma that yield water from the Permian-aged Garber-Wellington and Rush Springs aquifers, respectively. In addition, well-head samples were collected from 12 production wells yielding water with historically large concentrations of arsenic (greater than 10 micrograms per liter) from the Garber-Wellington aquifer, Rush Springs aquifer, and two minor aquifers: the Arbuckle-Timbered Hills aquifer in southern Oklahoma and a Permian-aged undefined aquifer in north-central Oklahoma. Three depth-dependent samples from a production well in the Rush Springs aquifer had similar water-quality characteristics to the well-head sample and did not show any substantial changes with depth. However, slightly larger arsenic concentrations in the two deepest depth-dependent samples indicate the zones yielding noncompliant arsenic concentrations are below the shallowest sampled depth. Five depth-dependent samples from a production well in the Garber-Wellington aquifer showed increases in arsenic concentrations with depth. Well-bore travel-time information and water-quality data from depth-dependent and well-head samples showed that most arsenic contaminated water (about 63 percent) was entering the borehole from perforations adjacent to or below the shroud that overlaid the pump. Arsenic concentrations ranged from 10.4 to 124 micrograms per liter in 11 of the 12 production wells sampled at the well head, exceeding the maximum contaminant level of 10 micrograms per liter for drinking water. pH values of the 12 well-head samples ranged from 6.9 to 9. Seven production wells in the Garber-Wellington aquifer had the largest arsenic concentrations ranging from 18.5 to 124 micrograms per liter. Large arsenic concentrations (10.4-18.5) and near neutral to slightly alkaline pH values (6.9-7.4) were detected in samples from one well in the Garber-Wellington aquifer, three production wells in the Rush Springs aquifer, and one well in an undefined Permian-aged aquifer. All well-head samples were oxic and arsenate was the only species of arsenic in water from 10 of the 12 production wells sampled. Arsenite was measured above the laboratory reporting level in water from a production well in the Garber-Wellington aquifer and was the only arsenic species measured in water from the Arbuckle-Timbered Hills aquifer. Fluoride and uranium were the only trace elements, other than arsenic, that exceeded the maximum contaminant level for drinking water in well-head samples collected for the study. Uranium concentrations in four production wells in the Garber-Wellington aquifer ranged from 30.2 to 99 micrograms per liter exceeding the maximum contaminant level of 30 micrograms per liter for drinking water. Water from these four wells also had the largest arsenic concentrations measured in the study ranging from 30 to 124 micrograms

A Lift-Off-Tolerant Magnetic Flux Leakage Testing Method for Drill Pipes at Wellhead.

PubMed

Wu, Jianbo; Fang, Hui; Li, Long; Wang, Jie; Huang, Xiaoming; Kang, Yihua; Sun, Yanhua; Tang, Chaoqing

2017-01-21

To meet the great needs for MFL (magnetic flux leakage) inspection of drill pipes at wellheads, a lift-off-tolerant MFL testing method is proposed and investigated in this paper. Firstly, a Helmholtz coil magnetization method and the whole MFL testing scheme are proposed. Then, based on the magnetic field focusing effect of ferrite cores, a lift-off-tolerant MFL sensor is developed and tested. It shows high sensitivity at a lift-off distance of 5.0 mm. Further, the follow-up high repeatability MFL probing system is designed and manufactured, which was embedded with the developed sensors. It can track the swing movement of drill pipes and allow the pipe ends to pass smoothly. Finally, the developed system is employed in a drilling field for drill pipe inspection. Test results show that the proposed method can fulfill the requirements for drill pipe inspection at wellheads, which is of great importance in drill pipe safety.

A Lift-Off-Tolerant Magnetic Flux Leakage Testing Method for Drill Pipes at Wellhead

PubMed Central

Wu, Jianbo; Fang, Hui; Li, Long; Wang, Jie; Huang, Xiaoming; Kang, Yihua; Sun, Yanhua; Tang, Chaoqing

2017-01-01

To meet the great needs for MFL (magnetic flux leakage) inspection of drill pipes at wellheads, a lift-off-tolerant MFL testing method is proposed and investigated in this paper. Firstly, a Helmholtz coil magnetization method and the whole MFL testing scheme are proposed. Then, based on the magnetic field focusing effect of ferrite cores, a lift-off-tolerant MFL sensor is developed and tested. It shows high sensitivity at a lift-off distance of 5.0 mm. Further, the follow-up high repeatability MFL probing system is designed and manufactured, which was embedded with the developed sensors. It can track the swing movement of drill pipes and allow the pipe ends to pass smoothly. Finally, the developed system is employed in a drilling field for drill pipe inspection. Test results show that the proposed method can fulfill the requirements for drill pipe inspection at wellheads, which is of great importance in drill pipe safety. PMID:28117721

A market survey of geothermal wellhead power generation systems

NASA Technical Reports Server (NTRS)

Leeds, M. W.

1978-01-01

The market potential for a portable geothermal wellhead power conversion device is assessed. Major study objectives included identifying the most promising applications for such a system, the potential impediments confronting their industrialization, and the various government actions needed to overcome these impediments. The heart of the study was a series of structured interviews with key decision-making individual in the various disciplines of the geothermal community. In addition, some technical and economic analyses of a candidate system were performed to support the feasibility of the basic concept.

Conductor shears as iceberg encroaches

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1984-10-01

Operators in the Arctic regions must protect wellheads from encroaching icebergs and icepack sheets. Diverting ice masses and excavating large holes below scour depth is expensive. Now an alternate approach allows the conductor to shear, shuts in the well, and provides a method of re-entering the well. The new system has been successfully used by Mobil on two exploratory wells in the Hibernia field off eastern Canada. The wells used 18 3/4-in. wellheads rated at 10,000 psi with 36-in. conductor pipe. The performance of the system is discussed.

Prediction of slug-to-annular flow pattern transition (STA) for reducing the risk of gas-lift instabilities and effective gas/liquid transport from low-pressure reservoirs

DOE Office of Scientific and Technical Information (OSTI.GOV)

Toma, P.R.; Vargas, E.; Kuru, E.

Flow-pattern instabilities have frequently been observed in both conventional gas-lifting and unloading operations of water and oil in low-pressure gas and coalbed reservoirs. This paper identifies the slug-to-annular flow-pattern transition (STA) during upward gas/liquid transportation as a potential cause of flow instability in these operations. It is recommended that the slug-flow pattern be used mainly to minimize the pressure drop and gas compression work associated with gas-lifting large volumes of oil and water. Conversely, the annular flow pattern should be used during the unloading operation to produce gas with relatively small amounts of water and condensate. New and efficient artificialmore » lifting strategies are required to transport the liquid out of the depleted gas or coalbed reservoir level to the surface. This paper presents held data and laboratory measurements supporting the hypothesis that STA significantly contributes to flow instabilities and should therefore be avoided in upward gas/liquid transportation operations. Laboratory high-speed measurements of flow-pressure components under a broad range of gas-injection rates including STA have also been included to illustrate the onset of large STA-related flow-pressure oscillations. The latter body of data provides important insights into gas deliquification mechanisms and identifies potential solutions for improved gas-lifting and unloading procedures. A comparison of laboratory data with existing STA models was performed first. Selected models were then numerically tested in field situations. Effective field strategies for avoiding STA occurrence in marginal and new (offshore) field applications (i.e.. through the use of a slug or annular flow pattern regimen from the bottomhole to wellhead levels) are discussed.« less

An approach for delineating drinking water wellhead protection areas at the Nile Delta, Egypt.

PubMed

Fadlelmawla, Amr A; Dawoud, Mohamed A

2006-04-01

In Egypt, production has a high priority. To this end protecting the quality of the groundwater, specifically when used for drinking water, and delineating protection areas around the drinking water wellheads for strict landuse restrictions is essential. The delineation methods are numerous; nonetheless, the uniqueness of the hydrogeological, institutional as well as social conditions in the Nile Delta region dictate a customized approach. The analysis of the hydrological conditions and land ownership at the Nile Delta indicates the need for an accurate methodology. On the other hand, attempting to calculate the wellhead protected areas around each of the drinking wells (more than 1500) requires data, human resources, and time that exceed the capabilities of the groundwater management agency. Accordingly, a combination of two methods (simplified variable shapes and numerical modeling) was adopted. Sensitivity analyses carried out using hypothetical modeling conditions have identified the pumping rate, clay thickness, hydraulic gradient, vertical conductivity of the clay, and the hydraulic conductivity as the most significant parameters in determining the dimensions of the wellhead protection areas (WHPAs). Tables of sets of WHPAs dimensions were calculated using synthetic modeling conditions representing the most common ranges of the significant parameters. Specific WHPA dimensions can be calculated by interpolation, utilizing the produced tables along with the operational and hydrogeological conditions for the well under consideration. In order to simplify the interpolation of the appropriate dimensions of the WHPAs from the calculated tables, an interactive computer program was written. The program accepts the real time data of the significant parameters as its input, and gives the appropriate WHPAs dimensions as its output.

Groundwater methane in relation to oil and gas development and shallow coal seams in the Denver-Julesburg Basin of Colorado

PubMed Central

Sherwood, Owen A.; Rogers, Jessica D.; Lackey, Greg; Burke, Troy L.; Osborn, Stephen G.; Ryan, Joseph N.

2016-01-01

Unconventional oil and gas development has generated intense public concerns about potential impacts to groundwater quality. Specific pathways of contamination have been identified; however, overall rates of contamination remain ambiguous. We used an archive of geochemical data collected from 1988 to 2014 to determine the sources and occurrence of groundwater methane in the Denver-Julesburg Basin of northeastern Colorado. This 60,000-km2 region has a 60-y-long history of hydraulic fracturing, with horizontal drilling and high-volume hydraulic fracturing beginning in 2010. Of 924 sampled water wells in the basin, dissolved methane was detected in 593 wells at depths of 20–190 m. Based on carbon and hydrogen stable isotopes and gas molecular ratios, most of this methane was microbially generated, likely within shallow coal seams. A total of 42 water wells contained thermogenic stray gas originating from underlying oil and gas producing formations. Inadequate surface casing and leaks in production casing and wellhead seals in older, vertical oil and gas wells were identified as stray gas migration pathways. The rate of oil and gas wellbore failure was estimated as 0.06% of the 54,000 oil and gas wells in the basin (lower estimate) to 0.15% of the 20,700 wells in the area where stray gas contamination occurred (upper estimate) and has remained steady at about two cases per year since 2001. These results show that wellbore barrier failure, not high-volume hydraulic fracturing in horizontal wells, is the main cause of thermogenic stray gas migration in this oil- and gas-producing basin. PMID:27402747

DOE Office of Scientific and Technical Information (OSTI.GOV)

Dougan, P.M.

During the year, design, construction and installation of all project equipment was completed, and continuous steam injection began on September 18, 1979 and continued until February 29, 1980. In the five-month period of steam injection, 235,060 barrels of water as steam at an average wellhead pressure of 1199 psig and an average wellhead temperature of 456/sup 0/F were injected into the eight project injection wells. Operation of the project at design temperature and pressure (1000/sup 0/F and 1500 psig) was not possible due to continuing problems with surface equipment. Environmental monitoring at the project site continued during startup and operation.

Nine steps to risk-informed wellhead protection and management: Methods and application to the Burgberg Catchment

NASA Astrophysics Data System (ADS)

Nowak, W.; Enzenhoefer, R.; Bunk, T.

2013-12-01

Wellhead protection zones are commonly delineated via advective travel time analysis without considering any aspects of model uncertainty. In the past decade, research efforts produced quantifiable risk-based safety margins for protection zones. They are based on well vulnerability criteria (e.g., travel times, exposure times, peak concentrations) cast into a probabilistic setting, i.e., they consider model and parameter uncertainty. Practitioners still refrain from applying these new techniques for mainly three reasons. (1) They fear the possibly cost-intensive additional areal demand of probabilistic safety margins, (2) probabilistic approaches are allegedly complex, not readily available, and consume huge computing resources, and (3) uncertainty bounds are fuzzy, whereas final decisions are binary. The primary goal of this study is to show that these reservations are unjustified. We present a straightforward and computationally affordable framework based on a novel combination of well-known tools (e.g., MODFLOW, PEST, Monte Carlo). This framework provides risk-informed decision support for robust and transparent wellhead delineation under uncertainty. Thus, probabilistic risk-informed wellhead protection is possible with methods readily available for practitioners. As vivid proof of concept, we illustrate our key points on a pumped karstic well catchment, located in Germany. In the case study, we show that reliability levels can be increased by re-allocating the existing delineated area at no increase in delineated area. This is achieved by simply swapping delineated low-risk areas against previously non-delineated high-risk areas. Also, we show that further improvements may often be available at only low additional delineation area. Depending on the context, increases or reductions of delineated area directly translate to costs and benefits, if the land is priced, or if land owners need to be compensated for land use restrictions.

GIS technology transfer for use in private sector consulting

NASA Astrophysics Data System (ADS)

Gibas, Dawn R.; Davis, Roger J.

1996-03-01

Summit Envirosolutions, Inc. (Summit) is an EOCAP '93 company working in partnership with NASA's Commercial Remote Sensing Program to integrate the use of Geographic Information Systems (GIS) and Remote Sensing (RS) technology into our environmental consulting business. The EOCAP program has allowed us to obtain the hardware and software necessary for this technology that would have been difficult for a small company, such as Summit, to purchase outright. We are integrating GIS/RS into our consulting business in several areas including wellhead protection and environmental assessments. The major emphasis in the EOCAP project is to develop a system, termed RealFlowSM. The goals of RealFlowSM are to reduce client costs associated with environmental compliance (in particular preparation of EPA-mandated Wellhead Protection Plans), more accurately characterize aquifer parameters, provide a scientifically sound basis for delineating Wellhead Protection Areas, and readily assess changes in well field operations and potential impacts of environmental stresses. RealFlowSM utilizes real-time telemetric data, digital imagery, GIS, Global Positioning System (GPS), and field data to characterize a study area at a lower cost. In addition, we are applying this technology in other service areas and showing a reduction in the overall costs for large projects.

Probabilistic approach: back pressure turbine for geothermal vapor-dominated system

NASA Astrophysics Data System (ADS)

Alfandi Ahmad, Angga; Xaverius Guwowijoyo, Fransiscus; Pratama, Heru Berian

2017-12-01

Geothermal bussiness nowadays needs to be accelerated in a way that profit can be obtained as soon as reasonable possible. One of the many ways to do this is by using one of geothermal wellhead generating unit (GWGU), called backpressure turbine. Backpressure turbine can be used in producing electricity as soon as there is productive or rather small-scale productive well existed after finished drilling. In a vapor dominated system, steam fraction in the wellhead capable to produce electricity based on each well productivity immediately. The advantage for using vapor dominated system is reduce brine disposal in the wellhead so it will be a cost benefit in operation. The design and calculation for backpressure turbine will use probablistic approach with Monte Carlo simulation. The parameter that will be evaluated in sensitivity would be steam flow rate, turbine inlet pressure, and turbine exhaust pressure/atmospheric pressure. The result are probability for P10, P50, and P90 of gross power output which are 1.78 MWe, 2.22 MWe and 2.66 Mwe respectively. Whereas the P10, P50, and P90 of SSC are 4.67 kg/s/MWe, 5.19 kg/s/MWe and 5.78 kg/s/MWe respectively.

Transient flow conditions in probabilistic wellhead protection: importance and ways to manage spatial and temporal uncertainty in capture zone delineation

NASA Astrophysics Data System (ADS)

Enzenhoefer, R.; Rodriguez-Pretelin, A.; Nowak, W.

2012-12-01

"From an engineering standpoint, the quantification of uncertainty is extremely important not only because it allows estimating risk but mostly because it allows taking optimal decisions in an uncertain framework" (Renard, 2007). The most common way to account for uncertainty in the field of subsurface hydrology and wellhead protection is to randomize spatial parameters, e.g. the log-hydraulic conductivity or porosity. This enables water managers to take robust decisions in delineating wellhead protection zones with rationally chosen safety margins in the spirit of probabilistic risk management. Probabilistic wellhead protection zones are commonly based on steady-state flow fields. However, several past studies showed that transient flow conditions may substantially influence the shape and extent of catchments. Therefore, we believe they should be accounted for in the probabilistic assessment and in the delineation process. The aim of our work is to show the significance of flow transients and to investigate the interplay between spatial uncertainty and flow transients in wellhead protection zone delineation. To this end, we advance our concept of probabilistic capture zone delineation (Enzenhoefer et al., 2012) that works with capture probabilities and other probabilistic criteria for delineation. The extended framework is able to evaluate the time fraction that any point on a map falls within a capture zone. In short, we separate capture probabilities into spatial/statistical and time-related frequencies. This will provide water managers additional information on how to manage a well catchment in the light of possible hazard conditions close to the capture boundary under uncertain and time-variable flow conditions. In order to save computational costs, we take advantage of super-positioned flow components with time-variable coefficients. We assume an instantaneous development of steady-state flow conditions after each temporal change in driving forces, following an idea by Festger and Walter, 2002. These quasi steady-state flow fields are cast into a geostatistical Monte Carlo framework to admit and evaluate the influence of parameter uncertainty on the delineation process. Furthermore, this framework enables conditioning on observed data with any conditioning scheme, such as rejection sampling, Ensemble Kalman Filters, etc. To further reduce the computational load, we use the reverse formulation of advective-dispersive transport. We simulate the reverse transport by particle tracking random walk in order to avoid numerical dispersion to account for well arrival times.

Quantification and source identification of the Total Elgin gas leak, UK - North Sea, by aircraft sampling

NASA Astrophysics Data System (ADS)

Lee, J. D.; Bauguitte, S.; Wellpott, A.; Lowry, D.; Fisher, R. E.; Lewis, A. C.; Hopkins, J.; Allen, G.; O'Shea, S.; Lanoiselle, M.; France, J.; Lidster, R.; Punjabi, S.; Manning, A. J.; Ryerson, T. B.; Mobbs, S.; Gallagher, M. W.; Coe, H.; Pyle, J. A.; Nisbet, E. G.

2012-12-01

Aircraft measurement and air sampling have been used to quantify the source and magnitude of the North Sea Total Elgin wellhead platform gas leak in March/April 2012. Isotopic techniques were used to characterise the geological source formation from which the gas came. Initially on 30 March 2012 the leak was in the range 1.6 - 0.7 kg s-1, reducing to less than half that rate by 3 April 2012. Keeling plot analysis of methane in air samples showed that the gas had δ13CCH4 -43‰, implying that the gas source was not the main high-pressure high-temperature Elgin gas field (5.5 km deep, at 190oC) but more probably the overlying Hod Formation. The evidence in the air plume for release of very volatile NMHCs confirmed media reports that the gas leak was on the production platform, above the sea level. This contrasts with the early situation in the BP Deepwater Horizon event, where release was underwater and volatile NMHC species were taken up in the water column. Non-methane hydrocarbons (NMHC) and other volatile organic compounds in the plumes were determined from flask samples by offline analysis. NMHC content was dominated by light alkanes ranging from >20 ppb ethane to <1 ppb benzene and <0.1 ppb higher monoaromatics. The methodology developed in this work is widely applicable to future emissions of environmental concern in circumstances where direct access is difficult or dangerous, and permits unbiased regulatory assessment of potential impact, independent of the emitting party.

Industrial Raman gas sensing for real-time system control

NASA Astrophysics Data System (ADS)

Buric, M.; Mullen, J.; Chorpening, B.; Woodruff, S.

2014-06-01

Opportunities exist to improve on-line process control in energy applications with a fast, non-destructive measurement of gas composition. Here, we demonstrate a Raman sensing system which is capable of reporting the concentrations of numerous species simultaneously with sub-percent accuracy and sampling times below one-second for process control applications in energy or chemical production. The sensor is based upon a hollow-core capillary waveguide with a 300 micron bore with reflective thin-film metal and dielectric linings. The effect of using such a waveguide in a Raman process is to integrate Raman photons along the length of the sample-filled waveguide, thus permitting the acquisition of very large Raman signals for low-density gases in a short time. The resultant integrated Raman signals can then be used for quick and accurate analysis of a gaseous mixture. The sensor is currently being tested for energy applications such as coal gasification, turbine control, well-head monitoring for exploration or production, and non-conventional gas utilization. In conjunction with an ongoing commercialization effort, the researchers have recently completed two prototype instruments suitable for hazardous area operation and testing. Here, we report pre-commercialization testing of those field prototypes for control applications in gasification or similar processes. Results will be discussed with respect to accuracy, calibration requirements, gas sampling techniques, and possible control strategies of industrial significance.

“Can LUSI be stopped? - A case study and lessons learned from the relief wells”

NASA Astrophysics Data System (ADS)

Sutrisna, E.

2009-12-01

Since May 2006, in East Java, Indonesia, the LUSI mud volcano has been erupting huge volumes of mixture of predominately mud and water, with little sign of slowing down. It has disrupted social and economic life in this highly populated region. Most geologists believe LUSI is a naturally-occurring mud volcano (MV), like other MV in the Java island of particular interest are the MV along the Watukosek fault, such as, Kalang Anyar, Pulungan, Gunung Anyar, and Socah MV. All of these MV lie in the vicinity of the SSW/NNE trending Watukosek fault that passes through LUSI. The Porong collapse structure is an ancient MV closest to LUSI approx. 7 km away, which on seismic sections demonstrate its complex multi-branching plumbing system. Assuming that the mudflow passed through the wellbore due to an underground blowout, relief wells (RW) were planned to kill the mudflow and carried out in 3 stages, these were: 1. Re-entering the original Banjarpanji-1 (BJP-1) well to obtain accurate survey data so the relief wells could be steered into intersect this original well. 2. Drilling a monitoring well (M-1) to ascertain whether the soil had sufficient strength to support relief wells. 3. Drilling RW-1 and RW-2. Both RW-1 and RW-2 suffered of surface and subsurface problems never achieved their objectives and had to be aborted. Numbers of good lessons were learned from the relief well initiative, such as: 1. No gas or liquid flowed from the wellhead area when it was excavated one month after the eruption started. The wellhead remained intact and totally dead suggesting that the mud flowed to surface through a fault zone or a fracture network instead of up the wellbore. 2. The ‘fish’ in BJP-1 wellbore was found at its original location and not eroded away. This suggests that the mud flow did not pass through the wellbore. 3. The Temperature log showed lower temp. than surface mud temp. The Sonan log response was quiet. These results suggest that there was no near casing mudflow. 4. Dynamic subsurface conditions of the area with shear movement at a depth of 1,100 ft to 1,500 ft. 5. The RW-1 experienced alternate loss and kicks at a depth of around 3,200 ft. as it entered the unstable fault zone and fracture network which likely served as the mud flow conduit. Drilling in the zone of instability around the mudflow conduit cannot be avoided and is full of hazards. 6. The area suffers a dynamic geological condition. The subsidence rate at the rig site of more than 100 cm in a month. The subsidence also had a lateral component. 7. LUSI has multiple mudflow conduits as reflected in the more than 100 gas bubbles currently occurring within a radius of 1.5 km. Although the relief wells did not achieve their intended purpose to stop the mudflow, they allowed the collection of valuable data, all of which suggests that the mudflow did not originate from the BJP-1 wellbore as originally assumed. The use of relief wells to kill the mudflow is a futile attempt since in such complex plumbing system. New conduits or the two dormant mudflow centers along the fault line that appeared at the beginning of LUSI may reactivate if the currently active conduit is blocked. In conclusion, LUSI appears to be another naturally occurring MV that is impossible to kill using relief wells.

Asphalt-derived high surface area activated porous carbons for carbon dioxide capture.

PubMed

Jalilov, Almaz S; Ruan, Gedeng; Hwang, Chih-Chau; Schipper, Desmond E; Tour, Josiah J; Li, Yilun; Fei, Huilong; Samuel, Errol L G; Tour, James M

2015-01-21

Research activity toward the development of new sorbents for carbon dioxide (CO2) capture have been increasing quickly. Despite the variety of existing materials with high surface areas and high CO2 uptake performances, the cost of the materials remains a dominant factor in slowing their industrial applications. Here we report preparation and CO2 uptake performance of microporous carbon materials synthesized from asphalt, a very inexpensive carbon source. Carbonization of asphalt with potassium hydroxide (KOH) at high temperatures (>600 °C) yields porous carbon materials (A-PC) with high surface areas of up to 2780 m(2) g(-1) and high CO2 uptake performance of 21 mmol g(-1) or 93 wt % at 30 bar and 25 °C. Furthermore, nitrogen doping and reduction with hydrogen yields active N-doped materials (A-NPC and A-rNPC) containing up to 9.3% nitrogen, making them nucleophilic porous carbons with further increase in the Brunauer-Emmett-Teller (BET) surface areas up to 2860 m(2) g(-1) for A-NPC and CO2 uptake to 26 mmol g(-1) or 114 wt % at 30 bar and 25 °C for A-rNPC. This is the highest reported CO2 uptake among the family of the activated porous carbonaceous materials. Thus, the porous carbon materials from asphalt have excellent properties for reversibly capturing CO2 at the well-head during the extraction of natural gas, a naturally occurring high pressure source of CO2. Through a pressure swing sorption process, when the asphalt-derived material is returned to 1 bar, the CO2 is released, thereby rendering a reversible capture medium that is highly efficient yet very inexpensive.

Water Sources and Their Protection from the Impact of Microbial Contamination in Rural Areas of Beijing, China

PubMed Central

Ye, Bixiong; Yang, Linsheng; Li, Yonghua; Wang, Wuyi; Li, Hairong

2013-01-01

Bacterial contamination of drinking water is a major public health problem in rural China. To explore bacterial contamination in rural areas of Beijing and identify possible causes of bacteria in drinking water samples, water samples were collected from wells in ten rural districts of Beijing, China. Total bacterial count, total coliforms and Escherichia coli in drinking water were then determined and water source and wellhead protection were investigated. The bacterial contamination in drinking water was serious in areas north of Beijing, with the total bacterial count, total coliforms and Escherichia coli in some water samples reaching 88,000 CFU/mL, 1,600 MPN/100 mL and 1,600 MPN/100 mL, respectively. Water source types, well depth, whether the well was adequately sealed and housed, and whether wellhead is above or below ground were the main factors influencing bacterial contamination levels in drinking water. The bacterial contamination was serious in the water of shallow wells and wells that were not closed, had no well housing or had a wellhead below ground level. The contamination sources around wells, including village dry toilets and livestock farms, were well correlated with bacterial contamination. Total bacterial counts were affected by proximity to sewage ditches and polluting industries, however, proximity to landfills did not influence the microbial indicators. PMID:23462436

Sulfide Generation by Dominant Halanaerobium Microorganisms in Hydraulically Fractured Shales

PubMed Central

Booker, Anne E.; Borton, Mikayla A.; Daly, Rebecca A.; Welch, Susan A.; Nicora, Carrie D.; Hoyt, David W.; Wilson, Travis; Purvine, Samuel O.; Wolfe, Richard A.; Sharma, Shikha; Mouser, Paula J.; Cole, David R.; Lipton, Mary S.; Wrighton, Kelly C.

2017-01-01

ABSTRACT Hydraulic fracturing of black shale formations has greatly increased United States oil and natural gas recovery. However, the accumulation of biomass in subsurface reservoirs and pipelines is detrimental because of possible well souring, microbially induced corrosion, and pore clogging. Temporal sampling of produced fluids from a well in the Utica Shale revealed the dominance of Halanaerobium strains within the in situ microbial community and the potential for these microorganisms to catalyze thiosulfate-dependent sulfidogenesis. From these field data, we investigated biogenic sulfide production catalyzed by a Halanaerobium strain isolated from the produced fluids using proteogenomics and laboratory growth experiments. Analysis of Halanaerobium isolate genomes and reconstructed genomes from metagenomic data sets revealed the conserved presence of rhodanese-like proteins and anaerobic sulfite reductase complexes capable of converting thiosulfate to sulfide. Shotgun proteomics measurements using a Halanaerobium isolate verified that these proteins were more abundant when thiosulfate was present in the growth medium, and culture-based assays identified thiosulfate-dependent sulfide production by the same isolate. Increased production of sulfide and organic acids during the stationary growth phase suggests that fermentative Halanaerobium uses thiosulfate to remove excess reductant. These findings emphasize the potential detrimental effects that could arise from thiosulfate-reducing microorganisms in hydraulically fractured shales, which are undetected by current industry-wide corrosion diagnostics. IMPORTANCE Although thousands of wells in deep shale formations across the United States have been hydraulically fractured for oil and gas recovery, the impact of microbial metabolism within these environments is poorly understood. Our research demonstrates that dominant microbial populations in these subsurface ecosystems contain the conserved capacity for the reduction of thiosulfate to sulfide and that this process is likely occurring in the environment. Sulfide generation (also known as “souring”) is considered deleterious in the oil and gas industry because of both toxicity issues and impacts on corrosion of the subsurface infrastructure. Critically, the capacity for sulfide generation via reduction of sulfate was not detected in our data sets. Given that current industry wellhead tests for sulfidogenesis target canonical sulfate-reducing microorganisms, these data suggest that new approaches to the detection of sulfide-producing microorganisms may be necessary. PMID:28685163

Sulfide Generation by Dominant Halanaerobium Microorganisms in Hydraulically Fractured Shales

DOE Office of Scientific and Technical Information (OSTI.GOV)

Booker, Anne E.; Borton, Mikayla A.; Daly, Rebecca A.

ABSTRACT Hydraulic fracturing of black shale formations has greatly increased United States oil and natural gas recovery. However, the accumulation of biomass in subsurface reservoirs and pipelines is detrimental because of possible well souring, microbially induced corrosion, and pore clogging. Temporal sampling of produced fluids from a well in the Utica Shale revealed the dominance ofHalanaerobiumstrains within thein situmicrobial community and the potential for these microorganisms to catalyze thiosulfate-dependent sulfidogenesis. From these field data, we investigated biogenic sulfide production catalyzed by aHalanaerobiumstrain isolated from the produced fluids using proteogenomics and laboratory growth experiments. Analysis ofHalanaerobiumisolate genomes and reconstructed genomes frommore » metagenomic data sets revealed the conserved presence of rhodanese-like proteins and anaerobic sulfite reductase complexes capable of converting thiosulfate to sulfide. Shotgun proteomics measurements using aHalanaerobiumisolate verified that these proteins were more abundant when thiosulfate was present in the growth medium, and culture-based assays identified thiosulfate-dependent sulfide production by the same isolate. Increased production of sulfide and organic acids during the stationary growth phase suggests that fermentativeHalanaerobiumuses thiosulfate to remove excess reductant. These findings emphasize the potential detrimental effects that could arise from thiosulfate-reducing microorganisms in hydraulically fractured shales, which are undetected by current industry-wide corrosion diagnostics. IMPORTANCEAlthough thousands of wells in deep shale formations across the United States have been hydraulically fractured for oil and gas recovery, the impact of microbial metabolism within these environments is poorly understood. Our research demonstrates that dominant microbial populations in these subsurface ecosystems contain the conserved capacity for the reduction of thiosulfate to sulfide and that this process is likely occurring in the environment. Sulfide generation (also known as “souring”) is considered deleterious in the oil and gas industry because of both toxicity issues and impacts on corrosion of the subsurface infrastructure. Critically, the capacity for sulfide generation via reduction of sulfate was not detected in our data sets. Given that current industry wellhead tests for sulfidogenesis target canonical sulfate-reducing microorganisms, these data suggest that new approaches to the detection of sulfide-producing microorganisms may be necessary.« less

Methods for Finding Legacy Wells in Residential and Commercial Areas

DOE Office of Scientific and Technical Information (OSTI.GOV)

Hammack, Richard W.; Veloski, Garret A.

In 1919, the enthusiasm surrounding a short-lived gas play in Versailles Borough, Pennsylvania resulted in the drilling of many needless wells. The legacy of this activity exists today in the form of abandoned, unplugged gas wells that are a continuing source of fugitive methane in the midst of a residential and commercial area. Flammable concentrations of methane have been detected near building foundations, which have forced people from their homes and businesses until methane concentrations decreased. Despite mitigation efforts, methane problems persist and have caused some buildings to be permanently abandoned and demolished. This paper describes the use of magneticmore » and methane sensing methods by the National Energy Technology Laboratory (NETL) to locate abandoned gas wells in Versailles Borough where site access is limited and existing infrastructure can interfere. Here, wells are located between closely spaced houses and beneath buildings and parking lots. Wells are seldom visible, often because wellheads and internal casing strings have been removed, and external casing has been cut off below ground level. The magnetic survey of Versailles Borough identified 53 strong, monopole magnetic anomalies that are presumed to indicate the locations of steel-cased wells. This hypothesis was tested by excavating the location of one strong, monopole magnetic anomaly that was within an area of anomalous methane concentrations. The excavation uncovered an unplugged gas well that was within 0.2 m of the location of the maximum magnetic signal. Truck-mounted methane surveys of Versailles Borough detected numerous methane anomalies that were useful for narrowing search areas. Methane sources identified during truck-mounted surveys included strong methane sources such as sewers and methane mitigation vents. However, inconsistent wind direction and speed, especially between buildings, made locating weaker methane sources (such as leaking wells) difficult. Walking surveys with the methane detector mounted on a cart or wagon were more effective for detecting leaking wells because the instrument’s air inlet was near the ground where: 1) the methane concentration from subsurface sources (including wells) was a maximum, and 2) there was less displacement of methane anomalies from methane sources by air currents. The Versailles Borough survey found 15 methane anomalies that coincided with the location of well-type magnetic anomalies; the methane sources for these anomalies were assumed to be leaking wells. For abandoned well locations where the wellhead and all casing strings have been removed and there is no magnetic anomaly, leaking wellbores can sometimes be detected by methane surveys. Unlike magnetic anomalies, methane anomalies can be: 1) ephemeral, 2) significantly displaced from the well location, and 3) from non-well sources that cannot be discriminated without isotopic analysis. If methane surveys are used for well location, the air inlet to the instrument should be kept as close to the ground as possible to minimize the likelihood of detecting methane from distant, wind-blown sources.« less

Four Years of Chemical Measurements from the Deepwater Horizon Oil Spill Define the Deep Sea Sediment footprint and Subsequent Recovery

NASA Astrophysics Data System (ADS)

Boehm, P.

2016-02-01

Chemical data acquired during and after the DWHOS showed that several mechanisms were responsible for transport of oil from the water column to the sediments in the deep sea off the continental shelf. Three primary pathways were identified:Sorption onto and sinking of drilling mud particles during "Top Kill" response activity, highly scattered deposition of residuesfrom in situ burns, and deposition of oil combined with microbial organic matter from diffuse oil plumes ("marine snow"). Data collected during 2010, 2011 and 2014 were used to define the oil footprint and estimate time to recovery. More than 1200 stations were sampled. Of these, 27 stations were visited all three years, providing a time series from which recovery rates were calculated using the loss of total polycyclic aromatic hydrocarbons (TPAH) over time fit to first order kinetics. Results showed that the footprint of the oil was limited to the area around the wellhead and in patches to the southwest. Mostsamples had returned to background levels by 2015, with some exceptions close to the wellhead. Deposition to the northeast (DeSoto Canyon) was minor as evidenced by the absence of oil in sediments in that area. Samples with the longest recovery times were within 2 nautical miles of the wellhead, and often contained drilling mud, as shown by olefin signatures on the GC/FID chromatogram. Detailed chemistry data evaluation and chemical fingerprinting provided evidence that oil was being degraded in situ.

The Areal Extent of Continuous Type Gas Accumulations in Lower Silurian Clinton Sands and Medina Group Sandstones of the Appalachian Basin and the Environments Affected by Their Development

USGS Publications Warehouse

Wandrey, C.J.; Ryder, Robert T.; Nuccio, Vito F.; Aggen, Kerry L.

1997-01-01

In order to best preserve and manage our energy and natural resources we must understand the relationships between these resources and the impacts of their development. To further this understanding the U.S. Geological Survey is studying unconventional continuous-type and, to a lesser extent, conventional oil and gas accumulations and the environmental impacts associated with their development. Continuous-type gas accumulations are generally characterized by low matrix permeabilities, large areal extents, and no distinct water contacts. This basin scale map shows the overall extent of these accumulations and the general land use types that may be impacted by their development. The Appalachian Basin has the longest history of oil and gas exploration and production in the United States. Since Drake's Titusville discovery well was drilled in 1859, oil and gas has been continuously produced in the basin. While there is still a great deal of oil and gas production, new field discoveries are rare and relatively small. For most of the second half of the 20th century the Appalachian basin has been considered a mature petroleum province because most of the large plays have already been discovered and developed. One exception to this trend is the Lower Silurian Clinton Sands and Medina Group Gas play which is being developed in New York, Pennsylvania, and Ohio. This continuous-type gas play has been expanding since the early 1970's (see inset maps). In the 1980's economic incentives such as large increases in wellhead prices further stimulated continuous-type gas resource development. Continuous-type gas plays can be large in areal extent and in thickness. 'Sweetspots' (areas of greater prodcution) are hard to predict and generally associated with better than average permeabilities, and enhanced by natural fracture systems. With an overall success rate often approaching 90%, drilling most of the play with closely spaced wells is often the best way to maximize gas recovery. Some positive economic characteristics associated with the development of these continuous-type accumulations are high success rates, low drilling and development costs, and low water production, which results in low water disposal costs. Large areas within the Appalachian basin with good potential for this type of gas accumulation remain to be tested. Positive environmental characteristics include, a clean energy source, low water production, and relatively low surface impact. Some negative characteristics associated with these continuous -type accumulations are low individual well production rates and small well drainage area. Negative environmental characteristics are primarily related to the dense well spacing used to develop the resource to its full potential. Often negative environmental impacts such as surface disturbance can be greatly reduced. The number of well sites can be decreased by using a single centrally located surface location and associated facilities for several directionally or horizonatally drilled wells. This also minimizes the transportation infrastructure (access roads and pipelines) required to maintain the wells and deliver the gas. Visual impacts can be reduced by selecting well locations visible only over short distances. While the prospective area is large, potential decreases basin- ward and toward the northeast and southwest. These areas are represented by the lower potential plays 6727, 6730, and 6731. The U.S. Geological Survey landuse and landcover data was derived from USGS 1:250,000 and 1:100,000 scale maps. This information was collected between the mid 1970s to mid 1980s. The land use and land cover data was mapped and coded using the Anderson classification system (Anderson, 1975) which is a hierarchical system of general (level 1) to more specific (level 2) characterization. Level 1 characterization was used for this map; the land use and land cover designations are displayed below in the Explanation. T

Experimental determination of methane dissolution from simulated subsurface oil leakages

NASA Astrophysics Data System (ADS)

Sauthoff, W.; Peltzer, E. T.; Walz, P. M.; Brewer, P. G.

2013-12-01

Subsurface oil leakages and increased offshore drilling efforts have raised concern over the fate of hydrocarbon mixtures of oil and gas in ocean environments. Recent wellhead and pipeline failures in the Gulf of Mexico are extreme examples of this problem. Understanding the mechanism and rate of vertical transport of hydrocarbon chemical species is necessary to predict the environmental impact of subsurface leakages. In a series of controlled experiments, we carried out a deep-sea field experiment in Monterey Canyon to investigate the behavior of a gas-saturated liquid hydrocarbon mass rising from the seafloor. Aboard the R/V Rachel Carson, we used the ROV Ventana to transport a laboratory prepared volume of decane (C10H22) saturated with methane gas (CH4) to mimic a subsurface seafloor discharge. We released the oil and gas mixture into a vertically oriented open bottom glass tube followed by methane loss rate measurements both at discrete depths, and during rapid, continuous vehicle ascent from 800 to 100 m water depth to monitor changes in dissolution and bubble nucleation. Using laser Raman techniques and HD video we quantified the chemical state of the hydrocarbon fluid, including rate of methane gas dissolution. The primary methane Raman peak was readily observable within the decane C-H stretching complex. Variation in the amount of gas dissolved in the oil greatly influences oil plume density and in turn oil plume vertical rise rate. Our results show that the rise rate of the hydrocarbon mass significantly exceeds the rate at which the excess methane was lost by dissolution. This result implies that vertical transport of methane in the saturated hydrocarbon liquid phase can greatly exceed a gas bubble plume ascending the water column from a seafloor source. These results and observations may be applicable to improved understanding of the composition, distribution, and environmental fate of leaked hydrocarbon mixtures and inform remediation efforts.

40 CFR 147.2920 - Operating requirements for wells authorized by permit.

Code of Federal Regulations, 2011 CFR

2011-07-01

.... (c) Injection pressure at the wellhead shall be limited so that it does not initiate new fractures or propagate existing fractures in the confining zone adjacent to any UDSW. (d) Injection wells or projects...

40 CFR 147.2920 - Operating requirements for wells authorized by permit.

Code of Federal Regulations, 2012 CFR

2012-07-01

.... (c) Injection pressure at the wellhead shall be limited so that it does not initiate new fractures or propagate existing fractures in the confining zone adjacent to any UDSW. (d) Injection wells or projects...

40 CFR 147.2920 - Operating requirements for wells authorized by permit.

Code of Federal Regulations, 2013 CFR

2013-07-01

.... (c) Injection pressure at the wellhead shall be limited so that it does not initiate new fractures or propagate existing fractures in the confining zone adjacent to any UDSW. (d) Injection wells or projects...

40 CFR 147.2920 - Operating requirements for wells authorized by permit.

Code of Federal Regulations, 2014 CFR

2014-07-01

.... (c) Injection pressure at the wellhead shall be limited so that it does not initiate new fractures or propagate existing fractures in the confining zone adjacent to any UDSW. (d) Injection wells or projects...

Preliminary assessment of the velocity pump reaction turbine as a geothermal total-flow expander

NASA Astrophysics Data System (ADS)

Demuth, O. J.

1984-06-01

The velocity pump reaction turbine (VPRT) was evaluated as a total flow expander in a geothermal-electric conversion cycle. Values of geofluid effectiveness of VPRT systems were estimated for conditions consisting of: a 360(F) geothermal resource, 60 F wet-bulb ambient temperature, zero and 0.003 mass concentrations of dissolved noncondensible gas in the geofluid, 100 and 120 F condensing temperatures, and engine efficiencies ranging from 0.4 to 1.0. Achievable engine efficiencies were estimated to range from 0.77, with plant geofluid effectiveness values ranging as high as 9.5 watt hr-lbm geofluid for the 360 F resource temperature. This value is competitive with magnitudes of geofluid effectiveness projected for advanced binary plants, and is on the order of 40% higher than estimates for dual-flash steam and other total flow systems reviewed. Because of its potentially high performance and relative simplicity, the VPRT system appears to warrant further investigation toward its use in a well-head geothermal plant.

Lateral instability of high temperature pipelines, the 20-in. Sleipner Vest pipeline

DOE Office of Scientific and Technical Information (OSTI.GOV)

Saevik, S.; Levold, E.; Johnsen, O.K.

1996-12-01

The present paper addresses methods to control snaking behavior of high temperature pipelines resting on a flat sea bed. A case study is presented based on the detail engineering of the 12.5 km long 20 inch gas pipeline connecting the Sleipner Vest wellhead platform to the Sleipner T processing platform in the North Sea. The study includes screening and evaluation of alternative expansion control methods, ending up with a recommended method. The methodology and philosophy, used as basis to ensure sufficient structural strength throughout the lifetime of the pipeline, are thereafter presented. The results show that in order to findmore » the optimum technical solution to control snaking behavior, many aspects need to be considered such as process requirements, allowable strain, hydrodynamic stability, vertical profile, pipelay installation and trawlboard loading. It is concluded that by proper consideration of all the above aspects, the high temperature pipeline can be designed to obtain sufficient safety level.« less

Impacts of the Deepwater Horizon oil spill on deep-sea coral-associated sediment communities

USGS Publications Warehouse

Demopoulos, Amanda W.J.; Bourque, Jill R.; Cordes, Erik E.; Stamler, Katherine

2016-01-01

Cold-water corals support distinct populations of infauna within surrounding sediments that provide vital ecosystem functions and services in the deep sea. Yet due to their sedentary existence, infauna are vulnerable to perturbation and contaminant exposure because they are unable to escape disturbance events. While multiple deep-sea coral habitats were injured by the 2010 Deepwater Horizon (DWH) oil spill, the extent of adverse effects on coral-associated sediment communities is unknown. In 2011, sediments were collected adjacent to several coral habitats located 6 to 183 km from the wellhead in order to quantify the extent of impact of the DWH spill on infaunal communities. Higher variance in macrofaunal abundance and diversity, and different community structure (higher multivariate dispersion) were associated with elevated hydrocarbon concentrations and contaminants at sites closest to the wellhead (MC294, MC297, and MC344), consistent with impacts from the spill. In contrast, variance in meiofaunal diversity was not significantly related to distance from the wellhead and no other community metric (e.g. density or multivariate dispersion) was correlated with contaminants or hydrocarbon concentrations. Concentrations of polycyclic aromatic hydrocarbons (PAH) provided the best statistical explanation for observed macrofaunal community structure, while depth and presence of fine-grained mud best explained meiofaunal community patterns. Impacts associated with contaminants from the DWH spill resulted in a patchwork pattern of infaunal community composition, diversity, and abundance, highlighting the role of variability as an indicator of disturbance. These data represent a useful baseline for tracking post-spill recovery of these deep-sea communities.

30 CFR 250.518 - What are the requirements for casing pressure management?

Code of Federal Regulations, 2010 CFR

2010-07-01

...? Once you install your wellhead, you must meet the casing pressure management requirements of API RP 90... there is a conflict between API RP 90 and the casing pressure requirements of this subpart, you must...

Fugitive methane emissions from natural, urban, agricultural, and energy-production landscapes of eastern Australia

NASA Astrophysics Data System (ADS)

Kelly, Bryce F. J.; Iverach, Charlotte P.; Lowry, Dave; Fisher, Rebecca E.; France, James L.; Nisbet, Euan G.

2015-04-01

Modern cavity ringdown spectroscopy systems (CRDS) enable the continuous measurement of methane concentration. This allows for improved quantification of greenhouse gas emissions associated with various natural and human landscapes. We present a subset of over 4000 km of continuous methane surveying along the east coast of Australia, made using a Picarro G2301 CRDS, deployed in a utility vehicle with an air inlet above the roof at 2.2 mAGL. Measurements were made every 5 seconds to a precision of <0.5 ppb for CH4. These surveys were undertaken during dry daytime hours and all measurements were moisture corrected. We compare the concentration of methane in the near surface atmosphere adjacent to open-cut coal mines, unconventional gas developments (coal seam gas; CSG), and leaks detected in cities and country towns. In areas of dryland crops the median methane concentration was 1.78 ppm, while in the irrigation districts located on vertisol soils the concentration was as low as 1.76 ppm, which may indicate that these soils are a sink for methane. In the Hunter Valley, New South Wales, open-cut coal mining district we mapped a continuous 50 km interval where the concentration of methane exceeded 1.80 ppm. The median concentration in this interval was 2.02 ppm. Peak readings were beyond the range of the reliable measurement (in excess of 3.00 ppm). This extended plume is an amalgamation of plumes from 17 major pits 1 to 10 km in length. Adjacent to CSG developments in the Surat Basin, southeast Queensland, only small anomalies were detected near the well-heads. Throughout the vast majority of the gas fields the concentration of methane was below 1.80 ppm. The largest source of fugitive methane associated with CSG was off-gassing methane from the co-produced water holding ponds. At one location the down wind plume had a cross section of approximately 1 km where the concentration of methane was above 1.80 ppm. The median concentration within this section was 1.82 ppm, with a peak reading of 2.11 ppm. The ambient air methane concentration was always higher in urban environments compared to the surrounding countryside. Along one major road in Sydney we mapped an interval that extended for 6 km where the concentration was greater than 1.80 ppm. The median concentration in this interval was 1.90 ppm, with a peak reading of 1.97 ppm. This high reading in an urban setting is most likely due to leaks from the domestic gas distribution system. Methane leaks were detected in all country towns. Our measurements show that at the point of resource extraction the methane emission footprint of CSG is smaller than that of open-cut coal mining. However, leaking gas from urban centers must be added to the fugitive emissions of CSG to calculate the total fugitive emission footprint of CSG, which may therefore not be as low as claimed in the national greenhouse gas accounts. Our results highlight the need for additional continuous monitoring of methane emissions from all sectors, and for the full life-cycle of energy resources to be considered.

Linking Effective Project Management to Business Strategy in Oil and Gas Industry through Decision-making Processes

NASA Astrophysics Data System (ADS)

Adeleke, Adeyinka

The construction project in the oil and gas industry covers the entire spectrum of hydrocarbon production from the wellhead (upstream) to downstream facilities. In each of these establishments, the activities in a construction project include: consulting, studies, front-end engineering, detail engineering, procurement, program management, construction, installation, commissioning and start-up. Efficient management of each of the activities involved in construction projects is one of the driving forces for the successful completion of the project. Optimizing the crucial factors in project management during each phase of a project in an oil and gas industry can assist managers to maximize the use of available resources and drive the project to successful conclusions. One of these factors is the decision-making process in the construction project. Current research effort investigated the relationship between decision-making processes and business strategy in oil and gas industry using employee surveys. I recruited employees of different races, age group, genders, and years of experience in order understand their influence on the implementation of the decision-making process in oil and gas industry through a quantitative survey. Decision-making was assessed using five decision measures: (a) rational, (b) intuitive, (c) dependent, (d) avoidant, and (e) spontaneous. The findings indicated gender, age, years of work experience and job titles as primary variables with a negative relationship with decision-making approach for employees working in a major oil and gas industry. The study results revealed that the two most likely decision-making methods in oil and gas industry include: making a decision in a logical and systematic way and seek assistance from others when making a decision. Additionally, the two leading management approaches to decision-making in the oil and gas industry include: decision analysis is part of organization culture and management is committed to the decision-making process. Some recommendations for future studies were presented based on the need to intensify the importance of the current study and enlarge the body of knowledge regarding decision-making process in oil and gas industry.

Atmospheric and soil-gas monitoring for surface leakage at the San Juan Basin CO{sub 2} pilot test site at Pump Canyon New Mexico, using perfluorocarbon tracers, CO{sub 2} soil-gas flux and soil-gas hydrocarbons

DOE Office of Scientific and Technical Information (OSTI.GOV)

Wells, Arthur W; Diehl, J Rodney; Strazisar, Brian R

2012-05-01

Near-surface monitoring and subsurface characterization activities were undertaken in collaboration with the Southwest Regional Carbon Sequestration Partnership on their San Juan Basin coal-bed methane pilot test site near Navajo City, New Mexico. Nearly 18,407 short tons (1.670 × 107 kg) of CO{sub 2} were injected into 3 seams of the Fruitland coal between July 2008 and April 2009. Between September 18 and October 30, 2008, two additions of approximately 20 L each of perfluorocarbon (PFC) tracers were mixed with the CO{sub 2} at the injection wellhead. PFC tracers in soil-gas and in the atmosphere were monitored over a period ofmore » 2 years using a rectangular array of permanent installations. Additional monitors were placed near existing well bores and at other locations of potential leakage identified during the pre-injection site survey. Monitoring was conducted using sorbent containing tubes to collect any released PFC tracer from soil-gas or the atmosphere. Near-surface monitoring activities also included CO{sub 2} surface flux and carbon isotopes, soil-gas hydrocarbon levels, and electrical conductivity in the soil. The value of the PFC tracers was demonstrated when a significant leakage event was detected near an offset production well. Subsurface characterization activities, including 3D seismic interpretation and attribute analysis, were conducted to evaluate reservoir integrity and the potential that leakage of injected CO{sub 2} might occur. Leakage from the injection reservoir was not detected. PFC tracers made breakthroughs at 2 of 3 offset wells which were not otherwise directly observable in produced gases containing 20–30% CO{sub 2}. These results have aided reservoir geophysical and simulation investigations to track the underground movement of CO{sub 2}. 3D seismic analysis provided a possible interpretation for the order of appearance of tracers at production wells.« less

USING PLANTS TO REMEDIATE PETROLEUM-CONTAMINATED SOIL: PROJECT CONTINUATION

EPA Science Inventory

Crude oil contamination of soil often occurs adjacent to wellheads and storage facilities. Phytoremediation is a promising tool that can be used to remediate such sites and uses plants and agronomic techniques to enhance biodegradation of hydrocarbons. This project has conduct...

30 CFR 250.1603 - Determination of sulphur deposit.

Code of Federal Regulations, 2011 CFR

2011-07-01

... 30 Mineral Resources 2 2011-07-01 2011-07-01 false Determination of sulphur deposit. 250.1603 Section 250.1603 Mineral Resources BUREAU OF OCEAN ENERGY MANAGEMENT, REGULATION, AND ENFORCEMENT..., after completion of the wells, of producing minerals at the wellheads). (b) A determination under...

DEMONSTRATION OF THE ANALYTIC ELEMENT METHOD FOR WELLHEAD PROTECTION

EPA Science Inventory

A new computer program has been developed to determine time-of-travel capture zones in relatively simple geohydrological settings. The WhAEM package contains an analytic element model that uses superposition of (many) closed form analytical solutions to generate a ground-water fl...

Comparison of geothermal power conversion cycles

NASA Technical Reports Server (NTRS)

Elliott, D. G.

1976-01-01

Geothermal power conversion cycles are compared with respect to recovery of the available wellhead power. The cycles compared are flash steam, in which steam turbines are driven by steam separated from one or more flash stages; binary, in which heat is transferred from the brine to an organic turbine cycle; flash binary, in which heat is transferred from flashed steam to an organic turbine cycle; and dual steam, in which two-phase expanders are driven by the flashing steam-brine mixture and steam turbines by the separated steam. Expander efficiencies assumed are 0.7 for steam turbines, 0.8 for organic turbines, and 0.6 for two-phase expanders. The fraction of available wellhead power delivered by each cycle is found to be about the same at all brine temperatures: 0.65 with one stage and 0.7 with four stages for dual stream; 0.4 with one stage and 0.6 with four stages for flash steam; 0.5 for binary; and 0.3 with one stage and 0.5 with four stages for flash binary.

30 CFR 250.1603 - Determination of sulphur deposit.

Code of Federal Regulations, 2013 CFR

2013-07-01

... 30 Mineral Resources 2 2013-07-01 2013-07-01 false Determination of sulphur deposit. 250.1603 Section 250.1603 Mineral Resources BUREAU OF SAFETY AND ENVIRONMENTAL ENFORCEMENT, DEPARTMENT OF THE... of the wells, of producing minerals at the wellheads). (b) A determination under paragraph (a) of...

30 CFR 250.1603 - Determination of sulphur deposit.

Code of Federal Regulations, 2010 CFR

2010-07-01

... 30 Mineral Resources 2 2010-07-01 2010-07-01 false Determination of sulphur deposit. 250.1603 Section 250.1603 Mineral Resources MINERALS MANAGEMENT SERVICE, DEPARTMENT OF THE INTERIOR OFFSHORE OIL... the wells, of producing minerals at the wellheads). (b) A determination under paragraph (a) of this...

30 CFR 250.1603 - Determination of sulphur deposit.

Code of Federal Regulations, 2012 CFR

2012-07-01

... 30 Mineral Resources 2 2012-07-01 2012-07-01 false Determination of sulphur deposit. 250.1603 Section 250.1603 Mineral Resources BUREAU OF SAFETY AND ENVIRONMENTAL ENFORCEMENT, DEPARTMENT OF THE... of the wells, of producing minerals at the wellheads). (b) A determination under paragraph (a) of...

30 CFR 250.1603 - Determination of sulphur deposit.

Code of Federal Regulations, 2014 CFR

2014-07-01

... 30 Mineral Resources 2 2014-07-01 2014-07-01 false Determination of sulphur deposit. 250.1603 Section 250.1603 Mineral Resources BUREAU OF SAFETY AND ENVIRONMENTAL ENFORCEMENT, DEPARTMENT OF THE... of the wells, of producing minerals at the wellheads). (b) A determination under paragraph (a) of...

DEMONSTRATION OF THE ANALYTIC ELEMENT METHOD FOR WELLHEAD PROJECTION - PROJECT SUMMARY

EPA Science Inventory

A new computer program has been developed to determine time-of-travel capture zones in relatively simple geohydrological settings. The WhAEM package contains an analytic element model that uses superposition of (many) closed form analytical solutions to generate a ground-water fl...

40 CFR 435.41 - Specialized definitions.

Code of Federal Regulations, 2011 CFR

2011-07-01

... separation even if located separately from wellheads. (dd) Sanitary waste means the human body waste... means the water area and water body floor beneath any exploratory, development, or production facility... preparing an area of the water body floor for the purpose of constructing or placing a development or...

Sustained in situ measurements of dissolved oxygen, methane and water transport processes in the benthic boundary layer at MC118, northern Gulf of Mexico

NASA Astrophysics Data System (ADS)

Martens, Christopher S.; Mendlovitz, Howard P.; Seim, Harvey; Lapham, Laura; D'Emidio, Marco

2016-07-01

Within months of the BP Macondo Wellhead blowout, elevated methane concentrations within the water column revealed a significant retention of light hydrocarbons in deep waters plus corresponding dissolved oxygen (DO) deficits. However, chemical plume tracking efforts were hindered by a lack of in situ monitoring capabilities. Here, we describe results from in situ time-series, lander-based investigations of physical and biogeochemical processes controlling dissolved oxygen, and methane at Mississippi Canyon lease block 118 ( 18 km from the oil spill) conducted shortly after the blowout through April 2012. Multiple sensor arrays plus open-cylinder flux chambers (;chimneys;) deployed from a benthic lander collected oxygen, methane, pressure, and current speed and direction data within one meter of the seafloor. The ROVARD lander system was deployed for an initial 21-day test experiment (9/13/2010-10/04/2010) at 882 m depth before a longer 160-day deployment (10/24/2011-4/01/2012) at 884 m depth. Temporal variability in current directions and velocities and water temperatures revealed strong influences of bathymetrically steered currents and overlying along-shelf flows on local and regional water transport processes. DO concentrations and temperature were inversely correlated as a result of water mass mixing processes. Flux chamber measurements during the 160-day deployment revealed total oxygen utilization (TOU) averaging 11.6 mmol/m2 day. Chimney DO concentrations measured during the 21-day deployment exhibited quasi-daily variations apparently resulting from an interaction between near inertial waves and the steep topography of an elevated scarp immediately adjacent to the 21-day deployment site that modulated currents at the top of the chimney. Variability in dissolved methane concentrations suggested significant temporal variability in gas release from nearby hydrocarbon seeps and/or delivery by local water transport processes. Free-vehicle (lander) monitoring over time scales of months to years utilizing in situ sensors can provide an understanding of processes controlling water transport, respiration and the fate and impacts of accidental and natural gas and oil releases.

Indicators used to monitor subsurface oil during the Deepwater Horizon Event

EPA Science Inventory

The Gulf of Mexico Deepwater Horizon oil spill was the largest accidental marine spill in the history of the petroleum industry. The spill was also unprecedented due to the extreme depth of the wellhead leak within the ocean, posing unique challenges to the monitoring efforts, w...

WHAEM: PROGRAM DOCUMENTATION FOR THE WELLHEAD ANALYTIC ELEMENT MODEL (EPA/600/SR-94/210)

EPA Science Inventory

A new computer program has been developed to determine time-of-travel capture zones in relatively simple geohydrological settings. The WhAEM package contains an analytic element model that uses superposition of (many) closed form analytical solutions to generate a groundwater flo...

40 CFR Appendix F to Part 112 - Facility-Specific Response Plan

Code of Federal Regulations, 2014 CFR

2014-07-01

... into a wellhead protection area as defined by the Safe Drinking Water Act of 1986 (SDWA). 1 The...) Water intakes (drinking, cooling, or other); (2) Schools; (3) Medical facilities; (4) Residential areas... discharge; (2) Proximity to downgradient wells, waterways, and drinking water intakes; (3) Proximity to fish...

30 CFR 250.618 - Tubing and wellhead equipment.

Code of Federal Regulations, 2011 CFR

2011-07-01

... following requirements during well-workover operations with the tree removed: (a) No tubing string shall be... pressure integrity and is otherwise suitable for its intended use. (b) In the event of prolonged operations... Manager. (c) When reinstalling the tree, you must: (1) Equip wells to monitor for casing pressure...

Toxiological Considerations in the Gulf of Mexico Oil Spill

EPA Science Inventory

The Deep Water Horizon oil rig exploded on April 20, 2010, resulting in an ongoing release of light sweet petroleum crude oil and methane into Gulf of Mexico waters. The release from the deepwater wellhead 41 miles from Louisiana is at approximately 1 mile depth, and flow rates e...

DOE Office of Scientific and Technical Information (OSTI.GOV)

Lucia M. Petkovic; Daniel M. Ginosar

Since the year 2000, the United States Patent and Trademark Office (USPTO) has granted a dozen patents for inventions related to methane dehydroaromatization processes. One of them was granted to UOP LLC (Des Plaines). It relates to a catalyst composition and preparation method. Two patents were granted to Conoco Phillips Company (Houston, TX). One was aimed at securing a process and operating conditions for methane aromatization. The other was aimed at securing a process that may be integrated with separation of wellhead fluids and blending of the aromatics produced from the gas with the crude. Nine patents were granted tomore » ExxonMobil Chemical Patents Inc. (Houston, TX). Most of these were aimed at securing a dehydroaromatization process where methane-containing feedstock moves counter currently to a particulate catalyst. The coked catalyst is heated or regenerated either in the reactor, by cyclic operation, or in annex equipment, and returned to the reactor. The reactor effluent stream may be separated in its main components and used or recycled as needed. A brief summary of those inventions is presented in this review.« less

75 FR 13524 - Northern Natural Gas Company, Southern Natural Gas Company, Florida Gas Transmission Company, LLC...

Federal Register 2010, 2011, 2012, 2013, 2014

2010-03-22

... Natural Gas Company, Southern Natural Gas Company, Florida Gas Transmission Company, LLC, Transcontinental... notice that on March 5, 2010, Northern Natural Gas Company (Northern Natural), 1111 South 103rd Street, Omaha, Nebraska 68124- 1000, filed on behalf of itself and other owners, Southern Natural Gas Company...

Flow rate and source reservoir identification from airborne chemical sampling of the uncontrolled Elgin platform gas release

NASA Astrophysics Data System (ADS)

Lee, James D.; Mobbs, Stephen D.; Wellpott, Axel; Allen, Grant; Bauguitte, Stephane J.-B.; Burton, Ralph R.; Camilli, Richard; Coe, Hugh; Fisher, Rebecca E.; France, James L.; Gallagher, Martin; Hopkins, James R.; Lanoiselle, Mathias; Lewis, Alastair C.; Lowry, David; Nisbet, Euan G.; Purvis, Ruth M.; O'Shea, Sebastian; Pyle, John A.; Ryerson, Thomas B.

2018-03-01

An uncontrolled gas leak from 25 March to 16 May 2012 led to evacuation of the Total Elgin wellhead and neighbouring drilling and production platforms in the UK North Sea. Initially the atmospheric flow rate of leaking gas and condensate was very poorly known, hampering environmental assessment and well control efforts. Six flights by the UK FAAM chemically instrumented BAe-146 research aircraft were used to quantify the flow rate. The flow rate was calculated by assuming the plume may be modelled by a Gaussian distribution with two different solution methods: Gaussian fitting in the vertical and fitting with a fully mixed layer. When both solution methods were used they compared within 6 % of each other, which was within combined errors. Data from the first flight on 30 March 2012 showed the flow rate to be 1.3 ± 0.2 kg CH4 s-1, decreasing to less than half that by the second flight on 17 April 2012. δ13CCH4 in the gas was found to be -43 ‰, implying that the gas source was unlikely to be from the main high pressure, high temperature Elgin gas field at 5.5 km depth, but more probably from the overlying Hod Formation at 4.2 km depth. This was deemed to be smaller and more manageable than the high pressure Elgin field and hence the response strategy was considerably simpler. The first flight was conducted within 5 days of the blowout and allowed a flow rate estimate within 48 h of sampling, with δ13CCH4 characterization soon thereafter, demonstrating the potential for a rapid-response capability that is widely applicable to future atmospheric emissions of environmental concern. Knowledge of the Elgin flow rate helped inform subsequent decision making. This study shows that leak assessment using appropriately designed airborne plume sampling strategies is well suited for circumstances where direct access is difficult or potentially dangerous. Measurements such as this also permit unbiased regulatory assessment of potential impact, independent of the emitting party, on timescales that can inform industry decision makers and assist rapid-response planning by government.

30 CFR 250.617 - Tubing and wellhead equipment.

Code of Federal Regulations, 2010 CFR

2010-07-01

...-workover operations with the tree removed: (a) No tubing string shall be placed in service or continue to... the tree, you must: (1) Equip wells to monitor for casing pressure according to the following chart... surface casing head, a surface tubing head, a surface tubing hanger, and a surface christmas tree. (2...

Eighteenth annual offshore technology conference. Volume 1

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1986-01-01

These sixty papers were given at a conference on offshore technology. Topics covered include friction effects of driving piles into sea beds of various compositions, wave forces on offshore platforms, stability, materials testing of various components such as plates, legs, wellheads, pipe joints, and protection of offshore platforms against ice and collision with icebergs.

30 CFR 250.619 - Tubing and wellhead equipment.

Code of Federal Regulations, 2013 CFR

2013-07-01

... during well-workover operations with the tree removed: (a) No tubing string shall be placed in service or... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... the tree, you must: (1) Equip wells to monitor for casing pressure according to the following chart...

30 CFR 250.618 - Tubing and wellhead equipment.

Code of Federal Regulations, 2012 CFR

2012-07-01

... during well-workover operations with the tree removed: (a) No tubing string shall be placed in service or... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... the tree, you must: (1) Equip wells to monitor for casing pressure according to the following chart...

30 CFR 250.619 - Tubing and wellhead equipment.

Code of Federal Regulations, 2014 CFR

2014-07-01

... during well-workover operations with the tree removed: (a) No tubing string shall be placed in service or... otherwise suitable for its intended use. (b) In the event of prolonged operations such as milling, fishing... the tree, you must: (1) Equip wells to monitor for casing pressure according to the following chart...

Tribal water utility management

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1993-03-01

Contents: primacy program (what is primacy, advantages and disadvantages, treatment as a state, grant applications and funding); safe drinking water act (sampling requirements, coliform standard, public notification, surface water treatment rule impacts, uic and wellhead protection programs, lead/copper rule); water utility management (how is the utility program evaluated, who's responsible, what is the board and tribal council role).

30 CFR 250.154 - What identification signs must I display?

Code of Federal Regulations, 2010 CFR

2010-07-01

... depicted on OCS Official Protraction Diagrams or leasing maps; (iii) In the Pacific OCS Region, list the... lease number individually on the well flowline at the wellhead; and (3) For subsea wells that flow... flow into a common pipeline or pipelines, no sign is required. Right-of-use and Easement ...

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

This paper reports on Amoco's Yombo offshore oil field development on Marine I permit which is well under way with installation of decks on two wellhead platforms. Initial production from the field has begun at about 6,000 bopd. With production estimated to be 40,000 bopd by early 1992, it will bring Congo's total production to more than 200,000 bopd.

SPR Hydrostatic Column Model Verification and Validation.

DOE Office of Scientific and Technical Information (OSTI.GOV)

Bettin, Giorgia; Lord, David; Rudeen, David Keith

2015-10-01

A Hydrostatic Column Model (HCM) was developed to help differentiate between normal "tight" well behavior and small-leak behavior under nitrogen for testing the pressure integrity of crude oil storage wells at the U.S. Strategic Petroleum Reserve. This effort was motivated by steady, yet distinct, pressure behavior of a series of Big Hill caverns that have been placed under nitrogen for extended period of time. This report describes the HCM model, its functional requirements, the model structure and the verification and validation process. Different modes of operation are also described, which illustrate how the software can be used to model extendedmore » nitrogen monitoring and Mechanical Integrity Tests by predicting wellhead pressures along with nitrogen interface movements. Model verification has shown that the program runs correctly and it is implemented as intended. The cavern BH101 long term nitrogen test was used to validate the model which showed very good agreement with measured data. This supports the claim that the model is, in fact, capturing the relevant physical phenomena and can be used to make accurate predictions of both wellhead pressure and interface movements.« less

40 CFR 307.14 - Definitions.

Code of Federal Regulations, 2013 CFR

2013-07-01

... natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). National Contingency Plan, or NCP means the National Oil and... under section 101(14)(A) through (F) of the Act, nor does it include natural gas, liquefied natural gas...

40 CFR 307.14 - Definitions.

Code of Federal Regulations, 2010 CFR

2010-07-01

... natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). National Contingency Plan, or NCP means the National Oil and... under section 101(14)(A) through (F) of the Act, nor does it include natural gas, liquefied natural gas...

40 CFR 307.14 - Definitions.

Code of Federal Regulations, 2012 CFR

2012-07-01

... natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). National Contingency Plan, or NCP means the National Oil and... under section 101(14)(A) through (F) of the Act, nor does it include natural gas, liquefied natural gas...

40 CFR 307.14 - Definitions.

Code of Federal Regulations, 2011 CFR

2011-07-01

... natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). National Contingency Plan, or NCP means the National Oil and... under section 101(14)(A) through (F) of the Act, nor does it include natural gas, liquefied natural gas...

40 CFR 307.14 - Definitions.

Code of Federal Regulations, 2014 CFR

2014-07-01

... natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). National Contingency Plan, or NCP means the National Oil and... under section 101(14)(A) through (F) of the Act, nor does it include natural gas, liquefied natural gas...

Distinct Bacterial Communities in Surficial Seafloor Sediments Following the 2010 Deepwater Horizon Blowout.

PubMed

Yang, Tingting; Speare, Kelly; McKay, Luke; MacGregor, Barbara J; Joye, Samantha B; Teske, Andreas

2016-01-01

A major fraction of the petroleum hydrocarbons discharged during the 2010 Macondo oil spill became associated with and sank to the seafloor as marine snow flocs. This sedimentation pulse induced the development of distinct bacterial communities. Between May 2010 and July 2011, full-length 16S rRNA gene clone libraries demonstrated bacterial community succession in oil-polluted sediment samples near the wellhead area. Libraries from early May 2010, before the sedimentation event, served as the baseline control. Freshly deposited oil-derived marine snow was collected on the surface of sediment cores in September 2010, and was characterized by abundantly detected members of the marine Roseobacter cluster within the Alphaproteobacteria. Samples collected in mid-October 2010 closest to the wellhead contained members of the sulfate-reducing, anaerobic bacterial families Desulfobacteraceae and Desulfobulbaceae within the Deltaproteobacteria, suggesting that the oil-derived sedimentation pulse triggered bacterial oxygen consumption and created patchy anaerobic microniches that favored sulfate-reducing bacteria. Phylotypes of the polycyclic aromatic hydrocarbon-degrading genus Cycloclasticus, previously found both in surface oil slicks and the deep hydrocarbon plume, were also found in oil-derived marine snow flocs sedimenting on the seafloor in September 2010, and in surficial sediments collected in October and November 2010, but not in any of the control samples. Due to the relative recalcitrance and stability of polycyclic aromatic compounds, Cycloclasticus represents the most persistent microbial marker of seafloor hydrocarbon deposition that we could identify in this dataset. The bacterial imprint of the DWH oil spill had diminished in late November 2010, when the bacterial communities in oil-impacted sediment samples collected near the Macondo wellhead began to resemble their pre-spill counterparts and spatial controls. Samples collected in summer of 2011 did not show a consistent bacterial community signature, suggesting that the bacterial community was no longer shaped by the DWH fallout of oil-derived marine snow, but instead by location-specific and seasonal factors.

Distinct Bacterial Communities in Surficial Seafloor Sediments Following the 2010 Deepwater Horizon Blowout

PubMed Central

Yang, Tingting; Speare, Kelly; McKay, Luke; MacGregor, Barbara J.; Joye, Samantha B.; Teske, Andreas

2016-01-01

A major fraction of the petroleum hydrocarbons discharged during the 2010 Macondo oil spill became associated with and sank to the seafloor as marine snow flocs. This sedimentation pulse induced the development of distinct bacterial communities. Between May 2010 and July 2011, full-length 16S rRNA gene clone libraries demonstrated bacterial community succession in oil-polluted sediment samples near the wellhead area. Libraries from early May 2010, before the sedimentation event, served as the baseline control. Freshly deposited oil-derived marine snow was collected on the surface of sediment cores in September 2010, and was characterized by abundantly detected members of the marine Roseobacter cluster within the Alphaproteobacteria. Samples collected in mid-October 2010 closest to the wellhead contained members of the sulfate-reducing, anaerobic bacterial families Desulfobacteraceae and Desulfobulbaceae within the Deltaproteobacteria, suggesting that the oil-derived sedimentation pulse triggered bacterial oxygen consumption and created patchy anaerobic microniches that favored sulfate-reducing bacteria. Phylotypes of the polycyclic aromatic hydrocarbon-degrading genus Cycloclasticus, previously found both in surface oil slicks and the deep hydrocarbon plume, were also found in oil-derived marine snow flocs sedimenting on the seafloor in September 2010, and in surficial sediments collected in October and November 2010, but not in any of the control samples. Due to the relative recalcitrance and stability of polycyclic aromatic compounds, Cycloclasticus represents the most persistent microbial marker of seafloor hydrocarbon deposition that we could identify in this dataset. The bacterial imprint of the DWH oil spill had diminished in late November 2010, when the bacterial communities in oil-impacted sediment samples collected near the Macondo wellhead began to resemble their pre-spill counterparts and spatial controls. Samples collected in summer of 2011 did not show a consistent bacterial community signature, suggesting that the bacterial community was no longer shaped by the DWH fallout of oil-derived marine snow, but instead by location-specific and seasonal factors. PMID:27679609

Instrumental research of lithodynamic processes in estuaries of the White Sea

NASA Astrophysics Data System (ADS)

Rimsky-Korsakov, Nikolai; Korotaev, Vladislav; Ivanov, Vadim

2017-04-01

The report provides a comparative analysis of morphological lithodynamic processes in estuaries and river deltas on the basis of 2013-2015 field geophysical and hydrographic surveys held by IO RAS and MSU. Studies performed using side scan sonar (Imagenex YellowFin SSS), bathymetric (FortXXI Scat Echo sounder) and navigation (DGPS/GLONASS Sigma Ashtek receiver) equipment. North Dvina modern delta can be classified as multi-arm delta estuary lagoon performance. Areas of modern river waters occupy a large accumulation of deltaic arms. It formed a young island with elevations of about 1 m. The islands are composed of river alluvium and annually flooded during the flood period. Onega river mouth area is unique due to the specific geological conditions. Short, wellhead site is the cause of the anomalous attenuation of the tidal wave and the limited range of penetration of salt water seashore only to Kokorinskogo threshold. Morphological lithodynamic processes in high tide Mezen estuaries (syzygy - 8.5 m) are caused by tidal currents, river runoff, wind waves and sediment longshore drift. Due to the movement of huge masses of sediment in the Mezen estuary occur intense deformation silty-sand banks, reshaping of the bottom channel trenches and displacement of navigable waterways. Thus, the specificity of the morphological lithodynamic processes in high tidal estuaries is a lack of modern delta, the development of mobile local sediment structures inside the estuary and the formation of a broad mouth bar on the open wellhead coast. In multi-arm deltas an intense process of increasing marine edge of the delta is observed due to wellhead delta arms elongation and the formation of small estuarine bars at the mouths of the underwater channel trenches coming out into the open coast. Simultaneously, the process of filling the river sediments of residual waters within the subaerial delta and the formation of marine coastal bars on the outer perimeter edge of the sea ground delta.

U.S. crude oil, natural gas, and natural gas liquids reserves 1997 annual report

DOE Office of Scientific and Technical Information (OSTI.GOV)

Wood, John H.; Grape, Steven G.; Green, Rhonda S.

1998-12-01

This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1997, as well as production volumes for the US and selected States and State subdivisions for the year 1997. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet natural gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, reserve estimates for two types of natural gas liquids, leasemore » condensate and natural gas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1997 is provided. 21 figs., 16 tabs.« less

78 FR 38309 - Northern Natural Gas Company; Southern Natural Gas Company, L.L.C.; Florida Gas Transmission...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-06-26

... Natural Gas Company; Southern Natural Gas Company, L.L.C.; Florida Gas Transmission Company, LLC; Notice of Application Take notice that on June 4, 2013, Northern Natural Gas Company (Northern), 1111 South 103rd Street, Omaha, Nebraska 68124; on behalf of itself, Southern Natural Gas Company, L.L.C., and...

40 CFR 310.3 - What terms have specific definitions?

Code of Federal Regulations, 2011 CFR

2011-07-01

..., and the term does not include natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). (g) Local emergency response... substance under section 101(14)(A) through (F) of CERCLA, nor does it include natural gas, liquefied natural...

40 CFR 310.3 - What terms have specific definitions?

Code of Federal Regulations, 2010 CFR

2010-07-01

..., and the term does not include natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). (g) Local emergency response... substance under section 101(14)(A) through (F) of CERCLA, nor does it include natural gas, liquefied natural...

40 CFR 310.3 - What terms have specific definitions?

Code of Federal Regulations, 2012 CFR

2012-07-01

..., and the term does not include natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). (g) Local emergency response... substance under section 101(14)(A) through (F) of CERCLA, nor does it include natural gas, liquefied natural...

40 CFR 310.3 - What terms have specific definitions?

Code of Federal Regulations, 2013 CFR

2013-07-01

..., and the term does not include natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). (g) Local emergency response... substance under section 101(14)(A) through (F) of CERCLA, nor does it include natural gas, liquefied natural...

40 CFR 310.3 - What terms have specific definitions?

Code of Federal Regulations, 2014 CFR

2014-07-01

..., and the term does not include natural gas, natural gas liquids, liquefied natural gas, or synthetic gas usable for fuel (or mixtures of natural gas and such synthetic gas). (g) Local emergency response... substance under section 101(14)(A) through (F) of CERCLA, nor does it include natural gas, liquefied natural...

75 FR 13644 - TORP Terminal LP, Bienville Offshore Energy Terminal Liquefied Natural Gas Deepwater Port License...

Federal Register 2010, 2011, 2012, 2013, 2014

2010-03-22

... interconnect pipelines to four existing offshore pipelines (Dauphin Natural Gas Pipeline, Williams Natural Gas Pipeline, Destin Natural Gas Pipeline, and Viosca Knoll Gathering System [VKGS] Gas Pipeline) that connect to the onshore natural gas transmission pipeline system. Natural gas would be delivered to customers...

Microstructural characteristics of natural gas hydrates hosted in various sand sediments.

PubMed

Zhao, Jiafei; Yang, Lei; Liu, Yu; Song, Yongchen

2015-09-21

Natural gas hydrates have aroused worldwide interest due to their energy potential and possible impact on climate. The occurrence of natural gas hydrates hosted in the pores of sediments governs the seismic exploration, resource assessment, stability of deposits, and gas production from natural gas hydrate reserves. In order to investigate the microstructure of natural gas hydrates occurring in pores, natural gas hydrate-bearing sediments were visualized using microfocus X-ray computed tomography (CT). Various types of sands with different grain sizes and wettability were used to study the effect of porous materials on the occurrence of natural gas hydrates. Spatial distributions of methane gas, natural gas hydrates, water, and sands were directly identified. This work indicates that natural gas hydrates tend to reside mainly within pore spaces and do not come in contact with adjacent sands. Such an occurring model of natural gas hydrates is termed the floating model. Furthermore, natural gas hydrates were observed to nucleate at gas-water interfaces as lens-shaped clusters. Smaller sand grain sizes contribute to higher hydrate saturation. The wetting behavior of various sands had little effect on the occurrence of natural gas hydrates within pores. Additionally, geometric properties of the sediments were collected through CT image reconstructions. These findings will be instructive for understanding the microstructure of natural gas hydrates within major global reserves and for future resource utilization of natural gas hydrates.

US crude oil, natural gas, and natural gas liquids reserves, 1992 annual report

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1993-10-18

This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1992, as well as production volumes for the United States, and selected States and State subdivisions for the year 1992. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), its two major components (nonassociated and associated-dissolved gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, two components of natural gas liquids, lease condensate and natural gas plant liquids, have their reservesmore » and production data presented. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1992 is provided.« less

18 CFR 382.202 - Annual charges under the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes.

Code of Federal Regulations, 2010 CFR

2010-04-01

... the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes. 382.202 Section 382.202... GENERAL RULES ANNUAL CHARGES Annual Charges § 382.202 Annual charges under the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes. The adjusted costs of administration of the natural gas...

18 CFR 382.202 - Annual charges under the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes.

Code of Federal Regulations, 2011 CFR

2011-04-01

... the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes. 382.202 Section 382.202... GENERAL RULES ANNUAL CHARGES Annual Charges § 382.202 Annual charges under the Natural Gas Act and Natural Gas Policy Act of 1978 and related statutes. The adjusted costs of administration of the natural gas...

43 CFR 3275.14 - What aspects of my geothermal operations must I measure?

Code of Federal Regulations, 2014 CFR

2014-10-01

... wellhead pressure. (b) For all electrical generation facilities, you must measure: (1) Steam and/or hot... steam and/or hot water exiting the facility. (c) For direct use facilities, you must measure: (1) Flow of steam and/or hot water; and (2) Temperature of the steam or water entering the facility. (d) We...

43 CFR 3275.14 - What aspects of my geothermal operations must I measure?

Code of Federal Regulations, 2011 CFR

2011-10-01

... wellhead pressure. (b) For all electrical generation facilities, you must measure: (1) Steam and/or hot... steam and/or hot water exiting the facility. (c) For direct use facilities, you must measure: (1) Flow of steam and/or hot water; and (2) Temperature of the steam or water entering the facility. (d) We...

43 CFR 3275.14 - What aspects of my geothermal operations must I measure?

Code of Federal Regulations, 2013 CFR

2013-10-01

... wellhead pressure. (b) For all electrical generation facilities, you must measure: (1) Steam and/or hot... steam and/or hot water exiting the facility. (c) For direct use facilities, you must measure: (1) Flow of steam and/or hot water; and (2) Temperature of the steam or water entering the facility. (d) We...

43 CFR 3275.14 - What aspects of my geothermal operations must I measure?

Code of Federal Regulations, 2012 CFR

2012-10-01

... wellhead pressure. (b) For all electrical generation facilities, you must measure: (1) Steam and/or hot... steam and/or hot water exiting the facility. (c) For direct use facilities, you must measure: (1) Flow of steam and/or hot water; and (2) Temperature of the steam or water entering the facility. (d) We...

30 CFR 250.520 - When do I have to perform a casing diagnostic test?

Code of Federal Regulations, 2011 CFR

2011-07-01

... 30 Mineral Resources 2 2011-07-01 2011-07-01 false When do I have to perform a casing diagnostic test? 250.520 Section 250.520 Mineral Resources BUREAU OF OCEAN ENERGY MANAGEMENT, REGULATION, AND... plus 100 psig measured at the subsea wellhead. (3) hybrid well, a riser or the production casing...

U.S. Natural Gas Markets: Mid-Term Prospects for Natural Gas Supply

EIA Publications

2001-01-01

This service report describes the recent behavior of natural gas markets with respect to natural gas prices, their potential future behavior, the potential future supply contribution of liquefied natural gas and increased access to federally restricted resources, and the need for improved natural gas data.

US crude oil, natural gas, and natural gas liquids reserves 1996 annual report

DOE Office of Scientific and Technical Information (OSTI.GOV)

NONE

1997-12-01

The EIA annual reserves report series is the only source of comprehensive domestic proved reserves estimates. This publication is used by the Congress, Federal and State agencies, industry, and other interested parties to obtain accurate estimates of the Nation`s proved reserves of crude oil, natural gas, and natural gas liquids. These data are essential to the development, implementation, and evaluation of energy policy and legislation. This report presents estimates of proved reserves of crude oil, natural gas, and natural gas liquids as of December 31, 1996, as well as production volumes for the US and selected States and State subdivisionsmore » for the year 1996. Estimates are presented for the following four categories of natural gas: total gas (wet after lease separation), nonassociated gas and associated-dissolved gas (which are the two major types of wet natural gas), and total dry gas (wet gas adjusted for the removal of liquids at natural gas processing plants). In addition, reserve estimates for two types of natural gas liquids, lease condensate and natural gas plant liquids, are presented. Also included is information on indicated additional crude oil reserves and crude oil, natural gas, and lease condensate reserves in nonproducing reservoirs. A discussion of notable oil and gas exploration and development activities during 1996 is provided. 21 figs., 16 tabs.« less

40 CFR 60.5430 - What definitions apply to this subpart?

Code of Federal Regulations, 2013 CFR

2013-07-01

... natural gas liquids from field gas, the fractionation of the liquids into natural gas products, or other... gas unit means a unit used to cool natural gas to the point at which it is condensed into a liquid... pressurized natural gas. Natural gas liquids means the hydrocarbons, such as ethane, propane, butane, and...

40 CFR 98.400 - Definition of the source category.

Code of Federal Regulations, 2012 CFR

2012-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.400 Definition of the source category. This supplier category consists of natural gas liquids fractionators and local natural gas distribution companies. (a) Natural gas liquids fractionators are installations that...

40 CFR 98.400 - Definition of the source category.

Code of Federal Regulations, 2013 CFR

2013-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.400 Definition of the source category. This supplier category consists of natural gas liquids fractionators and local natural gas distribution companies. (a) Natural gas liquids fractionators are installations that...

40 CFR 98.400 - Definition of the source category.

Code of Federal Regulations, 2014 CFR

2014-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.400 Definition of the source category. This supplier category consists of natural gas liquids fractionators and local natural gas distribution companies. (a) Natural gas liquids fractionators are installations that...

40 CFR 98.400 - Definition of the source category.

Code of Federal Regulations, 2010 CFR

2010-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.400 Definition of the source category. This supplier category consists of natural gas liquids fractionators and local natural gas distribution companies. (a) Natural gas liquids fractionators are installations that...

40 CFR 98.400 - Definition of the source category.

Code of Federal Regulations, 2011 CFR

2011-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.400 Definition of the source category. This supplier category consists of natural gas liquids fractionators and local natural gas distribution companies. (a) Natural gas liquids fractionators are installations that...

18 CFR 284.263 - Exemption from section 7 of Natural Gas Act and certain regulatory conditions.

Code of Federal Regulations, 2010 CFR

2010-04-01

... 7 of Natural Gas Act and certain regulatory conditions. 284.263 Section 284.263 Conservation of... UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale...

Alternative Fuels Data Center: Natural Gas

Science.gov Websites

Natural Gas Printable Version Share this resource Send a link to Alternative Fuels Data Center : Natural Gas to someone by E-mail Share Alternative Fuels Data Center: Natural Gas on Facebook Tweet about Alternative Fuels Data Center: Natural Gas on Twitter Bookmark Alternative Fuels Data Center: Natural Gas on

18 CFR 284.263 - Exemption from section 7 of Natural Gas Act and certain regulatory conditions.

Code of Federal Regulations, 2011 CFR

2011-04-01

... 7 of Natural Gas Act and certain regulatory conditions. 284.263 Section 284.263 Conservation of... UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale...

Natural Gas Exports from Iran

EIA Publications

2012-01-01

This assessment of the natural gas sector in Iran, with a focus on Iran’s natural gas exports, was prepared pursuant to section 505 (a) of the Iran Threat Reduction and Syria Human Rights Act of 2012 (Public Law No: 112-158). As requested, it includes: (1) an assessment of exports of natural gas from Iran; (2) an identification of the countries that purchase the most natural gas from Iran; (3) an assessment of alternative supplies of natural gas available to those countries; (4) an assessment of the impact a reduction in exports of natural gas from Iran would have on global natural gas supplies and the price of natural gas, especially in countries identified under number (2); and (5) such other information as the Administrator considers appropriate.

75 FR 35632 - Transparency Provisions of Section 23 of the Natural Gas Act

Federal Register 2010, 2011, 2012, 2013, 2014

2010-06-23

... pipeline- quality natural gas. For instance, some Respondents questioned whether pipeline-quality natural gas that is sold directly into an interstate or intrastate natural gas pipeline without processing... reported transactions of pipeline-quality gas under the assumption that ``unprocessed natural gas'' was...

76 FR 64010 - Special Rules Governing Certain Information Obtained Under the Clean Air Act: Technical Correction

Federal Register 2010, 2011, 2012, 2013, 2014

2011-10-17

... natural gas. 211112 Natural gas liquid extraction facilities. Petrochemical Production 32511 Ethylene.... Suppliers of Natural Gas and NGLs 221210 Natural gas distribution facilities. 211112 Natural gas liquid... Gas Reporting Rule, which are provided in the Special Rules Governing Certain Information Obtained...

Role of natural gas in meeting an electric sector emissions ...

EPA Pesticide Factsheets

With advances in natural gas extraction technologies, there is an increase in availability of domestic natural gas, and natural gas is gaining a larger share of use as a fuel in electricity production. At the power plant, natural gas is a cleaner burning fuel than coal, but uncertainties exist in the amount of methane leakage occurring upstream in the extraction and production of natural gas. At high leakage levels, these methane emissions could outweigh the benefits of switching from coal to natural gas. This analysis uses the MARKAL linear optimization model to compare the carbon emissions profiles and system-wide global warming potential of the U.S. energy system over a series of model runs in which the power sector is asked to meet a specific CO2 reduction target and the availability of natural gas changes. Scenarios are run with a range of upstream methane emission leakage rates from natural gas production. While the total CO2 emissions are reduced in most scenarios, total greenhouse gas emissions show an increase or no change when both natural gas availability and methane emissions from natural gas production are high. Article presents summary of results from an analyses of natural gas resource availability and power sector emissions reduction strategies under different estimates of methane leakage rates during natural gas extraction and production. This was study was undertaken as part of the Energy Modeling Forum Study #31:

77 FR 48878 - Approval and Promulgation of Federal Implementation Plan for Oil and Natural Gas Well Production...

Federal Register 2010, 2011, 2012, 2013, 2014

2012-08-15

... the sales natural gas pipeline or to an emissions control unit when a natural gas sales pipeline is... vapor recovery unit (VRU) to be injected into a natural gas sales pipeline for conveyance to a natural gas plant. In the event that pipeline injection of recoverable natural gas is temporarily infeasible...

18 CFR 152.1 - Exemption applications and blanket certificates.

Code of Federal Regulations, 2010 CFR

2010-04-01

... implementing the Natural Gas Act, “vehicular natural gas” or “VNG” means natural gas that will be used, in... Commission's regulations implementing the Natural Gas Act, vehicular natural gas, or VNG, is deemed to be... REGULATORY COMMISSION, DEPARTMENT OF ENERGY REGULATIONS UNDER NATURAL GAS ACT APPLICATION FOR EXEMPTION FROM...

76 FR 37300 - Mandatory Reporting of Greenhouse Gases: Petroleum and Natural Gas Systems: Revisions to Best...

Federal Register 2010, 2011, 2012, 2013, 2014

2011-06-27

... natural gas. 211112 Natural gas liquid extraction facilities. Table 1 of this preamble is not intended to... Mandatory Reporting of Greenhouse Gases: Petroleum and Natural Gas Systems: Revisions to Best Available... regulations for Petroleum and Natural Gas Systems of the Greenhouse Gas Reporting Rule. Specifically, EPA is...

76 FR 14812 - Final Regulation Extending the Reporting Deadline for Year 2010 Data Elements Required Under the...

Federal Register 2010, 2011, 2012, 2013, 2014

2011-03-18

.... Suppliers of Natural Gas and 221210 Natural gas Natural Gas Liquids. distribution facilities. 211112 Natural gas liquid extraction facilities. Suppliers of Industrial 325120 Industrial gas Greenhouse Gases..., 75 FR Natural Gas Liquids. 66434, 75 FR 79092. Suppliers of Industrial OO 74 FR 56260, 75 FR...

WORKING WITH WHAEM2000: CAPTURE ZONE DELINEATION FOR A CITY WELLFIELD IN A VALLEY FILL GLACIAL OUTWASH AQUIFER SUPPORTING WELLHEAD PROTECTION

EPA Science Inventory

The purpose of this document is to introduce through a case study the use of the ground water geohydrology computer program WhAEM for Microsoft Windows (32-bit), or WhAEM2000. WhAEM2000 is a public domain, ground-water flow model designed to facilitate capture zone delineation an...

30 CFR 250.1722 - If I install a subsea protective device, what requirements must I meet?

Code of Federal Regulations, 2010 CFR

2010-07-01

... protective covering, the casing stub or mud line suspension equipment, or the trawl, and a discussion of any... subsea wellheads, casing stubs, mud line suspensions, or other obstructions in water depths less than 300... reveals that a casing stub or mud line suspension is no longer properly protected, or if the trawl does...

77 FR 37034 - Notice of Effectiveness of Exempt Wholesale Generator Status

Federal Register 2010, 2011, 2012, 2013, 2014

2012-06-20

... EG12-45-000 Silver State Solar Power North, LLC EG12-46-000 Wellhead Power Delano, LLC EG12-47-000... Wholesale Generator Status Docket Nos. Solano 3 Wind LLC EG12-36-000 Atlantic Power (Coastal Rivers) Corporation EG12-37-000 Atlantic Power (Williams Lake) Ltd EG12-38-000 Atlantic Power Preferred Equity, Ltd...

Brady's Geothermal Field Distributed Temperature Sensing Data

DOE Data Explorer

Patterson, Jeremy

2016-03-26

This submission is an 8 day time history of vertical temperature measurements in Brady observation well 56-1 collected during the PoroTomo field experiment. The data was collected with a fiber-optic DTS system installed to a depth of 372 m below wellhead. DTS installation uses a double-loop set up. Data includes forward length and backward length temperature measurements.

15 CFR 742.1 - Introduction.

Code of Federal Regulations, 2014 CFR

2014-01-01

... (certain other petroleum products); 1C983 (Natural gas liquids and other natural gas derivatives); 1C984 (certain manufactured gas and synthetic natural gas (except when commingled with natural gas and thus...

15 CFR 742.1 - Introduction.

Code of Federal Regulations, 2010 CFR

2010-01-01

... (certain other petroleum products); 1C983 (Natural gas liquids and other natural gas derivatives); 1C984 (certain manufactured gas and synthetic natural gas (except when commingled with natural gas and thus...

15 CFR 742.1 - Introduction.

Code of Federal Regulations, 2012 CFR

2012-01-01

... (certain other petroleum products); 1C983 (Natural gas liquids and other natural gas derivatives); 1C984 (certain manufactured gas and synthetic natural gas (except when commingled with natural gas and thus...

15 CFR 742.1 - Introduction.

Code of Federal Regulations, 2011 CFR

2011-01-01

... (certain other petroleum products); 1C983 (Natural gas liquids and other natural gas derivatives); 1C984 (certain manufactured gas and synthetic natural gas (except when commingled with natural gas and thus...

15 CFR 742.1 - Introduction.

Code of Federal Regulations, 2013 CFR

2013-01-01

... (certain other petroleum products); 1C983 (Natural gas liquids and other natural gas derivatives); 1C984 (certain manufactured gas and synthetic natural gas (except when commingled with natural gas and thus...

76 FR 22825 - Mandatory Reporting of Greenhouse Gases: Petroleum and Natural Gas Systems

Federal Register 2010, 2011, 2012, 2013, 2014

2011-04-25

... Reporting of Greenhouse Gases: Petroleum and Natural Gas Systems AGENCY: Environmental Protection Agency... Subpart W: Petroleum and Natural Gas Systems of the Greenhouse Gas Reporting Rule. As part of the... greenhouse gas emissions for the petroleum and natural gas systems source category of the greenhouse gas...

76 FR 52037 - Self-Regulatory Organizations; NYSE Arca, Inc.; Order Approving a Proposed Rule Change To List...

Federal Register 2010, 2011, 2012, 2013, 2014

2011-08-19

... the Following Under NYSE Arca Equities Rule 8.200: ProShares Short DJ-UBS Natural Gas, ProShares Ultra DJ-UBS Natural Gas and ProShares UltraShort DJ-UBS Natural Gas August 15, 2011. I. Introduction On... DJ-UBS Natural Gas, ProShares Ultra DJ-UBS Natural Gas, and ProShares UltraShort DJ-UBS Natural Gas...

15 CFR 754.1 - Introduction.

Code of Federal Regulations, 2010 CFR

2010-01-01

... (Other petroleum products); (C) ECCN 1C983 (Natural gas liquids and other natural gas derivatives); and (D) ECCN 1C984 (Manufactured gas and synthetic natural gas (except when commingled with natural gas...

15 CFR 754.1 - Introduction.

Code of Federal Regulations, 2014 CFR

2014-01-01

... (Other petroleum products); (C) ECCN 1C983 (Natural gas liquids and other natural gas derivatives); and (D) ECCN 1C984 (Manufactured gas and synthetic natural gas (except when commingled with natural gas...

15 CFR 754.1 - Introduction.

Code of Federal Regulations, 2012 CFR

2012-01-01

... (Other petroleum products); (C) ECCN 1C983 (Natural gas liquids and other natural gas derivatives); and (D) ECCN 1C984 (Manufactured gas and synthetic natural gas (except when commingled with natural gas...

15 CFR 754.1 - Introduction.

Code of Federal Regulations, 2011 CFR

2011-01-01

... (Other petroleum products); (C) ECCN 1C983 (Natural gas liquids and other natural gas derivatives); and (D) ECCN 1C984 (Manufactured gas and synthetic natural gas (except when commingled with natural gas...

15 CFR 754.1 - Introduction.

Code of Federal Regulations, 2013 CFR

2013-01-01

... (Other petroleum products); (C) ECCN 1C983 (Natural gas liquids and other natural gas derivatives); and (D) ECCN 1C984 (Manufactured gas and synthetic natural gas (except when commingled with natural gas...

40 CFR 98.405 - Procedures for estimating missing data.

Code of Federal Regulations, 2012 CFR

2012-07-01

... PROGRAMS (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids... of natural gas liquids or natural gas supplied during any period is unavailable (e.g., if a flow...

40 CFR 98.405 - Procedures for estimating missing data.

Code of Federal Regulations, 2014 CFR

2014-07-01

... PROGRAMS (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids... of natural gas liquids or natural gas supplied during any period is unavailable (e.g., if a flow...

40 CFR 98.405 - Procedures for estimating missing data.

Code of Federal Regulations, 2010 CFR

2010-07-01

... PROGRAMS (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids... of natural gas liquids or natural gas supplied during any period is unavailable (e.g., if a flow...

40 CFR 98.405 - Procedures for estimating missing data.

Code of Federal Regulations, 2013 CFR

2013-07-01

... PROGRAMS (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids... of natural gas liquids or natural gas supplied during any period is unavailable (e.g., if a flow...

40 CFR 98.405 - Procedures for estimating missing data.

Code of Federal Regulations, 2011 CFR

2011-07-01

... PROGRAMS (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids... of natural gas liquids or natural gas supplied during any period is unavailable (e.g., if a flow...

Alternative Fuels Data Center: Natural Gas Related Links

Science.gov Websites

, AGA provides services to member natural gas pipelines, marketers, gatherers, international gas Natural Gas Printable Version Share this resource Send a link to Alternative Fuels Data Center : Natural Gas Related Links to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Related

Role of natural gas in meeting an electric sector emissions reduction strategy and effects on greenhouse gas emissions

EPA Science Inventory

With advances in natural gas extraction technologies, there is an increase in availability of domestic natural gas, and natural gas is gaining a larger share of use as a fuel in electricity production. At the power plant, natural gas is a cleaner burning fuel than coal, but unce...

40 CFR 68.3 - Definitions.

Code of Federal Regulations, 2010 CFR

2010-07-01

... for reasons of national security.” Condensate means hydrocarbon liquid separated from natural gas that... processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both, classified as...

40 CFR 68.3 - Definitions.

Code of Federal Regulations, 2011 CFR

2011-07-01

... for reasons of national security.” Condensate means hydrocarbon liquid separated from natural gas that... processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both, classified as...

40 CFR 68.3 - Definitions.

Code of Federal Regulations, 2012 CFR

2012-07-01

... for reasons of national security.” Condensate means hydrocarbon liquid separated from natural gas that... processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both, classified as...

40 CFR 68.3 - Definitions.

Code of Federal Regulations, 2013 CFR

2013-07-01

... for reasons of national security.” Condensate means hydrocarbon liquid separated from natural gas that... processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both, classified as...

40 CFR 68.3 - Definitions.

Code of Federal Regulations, 2014 CFR

2014-07-01

... for reasons of national security.” Condensate means hydrocarbon liquid separated from natural gas that... processing plant (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both, classified as...

40 CFR 98.401 - Reporting threshold.

Code of Federal Regulations, 2010 CFR

2010-07-01

...) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.401 Reporting threshold. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4...

40 CFR 98.401 - Reporting threshold.

Code of Federal Regulations, 2014 CFR

2014-07-01

...) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.401 Reporting threshold. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4...

40 CFR 98.401 - Reporting threshold.

Code of Federal Regulations, 2012 CFR

2012-07-01

...) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.401 Reporting threshold. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4...

40 CFR 98.401 - Reporting threshold.

Code of Federal Regulations, 2013 CFR

2013-07-01

...) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.401 Reporting threshold. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4...

40 CFR 98.401 - Reporting threshold.

Code of Federal Regulations, 2011 CFR

2011-07-01

...) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.401 Reporting threshold. Any supplier of natural gas and natural gas liquids that meets the requirements of § 98.2(a)(4...

Assessment of undiscovered oil and gas resources of the Assam, Bombay, Cauvery, and Krishna-Godavari Provinces, South Asia, 2011

USGS Publications Warehouse

Klett, T.R.; Schenk, Christopher J.; Wandrey, Craig J.; Charpentier, Ronald R.; Cook, Troy A.; Brownfield, Michael E.; Pitman, Janet K.; Pollastro, Richard M.

2012-01-01

Using a geology-based assessment methodology, the U.S. Geological Survey estimated volumes of undiscovered, technically recoverable, conventional petroleum resources for the Assam, Bombay, Cauvery, and Krishna–Godavari Provinces, South Asia. The estimated mean volumes are as follows: (1) Assam Province, 273 million barrels of crude oil, 1,559 billion cubic feet of natural gas, and 43 million barrels of natural gas liquids; (2) Bombay Province, 1,854 million barrels of crude oil, 15,417 billion cubic feet of natural gas, and 498 million barrels of natural gas liquids; (3) Cauvery Province, 941 million barrels of crude oil, 25,208 billion cubic feet of natural gas, and 654 million barrels of natural gas liquids; and (4) Krishna–Godavari Province, 466 million barrels of crude oil, 37,168 billion cubic feet of natural gas, and 484 million barrels of natural gas liquids. The totals for the four provinces are 3,534 million barrels of crude oil, 79,352 billion cubic feet of natural gas, and 1,679 million barrels of natural gas liquids.

40 CFR 80.33 - Controls applicable to natural gas retailers and wholesale purchaser-consumers.

Code of Federal Regulations, 2010 CFR

2010-07-01

... 40 Protection of Environment 16 2010-07-01 2010-07-01 false Controls applicable to natural gas... Prohibitions § 80.33 Controls applicable to natural gas retailers and wholesale purchaser-consumers. (a) After... feet of natural gas per month shall equip each pump from which natural gas is introduced into natural...

40 CFR 80.33 - Controls applicable to natural gas retailers and wholesale purchaser-consumers.

Code of Federal Regulations, 2011 CFR

2011-07-01

... 40 Protection of Environment 16 2011-07-01 2011-07-01 false Controls applicable to natural gas... Prohibitions § 80.33 Controls applicable to natural gas retailers and wholesale purchaser-consumers. (a) After... feet of natural gas per month shall equip each pump from which natural gas is introduced into natural...

77 FR 72840 - CE FLNG, LLC; Application for Long-Term Authorization To Export Liquefied Natural Gas Produced...

Federal Register 2010, 2011, 2012, 2013, 2014

2012-12-06

... States natural gas pipeline system. CE FLNG states that the source of natural gas supply will come from... purchase gas for export from any point in the U.S. interstate pipeline system. CE FLNG states that this... Authorization To Export Liquefied Natural Gas Produced From Domestic Natural Gas Resources to Non-Free Trade...

76 FR 4417 - Liberty Natural Gas LLC, Liberty Liquefied Natural Gas (LNG) Deepwater Port License Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-01-25

... DEPARTMENT OF TRANSPORTATION Maritime Administration [USCG-2010-0993] Liberty Natural Gas LLC, Liberty Liquefied Natural Gas (LNG) Deepwater Port License Application AGENCY: Maritime Administration... application describes an offshore natural gas deepwater port facility that would be located approximately 16.2...

75 FR 39934 - Oil and Natural Gas Sector-Notice of Public Meeting

Federal Register 2010, 2011, 2012, 2013, 2014

2010-07-13

... ENVIRONMENTAL PROTECTION AGENCY [EPA-HQ-OAR-2010-0505; FRL-9174-8] Oil and Natural Gas Sector... EPA's review of air regulations affecting the oil and natural gas industry. The review in progress covers oil and natural gas exploration and production, as well as natural gas processing, transmission...

75 FR 70350 - Liberty Natural Gas LLC, Liberty Liquefied Natural Gas (LNG) Deepwater Port License Application

Federal Register 2010, 2011, 2012, 2013, 2014

2010-11-17

... DEPARTMENT OF TRANSPORTATION Maritime Administration [USCG-2010-0993] Liberty Natural Gas LLC, Liberty Liquefied Natural Gas (LNG) Deepwater Port License Application AGENCY: Maritime Administration... announce they have received an application for the licensing of a natural gas deepwater port and the...

7 CFR 2900.4 - Natural gas requirements.

Code of Federal Regulations, 2010 CFR

2010-01-01

... 7 Agriculture 15 2010-01-01 2010-01-01 false Natural gas requirements. 2900.4 Section 2900.4..., DEPARTMENT OF AGRICULTURE ESSENTIAL AGRICULTURAL USES AND VOLUMETRIC REQUIREMENTS-NATURAL GAS POLICY ACT § 2900.4 Natural gas requirements. For purposes of Section 401(c), NGPA, the natural gas requirements for...

77 FR 32624 - Eastern Shore Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2012-06-01

... Natural Gas Company; Notice of Application Take notice that on May 14, 2012, Eastern Shore Natural Gas... Natural Gas Act (NGA) and Part 157 of the Commission's regulations, requesting authorization to construct..., Eastern Shore Natural Gas Company, 1110 Forrest Avenue, Suite 201, Dover, Delaware, 19904, or by calling...

Alternative Fuels Data Center: Natural Gas Benefits

Science.gov Websites

Benefits to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Benefits on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Benefits on Twitter Bookmark Alternative Fuels Data Center: Natural Gas Benefits on Google Bookmark Alternative Fuels Data Center: Natural Gas

Alternative Fuels Data Center: Natural Gas Production

Science.gov Websites

Production to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Production on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Production on Twitter Bookmark Alternative Fuels Data Center: Natural Gas Production on Google Bookmark Alternative Fuels Data Center: Natural Gas

Alternative Fuels Data Center: Conventional Natural Gas Production

Science.gov Websites

Conventional Natural Gas Production to someone by E-mail Share Alternative Fuels Data Center : Conventional Natural Gas Production on Facebook Tweet about Alternative Fuels Data Center: Conventional Natural Gas Production on Twitter Bookmark Alternative Fuels Data Center: Conventional Natural Gas Production

7 CFR 2900.4 - Natural gas requirements.

Code of Federal Regulations, 2011 CFR

2011-01-01

... 7 Agriculture 15 2011-01-01 2011-01-01 false Natural gas requirements. 2900.4 Section 2900.4..., DEPARTMENT OF AGRICULTURE ESSENTIAL AGRICULTURAL USES AND VOLUMETRIC REQUIREMENTS-NATURAL GAS POLICY ACT § 2900.4 Natural gas requirements. For purposes of Section 401(c), NGPA, the natural gas requirements for...

77 FR 33453 - Agency Information Collection Extension

Federal Register 2010, 2011, 2012, 2013, 2014

2012-06-06

... Report of the Origin of Natural Gas Liquids. Comments are invited on: (a) Whether the proposed extended... accurate annual estimates of U.S. proved crude oil, natural gas, and natural gas liquids reserves, and EIA..., natural gas, and natural gas liquids to facilitate national energy policy decisions. These estimates are...

40 CFR 98.403 - Calculating GHG emissions.

Code of Federal Regulations, 2010 CFR

2010-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.403...). Fuel = Total annual volume of product “h” supplied (volume per year, in Mscf for natural gas and bbl... procedures below. (1) For natural gas that is received for redelivery to downstream gas transmission...

GHGRP Natural Gas and Natural Gas Liquids Suppliers Sector Industrial Profile

EPA Pesticide Factsheets

EPA's Greenhouse Gas Reporting Program periodically produces detailed profiles of the various industries that report under the program. The profiles available for download below contain detailed analyses for the Natural Gas and Natural Gas Suppliers indust

Prospects of and Problems in Using Natural Gas for Motor Transport in RUSSIA

NASA Astrophysics Data System (ADS)

Chikishev, E.; Ivanov, A.; Anisimov, I.; Chainikov, D.

2016-08-01

This article is devoted to increasing the use of natural gas in Russia as a measure to decrease the negative influence of motor transport on the environment. A brief analysis of the global fleet of natural gas vehicles is provided above. The documents accepted in Russia to promote public awareness of compressed natural gas in transport are submitted. The basic reasons keeping the growth of natural gas vehicle fleets in Russia consist of weak branching of refuelling stations; difficulty in determining the actual amount of compressed natural gas required; and control methods of the consumption of gas fuel. The offers promoting the growth of the fleet of natural gas vehicles are given.

77 FR 3255 - Notice of Intent To Prepare an Environmental Impact Statement for the Acquisition of a Natural...

Federal Register 2010, 2011, 2012, 2013, 2014

2012-01-23

... Acquisition of a Natural Gas Pipeline and Natural Gas Utility Service at the Hanford Site, Richland, WA, and... Environmental Impact Statement for the Acquisition of a Natural Gas Pipeline and Natural Gas Utility Service at the Hanford Site, Richland, Washington (Natural Gas Pipeline or NGP EIS), and initiate a 30-day public...

Hydrocarbon gas liquids production and related industrial development

EIA Publications

2016-01-01

Hydrocarbon gas liquids (HGL) are produced at refineries from crude oil and at natural gas processing plants from unprocessed natural gas. From 2010 to 2015, total HGL production increased by 42%. Natural gas processing plants accounted for all the increase, with recovered natural gas plant liquids (NGPL)—light hydrocarbon gases such as propane—rising by 58%, from 2.07 million barrels per day (b/d) in 2010 to 3.27 million b/d in 2015, while refinery output of HGL declined by 7%. The rapid increase in NGPL output was the result of rapid growth in natural gas production, as production shifted to tight gas and shale gas resources, and as producers targeted formations likely to yield natural gas with high liquids content. Annual Energy Outlook 2016 results suggest varying rates of future NGPL production growth, depending on relative crude oil and natural gas prices.

Importance of Low Permeability Natural Gas Reservoirs (released in AEO2010)

EIA Publications

2010-01-01

Production from low-permeability reservoirs, including shale gas and tight gas, has become a major source of domestic natural gas supply. In 2008, low-permeability reservoirs accounted for about 40% of natural gas production and about 35% of natural gas consumption in the United States. Permeability is a measure of the rate at which liquids and gases can move through rock. Low-permeability natural gas reservoirs encompass the shale, sandstone, and carbonate formations whose natural permeability is roughly 0.1 millidarcies or below. (Permeability is measured in darcies.)

Greenhouse gas impacts of natural gas: Influence of deployment choice, methane leak rate, and methane GWP

NASA Astrophysics Data System (ADS)

Cohan, D. S.

2015-12-01

Growing supplies of natural gas have heightened interest in the net impacts of natural gas on climate. Although its production and consumption result in greenhouse gas emissions, natural gas most often substitutes for other fossil fuels whose emission rates may be higher. Because natural gas can be used throughout the sectors of the energy economy, its net impacts on greenhouse gas emissions will depend not only on the leak rates of production and distribution, but also on the use for which natural gas is substituted. Here, we present our estimates of the net greenhouse gas emissions impacts of substituting natural gas for other fossil fuels for five purposes: light-duty vehicles, transit buses, residential heating, electricity generation, and export for electricity generation overseas. Emissions are evaluated on a fuel cycle basis, from production and transport of each fuel through end use combustion, based on recent conditions in the United States. We show that displacement of existing coal-fired electricity and heating oil furnaces yield the largest reductions in emissions. The impact of compressed natural gas replacing petroleum-based vehicles is highly uncertain, with the sign of impact depending on multiple assumptions. Export of liquefied natural gas for electricity yields a moderate amount of emissions reductions. We further show how uncertainties in upstream emission rates for natural gas and in the global warming potential of methane influence the net greenhouse gas impacts. Our presentation will make the case that how natural gas is deployed is crucial to determining how it will impact climate.

Abundance and Utility: For Military Operations, Liquid Fuels Remain a Solid Choice over Natural Gas

DTIC Science & Technology

2014-08-01

and combat support vehicles, ships, and aircraft, the adoption of natural gas —whether as compressed natural gas (CNG) or liquefied natural gas (LNG...dangers to U.S. forces and vehicles. Natural gas has different flammability properties than traditional liquid fuels, and as CNG tanks are under high...tacticaldefensemedia.com16 | DoD Power & Energy Fall 2014 For Military Operations, Liquid Fuels Remain a Solid Choice over Natural Gas By Bret

76 FR 35202 - Piedmont Natural Gas Company, Inc.; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-06-16

... Natural Gas Company, Inc.; Notice of Application On June 3, 2011, Piedmont Natural Gas Company, Inc... section 7(f) of the Natural Gas Act (NGA), as amended, and section 157 of the Commission's Regulations.... Questions regarding this application should be directed to Michelle R. Mendoza, Piedmont Natural Gas Company...

76 FR 12721 - Northern Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-03-08

... Natural Gas Company; Notice of Application Take notice that on February 18, 2011, Northern Natural Gas... application pursuant to section 7(b) of the Natural Gas Act (NGA) and Part 157 of the Commission's regulations..., Northern Natural Gas Company, P.O. Box 3330, Omaha, Nebraska 68103-0330, or by calling (402) 398-7103...

18 CFR 284.3 - Jurisdiction under the Natural Gas Act.

Code of Federal Regulations, 2010 CFR

2010-04-01

... Natural Gas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND...

Alternative Fuels Data Center: Natural Gas Fueling Stations

Science.gov Websites

Natural Gas Fueling Stations to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Fueling Stations on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Fueling Stations on Twitter Bookmark Alternative Fuels Data Center: Natural Gas Fueling Stations on Google Bookmark

JEDI Natural Gas Model | Jobs and Economic Development Impact Models | NREL

Science.gov Websites

Natural Gas Model JEDI Natural Gas Model The Jobs and Economic Development Impacts (JEDI) Natural Gas model allows users to estimate economic development impacts from natural gas power generation -specific data should be used to obtain the best estimate of economic development impacts. This model has

18 CFR 284.3 - Jurisdiction under the Natural Gas Act.

Code of Federal Regulations, 2011 CFR

2011-04-01

... Natural Gas Act. 284.3 Section 284.3 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND...

40 CFR 60.631 - Definitions.

Code of Federal Regulations, 2014 CFR

2014-07-01

... this subpart. Field gas means feedstock gas entering the natural gas processing plant. In light liquid... field gas before the extraction step in the process. Natural gas liquids means the hydrocarbons, such as... (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas...

40 CFR 60.631 - Definitions.

Code of Federal Regulations, 2013 CFR

2013-07-01

... this subpart. Field gas means feedstock gas entering the natural gas processing plant. In light liquid... field gas before the extraction step in the process. Natural gas liquids means the hydrocarbons, such as... (gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas...

18 CFR 2.78 - Utilization and conservation of natural resources-natural gas.

Code of Federal Regulations, 2011 CFR

2011-04-01

... conservation of natural resources-natural gas. 2.78 Section 2.78 Conservation of Power and Water Resources... INTERPRETATIONS Statements of General Policy and Interpretations Under the Natural Gas Act § 2.78 Utilization and conservation of natural resources—natural gas. (a)(1) The national interests in the development and utilization...

The experiment of the elemental mercury was removed from natural gas by 4A molecular sieve

NASA Astrophysics Data System (ADS)

Jiang, Cong; Chen, Yanhao

2018-04-01

Most of the world's natural gas fields contain elemental mercury and mercury compounds, and the amount of mercury in natural gas is generally 1μg/m3 200μg/m3. This paper analyzes the mercury removal principle of chemical adsorption process, the characteristics and application of mercury removal gent and the factors that affect the efficiency of mercury removal. The mercury in the natural gas is adsorbed by the mercury-silver reaction of the 4 molecular sieve after the manned treatment. The limits for mercury content for natural gas for different uses and different treatment processes are also different. From the environmental protection, safety and other factors, it is recommended that the mercury content of natural gas in the pipeline is less than 28μg / m3, and the mercury content of the raw material gas in the equipment such as natural gas liquefaction and natural gas condensate recovery is less than 0.01μg/m3. This paper mainly analyzes the existence of mercury in natural gas, and the experimental research process of using 4A molecular sieve to absorb mercury in natural gas.

ISO New England Dual Fuel Capabilities to Limit Natural Gas and Electricity Interdependencies

DOE Office of Scientific and Technical Information (OSTI.GOV)

Adder, Justin M.

Since 2000, natural gas has seen tremendous growth as a fuel source for electricity generation in the United States (U.S.) with annual installations exceeding 20 GW in all but four years. It also accounts for an increasingly significant share of the nation’s electricity generation, growing from around 15 percent in the early part of the 2000s to between 26 and 29 percent in the last three years. (1) Increasing reliance on natural gas has led to concerns that an extreme weather event – which may cause curtailments in gas delivery – or a natural gas infrastructure failure could lead tomore » local or regional electric reliability issues. (2) These concerns stem from differences in delivery methods of natural gas to electric generating units (EGUs) contrasted with the fuel delivery and storage methods for traditional baseload power systems (i.e. coal and nuclear units).1 (3) Although it seems that there is an abundance of natural gas in a post-shale gas world, infrastructure limitations and differences in electric and natural gas markets persist that differentiate natural gas-fired generators from traditional baseload power generators. Such concerns can be partially mitigated by modifying natural gas EGUs for operation on secondary fuels and installing on-site fuel storage for the secondary fuel, thus ensuring continuity of operation in the case of a gas delivery problem.2 This report examines technical, regulatory, and market issues associated with operating power plants primarily fueled with natural gas, on a secondary fuel, such as fuel oil or liquefied natural gas (LNG). In addition, a regional case study was completed to identify the current and near-term potential for dual fuel operation in New England, along with a market impact analysis of potential cost savings during an extreme weather event. The New England Independent System Operator (ISO-NE) was selected as the study area based on a preponderance of natural gas-fired generators contributing to the regional generating capacity mix (nearly 50 percent natural gas), limited natural gas supply infrastructure, and the potential for natural gas delivery disruptions due to cold weather events, exacerbated by the lack of bulk natural gas storage in the region.« less

30 CFR 250.1721 - If I temporarily abandon a well that I plan to re-enter, what must I do?

Code of Federal Regulations, 2010 CFR

2010-07-01

... or cement plug must be no more than 1,000 feet below the mud line. MMS may consider approving..., or other obstructions that extend above the mud line according to U.S. Coast Guard (USCG) requirements; and (f) Except in water depths greater than 300 feet, protect subsea wellheads, casing stubs, mud...

Cameron predicts dry tree production system as the future subsea trend

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1978-06-05

Dry chambers are coming into increasing use in the search for offshore oil. With Subsea Station Cameron, an oil well can be drilled on the ocean floor and then topped with a dry production chamber for shirtsleeve work at the wellhead. Components of the station are described: production Christmas tree, chamber, adapter spool, docking plate, entry hatch, flowline connection, and variable controls. (DLC)

Geothermal systems

NASA Technical Reports Server (NTRS)

Mohl, C.

1978-01-01

Several tasks of JPL related to geothermal energy are discussed. The major task is the procurement and test and evaluation of a helical screw drive (wellhead unit). A general review of geothermal energy systems is given. The presentation focuses attention on geothermal reservoirs in California, with graphs and charts to support the discussion. Included are discussions on cost analysis, systems maintenance, and a comparison of geothermal and conventional heating and cooling systems.

78 FR 34894 - Regulated Navigation Area, Gulf of Mexico: Mississippi Canyon Block 20, South of New Orleans, LA...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-06-11

...). As noted in that document, the center of this RNA was established to surround an oil wellhead that... you fax, hand deliver or mail your comment, it will be considered as having been received by the Coast.... Viewing Comments and Documents To view comments, as well as documents mentioned in this preamble as being...

Evaluation of an Innovative Technology for Treatment of Water Contaminated with Perchlorate and Organic Compounds

DTIC Science & Technology

2009-03-26

signed// 13 March 2009 ____________________________________ Mark N. Goltz (Chairman) Date //signed// 2 March...I would like to thank Dr. Mark N. Goltz for his guidance throughout this process. His dedication as an advisor, sincere interest in the project...Parette, M. Goltz , D. Felker, A. Thal, and D. Craig, Tailored Granular Activated Carbon for Wellhead Perchlorate Treatment. Report, 2007

Natural gas monthly, April 1997

DOE Office of Scientific and Technical Information (OSTI.GOV)

NONE

1997-04-01

The Natural Gas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are present3ed each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information. The feature article is entitled ``Natural gas pipeline and system expansions.`` 6 figs., 27 tabs.

Natural gas monthly, June 1996

DOE Office of Scientific and Technical Information (OSTI.GOV)

NONE

1996-06-24

The natural gas monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information. The feature article for this month is Natural Gas Industry Restructuring and EIA Data Collection.

Fingerprinting Deepwater Horizon Oil in the northern Gulf of Mexico using biomarkers and Gas Chromatography-Triple Quadrupole Mass Spectrometry (GC/MS/MS)

NASA Astrophysics Data System (ADS)

Adhikari, P. L.; Overton, E. B.; Maiti, K.; Wong, R. L.

2016-02-01

Petroleum biomarkers such as hopanes, steranes, and triaromatic steroids are more persistent than alkanes and aromatic compounds. Thus, they are often used to track spilled oil in the environments and as a proxy for weathering processes. The present study utilizes water samples, suspended and sinking particles, and seafloor sediments collected during 2011-2013 from various locations of the northern Gulf of Mexico with wide range of contaminated oil for Deepwater Horizon (DWH) oil fingerprinting. The MC252 source oil along with the samples collected in this study were analyzed using a gas chromatography coupled with a triple quadrupole mass spectrometry (GC/MS/MS) in Multiple Reaction Monitoring (MRM) mode and the results were compared with results from commonly used GC/MS selective ion monitoring (SIM) method. The results indicate that the MRM method separates interfering ions from interfering compounds and can be a powerful analytical strategy for a reliable identification and determination of trace levels of biomarkers in complex matrices. Source indicators such as the MRM fragment ion chromatograms of the biomarkers and their diagnostic ratios in samples were compared with the MC252 source oil. The preliminary results show that the biomarkers were below detection limits in dissolved samples. However, in few particulate and seafloor sediment samples, primarily from the immediate vicinity of the Macondo wellhead, contained their patterns. The results also illustrate that these biomarker compounds have been weathered within 1-3 years following the oil spill, and their DWH oil signature in some of these samples reflects this weathering.

Growth model for large branched three-dimensional hydraulic crack system in gas or oil shale

PubMed Central

Chau, Viet T.

2016-01-01

Recent analysis of gas outflow histories at wellheads shows that the hydraulic crack spacing must be of the order of 0.1 m (rather than 1 m or 10 m). Consequently, the existing models, limited to one or several cracks, are unrealistic. The reality is 105–106 almost vertical hydraulic cracks per fracking stage. Here, we study the growth of two intersecting near-orthogonal systems of parallel hydraulic cracks spaced at 0.1 m, preferably following pre-existing rock joints. One key idea is that, to model lateral cracks branching from a primary crack wall, crack pressurization, by viscous Poiseuille-type flow, of compressible (proppant-laden) frac water must be complemented with the pressurization of a sufficient volume of micropores and microcracks by Darcy-type water diffusion into the shale, to generate tension along existing crack walls, overcoming the strength limit of the cohesive-crack or crack-band model. A second key idea is that enforcing the equilibrium of stresses in cracks, pores and water, with the generation of tension in the solid phase, requires a new three-phase medium concept, which is transitional between Biot’s two-phase medium and Terzaghi’s effective stress and introduces the loading of the solid by pressure gradients of diffusing pore water. A computer program, combining finite elements for deformation and fracture with volume elements for water flow, is developed to validate the new model. This article is part of the themed issue ‘Energy and the subsurface’. PMID:27597791

Growth model for large branched three-dimensional hydraulic crack system in gas or oil shale.

PubMed

Chau, Viet T; Bažant, Zdeněk P; Su, Yewang

2016-10-13

Recent analysis of gas outflow histories at wellheads shows that the hydraulic crack spacing must be of the order of 0.1 m (rather than 1 m or 10 m). Consequently, the existing models, limited to one or several cracks, are unrealistic. The reality is 10(5)-10(6) almost vertical hydraulic cracks per fracking stage. Here, we study the growth of two intersecting near-orthogonal systems of parallel hydraulic cracks spaced at 0.1 m, preferably following pre-existing rock joints. One key idea is that, to model lateral cracks branching from a primary crack wall, crack pressurization, by viscous Poiseuille-type flow, of compressible (proppant-laden) frac water must be complemented with the pressurization of a sufficient volume of micropores and microcracks by Darcy-type water diffusion into the shale, to generate tension along existing crack walls, overcoming the strength limit of the cohesive-crack or crack-band model. A second key idea is that enforcing the equilibrium of stresses in cracks, pores and water, with the generation of tension in the solid phase, requires a new three-phase medium concept, which is transitional between Biot's two-phase medium and Terzaghi's effective stress and introduces the loading of the solid by pressure gradients of diffusing pore water. A computer program, combining finite elements for deformation and fracture with volume elements for water flow, is developed to validate the new model.This article is part of the themed issue 'Energy and the subsurface'. © 2016 The Author(s).

Atmospheric emissions and air quality impacts from natural gas production and use.

PubMed

Allen, David T

2014-01-01

The US Energy Information Administration projects that hydraulic fracturing of shale formations will become a dominant source of domestic natural gas supply over the next several decades, transforming the energy landscape in the United States. However, the environmental impacts associated with fracking for shale gas have made it controversial. This review examines emissions and impacts of air pollutants associated with shale gas production and use. Emissions and impacts of greenhouse gases, photochemically active air pollutants, and toxic air pollutants are described. In addition to the direct atmospheric impacts of expanded natural gas production, indirect effects are also described. Widespread availability of shale gas can drive down natural gas prices, which, in turn, can impact the use patterns for natural gas. Natural gas production and use in electricity generation are used as a case study for examining these indirect consequences of expanded natural gas availability.

Alternative Fuels Data Center: How Do Natural Gas Vehicles Work?

Science.gov Websites

Natural Gas Vehicles Work? to someone by E-mail Share Alternative Fuels Data Center: How Do Natural Gas Vehicles Work? on Facebook Tweet about Alternative Fuels Data Center: How Do Natural Gas Vehicles Work? on Twitter Bookmark Alternative Fuels Data Center: How Do Natural Gas Vehicles Work? on Google

30 CFR 203.73 - How do suspension volumes apply to natural gas?

Code of Federal Regulations, 2010 CFR

2010-07-01

... 30 Mineral Resources 2 2010-07-01 2010-07-01 false How do suspension volumes apply to natural gas... suspension volumes apply to natural gas? You must measure natural gas production under the royalty-suspension volume as follows: 5.62 thousand cubic feet of natural gas, measured in accordance with 30 CFR part 250...

76 FR 28016 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-05-13

... Natural Gas Company; Notice of Application On April 26, 2011, El Paso Natural Gas Company (El Paso), P.O...) an application under section 7(b) of the Natural Gas Act (NGA) and Part 157.5 of the Commission's... Unit 2B since it has become functionally obsolete and is no longer needed to provide natural gas...

Alternative Fuels Data Center: Natural Gas Safety after a Traffic Accident

Science.gov Websites

Natural Gas Safety after a Traffic Accident to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Safety after a Traffic Accident on Facebook Tweet about Alternative Fuels Data Center : Natural Gas Safety after a Traffic Accident on Twitter Bookmark Alternative Fuels Data Center: Natural Gas

18 CFR 284.269 - Intrastate pipeline and local distribution company emergency sales rates.

Code of Federal Regulations, 2011 CFR

2011-04-01

... NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale... emergency natural gas under this subpart in accordance with § 284.142. [Order 449, 51 FR 9187, Mar. 18, 1986...

30 CFR 203.73 - How do suspension volumes apply to natural gas?

Code of Federal Regulations, 2011 CFR

2011-07-01

... 30 Mineral Resources 2 2011-07-01 2011-07-01 false How do suspension volumes apply to natural gas... § 203.73 How do suspension volumes apply to natural gas? You must measure natural gas production under the royalty-suspension volume as follows: 5.62 thousand cubic feet of natural gas, measured in...

Alternative Fuels Data Center: Natural Gas Laws and Incentives

Science.gov Websites

Natural Gas Printable Version Share this resource Send a link to Alternative Fuels Data Center : Natural Gas Laws and Incentives to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Laws and Incentives on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Laws and Incentives

Technical Path Evaluation for High Efficiency, Low Emission Natural Gas Engine

DTIC Science & Technology

2002-05-01

Modeling and Mitigation for Large Bore Natural Gas Engines C. Evaluation of Technologies for Achieving High BMEP Levels in Natural Gas Engines D. Microfine ...Natural Gas Engines C. Evaluation of Technologies for Achieving High BMEP Levels in Natural Gas Engines D. Microfine Water Spray Injection for Knock...91 vi D. MICROFINE WATER SPRAY INJECTION FOR

40 CFR 1048.620 - What are the provisions for exempting large engines fueled by natural gas or liquefied petroleum...

Code of Federal Regulations, 2010 CFR

2010-07-01

... large engines fueled by natural gas or liquefied petroleum gas? 1048.620 Section 1048.620 Protection of... exempting large engines fueled by natural gas or liquefied petroleum gas? (a) If an engine meets all the... natural gas or liquefied petroleum gas. (2) The engine must have maximum engine power at or above 250 kW...

40 CFR 1048.620 - What are the provisions for exempting large engines fueled by natural gas or liquefied petroleum...

Code of Federal Regulations, 2011 CFR

2011-07-01

... large engines fueled by natural gas or liquefied petroleum gas? 1048.620 Section 1048.620 Protection of... exempting large engines fueled by natural gas or liquefied petroleum gas? (a) If an engine meets all the... natural gas or liquefied petroleum gas. (2) The engine must have maximum engine power at or above 250 kW...

Life-cycle greenhouse gas emissions of shale gas, natural gas, coal, and petroleum.

PubMed

Burnham, Andrew; Han, Jeongwoo; Clark, Corrie E; Wang, Michael; Dunn, Jennifer B; Palou-Rivera, Ignasi

2012-01-17

The technologies and practices that have enabled the recent boom in shale gas production have also brought attention to the environmental impacts of its use. It has been debated whether the fugitive methane emissions during natural gas production and transmission outweigh the lower carbon dioxide emissions during combustion when compared to coal and petroleum. Using the current state of knowledge of methane emissions from shale gas, conventional natural gas, coal, and petroleum, we estimated up-to-date life-cycle greenhouse gas emissions. In addition, we developed distribution functions for key parameters in each pathway to examine uncertainty and identify data gaps such as methane emissions from shale gas well completions and conventional natural gas liquid unloadings that need to be further addressed. Our base case results show that shale gas life-cycle emissions are 6% lower than conventional natural gas, 23% lower than gasoline, and 33% lower than coal. However, the range in values for shale and conventional gas overlap, so there is a statistical uncertainty whether shale gas emissions are indeed lower than conventional gas. Moreover, this life-cycle analysis, among other work in this area, provides insight on critical stages that the natural gas industry and government agencies can work together on to reduce the greenhouse gas footprint of natural gas.

Natural gas monthly, August 1993

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1993-08-25

The Natural Gas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and Natural Gas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of Energy (DOE). The NGM highhghts activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information.

17 CFR Appendix D to Part 43 - Other Commodity Swap Categories

Code of Federal Regulations, 2014 CFR

2014-04-01

... Gasoline Naphtha Crude Oil Diesel Petroleum and Products—Other Natural Gas and Related Products Natural Gas Liquids Natural Gas Natural Gas and Related Products—Other Electricity and Sources Coal Electricity...

18 CFR 157.210 - Mainline natural gas facilities.

Code of Federal Regulations, 2010 CFR

2010-04-01

... 18 Conservation of Power and Water Resources 1 2010-04-01 2010-04-01 false Mainline natural gas... COMMISSION, DEPARTMENT OF ENERGY REGULATIONS UNDER NATURAL GAS ACT APPLICATIONS FOR CERTIFICATES OF PUBLIC... GAS ACT Interstate Pipeline Blanket Certificates and Authorization Under Section 7 of the Natural Gas...

Life-cycle analysis of shale gas and natural gas.

DOE Office of Scientific and Technical Information (OSTI.GOV)

Clark, C.E.; Han, J.; Burnham, A.

2012-01-27

The technologies and practices that have enabled the recent boom in shale gas production have also brought attention to the environmental impacts of its use. Using the current state of knowledge of the recovery, processing, and distribution of shale gas and conventional natural gas, we have estimated up-to-date, life-cycle greenhouse gas emissions. In addition, we have developed distribution functions for key parameters in each pathway to examine uncertainty and identify data gaps - such as methane emissions from shale gas well completions and conventional natural gas liquid unloadings - that need to be addressed further. Our base case results showmore » that shale gas life-cycle emissions are 6% lower than those of conventional natural gas. However, the range in values for shale and conventional gas overlap, so there is a statistical uncertainty regarding whether shale gas emissions are indeed lower than conventional gas emissions. This life-cycle analysis provides insight into the critical stages in the natural gas industry where emissions occur and where opportunities exist to reduce the greenhouse gas footprint of natural gas.« less

Air impacts of increased natural gas acquisition, processing, and use: a critical review.

PubMed

Moore, Christopher W; Zielinska, Barbara; Pétron, Gabrielle; Jackson, Robert B

2014-01-01

During the past decade, technological advancements in the United States and Canada have led to rapid and intensive development of many unconventional natural gas plays (e.g., shale gas, tight sand gas, coal-bed methane), raising concerns about environmental impacts. Here, we summarize the current understanding of local and regional air quality impacts of natural gas extraction, production, and use. Air emissions from the natural gas life cycle include greenhouse gases, ozone precursors (volatile organic compounds and nitrogen oxides), air toxics, and particulates. National and state regulators primarily use generic emission inventories to assess the climate, air quality, and health impacts of natural gas systems. These inventories rely on limited, incomplete, and sometimes outdated emission factors and activity data, based on few measurements. We discuss case studies for specific air impacts grouped by natural gas life cycle segment, summarize the potential benefits of using natural gas over other fossil fuels, and examine national and state emission regulations pertaining to natural gas systems. Finally, we highlight specific gaps in scientific knowledge and suggest that substantial additional measurements of air emissions from the natural gas life cycle are essential to understanding the impacts and benefits of this resource.

Alternative Fuels Data Center: How Do Natural Gas Class 8 Trucks Work?

Science.gov Websites

Natural Gas Class 8 Trucks Work? to someone by E-mail Share Alternative Fuels Data Center: How Do Natural Gas Class 8 Trucks Work? on Facebook Tweet about Alternative Fuels Data Center: How Do Natural Gas Class 8 Trucks Work? on Twitter Bookmark Alternative Fuels Data Center: How Do Natural Gas Class 8

18 CFR 260.9 - Reports by natural gas pipeline companies on service interruptions and damage to facilities.

Code of Federal Regulations, 2010 CFR

2010-04-01

... 18 Conservation of Power and Water Resources 1 2010-04-01 2010-04-01 false Reports by natural gas..., NATURAL GAS ACT STATEMENTS AND REPORTS (SCHEDULES) § 260.9 Reports by natural gas pipeline companies on service interruptions and damage to facilities. (a)(1) Every natural gas company must report to the...

30 CFR 260.116 - How do I measure natural gas production on my eligible lease?

Code of Federal Regulations, 2010 CFR

2010-07-01

... 30 Mineral Resources 2 2010-07-01 2010-07-01 false How do I measure natural gas production on my... do I measure natural gas production on my eligible lease? You must measure natural gas production on... natural gas, measured according to part 250, subpart L of this title, equals one barrel of oil equivalent...

76 FR 47573 - TransCanada Alaska Company, LLC; Notice of Intent To Prepare an Environmental Impact Statement...

Federal Register 2010, 2011, 2012, 2013, 2014

2011-08-05

... is a new natural gas pipeline system that would transport natural gas produced on the Alaska North... provisions of section 7(c) of the Natural Gas Act (NGA) and the Alaska Natural Gas Pipeline Act of 2004... pipeline to Valdez, Alaska for delivery into a liquefied natural gas (LNG) plant for liquefaction and...

Alternative Fuels Data Center: How Do Liquefied Natural Gas Trucks Work?

Science.gov Websites

Liquefied Natural Gas Trucks Work? to someone by E-mail Share Alternative Fuels Data Center: How Do Liquefied Natural Gas Trucks Work? on Facebook Tweet about Alternative Fuels Data Center: How Do Liquefied Natural Gas Trucks Work? on Twitter Bookmark Alternative Fuels Data Center: How Do Liquefied Natural Gas

26 CFR 1.613A-0 - Limitations on percentage depletion in the case of oil and gas wells; table of contents.

Code of Federal Regulations, 2011 CFR

2011-04-01

... SERVICE, DEPARTMENT OF THE TREASURY (CONTINUED) INCOME TAX (CONTINUED) INCOME TAXES (CONTINUED) Natural Resources § 1.613A-0 Limitations on percentage depletion in the case of oil and gas wells; table of contents...) Natural gas. (c) Regulated natural gas. (d) Natural gas sold under fixed contract. (e) Qualified natural...

40 CFR Table A-5 to Subpart A of... - Supplier Category List for § 98.2(a)(4)

Code of Federal Regulations, 2013 CFR

2013-07-01

... crude oil. (B) Importers of an annual quantity of petroleum products and natural gas liquids that is... natural gas liquids that is equivalent to 25,000 metric tons CO2e or more. Natural gas and natural gas liquids suppliers (subpart NN): (A) All fractionators. (B) Local natural gas distribution companies that...

40 CFR Table A-5 to Subpart A of... - Supplier Category List for § 98.2(a)(4)

Code of Federal Regulations, 2014 CFR

2014-07-01

... crude oil. (B) Importers of an annual quantity of petroleum products and natural gas liquids that is... natural gas liquids that is equivalent to 25,000 metric tons CO2e or more. Natural gas and natural gas liquids suppliers (subpart NN): (A) All fractionators. (B) Local natural gas distribution companies that...

40 CFR Table A-5 to Subpart A of... - Supplier Category List for § 98.2(a)(4)

Code of Federal Regulations, 2012 CFR

2012-07-01

... crude oil. (B) Importers of an annual quantity of petroleum products and natural gas liquids that is... natural gas liquids that is equivalent to 25,000 metric tons CO2e or more. Natural gas and natural gas liquids suppliers (subpart NN): (A) All fractionators. (B) Local natural gas distribution companies that...

15 CFR Supplement No. 1 to Part 754 - Petroleum and Petroleum Products

Code of Federal Regulations, 2012 CFR

2012-01-01

... more than 125 seconds. 2711.11.0000 Natural gas, methane and mixtures thereof (including liquefied... Petroleum Reserves Production Act. 2 Natural gas and liquefied natural gas (LNG), and synthetic natural gas...

15 CFR Supplement No. 1 to Part 754 - Petroleum and Petroleum Products

Code of Federal Regulations, 2014 CFR

2014-01-01

... more than 125 seconds. 2711.11.0000 Natural gas, methane and mixtures thereof (including liquefied... Petroleum Reserves Production Act. 2 Natural gas and liquefied natural gas (LNG), and synthetic natural gas...

15 CFR Supplement No. 1 to Part 754 - Petroleum and Petroleum Products

Code of Federal Regulations, 2011 CFR

2011-01-01

... more than 125 seconds. 2711.11.0000 Natural gas, methane and mixtures thereof (including liquefied... Petroleum Reserves Production Act. 2 Natural gas and liquefied natural gas (LNG), and synthetic natural gas...

15 CFR Supplement No. 1 to Part 754 - Petroleum and Petroleum Products

Code of Federal Regulations, 2010 CFR

2010-01-01

... more than 125 seconds. 2711.11.0000 Natural gas, methane and mixtures thereof (including liquefied... Petroleum Reserves Production Act. 2 Natural gas and liquefied natural gas (LNG), and synthetic natural gas...

15 CFR Supplement No. 1 to Part 754 - Petroleum and Petroleum Products

Code of Federal Regulations, 2013 CFR

2013-01-01

... more than 125 seconds. 2711.11.0000 Natural gas, methane and mixtures thereof (including liquefied... Petroleum Reserves Production Act. 2 Natural gas and liquefied natural gas (LNG), and synthetic natural gas...

77 FR 28331 - Standards for Business Practices for Interstate Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2012-05-14

...] Standards for Business Practices for Interstate Natural Gas Pipelines AGENCY: Federal Energy Regulatory...) applicable to natural gas pipelines. The Commission, however, did not propose to adopt two standards it found... Wholesale Gas Quadrant of the North American Energy Standards Board (NAESB) applicable to natural gas...

75 FR 67352 - Liberty Natural Gas, LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2010-11-02

... Gas, LLC; Notice of Application October 26, 2010. On October 14, 2010, Liberty Natural Gas, LLC... of the Natural Gas Act and section 157 of the Commission's Regulations requesting: (1) A certificate of public convenience and necessity to construct and operate a 9.2-mile natural gas pipeline and...

26 CFR 1.613A-7 - Definitions.

Code of Federal Regulations, 2014 CFR

2014-04-01

... regulations thereunder— (a) Domestic. The term domestic, as applied to oil and gas wells (or to production..., as defined in section 638 and the regulations thereunder. (b) Natural gas. The term natural gas means... mineral or minerals produced. (d) Natural gas sold under a fixed contract. The term natural gas sold under...

40 CFR 98.407 - Records that must be retained.

Code of Federal Regulations, 2010 CFR

2010-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.407... support volumes of natural gas and NGLs that are reported under this part. (b) Records documenting any... on the accuracy of measurements of volumes of natural gas and NGLs delivered to customers or on...

40 CFR 98.406 - Data reporting requirements.

Code of Federal Regulations, 2010 CFR

2010-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.406 Data..., isobutane, and pentanes plus. (3) Annual volumes in Mscf of natural gas received for processing. (4) Annual... report for each LDC shall contain the following information. (1) Annual volume in Mscf of natural gas...

40 CFR 98.407 - Records that must be retained.

Code of Federal Regulations, 2012 CFR

2012-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.407... volumes of natural gas and NGLs that are reported under this part. (b) Records documenting any estimates... on the accuracy of measurements of volumes of natural gas and NGLs delivered to customers or on...

40 CFR 98.406 - Data reporting requirements.

Code of Federal Regulations, 2011 CFR

2011-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.406 Data..., isobutane, and pentanes plus. (3) Annual volumes in Mscf of natural gas received for processing. (4) Annual... Mscf of natural gas received by the LDC at its city gate stations for redelivery on the LDC's...

40 CFR 98.406 - Data reporting requirements.

Code of Federal Regulations, 2012 CFR

2012-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.406 Data..., isobutane, and pentanes plus. (3) Annual volumes in Mscf of natural gas received for processing. (4) Annual... Mscf of natural gas received by the LDC at its city gate stations for redelivery on the LDC's...

40 CFR 98.403 - Calculating GHG emissions.

Code of Federal Regulations, 2014 CFR

2014-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.403... natural gas processing plants from local production, received as a liquid and vaporized for delivery, or... local production, or natural gas that was received as a liquid, vaporized and delivered, and any other...

40 CFR 98.407 - Records that must be retained.

Code of Federal Regulations, 2011 CFR

2011-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.407... volumes of natural gas and NGLs that are reported under this part. (b) Records documenting any estimates... on the accuracy of measurements of volumes of natural gas and NGLs delivered to customers or on...

40 CFR 98.406 - Data reporting requirements.

Code of Federal Regulations, 2014 CFR

2014-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.406 Data..., isobutane, and pentanes plus. (3) Annual volumes in Mscf of natural gas received for processing. (4) Annual... shall contain the following information. (1) Annual volume in Mscf of natural gas received by the LDC at...

40 CFR 98.407 - Records that must be retained.

Code of Federal Regulations, 2013 CFR

2013-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.407... volumes of natural gas and NGLs that are reported under this part. (b) Records documenting any estimates... on the accuracy of measurements of volumes of natural gas and NGLs delivered to customers or on...

40 CFR 98.403 - Calculating GHG emissions.

Code of Federal Regulations, 2013 CFR

2013-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.403... (Mscf) for natural gas and bbl for NGLs). HHVh = Higher heating value of product “h” supplied (MMBtu... LDC shall follow the procedures below. (1) For natural gas that is received for redelivery to...

40 CFR 98.403 - Calculating GHG emissions.

Code of Federal Regulations, 2012 CFR

2012-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.403... (Mscf) for natural gas and bbl for NGLs). HHVh = Higher heating value of product “h” supplied (MMBtu... LDC shall follow the procedures below. (1) For natural gas that is received for redelivery to...

40 CFR 98.406 - Data reporting requirements.

Code of Federal Regulations, 2013 CFR

2013-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.406 Data..., isobutane, and pentanes plus. (3) Annual volumes in Mscf of natural gas received for processing. (4) Annual... Mscf of natural gas received by the LDC at its city gate stations for redelivery on the LDC's...

40 CFR 98.407 - Records that must be retained.

Code of Federal Regulations, 2014 CFR

2014-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.407... natural gas and NGLs that are reported under this part. (b) Records documenting any estimates of missing... accuracy of measurements of volumes of natural gas and NGLs delivered to customers or on behalf of...

40 CFR 98.403 - Calculating GHG emissions.

Code of Federal Regulations, 2011 CFR

2011-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.403... (Mscf) for natural gas and bbl for NGLs). HHVh = Higher heating value of product “h” supplied (MMBtu... LDC shall follow the procedures below. (1) For natural gas that is received for redelivery to...

75 FR 54864 - Combined Notice of Filings No. 2

Federal Register 2010, 2011, 2012, 2013, 2014

2010-09-09

... Refund Report filings: Docket Numbers: RP10-1223-000. Applicants: Natural Gas Pipeline Company of America. Description: Natural Gas Pipeline Company of America LLC submits First Revised Sheet 405 et al. to FERC Gas...: RP10-1225-000. Applicants: Natural Gas Pipeline Company of America. Description: Natural Gas Pipeline...

Vapor spill monitoring method

DOEpatents

Bianchini, Gregory M.; McRae, Thomas G.

1985-01-01

Method for continuous sampling of liquified natural gas effluent from a spill pipe, vaporizing the cold liquified natural gas, and feeding the vaporized gas into an infrared detector to measure the gas composition. The apparatus utilizes a probe having an inner channel for receiving samples of liquified natural gas and a surrounding water jacket through which warm water is flowed to flash vaporize the liquified natural gas.

17 CFR 210.4-10 - Financial accounting and reporting for oil and gas producing activities pursuant to the Federal...

Code of Federal Regulations, 2013 CFR

2013-04-01

... natural gas liquids, or natural gas (“oil and gas”) in their natural states and original locations; (B... processing gas to extract liquid hydrocarbons); and (D) Extraction of saleable hydrocarbons, in the solid... production function as: a. The first point at which oil, gas, or gas liquids, natural or synthetic, are...

17 CFR 210.4-10 - Financial accounting and reporting for oil and gas producing activities pursuant to the Federal...

Code of Federal Regulations, 2012 CFR

2012-04-01

... natural gas liquids, or natural gas (“oil and gas”) in their natural states and original locations; (B... processing gas to extract liquid hydrocarbons); and (D) Extraction of saleable hydrocarbons, in the solid... production function as: a. The first point at which oil, gas, or gas liquids, natural or synthetic, are...

78 FR 8501 - Northern Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2013-02-06

... Natural Gas Company; Notice of Application Take notice that on January 18, 2013, Northern Natural Gas... application pursuant to section 7(c) of the Natural Gas Act (NGA), to amend its certificate [[Page 8502

78 FR 33051 - Notification of Proposed Production Activity, The Gas Company, LLC dba Hawai'i Gas, Subzone 9F...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-06-03

... Activity, The Gas Company, LLC dba Hawai'i Gas, Subzone 9F (Synthetic Natural Gas), Kapolei, Hawaii The Gas... May 22, 2013. The subzone currently has authority to produce synthetic natural gas, carbon dioxide... during customs entry procedures that apply to synthetic natural gas, carbon dioxide, hydrogen...

What is shale gas and why is it important?

EIA Publications

2012-01-01

Shale gas refers to natural gas that is trapped within shale formations. Shales are fine-grained sedimentary rocks that can be rich sources of petroleum and natural gas. Over the past decade, the combination of horizontal drilling and hydraulic fracturing has allowed access to large volumes of shale gas that were previously uneconomical to produce. The production of natural gas from shale formations has rejuvenated the natural gas industry in the United States.

Natural gas and CO2 price variation: impact on the relative cost-efficiency of LNG and pipelines.

PubMed

Ulvestad, Marte; Overland, Indra

2012-06-01

THIS ARTICLE DEVELOPS A FORMAL MODEL FOR COMPARING THE COST STRUCTURE OF THE TWO MAIN TRANSPORT OPTIONS FOR NATURAL GAS: liquefied natural gas (LNG) and pipelines. In particular, it evaluates how variations in the prices of natural gas and greenhouse gas emissions affect the relative cost-efficiency of these two options. Natural gas is often promoted as the most environmentally friendly of all fossil fuels, and LNG as a modern and efficient way of transporting it. Some research has been carried out into the local environmental impact of LNG facilities, but almost none into aspects related to climate change. This paper concludes that at current price levels for natural gas and CO 2 emissions the distance from field to consumer and the volume of natural gas transported are the main determinants of transport costs. The pricing of natural gas and greenhouse emissions influence the relative cost-efficiency of LNG and pipeline transport, but only to a limited degree at current price levels. Because more energy is required for the LNG process (especially for fuelling the liquefaction process) than for pipelines at distances below 9100 km, LNG is more exposed to variability in the price of natural gas and greenhouse gas emissions up to this distance. If the prices of natural gas and/or greenhouse gas emission rise dramatically in the future, this will affect the choice between pipelines and LNG. Such a price increase will be favourable for pipelines relative to LNG.

Natural gas and CO2 price variation: impact on the relative cost-efficiency of LNG and pipelines

PubMed Central

Ulvestad, Marte; Overland, Indra

2012-01-01

This article develops a formal model for comparing the cost structure of the two main transport options for natural gas: liquefied natural gas (LNG) and pipelines. In particular, it evaluates how variations in the prices of natural gas and greenhouse gas emissions affect the relative cost-efficiency of these two options. Natural gas is often promoted as the most environmentally friendly of all fossil fuels, and LNG as a modern and efficient way of transporting it. Some research has been carried out into the local environmental impact of LNG facilities, but almost none into aspects related to climate change. This paper concludes that at current price levels for natural gas and CO2 emissions the distance from field to consumer and the volume of natural gas transported are the main determinants of transport costs. The pricing of natural gas and greenhouse emissions influence the relative cost-efficiency of LNG and pipeline transport, but only to a limited degree at current price levels. Because more energy is required for the LNG process (especially for fuelling the liquefaction process) than for pipelines at distances below 9100 km, LNG is more exposed to variability in the price of natural gas and greenhouse gas emissions up to this distance. If the prices of natural gas and/or greenhouse gas emission rise dramatically in the future, this will affect the choice between pipelines and LNG. Such a price increase will be favourable for pipelines relative to LNG. PMID:24683269

U.S. Natural Gas Markets: Recent Trends and Prospects for the Future

EIA Publications

2001-01-01

The purpose of this study is to examine recent trends and prospects for the future of the U.S. natural gas market. Natural gas prices rose dramatically in 2000 and remained high through the first part of 2001, raising concerns about the future of natural gas prices and potential for natural gas to fuel the growth of the U.S. economy.

Natural Gas Imports and Exports

EIA Publications

2017-01-01

Natural gas net imports set a record low of 685 billion cubic feet (Bcf) in 2016, continuing a decline for the 10th consecutive year. U.S. exports were more than three times larger than the level 10 years ago as a result of significant infrastructure improvements to natural gas pipelines and liquefied natural gas facilities. These changes are discussed in the U.S. Natural Gas Imports & Exports 2016 report.

Blending Hydrogen into Natural Gas Pipeline Networks: A Review of Key Issues

DOE Office of Scientific and Technical Information (OSTI.GOV)

Melaina, M. W.; Antonia, O.; Penev, M.

2013-03-01

The United States has 11 distinct natural gas pipeline corridors: five originate in the Southwest, four deliver natural gas from Canada, and two extend from the Rocky Mountain region. This study assesses the potential to deliver hydrogen through the existing natural gas pipeline network as a hydrogen and natural gas mixture to defray the cost of building dedicated hydrogen pipelines.

Alternative Fuels Data Center: How Do Bi-fuel Natural Gas Vehicles Work?

Science.gov Websites

AddThis.com... How Do Bi-fuel Natural Gas Vehicles Work? A bi-fuel natural gas vehicle can use either gasoline or natural gas in the same internal combustion engine. Both fuels are stored on board and the driver Components of a Bi-fuel Natural Gas Vehicle Battery: The battery provides electricity to start the engine and

Accounting for fuel price risk: Using forward natural gas prices instead of gas price forecasts to compare renewable to natural gas-fired generation

DOE Office of Scientific and Technical Information (OSTI.GOV)

Bolinger, Mark; Wiser, Ryan; Golove, William

2003-08-13

Against the backdrop of increasingly volatile natural gas prices, renewable energy resources, which by their nature are immune to natural gas fuel price risk, provide a real economic benefit. Unlike many contracts for natural gas-fired generation, renewable generation is typically sold under fixed-price contracts. Assuming that electricity consumers value long-term price stability, a utility or other retail electricity supplier that is looking to expand its resource portfolio (or a policymaker interested in evaluating different resource options) should therefore compare the cost of fixed-price renewable generation to the hedged or guaranteed cost of new natural gas-fired generation, rather than to projectedmore » costs based on uncertain gas price forecasts. To do otherwise would be to compare apples to oranges: by their nature, renewable resources carry no natural gas fuel price risk, and if the market values that attribute, then the most appropriate comparison is to the hedged cost of natural gas-fired generation. Nonetheless, utilities and others often compare the costs of renewable to gas-fired generation using as their fuel price input long-term gas price forecasts that are inherently uncertain, rather than long-term natural gas forward prices that can actually be locked in. This practice raises the critical question of how these two price streams compare. If they are similar, then one might conclude that forecast-based modeling and planning exercises are in fact approximating an apples-to-apples comparison, and no further consideration is necessary. If, however, natural gas forward prices systematically differ from price forecasts, then the use of such forecasts in planning and modeling exercises will yield results that are biased in favor of either renewable (if forwards < forecasts) or natural gas-fired generation (if forwards > forecasts). In this report we compare the cost of hedging natural gas price risk through traditional gas-based hedging instruments (e.g., futures, swaps, and fixed-price physical supply contracts) to contemporaneous forecasts of spot natural gas prices, with the purpose of identifying any systematic differences between the two. Although our data set is quite limited, we find that over the past three years, forward gas prices for durations of 2-10 years have been considerably higher than most natural gas spot price forecasts, including the reference case forecasts developed by the Energy Information Administration (EIA). This difference is striking, and implies that resource planning and modeling exercises based on these forecasts over the past three years have yielded results that are biased in favor of gas-fired generation (again, presuming that long-term stability is desirable). As discussed later, these findings have important ramifications for resource planners, energy modelers, and policy-makers.« less

75 FR 29404 - Contract Reporting Requirements of Intrastate Natural Gas Companies

Federal Register 2010, 2011, 2012, 2013, 2014

2010-05-26

...; Order No. 735] Contract Reporting Requirements of Intrastate Natural Gas Companies May 20, 2010. AGENCY... revises the contract reporting requirements for those natural gas pipelines that fall under the Commission's jurisdiction pursuant to section 311 of the Natural Gas Policy Act or section 1(c) of the Natural...

76 FR 80553 - Mandatory Reporting of Greenhouse Gases: Technical Revisions to the Petroleum and Natural Gas...

Federal Register 2010, 2011, 2012, 2013, 2014

2011-12-23

... facilities 486210 Pipeline transportation of natural gas. Petroleum and Natural Gas Systems. 221210 Natural... and Budget PHMSA Pipeline and Hazardous Material Safety Administration QA/QC quality assurance/quality... distribution pipelines, but also into liquefied natural gas storage or into underground storage. We are...

76 FR 70123 - Agency Information Collection Activities: Proposed Collection; Comment Request

Federal Register 2010, 2011, 2012, 2013, 2014

2011-11-10

... Natural Gas Production Report. DATES: Comments must be filed by January 9, 2012. If you anticipate... the United States and the requirement for accurate and timely natural gas production information... disseminated through the EIA Natural Gas Monthly, Monthly Natural Gas Gross Production Report, and EIA Natural...

78 FR 58529 - Floridian Natural Gas Storage Company, LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2013-09-24

... Natural Gas Storage Company, LLC; Notice of Application Take notice that on September 4, 2013, Floridian Natural Gas Storage Company, LLC (Floridian Gas Storage), 1000 Louisiana Street, Suite 4361, Houston, Texas 77002, filed in Docket No. CP13-541-000 an application under section 7(c) of the Natural Gas Act...

76 FR 66708 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-10-27

... Gas Company; Notice of Application Take notice that on October 7, 2011, El Paso Natural Gas Company... application pursuant to section 3 of the Natural Gas Act (NGA), requesting amendment and reissuance of its... application may be directed to Susan C. Stires, Director, Regulatory Affairs Department, El Paso Natural Gas...

77 FR 3757 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2012-01-25

... Gas Company; Notice of Application Take notice that on January 5, 2012, El Paso Natural Gas Company... referenced docket pursuant to section 7(b) of the Natural Gas Act (NGA) for approval to abandon in place... application may be directed to Susan C. Stires, Director, Regulatory Affairs Department, El Paso Natural Gas...

77 FR 20617 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2012-04-05

... Gas Company; Notice of Application Take notice that on March 23, 2012, El Paso Natural Gas Company (El... application pursuant to section 3 of the Natural Gas Act (NGA), for a new Presidential Permit and... transport natural gas to a new delivery interconnect with Tarahumara Pipeline at the United States/Mexico...

Alternative Fuels Data Center: Natural Gas Distribution

Science.gov Websites

. Gas is distributed using 305,000 miles of transmission pipelines (see map), while an additional 2.2 Natural Gas Distribution to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Distribution on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Distribution on Twitter

Volatile organic compound emissions from unconventional natural gas production: Source signatures and air quality impacts

NASA Astrophysics Data System (ADS)

Swarthout, Robert F.

Advances in horizontal drilling and hydraulic fracturing over the past two decades have allowed access to previously unrecoverable reservoirs of natural gas and led to an increase in natural gas production. Intensive unconventional natural gas extraction has led to concerns about impacts on air quality. Unconventional natural gas production has the potential to emit vast quantities of volatile organic compounds (VOCs) into the atmosphere. Many VOCs can be toxic, can produce ground-level ozone or secondary organic aerosols, and can impact climate. This dissertation presents the results of experiments designed to validate VOC measurement techniques, to quantify VOC emission rates from natural gas sources, to identify source signatures specific to natural gas emissions, and to quantify the impacts of these emissions on potential ozone formation and human health. Measurement campaigns were conducted in two natural gas production regions: the Denver-Julesburg Basin in northeast Colorado and the Marcellus Shale region surrounding Pittsburgh, Pennsylvania. An informal measurement intercomparison validated the canister sampling methodology used throughout this dissertation for the measurement of oxygenated VOCs. Mixing ratios of many VOCs measured during both campaigns were similar to or higher than those observed in polluted cities. Fluxes of natural gas-associated VOCs in Colorado ranged from 1.5-3 times industry estimates. Similar emission ratios relative to propane were observed for C2-C6 alkanes in both regions, and an isopentane:n-pentane ratio ≈1 was identified as a unique tracer for natural gas emissions. Source apportionment estimates indicated that natural gas emissions were responsible for the majority of C2-C8 alkanes observed in each region, but accounted for a small proportion of alkenes and aromatic compounds. Natural gas emissions in both regions accounted for approximately 20% of hydroxyl radical reactivity, which could hinder federal ozone standard compliance in downwind cities. A health risk assessment showed no increase in cancer or chronic non-cancer risk at locations near natural gas wells in Pennsylvania, but the contribution of natural gas emissions to total risk was 3-6 times higher near wells. These results will assist policy makers, natural gas producers, and citizen stakeholders in crafting effective policies to control VOC emissions from natural gas production activities.

75 FR 71733 - Requirements for Measurement Facilities Used for the Royalty Valuation of Processed Natural Gas

Federal Register 2010, 2011, 2012, 2013, 2014

2010-11-24

... measurement of inlet production, residue gas, fuel gas, flare gas, condensate, natural gas liquids, or any... governing gas and liquid hydrocarbon production measurement. We have recently completed the first phase of... Requirements for Measurement Facilities Used for the Royalty Valuation of Processed Natural Gas AGENCY: Bureau...

Life cycle water consumption for shale gas and conventional natural gas.

PubMed

Clark, Corrie E; Horner, Robert M; Harto, Christopher B

2013-10-15

Shale gas production represents a large potential source of natural gas for the nation. The scale and rapid growth in shale gas development underscore the need to better understand its environmental implications, including water consumption. This study estimates the water consumed over the life cycle of conventional and shale gas production, accounting for the different stages of production and for flowback water reuse (in the case of shale gas). This study finds that shale gas consumes more water over its life cycle (13-37 L/GJ) than conventional natural gas consumes (9.3-9.6 L/GJ). However, when used as a transportation fuel, shale gas consumes significantly less water than other transportation fuels. When used for electricity generation, the combustion of shale gas adds incrementally to the overall water consumption compared to conventional natural gas. The impact of fuel production, however, is small relative to that of power plant operations. The type of power plant where the natural gas is utilized is far more important than the source of the natural gas.

Low carbon renewable natural gas production from coalbeds and implications for carbon capture and storage.

PubMed

Huang, Zaixing; Sednek, Christine; Urynowicz, Michael A; Guo, Hongguang; Wang, Qiurong; Fallgren, Paul; Jin, Song; Jin, Yan; Igwe, Uche; Li, Shengpin

2017-09-18

Isotopic studies have shown that many of the world's coalbed natural gas plays are secondary biogenic in origin, suggesting a potential for gas regeneration through enhanced microbial activities. The generation of biogas through biostimulation and bioaugmentation is limited to the bioavailability of coal-derived compounds and is considered carbon positive. Here we show that plant-derived carbohydrates can be used as alternative substrates for gas generation by the indigenous coal seam microorganisms. The results suggest that coalbeds can act as natural geobioreactors to produce low carbon renewable natural gas, which can be considered carbon neutral, or perhaps even carbon negative depending on the amount of carbon sequestered within the coal. In addition, coal bioavailability is no longer a limiting factor. This approach has the potential of bridging the gap between fossil fuels and renewable energy by utilizing existing coalbed natural gas infrastructure to produce low carbon renewable natural gas and reducing global warming.Coalbeds produce natural gas, which has been observed to be enhanced by in situ microbes. Here, the authors add plant-derived carbohydrates (monosaccharides) to coal seams to be converted by indigenous microbes into natural gas, thus demonstrating a potential low carbon renewable natural gas resource.

Apparatus for the liquefaction of natural gas and methods relating to same

DOEpatents

Turner, Terry D [Ammon, ID; Wilding, Bruce M [Idaho Falls, ID; McKellar, Michael G [Idaho Falls, ID

2009-09-22

An apparatus and method for producing liquefied natural gas. A liquefaction plant may be coupled to a source of unpurified natural gas, such as a natural gas pipeline at a pressure letdown station. A portion of the gas is drawn off and split into a process stream and a cooling stream. The cooling stream passes through an expander creating work output. A compressor may be driven by the work output and compresses the process stream. The compressed process stream is cooled, such as by the expanded cooling stream. The cooled, compressed process stream is expanded to liquefy the natural gas. A gas-liquid separator separates a vapor from the liquid natural gas. A portion of the liquid gas is used for additional cooling. Gas produced within the system may be recompressed for reintroduction into a receiving line or recirculation within the system for further processing.

Natural Gas and Cellulosic Biomass: A Clean Fuel Combination? Determining the Natural Gas Blending Wall in Biofuel Production.

PubMed

M Wright, Mark; Seifkar, Navid; Green, William H; Román-Leshkov, Yuriy

2015-07-07

Natural gas has the potential to increase the biofuel production output by combining gas- and biomass-to-liquids (GBTL) processes followed by naphtha and diesel fuel synthesis via Fischer-Tropsch (FT). This study reflects on the use of commercial-ready configurations of GBTL technologies and the environmental impact of enhancing biofuels with natural gas. The autothermal and steam-methane reforming processes for natural gas conversion and the gasification of biomass for FT fuel synthesis are modeled to estimate system well-to-wheel emissions and compare them to limits established by U.S. renewable fuel mandates. We show that natural gas can enhance FT biofuel production by reducing the need for water-gas shift (WGS) of biomass-derived syngas to achieve appropriate H2/CO ratios. Specifically, fuel yields are increased from less than 60 gallons per ton to over 100 gallons per ton with increasing natural gas input. However, GBTL facilities would need to limit natural gas use to less than 19.1% on a LHV energy basis (7.83 wt %) to avoid exceeding the emissions limits established by the Renewable Fuels Standard (RFS2) for clean, advanced biofuels. This effectively constitutes a blending limit that constrains the use of natural gas for enhancing the biomass-to-liquids (BTL) process.

Natural Gas Market Centers: A 2008 Update

EIA Publications

2009-01-01

This special report looks at the current status of market centers in today's natural gas marketplace, examining their role and their importance to natural gas shippers, pipelines, and others involved in the transportation of natural gas over the North American pipeline network.

Natural gas monthly, July 1994

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1994-07-20

The Natural Gas Monthly (NGM) highlights activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information.

Natural gas monthly, September 1995

DOE Office of Scientific and Technical Information (OSTI.GOV)

NONE

1995-09-27

The (NGM) Natural Gas Monthly highlights activities, events, and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information.

Mathematical simulation of the process of condensing natural gas

NASA Astrophysics Data System (ADS)

Tastandieva, G. M.

2015-01-01

Presents a two-dimensional unsteady model of heat transfer in terms of condensation of natural gas at low temperatures. Performed calculations of the process heat and mass transfer of liquefied natural gas (LNG) storage tanks of cylindrical shape. The influence of model parameters on the nature of heat transfer. Defined temperature regimes eliminate evaporation by cooling liquefied natural gas. The obtained dependence of the mass flow rate of vapor condensation gas temperature. Identified the possibility of regulating the process of "cooling down" liquefied natural gas in terms of its partial evaporation with low cost energy.

26 CFR 1.907(c)-3 - FOGEI and FORI taxes (for taxable years beginning after December 31, 1982).

Code of Federal Regulations, 2012 CFR

2012-04-01

... such a percentage of value solely for purposes of making the tax allocation in paragraph (a)(4) of this... creditable taxes under section 901, that the fair market value of the oil at the port is $10 per barrel, and... added to the oil beyond the well-head which is part of Y's tax base ($10-$9). (v) The royalty deductions...

Scientific basis for safely shutting in the Macondo Well after the April 20, 2010 Deepwater Horizon blowout

USGS Publications Warehouse

Hickman, Stephen H.; Hsieh, Paul A.; Mooney, Walter D.; Enomoto, Catherine B.; Nelson, Philip H.; Flemings, Peter; Mayer, Larry; Moran, Kathryn; Weber, Thomas; McNutt, Marcia K.; Rice, James R.

2012-01-01

As part of the government response to the Deepwater Horizon blowout, a Well Integrity Team evaluated the geologic hazards of shutting in the Macondo Well at the seafloor and determined the conditions under which it could safely be undertaken. Of particular concern was the possibility that, under the anticipated high shut-in pressures, oil could leak out of the well casing below the seafloor. Such a leak could lead to new geologic pathways for hydrocarbon release to the Gulf of Mexico. Evaluating this hazard required analyses of 2D and 3D seismic surveys, seafloor bathymetry, sediment properties, geophysical well logs, and drilling data to assess the geological, hydrological, and geomechanical conditions around the Macondo Well. After the well was successfully capped and shut in on July 15, 2010, a variety of monitoring activities were used to assess subsurface well integrity. These activities included acquisition of wellhead pressure data, marine multichannel seismic profiles, seafloor and water-column sonar surveys, and wellhead visual/acoustic monitoring. These data showed that the Macondo Well was not leaking after shut in, and therefore, it could remain safely shut until reservoir pressures were suppressed (killed) with heavy drilling mud and the well was sealed with cement.

The Effect of Hydrostatic Pressure on Enrichments of Hydrocarbon Degrading Microbes From the Gulf of Mexico Following the Deepwater Horizon Oil Spill

PubMed Central

Marietou, Angeliki; Chastain, Roger; Beulig, Felix; Scoma, Alberto; Hazen, Terry C.; Bartlett, Douglas H.

2018-01-01

The Deepwater Horizon oil spill was one of the largest and deepest oil spills recorded. The wellhead was located at approximately 1500 m below the sea where low temperature and high pressure are key environmental characteristics. Using cells collected 4 months following the Deepwater Horizon oil spill at the Gulf of Mexico, we set up Macondo crude oil enrichments at wellhead temperature and different pressures to determine the effect of increasing depth/pressure to the in situ microbial community and their ability to degrade oil. We observed oil degradation under all pressure conditions tested [0.1, 15, and 30 megapascals (MPa)], although oil degradation profiles, cell numbers, and hydrocarbon degradation gene abundances indicated greatest activity at atmospheric pressure. Under all incubations the growth of psychrophilic bacteria was promoted. Bacteria closely related to Oleispira antarctica RB-8 dominated the communities at all pressures. At 30 MPa we observed a shift toward Photobacterium, a genus that includes piezophiles. Alphaproteobacterial members of the Sulfitobacter, previously associated with oil-degradation, were also highly abundant at 0.1 MPa. Our results suggest that pressure acts synergistically with low temperature to slow microbial growth and thus oil degradation in deep-sea environments. PMID:29755436

Oil release from Macondo well MC252 following the Deepwater Horizon accident.

PubMed

Griffiths, Stewart K

2012-05-15

Oil flow rates and cumulative discharge from the BP Macondo Prospect well in the Gulf of Mexico are calculated using a physically based model along with wellhead pressures measured at the blowout preventer (BOP) over the 86-day period following the Deepwater Horizon accident. Parameters appearing in the model are determined empirically from pressures measured during well shut-in and from pressures and flow rates measured the preceding day. This methodology rigorously accounts for ill-characterized evolution of the marine riser, installation and removal of collection caps, and any erosion at the wellhead. The calculated initial flow rate is 67,100 stock-tank barrels per day (stbd), which decays to 54,400 stbd just prior to installation of the capping stack and subsequent shut-in. The calculated cumulative discharge is 5.4 million stock-tank barrels, of which 4.6 million barrels entered the Gulf. Quantifiable uncertainties in these values are -9.3% and +7.5%, yielding a likely total discharge in the range from 4.9 to 5.8 million barrels. Minimum and maximum credible values of this discharge are 4.6 and 6.2 million barrels. Alternative calculations using the reservoir and sea-floor pressures indicate that any erosion within the BOP had little affect on cumulative discharge.

The Effect of Hydrostatic Pressure on Enrichments of Hydrocarbon Degrading Microbes From the Gulf of Mexico Following the Deepwater Horizon Oil Spill.

PubMed

Marietou, Angeliki; Chastain, Roger; Beulig, Felix; Scoma, Alberto; Hazen, Terry C; Bartlett, Douglas H

2018-01-01

The Deepwater Horizon oil spill was one of the largest and deepest oil spills recorded. The wellhead was located at approximately 1500 m below the sea where low temperature and high pressure are key environmental characteristics. Using cells collected 4 months following the Deepwater Horizon oil spill at the Gulf of Mexico, we set up Macondo crude oil enrichments at wellhead temperature and different pressures to determine the effect of increasing depth/pressure to the in situ microbial community and their ability to degrade oil. We observed oil degradation under all pressure conditions tested [0.1, 15, and 30 megapascals (MPa)], although oil degradation profiles, cell numbers, and hydrocarbon degradation gene abundances indicated greatest activity at atmospheric pressure. Under all incubations the growth of psychrophilic bacteria was promoted. Bacteria closely related to Oleispira antarctica RB-8 dominated the communities at all pressures. At 30 MPa we observed a shift toward Photobacterium , a genus that includes piezophiles. Alphaproteobacterial members of the Sulfitobacter , previously associated with oil-degradation, were also highly abundant at 0.1 MPa. Our results suggest that pressure acts synergistically with low temperature to slow microbial growth and thus oil degradation in deep-sea environments.

26 CFR 1.613A-7 - Definitions.

Code of Federal Regulations, 2011 CFR

2011-04-01

... TAXES (CONTINUED) Natural Resources § 1.613A-7 Definitions. For purposes of section 613A and the..., as defined in section 638 and the regulations thereunder. (b) Natural gas. The term natural gas means...) Regulated natural gas. Natural gas is considered to be “regulated” only if all of the following requirements...

77 FR 35958 - Northern Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2012-06-15

... Natural Gas Company; Notice of Application Take notice that on May 30, 2012, Northern Natural Gas Company... authority, pursuant to Part 157 of the Commission's regulations and section 7(b) of the Natural Gas Act, to... public inspection. Specifically, Northern Natural Proposes to sell to DKM approximately 126 miles of 24...

Greater focus needed on methane leakage from natural gas infrastructure.

PubMed

Alvarez, Ramón A; Pacala, Stephen W; Winebrake, James J; Chameides, William L; Hamburg, Steven P

2012-04-24

Natural gas is seen by many as the future of American energy: a fuel that can provide energy independence and reduce greenhouse gas emissions in the process. However, there has also been confusion about the climate implications of increased use of natural gas for electric power and transportation. We propose and illustrate the use of technology warming potentials as a robust and transparent way to compare the cumulative radiative forcing created by alternative technologies fueled by natural gas and oil or coal by using the best available estimates of greenhouse gas emissions from each fuel cycle (i.e., production, transportation and use). We find that a shift to compressed natural gas vehicles from gasoline or diesel vehicles leads to greater radiative forcing of the climate for 80 or 280 yr, respectively, before beginning to produce benefits. Compressed natural gas vehicles could produce climate benefits on all time frames if the well-to-wheels CH(4) leakage were capped at a level 45-70% below current estimates. By contrast, using natural gas instead of coal for electric power plants can reduce radiative forcing immediately, and reducing CH(4) losses from the production and transportation of natural gas would produce even greater benefits. There is a need for the natural gas industry and science community to help obtain better emissions data and for increased efforts to reduce methane leakage in order to minimize the climate footprint of natural gas.

Greater focus needed on methane leakage from natural gas infrastructure

PubMed Central

Alvarez, Ramón A.; Pacala, Stephen W.; Winebrake, James J.; Chameides, William L.; Hamburg, Steven P.

2012-01-01

Natural gas is seen by many as the future of American energy: a fuel that can provide energy independence and reduce greenhouse gas emissions in the process. However, there has also been confusion about the climate implications of increased use of natural gas for electric power and transportation. We propose and illustrate the use of technology warming potentials as a robust and transparent way to compare the cumulative radiative forcing created by alternative technologies fueled by natural gas and oil or coal by using the best available estimates of greenhouse gas emissions from each fuel cycle (i.e., production, transportation and use). We find that a shift to compressed natural gas vehicles from gasoline or diesel vehicles leads to greater radiative forcing of the climate for 80 or 280 yr, respectively, before beginning to produce benefits. Compressed natural gas vehicles could produce climate benefits on all time frames if the well-to-wheels CH4 leakage were capped at a level 45–70% below current estimates. By contrast, using natural gas instead of coal for electric power plants can reduce radiative forcing immediately, and reducing CH4 losses from the production and transportation of natural gas would produce even greater benefits. There is a need for the natural gas industry and science community to help obtain better emissions data and for increased efforts to reduce methane leakage in order to minimize the climate footprint of natural gas. PMID:22493226

76 FR 41235 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-07-13

... Natural Gas Company; Notice of Application Take notice that on June 28, 2011, El Paso Natural Gas Company... request for authority, pursuant to 18 CFR part 157 and section 7(b) of the Natural Gas Act, to abandon, by..., Director, Regulatory affairs Department, Colorado Interstate Gas Company, P.O. Box 1087, Colorado Springs...

76 FR 48833 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-08-09

... Natural Gas Company; Notice of Application Take notice that on July 20, 2011, El Paso Natural Gas Company... request for authority, pursuant to 18 CFR part 157 and section 7(b) of the Natural Gas Act, to abandon, in... Department, Colorado Interstate Gas Company, P.O. Box 1087, Colorado Springs, CO 80944, telephone no. (719...

76 FR 66711 - El Paso Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-10-27

... Gas Company; Notice of Application Take notice that on October 11, 2011, El Paso Natural Gas Company... application pursuant to section 7(c) of the Natural Gas Act (NGA) and Part 157 of the Commission's regulations... Natural Gas Company, P.O. Box 1087, Colorado Springs, Colorado 80904, by telephone at (719) 667-7514, by...

75 FR 20271 - Oil and Gas and Sulphur Operations in the Outer Continental Shelf-Oil and Gas Production...

Federal Register 2010, 2011, 2012, 2013, 2014

2010-04-19

... amending the regulations regarding oil and natural gas production requirements. This is a complete rewrite... flaring natural gas, to ensure appropriate development of these natural resources. The final rule eliminates most restrictions on production rates and clarifies limits on the amount of natural gas that can...

40 CFR 98.408 - Definitions.

Code of Federal Regulations, 2010 CFR

2010-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.408 Definitions. All terms...) Natural Gas 1.027 MMBtu/Mscf 53.02 Propane 3.836 MMBtu/bbl 63.02 Normal butane 4.326 MMBtu/bbl 64.93... Unit Default CO2 emission value(MT CO2/Unit) Natural Gas Mscf 0.054452 Propane Barrel 0.241745 Normal...

Life Cycle Water Consumption for Shale Gas and Conventional Natural Gas

DOE Office of Scientific and Technical Information (OSTI.GOV)

Clark, Corrie E.; Horner, Robert M.; Harto, Christopher B.

2013-10-15

Shale gas production represents a large potential source of natural gas for the nation. The scale and rapid growth in shale gas development underscore the need to better understand its environmental implications, including water consumption. This study estimates the water consumed over the life cycle of conventional and shale gas production, accounting for the different stages of production and for flowback water reuse (in the case of shale gas). This study finds that shale gas consumes more water over its life cycle (13–37 L/GJ) than conventional natural gas consumes (9.3–9.6 L/GJ). However, when used as a transportation fuel, shale gasmore » consumes significantly less water than other transportation fuels. When used for electricity generation, the combustion of shale gas adds incrementally to the overall water consumption compared to conventional natural gas. The impact of fuel production, however, is small relative to that of power plant operations. The type of power plant where the natural gas is utilized is far more important than the source of the natural gas.« less

30 CFR 250.1160 - When may I flare or vent gas?

Code of Federal Regulations, 2010 CFR

2010-07-01

... receive approval from the Regional Supervisor to flare or vent natural gas at your facility, except in the following situations: Condition Additional requirements (1) When the gas is lease use gas (produced natural...) When properly working equipment yields flash gas (natural gas released from liquid hydrocarbons as a...

76 FR 34070 - Secretary of Energy Advisory Board, Natural Gas Subcommittee

Federal Register 2010, 2011, 2012, 2013, 2014

2011-06-10

... DEPARTMENT OF ENERGY Secretary of Energy Advisory Board, Natural Gas Subcommittee AGENCY... the Secretary of Energy Advisory Board (SEAB), Natural Gas Subcommittee. SEAB was reestablished... directed by the Secretary. The Natural Gas Subcommittee was established to provide advice and...

10 CFR 590.201 - General.

Code of Federal Regulations, 2010 CFR

2010-01-01

... ENERGY (CONTINUED) NATURAL GAS (ECONOMIC REGULATORY ADMINISTRATION) ADMINISTRATIVE PROCEDURES WITH RESPECT TO THE IMPORT AND EXPORT OF NATURAL GAS Applications for Authorization To Import or Export Natural Gas § 590.201 General. (a) Any person seeking authorization to import or export natural gas into or...

10 CFR 590.201 - General.

Code of Federal Regulations, 2011 CFR

2011-01-01

... ENERGY (CONTINUED) NATURAL GAS (ECONOMIC REGULATORY ADMINISTRATION) ADMINISTRATIVE PROCEDURES WITH RESPECT TO THE IMPORT AND EXPORT OF NATURAL GAS Applications for Authorization To Import or Export Natural Gas § 590.201 General. (a) Any person seeking authorization to import or export natural gas into or...

77 FR 23105 - Supporting Safe and Responsible Development of Unconventional Domestic Natural Gas Resources

Federal Register 2010, 2011, 2012, 2013, 2014

2012-04-17

... Safe and Responsible Development of Unconventional Domestic Natural Gas Resources #0; #0; #0..., 2012 Supporting Safe and Responsible Development of Unconventional Domestic Natural Gas Resources By... and responsible development of unconventional domestic natural gas resources and associated...

Implications of low natural gas prices on life cycle greenhouse gas emissions in the U.S. electricity sector

NASA Astrophysics Data System (ADS)

Jaramillo, P.; Venkatesh, A.; Griffin, M.; Matthews, S.

2012-12-01

Increased production of unconventional natural gas resources in the U.S. has drastically reduced the price of natural gas. While in 2005 prices went above 10/MMBtu, since 2011 they have been below 3/MMBtu. These low prices have encouraged the increase of natural gas utilization in the United States electricity sector. Natural gas can offset coal for power generation, reducing emissions such as greenhouse gases, sulfur and nitrogen oxides. In quantifying the benefit of offsetting coal by using natural gas, life cycle assessment (LCA) studies have shown up to 50% reductions in life cycle greenhouse gas (GHG) emissions can be expected. However, these studies predominantly use limited system boundaries that contain single individual coal and natural gas power plants. They do not consider (regional) fleets of power plants that are dispatched on the basis of their short-run marginal costs. In this study, simplified economic dispatch models (representing existing power plants in a given region) are developed for three U.S. regions - ERCOT, MISO and PJM. These models, along with historical load data are used to determine how natural gas utilization will increase in the short-term due to changes in natural gas price. The associated changes in fuel mix and life cycle GHG emissions are estimated. Results indicate that life cycle GHG emissions may, at best, decrease by 5-15% as a result of low natural gas prices, compared to almost 50% reductions estimated by previous LCAs. This study thus provides more reasonable estimates of potential reductions in GHG emissions from using natural gas instead of coal in the electricity sector in the short-term.

Microbial production of natural gas from coal and organic-rich shale

USGS Publications Warehouse

Orem, William

2013-01-01

Natural gas is an important component of the energy mix in the United States, producing greater energy yield per unit weight and less pollution compared to coal and oil. Most of the world’s natural gas resource is thermogenic, produced in the geologic environment over time by high temperature and pressure within deposits of oil, coal, and shale. About 20 percent of the natural gas resource, however, is produced by microorganisms (microbes). Microbes potentially could be used to generate economic quantities of natural gas from otherwise unexploitable coal and shale deposits, from coal and shale from which natural gas has already been recovered, and from waste material such as coal slurry. Little is known, however, about the microbial production of natural gas from coal and shale.

Natural Gas Basics

DOE Office of Scientific and Technical Information (OSTI.GOV)

None

2016-06-08

Natural gas powers about 150,000 vehicles in the United States and roughly 22 million vehicles worldwide. Natural gas vehicles (NGVs) are a good choice for high-mileage fleets -- such as buses, taxis, and refuse vehicles -- that are centrally fueled or operate within a limited area or along a route with natural gas fueling stations. This brochure highlights the advantages of natural gas as an alternative fuel, including its domestic availability, established distribution network, relatively low cost, and emissions benefits.

Natural Gas Basics

DOE Office of Scientific and Technical Information (OSTI.GOV)

2016-06-01

Natural gas powers about 150,000 vehicles in the United States and roughly 22 million vehicles worldwide. Natural gas vehicles (NGVs) are a good choice for high-mileage fleets -- such as buses, taxis, and refuse vehicles -- that are centrally fueled or operate within a limited area or along a route with natural gas fueling stations. This brochure highlights the advantages of natural gas as an alternative fuel, including its domestic availability, established distribution network, relatively low cost, and emissions benefits.

Unconventional Oil and Gas Resources in Texas and Other Mining Activities: the Water Challenge

NASA Astrophysics Data System (ADS)

Nicot, J.

2011-12-01

A recent study, sponsored by the Texas Water Development Board, considered current and projected water use in the mining industry. It looked at the upstream segment of the oil and gas industry (that is, water used to extract the commodity until it leaves the wellhead), the aggregate, and coal industry, and other substances (industrial sand, lime, etc.). We obtained data through state databases, data collection from private vendors, and direct surveys of the various sectors of the industry. Overall, in 2008, we estimated that the state consumed ~160 thousand acre-feet (AF) in the mining industry, including 35.8 thousand AF for fracing wells (mostly in the Barnett Shale/Fort Worth area) and ~21.0 thousand AF for other purposes in the oil and gas industry, although more spread out across the state, with a higher demand in the Permian Basin area in West Texas. The coal industry used 20.0 thousand AF along the lignite belt from Central to East Texas. The 71.6 thousand AF used by the aggregate industry is distributed over most of the state, but with a clear concentration around major metropolitan areas. The remainder amounts to 11.0 thousand AF and is dominated by industrial sand production (~80% of total). Water is used mostly for drilling wells, stimulating/fracing wells, and secondary and tertiary recovery processes (oil and gas industry); for dewatering and depressurizing pits, with a small amount used for dust control (coal industry); and for dust control and washing (aggregate industry and industrial sand). Reuse/recycling has already been accounted for in water-use values, as well as opportunity usages, such as stormwater collection (aggregates). The split between surface water and groundwater is difficult to assess but it is estimated at ~56% groundwater in 2008. Projections for future use were done by extrapolating current trends, mainly for coal (same energy mix) and aggregates (following population growth). Projections for the oil and gas industry (Barnett, Eagle Ford, Haynesville, and other shales and tight formations) were made with the help of various sources by estimating the amount of oil and gas to be produced in the state in the next decades and by distributing it through time. We projected that the state overall water use will peak in the 2020-2030 decade at ~305 thousand AF, thanks to the oil and gas unconventional resources that will start to decrease in terms of water use around that time. Both coal and aggregates are slated to keep increasing, more strongly for aggregates.

76 FR 34071 - Secretary of Energy Advisory Board, Natural Gas Subcommittee; Meeting

Federal Register 2010, 2011, 2012, 2013, 2014

2011-06-10

... DEPARTMENT OF ENERGY Secretary of Energy Advisory Board, Natural Gas Subcommittee; Meeting AGENCY... the Secretary of Energy Advisory Board (SEAB), Natural Gas Subcommittee. SEAB was reestablished... directed by the Secretary. The Natural Gas Subcommittee was established to provide advice and...

76 FR 34070 - Secretary of Energy Advisory Board Natural Gas Subcommittee

Federal Register 2010, 2011, 2012, 2013, 2014

2011-06-10

... DEPARTMENT OF ENERGY Secretary of Energy Advisory Board Natural Gas Subcommittee AGENCY... the Secretary of Energy Advisory Board (SEAB) Natural Gas Subcommittee. SEAB was reestablished... Natural Gas Subcommittee was established to provide advice and recommendations to the Full Board on how to...

77 FR 8724 - Natural Gas Pipelines; Project Cost and Annual Limits

Federal Register 2010, 2011, 2012, 2013, 2014

2012-02-15

...] Natural Gas Pipelines; Project Cost and Annual Limits February 9, 2012. AGENCY: Federal Energy Regulatory... limits for natural gas pipelines blanket construction certificates for each calendar year. DATES: This... CFR Part 157 Administrative practice and procedure, Natural gas, Reporting and recordkeeping...

18 CFR 284.281 - Applicability.

Code of Federal Regulations, 2011 CFR

2011-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by Interstate Pipelines § 284.281 Applicability...

18 CFR 284.265 - Cost recovery by interstate pipeline.

Code of Federal Regulations, 2011 CFR

2011-04-01

... REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions...

18 CFR 284.287 - Implementation and effective date.

Code of Federal Regulations, 2011 CFR

2011-04-01

... COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by Interstate Pipelines...

18 CFR 284.261 - Purpose.

Code of Federal Regulations, 2011 CFR

2011-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions § 284.261 Purpose. This subpart...

18 CFR 284.282 - Definitions.

Code of Federal Regulations, 2011 CFR

2011-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by Interstate Pipelines § 284.282 Definitions...

18 CFR 284.262 - Definitions.

Code of Federal Regulations, 2011 CFR

2011-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions § 284.262 Definitions. For purposes of...

18 CFR 284.271 - Waiver.

Code of Federal Regulations, 2011 CFR

2011-04-01

... ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions § 284.271 Waiver. The Commission may...

18 CFR 284.267 - Intrastate pipeline emergency transportation rates.

Code of Federal Regulations, 2011 CFR

2011-04-01

... ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange...

77 FR 20618 - PetroLogistics Natural Gas Storage, LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2012-04-05

... Natural Gas Storage, LLC; Notice of Application Take notice that on March 22, 2012, PetroLogistics Natural... Docket No. CP12-95-000, an application pursuant to section 7(c) of the Natural Gas Act (NGA) and Part 157... questions regarding this application should be directed to Kevin M. Miller, PetroLogistics Natural Gas...

75 FR 36376 - Natural Gas Pipeline Company of America LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2010-06-25

... DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Docket No. CP10-452-000] Natural Gas..., Natural Gas Pipeline Company of America LLC (Natural), 3250 Lacey Road, 7th Floor, Downers Grove, Illinois 60515-7918, filed in Docket Number CP10-452-000, pursuant to sections 7(b) and 7(c) of the Natural Gas...

Alternative Fuels Data Center: Phoenix Cleans Up with Natural Gas

Science.gov Websites

Phoenix Cleans Up with Natural Gas to someone by E-mail Share Alternative Fuels Data Center : Phoenix Cleans Up with Natural Gas on Facebook Tweet about Alternative Fuels Data Center: Phoenix Cleans Up with Natural Gas on Twitter Bookmark Alternative Fuels Data Center: Phoenix Cleans Up with Natural

Effect of temperature shock and inventory surprises on natural gas and heating oil futures returns.

PubMed

Hu, John Wei-Shan; Hu, Yi-Chung; Lin, Chien-Yu

2014-01-01

The aim of this paper is to examine the impact of temperature shock on both near-month and far-month natural gas and heating oil futures returns by extending the weather and storage models of the previous study. Several notable findings from the empirical studies are presented. First, the expected temperature shock significantly and positively affects both the near-month and far-month natural gas and heating oil futures returns. Next, significant temperature shock has effect on both the conditional mean and volatility of natural gas and heating oil prices. The results indicate that expected inventory surprises significantly and negatively affects the far-month natural gas futures returns. Moreover, volatility of natural gas futures returns is higher on Thursdays and that of near-month heating oil futures returns is higher on Wednesdays than other days. Finally, it is found that storage announcement for natural gas significantly affects near-month and far-month natural gas futures returns. Furthermore, both natural gas and heating oil futures returns are affected more by the weighted average temperature reported by multiple weather reporting stations than that reported by a single weather reporting station.

Effect of Temperature Shock and Inventory Surprises on Natural Gas and Heating Oil Futures Returns

PubMed Central

Hu, John Wei-Shan; Lin, Chien-Yu

2014-01-01

The aim of this paper is to examine the impact of temperature shock on both near-month and far-month natural gas and heating oil futures returns by extending the weather and storage models of the previous study. Several notable findings from the empirical studies are presented. First, the expected temperature shock significantly and positively affects both the near-month and far-month natural gas and heating oil futures returns. Next, significant temperature shock has effect on both the conditional mean and volatility of natural gas and heating oil prices. The results indicate that expected inventory surprises significantly and negatively affects the far-month natural gas futures returns. Moreover, volatility of natural gas futures returns is higher on Thursdays and that of near-month heating oil futures returns is higher on Wednesdays than other days. Finally, it is found that storage announcement for natural gas significantly affects near-month and far-month natural gas futures returns. Furthermore, both natural gas and heating oil futures returns are affected more by the weighted average temperature reported by multiple weather reporting stations than that reported by a single weather reporting station. PMID:25133233

Apparatus for the liquefaction of a gas and methods relating to same

DOEpatents

Turner, Terry D [Idaho Falls, ID; Wilding, Bruce M [Idaho Falls, ID; McKellar, Michael G [Idaho Falls, ID

2009-12-29

Apparatuses and methods are provided for producing liquefied gas, such as liquefied natural gas. In one embodiment, a liquefaction plant may be coupled to a source of unpurified natural gas, such as a natural gas pipeline at a pressure letdown station. A portion of the gas is drawn off and split into a process stream and a cooling stream. The cooling stream may be sequentially pass through a compressor and an expander. The process stream may also pass through a compressor. The compressed process stream is cooled, such as by the expanded cooling stream. The cooled, compressed process stream is expanded to liquefy the natural gas. A gas-liquid separator separates the vapor from the liquid natural gas. A portion of the liquid gas may be used for additional cooling. Gas produced within the system may be recompressed for reintroduction into a receiving line.

75 FR 8245 - Natural Gas Pipelines; Project Cost and Annual Limits

Federal Register 2010, 2011, 2012, 2013, 2014

2010-02-24

...] Natural Gas Pipelines; Project Cost and Annual Limits February 18, 2010. AGENCY: Federal Energy Regulatory... for natural gas pipelines blanket construction certificates for each calendar year. DATES: This final..., Natural gas, Reporting and recordkeeping requirements. Jeff C. Wright, Director, Office of Energy Projects...

77 FR 10415 - Standards for Business Practices for Interstate Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2012-02-22

...] Standards for Business Practices for Interstate Natural Gas Pipelines AGENCY: Federal Energy Regulatory... American Energy Standards Board (NAESB) applicable to natural gas pipelines.\\1\\ The Commission also... Quadrant (WGQ) of the North American Energy Standards Board (NAESB) applicable to natural gas pipelines...

18 CFR 157.212 - Synthetic and liquefied natural gas facilities.

Code of Federal Regulations, 2010 CFR

2010-04-01

... natural gas facilities. 157.212 Section 157.212 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY REGULATIONS UNDER NATURAL GAS ACT APPLICATIONS FOR CERTIFICATES... 7 OF THE NATURAL GAS ACT Interstate Pipeline Blanket Certificates and Authorization Under Section 7...

76 FR 63613 - Secretary of Energy Advisory Board Natural Gas Subcommittee

Federal Register 2010, 2011, 2012, 2013, 2014

2011-10-13

... DEPARTMENT OF ENERGY Secretary of Energy Advisory Board Natural Gas Subcommittee AGENCY... Secretary of Energy Advisory Board (SEAB) Natural Gas Subcommittee. SEAB was reestablished pursuant to the... recommendations to the SEAB on how to improve the safety and environmental performance of natural gas hydraulic...

10 CFR 590.101 - Purpose and scope.

Code of Federal Regulations, 2010 CFR

2010-01-01

... DEPARTMENT OF ENERGY (CONTINUED) NATURAL GAS (ECONOMIC REGULATORY ADMINISTRATION) ADMINISTRATIVE PROCEDURES WITH RESPECT TO THE IMPORT AND EXPORT OF NATURAL GAS General Provisions § 590.101 Purpose and scope... to obtain authorizations from DOE to import or export natural gas under the Natural Gas Act and by...

78 FR 44900 - Communication of Operational Information Between Natural Gas Pipelines and Electric Transmission...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-07-25

...-17-000] Communication of Operational Information Between Natural Gas Pipelines and Electric... the Commission's regulations to provide explicit authority to interstate natural gas pipelines and... explicit authority to interstate natural gas pipelines and public utilities that own, operate, or control...

76 FR 8293 - Natural Gas Pipelines; Project Cost and Annual Limits

Federal Register 2010, 2011, 2012, 2013, 2014

2011-02-14

...] Natural Gas Pipelines; Project Cost and Annual Limits February 8, 2011. AGENCY: Federal Energy Regulatory... for natural gas pipelines blanket construction certificates for each calendar year. DATES: Effective... of Subjects in 18 CFR Part 157 Administrative practice and procedure, Natural Gas, Reporting and...

75 FR 80685 - Contract Reporting Requirements of Intrastate Natural Gas Companies

Federal Register 2010, 2011, 2012, 2013, 2014

2010-12-23

... Storage Report for Intrastate Natural Gas and Hinshaw Pipelines. Order No. 735-A generally reaffirms the... reporting requirements for (1) intrastate natural gas pipelines \\2\\ providing interstate transportation...) Hinshaw pipelines providing interstate service subject to the Commission's Natural Gas Act (NGA) section 1...

Alternative Fuels Data Center: Renewable Natural Gas (Biomethane)

Science.gov Websites

Production Renewable Natural Gas (Biomethane) Production to someone by E-mail Share Alternative Fuels Data Center: Renewable Natural Gas (Biomethane) Production on Facebook Tweet about Alternative Fuels Data Center: Renewable Natural Gas (Biomethane) Production on Twitter Bookmark Alternative Fuels

18 CFR 284.266 - Rates and charges for interstate pipelines.

Code of Federal Regulations, 2011 CFR

2011-04-01

... REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions...

18 CFR 284.264 - Terms and conditions.

Code of Federal Regulations, 2011 CFR

2011-04-01

..., DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and Exchange Transactions § 284.264 Terms and...

18 CFR 284.283 - Point of unbundling.

Code of Federal Regulations, 2011 CFR

2011-04-01

..., DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by Interstate Pipelines § 284.283 Point...

10 CFR 590.101 - Purpose and scope.

Code of Federal Regulations, 2011 CFR

2011-01-01

... DEPARTMENT OF ENERGY (CONTINUED) NATURAL GAS (ECONOMIC REGULATORY ADMINISTRATION) ADMINISTRATIVE PROCEDURES WITH RESPECT TO THE IMPORT AND EXPORT OF NATURAL GAS General Provisions § 590.101 Purpose and scope... to obtain authorizations from DOE to import or export natural gas under the Natural Gas Act and by...

18 CFR 284.268 - Local distribution company emergency transportation rates.

Code of Federal Regulations, 2011 CFR

2011-04-01

... FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Emergency Natural Gas Sale, Transportation, and...

18 CFR 284.284 - Blanket certificates for unbundled sales services.

Code of Federal Regulations, 2011 CFR

2011-04-01

... FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas...

18 CFR 284.285 - Pregrant of abandonment of unbundled sales services.

Code of Federal Regulations, 2011 CFR

2011-04-01

... FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas...

18 CFR 157.212 - Synthetic and liquefied natural gas facilities.

Code of Federal Regulations, 2011 CFR

2011-04-01

... natural gas facilities. 157.212 Section 157.212 Conservation of Power and Water Resources FEDERAL ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY REGULATIONS UNDER NATURAL GAS ACT APPLICATIONS FOR CERTIFICATES... 7 OF THE NATURAL GAS ACT Interstate Pipeline Blanket Certificates and Authorization Under Section 7...

Postextraction Separation, On-Board Storage, and Catalytic Conversion of Methane in Natural Gas: A Review.

PubMed

Saha, Dipendu; Grappe, Hippolyte A; Chakraborty, Amlan; Orkoulas, Gerassimos

2016-10-12

In today's perspective, natural gas has gained considerable attention, due to its low emission, indigenous availability, and improvement in the extraction technology. Upon extraction, it undergoes several purification protocols including dehydration, sweetening, and inert rejection. Although purification is a commercially established technology, several drawbacks of the current process provide an essential impetus for developing newer separation protocols, most importantly, adsorption and membrane separation. This Review summarizes the needs of natural gas separation, gives an overview of the current technology, and provides a detailed discussion of the progress in research on separation and purification of natural gas including the benefits and drawbacks of each of the processes. The transportation sector is another growing sector of natural gas utilization, and it requires an efficient and safe on-board storage system. Compressed natural gas (CNG) and liquefied natural gas (LNG) are the most common forms in which natural gas can be stored. Adsorbed natural gas (ANG) is an alternate storage system of natural gas, which is advantageous as compared to CNG and LNG in terms of safety and also in terms of temperature and pressure requirements. This Review provides a detailed discussion on ANG along with computation predictions. The catalytic conversion of methane to different useful chemicals including syngas, methanol, formaldehyde, dimethyl ether, heavier hydrocarbons, aromatics, and hydrogen is also reviewed. Finally, direct utilization of methane onto fuel cells is also discussed.

Natural Gas and the Transformation of the U.S. Energy Sector: Electricity

DOE Office of Scientific and Technical Information (OSTI.GOV)

Logan, Jeffrey; Heath, Garvin; Macknick, Jordan

2012-11-01

Domestic natural gas production was largely stagnant from the mid-1970s until about 2005. However, beginning in the late 1990s, advances linking horizontal drilling techniques with hydraulic fracturing allowed drilling to proceed in shale and other formations at much lower cost. The result was a slow, steady increase in unconventional gas production. The Joint Institute for Strategic Energy Analysis (JISEA) designed this study to address four related key questions, which are a subset from the wider dialogue on natural gas; regarding the life cycle greenhouse gas (GHG) emissions associated with shale gas compared to conventional natural gas and other fuels usedmore » to generate electricity; existing legal and regulatory frameworks governing unconventional gas development at federal, state, and local levels, and changes in response to the rapid industry growth and public concerns; natural gas production companies changing their water-related practices; and demand for natural gas in the electric sector.« less

Assessment of undiscovered oil and gas resources of the Sud Province, north-central Africa

USGS Publications Warehouse

Brownfield, M.E.; Klett, T.R.; Schenk, C.J.; Charpentier, R.R.; Cook, T.A.; Pollastro, R.M.; Tennyson, Marilyn E.

2011-01-01

The Sud Province located in north-central Africa recently was assessed for undiscovered, technically recoverable oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's (USGS) World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 7.31 billion barrels of oil, 13.42 trillion cubic feet of natural gas, and 353 million barrels of natural gas liquids.

Assessment of undiscovered oil and gas resources of the Chad Basin Province, North-Central Africa

USGS Publications Warehouse

Brownfield, Michael E.; Schenk, Christopher J.; Charpentier, Ronald R.; Klett, Timothy R.; Cook, Troy A.; Pollastro, Richard M.; Tennyson, Marilyn E.

2010-01-01

The Chad Basin Province located in north-central Africa recently was assessed for undiscovered, technically recoverable oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's (USGS) World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 2.32 billion barrels of oil, 14.65 trillion cubic feet of natural gas, and 391 million barrels of natural gas liquids.

Assessment of undiscovered oil and gas resources of four East Africa Geologic Provinces

USGS Publications Warehouse

Brownfield, Michael E.; Schenk, Christopher J.; Charpentier, Ronald R.; Klett, Timothy R.; Cook, Troy A.; Pollastro, Richard M.; Tennyson, Marilyn E.

2012-01-01

Four geologic provinces along the east coast of Africa recently were assessed for undiscovered, technically recoverable oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's (USGS) World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 27.6 billion barrels of oil, 441.1 trillion cubic feet of natural gas, and 13.77 billion barrels of natural gas liquids.

Alternative Fuels Data Center: Natural Gas Fuel Basics

Science.gov Websites

-derived natural gas, renewable natural gas-which is produced from decaying organic materials-must be on organic materials. Alternatively, renewable natural gas (RNG), also known as biomethane, is produced from organic materials-such as waste from landfills and livestock-through anaerobic digestion. RNG

40 CFR 1065.715 - Natural gas.

Code of Federal Regulations, 2010 CFR

2010-07-01

... 40 Protection of Environment 32 2010-07-01 2010-07-01 false Natural gas. 1065.715 Section 1065.715... PROCEDURES Engine Fluids, Test Fuels, Analytical Gases and Other Calibration Standards § 1065.715 Natural gas. (a) Except as specified in paragraph (b) of this section, natural gas for testing must meet the...

77 FR 65508 - Annual Charge Filing Procedures for Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2012-10-29

...] Annual Charge Filing Procedures for Natural Gas Pipelines AGENCY: Federal Energy Regulatory Commission... FERC) is proposing to amend its regulations to revise the filing requirements for natural gas pipelines...) clause. Currently, natural gas pipelines utilizing an ACA clause must make a tariff filing to reflect a...

78 FR 41048 - Combined Notice of Filings #1

Federal Register 2010, 2011, 2012, 2013, 2014

2013-07-09

...-000. Applicants: Gas Natural Inc. Description: FERC-65A Exemption Request of Gas Natural Inc. Filed...-19-000. Applicants: Gas Natural Inc. Description: Notification of Holding Company Status filed on behalf of Gas Natural Inc. Filed Date: 6/26/13. Accession Number: 20130626-5157. Comments Due: 5 p.m. ET...

76 FR 544 - PetroLogistics Natural Gas Storage, LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2011-01-05

... Natural Gas Storage, LLC; Notice of Application December 28, 2010. Take notice that on December 14, 2010, PetroLogistics Natural Gas Storage, LLC (PetroLogistics), 4470 Bluebonnet Blvd., Baton Rouge, Louisiana... Natural Gas Act (NGA) and Part 157 of the Commission's regulations, requesting a certificate of public...

75 FR 66046 - Capacity Transfers on Intrastate Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2010-10-27

...] Capacity Transfers on Intrastate Natural Gas Pipelines October 21, 2010. AGENCY: Federal Energy Regulatory... comments on whether and how holders of firm capacity on intrastate natural gas pipelines providing interstate transportation and storage services under section 311 of the Natural Gas Policy Act of 1978 and...

18 CFR 270.303 - Natural gas produced from Devonian shale.

Code of Federal Regulations, 2010 CFR

2010-04-01

... 18 Conservation of Power and Water Resources 1 2010-04-01 2010-04-01 false Natural gas produced... DETERMINATION PROCEDURES Requirements for Filings With Jurisdictional Agencies § 270.303 Natural gas produced from Devonian shale. A person seeking a determination that natural gas is produced from Devonian shale...

78 FR 51716 - Northern Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2013-08-21

... DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Docket No. CP13-528-000] Northern Natural Gas Company; Notice of Application Take notice that on August 1, 2013, Northern Natural Gas... section 7(c) of the Natural Gas Act and part 157 of the Commission's regulations to construct and operate...

75 FR 15426 - East Tennessee Natural Gas, LLC; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2010-03-29

...] East Tennessee Natural Gas, LLC; Notice of Application March 22, 2010. Take notice that on March 8, 2010, East Tennessee Natural Gas, LLC (East Tennessee), 5400 Westheimer Court, Houston, Texas 77056... Natural Gas Act (NGA) for authorization to: (i) Install an approximately 8.4-mile, 24-inch diameter...

75 FR 13535 - Northern Natural Gas Company; Notice of Request Under Blanket Authorization

Federal Register 2010, 2011, 2012, 2013, 2014

2010-03-22

... Natural Gas Company; Notice of Request Under Blanket Authorization March 16, 2010. Take notice that on March 12, 2010, Northern Natural Gas Company (Northern), 1111 South 103rd Street, Omaha, Nebraska 68124... Federal Energy Regulatory Commission's regulations under the Natural Gas Act for authorization to abandon...

77 FR 31004 - Southern Natural Gas Company; Notice of Request Under Blanket Authorization

Federal Register 2010, 2011, 2012, 2013, 2014

2012-05-24

... Natural Gas Company; Notice of Request Under Blanket Authorization Take notice that on May 9, 2012, Southern Natural Gas Company (Southern), 569 Brookwood Village, Suite 501, Birmingham, Alabama 35209, filed... Commission's regulations under the Natural Gas Act (NGA), and Southern's blanket certificate issued in Docket...

78 FR 19409 - Annual Charge Filing Procedures for Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2013-04-01

...; Order No. 776] Annual Charge Filing Procedures for Natural Gas Pipelines AGENCY: Federal Energy... Commission (Commission or FERC) is amending its regulations to revise the filing requirements for natural gas...) clause. Currently, natural gas pipelines utilizing an ACA clause must make an annual tariff filing to...

77 FR 43711 - Standards for Business Practices of Interstate Natural Gas Pipelines

Federal Register 2010, 2011, 2012, 2013, 2014

2012-07-26

...; Order No. 587-V] Standards for Business Practices of Interstate Natural Gas Pipelines AGENCY: Federal... North American Energy Standards Board (NAESB) applicable to natural gas pipelines. In addition, based on... (WGQ) of the North American Energy Standards Board (NAESB) applicable to natural gas pipelines...

75 FR 2130 - Southern Natural Gas Company; Notice of Application

Federal Register 2010, 2011, 2012, 2013, 2014

2010-01-14

... Natural Gas Company; Notice of Application January 6, 2010. Take notice that on December 29, 2009, Southern Natural Gas Company (Southern), 569 Brookwood Village, Suite 501, Birmingham, Alabama 35209, filed in the above referenced docket an application pursuant to section 7(b) of the Natural Gas Act (NGA...

49 CFR 393.68 - Compressed natural gas fuel containers.

Code of Federal Regulations, 2010 CFR

2010-10-01

... 49 Transportation 5 2010-10-01 2010-10-01 false Compressed natural gas fuel containers. 393.68... AND ACCESSORIES NECESSARY FOR SAFE OPERATION Fuel Systems § 393.68 Compressed natural gas fuel containers. (a) Applicability. The rules in this section apply to compressed natural gas (CNG) fuel...

Alternative Fuels Data Center: Natural Gas Vehicle Conversions

Science.gov Websites

Conversions to someone by E-mail Share Alternative Fuels Data Center: Natural Gas Vehicle Conversions on Facebook Tweet about Alternative Fuels Data Center: Natural Gas Vehicle Conversions on Twitter Bookmark Alternative Fuels Data Center: Natural Gas Vehicle Conversions on Google Bookmark Alternative

75 FR 5177 - Pipeline Posting Requirements under Section 23 of the Natural Gas Act

Federal Register 2010, 2011, 2012, 2013, 2014

2010-02-01

.... The Commission denies requests to revise its regulations requiring interstate natural gas pipelines to... Pipeline Posting of No-Notice Service.... 94 H. Additional Exemptions 102 1. Natural Gas Companies With.... 720,\\1\\ requiring interstate and certain major non-interstate natural gas pipelines to post limited...

77 FR 76024 - Combined Notice of Filings

Federal Register 2010, 2011, 2012, 2013, 2014

2012-12-26

... that the Commission has received the following Natural Gas Pipeline Rate and Refund Report filings...: Natural Gas Pipeline Company of America. Description: Removal of Agreements to be effective 1/19/2013... Natural Gas System, L.L.C. Description: Gulfstream Natural Gas System, L.L.C. submits tariff filing per...

18 CFR 281.205 - General rules.

Code of Federal Regulations, 2010 CFR

2010-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES NATURAL GAS CURTAILMENT UNDER THE NATURAL GAS POLICY ACT OF 1978 Permanent Curtailment Rule § 281.205 General... volumes of natural gas not included in priorities 1 and 2 shall be fully curtailed by the interstate...

18 CFR 284.288 - Code of conduct for unbundled sales service.

Code of Federal Regulations, 2011 CFR

2011-04-01

... REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by Interstate...

18 CFR 284.286 - Standards of conduct for unbundled sales service.

Code of Federal Regulations, 2011 CFR

2011-04-01

... ENERGY REGULATORY COMMISSION, DEPARTMENT OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES Blanket Certificates Authorizing Certain Natural Gas Sales by...

18 CFR 225.2 - General instructions.

Code of Federal Regulations, 2011 CFR

2011-04-01

..., DEPARTMENT OF ENERGY ACCOUNTS, NATURAL GAS ACT PRESERVATION OF RECORDS OF NATURAL GAS COMPANIES § 225.2... account and other records prepared by or on behalf of the natural gas company. See item 40 of the schedule for those records that come into possession of the natural gas company in connection with the...

49 CFR 393.68 - Compressed natural gas fuel containers.

Code of Federal Regulations, 2011 CFR

2011-10-01

... 49 Transportation 5 2011-10-01 2011-10-01 false Compressed natural gas fuel containers. 393.68... AND ACCESSORIES NECESSARY FOR SAFE OPERATION Fuel Systems § 393.68 Compressed natural gas fuel containers. (a) Applicability. The rules in this section apply to compressed natural gas (CNG) fuel...

18 CFR 270.303 - Natural gas produced from Devonian shale.

Code of Federal Regulations, 2011 CFR

2011-04-01

... 18 Conservation of Power and Water Resources 1 2011-04-01 2011-04-01 false Natural gas produced... DETERMINATION PROCEDURES Requirements for Filings With Jurisdictional Agencies § 270.303 Natural gas produced from Devonian shale. A person seeking a determination that natural gas is produced from Devonian shale...

DOE Office of Scientific and Technical Information (OSTI.GOV)

Smith, R.V.

This book reports on remedial measures for gas wells and new methods for calculating the position of the stabilized performance curves for gas wells as well as the heating value for natural gases from compositional analyses. In addition, the author includes problem solutions in an appendix and a section showing the relation between the conventional empirical equation and the theoretical performance equation of A.S. Odeh. The author successfully bridges the gap between the results of empirical testing and the theory of unsteady-state flow in porous media. It strengthens the bond between conventional reservoir engineering practices and understanding gas well behavior.more » Problems listed at the end of each chapter are excellent exercises for practitioners. This book provides information on: Natural Gas Engineering; Properties of natural gas; Application of gas laws to reservoir engineering; Gas measurement; Flow of natural gas in circular pipe and annular conductors; Flow of gas in porous media (a review); Gas well testing; Unsteady-state flow behavior of gas wells; Production forecasting for gas wells; Production decline curves for gas wells; Sizing flow strings for gas wells; Remedial measures for gas wells; Gas sales contracts; and appendices on Compressibility for natural gas, Gas measurement factors, SI metric conversion factors, and Solutions to problems.« less

Considering the Role of Natural Gas in the Deep Decarbonization of the U.S. Electricity Sector. Natural Gas and the Evolving U.S. Power Sector Monograph Series: Number 2

DOE Office of Scientific and Technical Information (OSTI.GOV)

Cole, Wesley; Beppler, Ross; Zinaman, Owen

Natural gas generation in the U.S. electricity sector has grown substantially in recent years, while the sector's carbon dioxide (CO2) emissions have generally declined. This relationship highlights the concept of natural gas as a potential enabler of a transition to a lower-carbon future. This work considers that concept by using the National Renewable Energy Laboratory (NREL) Renewable Energy Deployment System (ReEDS) model. ReEDS is a long-term capacity expansion model of the U.S. electricity sector. We examine the role of natural gas within the ReEDS modeling framework as increasingly strict carbon emission targets are imposed on the electricity sector. In additionmore » to various natural gas price futures, we also consider scenarios that emphasize a low-carbon technology in order to better understand the role of natural gas if that low-carbon technology shows particular promise. Specifically, we consider scenarios with high amounts of energy efficiency (EE), low nuclear power costs, low renewable energy (RE) costs, and low carbon capture and storage (CCS) costs. Within these scenarios we find that requiring the electricity sector to lower CO2 emissions over time increases near-to-mid-term (through 2030) natural gas generation (see Figure 1 - left). The long-term (2050) role of natural gas generation in the electricity sector is dependent on the level of CO2 emission reduction required. Moderate reductions in long-term CO2 emissions have relatively little impact on long-term natural gas generation, while more stringent CO2 emission limits lower long-term natural gas generation (see Figure 1 - right). More stringent carbon targets also impact other generating technologies, with the scenarios considered here seeing significant decreases in coal generation, and new capacity of nuclear and renewable energy technologies over time. Figure 1 also demonstrates the role of natural gas in the context of scenarios where a specific low-carbon technology is advantaged. In 2030, natural gas generation in the technology scenarios is quite similar to that in the reference scenarios, indicating relatively little change in the role of natural gas in the near-to-mid-term due to advancements in those technology areas. The 2050 natural gas generation shows more significant differences, suggesting that technology advancements will likely have substantial impacts on the role of natural gas in the longer-term timeframe. Natural gas generation differences are most strongly driven by alternative natural gas price trajectories--changes in natural gas generation in the Low NG Price and High NG Price scenarios are much larger than in any other scenario in both the 2030 and 2050 timeframes. The only low-carbon technology scenarios that showed any increase in long-term natural gas generation relative to the reference case were the Low CCS cost scenarios. Carbon capture and storage technology costs are currently high, but have the potential to allow fossil fuels to play a larger role in low-carbon grid. This work considers three CCS cost trajectories for natural gas and coal generators: a baseline trajectory and two lower cost trajectories where CO2 capture costs reach $40/metric ton and $10/metric ton, respectively. We find that in the context of the ReEDS model and with these assumed cost trajectories, CCS can increase the long-term natural gas generation under a low carbon target (see Figure 2). Under less stringent carbon targets we do not see ReEDS electing to use CCS as part of its electricity generating portfolio for the scenarios considered in this work.« less

18 CFR 284.282 - Definitions.

Code of Federal Regulations, 2010 CFR

2010-04-01

... OF ENERGY OTHER REGULATIONS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES... service. (b) Sales service includes firm or interruptible gas sales. (c) Unbundled sales service is gas...

76 FR 64055 - Special Rules Governing Certain Information Obtained Under the Clean Air Act: Technical Correction

Federal Register 2010, 2011, 2012, 2013, 2014

2011-10-17

... natural gas. 211112 Natural gas liquid extraction facilities. Petrochemical Production....... 32511... facilities. 211112 Natural gas liquid extraction facilities. Suppliers of Industrial 325120 Industrial gas... reference in EPA's procedures for handling data collected under the Mandatory Greenhouse Gas Reporting Rule...

40 CFR 98.230 - Definition of the source category.

Code of Federal Regulations, 2013 CFR

2013-07-01

... processing means the separation of natural gas liquids (NGLs) or non-methane gases from produced natural gas... following: forced extraction of natural gas liquids, sulfur and carbon dioxide removal, fractionation of... includes processing plants that fractionate gas liquids, and processing plants that do not fractionate gas...

40 CFR 98.230 - Definition of the source category.

Code of Federal Regulations, 2012 CFR

2012-07-01

... processing means the separation of natural gas liquids (NGLs) or non-methane gases from produced natural gas... following: forced extraction of natural gas liquids, sulfur and carbon dioxide removal, fractionation of... includes processing plants that fractionate gas liquids, and processing plants that do not fractionate gas...

40 CFR 98.230 - Definition of the source category.

Code of Federal Regulations, 2014 CFR

2014-07-01

... processing means the separation of natural gas liquids (NGLs) or non-methane gases from produced natural gas... following: forced extraction of natural gas liquids, sulfur and carbon dioxide removal, fractionation of... includes processing plants that fractionate gas liquids, and processing plants that do not fractionate gas...

40 CFR 98.402 - GHGs to report.

Code of Federal Regulations, 2014 CFR

2014-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.402 GHGs to report. (a) NGL... combustion or oxidation of the annual volumes of natural gas provided to end-users on their distribution...

40 CFR 98.402 - GHGs to report.

Code of Federal Regulations, 2013 CFR

2013-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.402 GHGs to report. (a) NGL... combustion or oxidation of the annual volumes of natural gas provided to end-users on their distribution...

40 CFR 98.402 - GHGs to report.

Code of Federal Regulations, 2012 CFR

2012-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.402 GHGs to report. (a) NGL... combustion or oxidation of the annual volumes of natural gas provided to end-users on their distribution...

40 CFR 98.402 - GHGs to report.

Code of Federal Regulations, 2011 CFR

2011-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.402 GHGs to report. (a) NGL... combustion or oxidation of the annual volumes of natural gas provided to end-users on their distribution...

40 CFR 98.402 - GHGs to report.

Code of Federal Regulations, 2010 CFR

2010-07-01

... GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.402 GHGs to report. (a) NGL... combustion or oxidation of the annual volumes of natural gas provided to end-users on their distribution...

Methods of natural gas liquefaction and natural gas liquefaction plants utilizing multiple and varying gas streams

DOEpatents

Wilding, Bruce M; Turner, Terry D

2014-12-02

A method of natural gas liquefaction may include cooling a gaseous NG process stream to form a liquid NG process stream. The method may further include directing the first tail gas stream out of a plant at a first pressure and directing a second tail gas stream out of the plant at a second pressure. An additional method of natural gas liquefaction may include separating CO.sub.2 from a liquid NG process stream and processing the CO.sub.2 to provide a CO.sub.2 product stream. Another method of natural gas liquefaction may include combining a marginal gaseous NG process stream with a secondary substantially pure NG stream to provide an improved gaseous NG process stream. Additionally, a NG liquefaction plant may include a first tail gas outlet, and at least a second tail gas outlet, the at least a second tail gas outlet separate from the first tail gas outlet.

Induced seismicity response of hydraulic fracturing: results of a multidisciplinary monitoring at the Wysin site, Poland.

PubMed

López-Comino, J A; Cesca, S; Jarosławski, J; Montcoudiol, N; Heimann, S; Dahm, T; Lasocki, S; Gunning, A; Capuano, P; Ellsworth, W L

2018-06-05

Shale oil and gas exploitation by hydraulic fracturing experienced a strong development worldwide over the last years, accompanied by a substantial increase of related induced seismicity, either consequence of fracturing or wastewater injection. In Europe, unconventional hydrocarbon resources remain underdeveloped and their exploitation controversial. In UK, fracturing operations were stopped after the M w 2.3 Blackpool induced earthquake; in Poland, operations were halted in 2017 due to adverse oil market conditions. One of the last operated well at Wysin, Poland, was monitored independently in the framework of the EU project SHEER, through a multidisciplinary system including seismic, water and air quality monitoring. The hybrid seismic network combines surface mini-arrays, broadband and shallow borehole sensors. This paper summarizes the outcomes of the seismological analysis of these data. Shallow artificial seismic noise sources were detected and located at the wellhead active during the fracturing stages. Local microseismicity was also detected, located and characterised, culminating in two events of M w 1.0 and 0.5, occurring days after the stimulation in the vicinity of the operational well, but at very shallow depths. A sharp methane peak was detected ~19 hours after the M w 0.5 event. No correlation was observed between injected volumes, seismicity and groundwater parameters.

Assessment of undiscovered oil and gas resources of the West African Costal Province, West Africa

USGS Publications Warehouse

Brownfield, Michael E.; Charpentier, Ronald R.; Schenk, Christopher J.; Klett, Timothy R.; Cook, Troy A.; Pollastro, Richard M.

2011-01-01

The West African Coastal Province along the west African coastline recently was assessed for undiscovered, technically recoverable oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's USGS World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 3.2 billion barrels of oil, 23.63 trillion cubic feet of natural gas, and 721 million barrels of natural gas liquids.

Assessment of Undiscovered Oil and Gas Resources of Four West Africa Geologic Provinces

USGS Publications Warehouse

Brownfield, Michael E.; Charpentier, Ronald R.; Cook, Troy A.; Klett, Timothy R.; Pitman, Janet K.; Pollastro, Richard M.; Schenk, Christopher J.; Tennyson, Marilyn E.

2010-01-01

Four geologic provinces located along the northwest and west-central coast of Africa recently were assessed for undiscovered oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's (USGS) World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 71.7 billion barrels of oil, 187.2 trillion cubic feet of natural gas, and 10.9 billion barrels of natural gas liquids.

Assessment of undiscovered oil and gas resources of the South Africa Coastal Province, Africa

USGS Publications Warehouse

Brownfield, Michael E.; Schenk, Christopher J.; Charpentier, Ronald R.; Klett, Timothy R.; Cook, Troy A.; Pollastro, Richard M.

2012-01-01

The South Africa Coastal Province along the South Africa coast recently was assessed for undiscovered, technically recoverable oil, natural gas, and natural gas liquids resources as part of the U.S. Geological Survey's (USGS) World Oil and Gas Assessment. Using a geology-based assessment methodology, the USGS estimated mean volumes of 2.13 billion barrels of oil, 35.96 trillion cubic feet of natural gas, and 1,115 million barrels of natural gas liquids.

78 FR 18970 - Trunkline LNG Company, LLC; Trunkline LNG Export, LLC; Trunkline Gas Company, LLC; Supplemental...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-03-28

... include plans to construct and modify certain pipeline facilities to supply natural gas to the..., Louisiana to supply natural gas to the liquefaction facility from existing gas transmission pipelines... greenfield natural gas pipeline (Mainline Connector) in Jefferson Davis and Calcasieu Parishes, Louisiana...

Lifecycle greenhouse gas emissions of coal, conventional and unconventional natural gas for electricity generation

EPA Science Inventory

An analysis of the lifecycle greenhouse gas (GHG) emissions associated with natural gas use recently published by Howarth et al. (2011) stated that use of natural gas produced from shale formations via hydraulic fracturing would generate greater lifecycle GHG emissions than petro...

40 CFR 98.404 - Monitoring and QA/QC requirements.

Code of Federal Regulations, 2014 CFR

2014-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.404... determine the quantity of NGLs and natural gas using methods in common use in the industry for billing... National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical...

40 CFR 98.404 - Monitoring and QA/QC requirements.

Code of Federal Regulations, 2013 CFR

2013-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.404... determine the quantity of NGLs and natural gas using methods in common use in the industry for billing... National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical...

78 FR 11585 - Greenhouse Gas Reporting Rule: Revision to Best Available Monitoring Method Request Submission...

Federal Register 2010, 2011, 2012, 2013, 2014

2013-02-19

... facilities. 211 Extractors of crude petroleum and natural gas. 211112 Natural gas liquid extraction... Greenhouse Gas Reporting Rule: Revision to Best Available Monitoring Method Request Submission Deadline for Petroleum and Natural Gas Systems Source Category AGENCY: Environmental Protection Agency (EPA). ACTION...

40 CFR 98.404 - Monitoring and QA/QC requirements.

Code of Federal Regulations, 2010 CFR

2010-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.404... determine the quantity of NGLs and natural gas using methods in common use in the industry for billing... National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical...

40 CFR 98.404 - Monitoring and QA/QC requirements.

Code of Federal Regulations, 2012 CFR

2012-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.404... determine the quantity of NGLs and natural gas using methods in common use in the industry for billing... National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical...

40 CFR 98.404 - Monitoring and QA/QC requirements.

Code of Federal Regulations, 2011 CFR

2011-07-01

... (CONTINUED) MANDATORY GREENHOUSE GAS REPORTING Suppliers of Natural Gas and Natural Gas Liquids § 98.404... determine the quantity of NGLs and natural gas using methods in common use in the industry for billing... National Standards Institute (ANSI), the American Gas Association (AGA), the American Society of Mechanical...

Natural gas monthly, March 1991. [Glossary included

DOE Office of Scientific and Technical Information (OSTI.GOV)

Not Available

1991-03-01

The Natural Gas Monthly (NGM) is prepared in the Data Operations Branch of the Reserves and Natural Gas Division, Office of Oil and Gas, Energy Information Administration (EIA), US Department of Energy (DOE). The NGM highlights activities, events and analyses of interest to public and private sector organizations associated with the natural gas industry. Volume and price data are presented each month for natural gas production, distribution, consumption, and interstate pipeline activities. Producer-related activities and underground storage data are also reported. From time to time, the NGM features articles designed to assist readers in using and interpreting natural gas information.more » This month's article is an update on natural gas distribution services. Explanatory Notes supplement the information found in tables of the report. A description of the data collection surveys that support the NGM is provided in the Data Sources section. A glossary of the terms used in this report is also provided to assist readers in understanding the data presented in this publication. 9 figs., 39 tabs.« less