1ST NRG Corp
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| Eröffnet am: | 07.03.13 19:06 | von: 2brix2 | Anzahl Beiträge: | 2.159 |
| Neuester Beitrag: | 24.04.21 23:13 | von: Brigitteszuaa | Leser gesamt: | 111.248 |
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Support/Resistance
Type Value Conf.
resist. 0.23 2
resist. 0.06 2
resist. 0.05 4
resist. 0.02 2
resist. 0.01 33 geht es hier drüber gibt es nur doch die 5 uscent siehe oben mit 4
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#XI7PqARkSHfGlCvM.99
Chart Indicators
Ind. short Inter Long
EMA VBu Bu VBe
MACD VBu VBu VBu
RSI Be
TDD Bu
Fibs VBe Be VBe
Highs VBe VBe VBe
Lows N VBe N
Trends N N N
Stoch. Bu
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#XI7PqARkSHfGlCvM.99
Stoch auch bullisch
wir können dann starten ;)
... ich kann dir einen chart nennen, wie er auzusehen hat, wo es auch in zukunft hoch geht:,,,...schau dir einfach mal thomas cook an....,,, dies nenn ich einen Chart aber deine chartbilder
Wenn ich mich nicht irre erzählt du bei bmsn und hier seit April, wenn nicht sogar seit März...hier sieht es bullish aus und dann deine Zeichnungen dazu.... ...ach hör doch auf ist doch alles schwachsin, was deine Chart die letzten Wochen sagen,
Bmsn steht bei 0,0022
Und
1st Nrg steht bei 0,0025
Beide stehen derzeit viel tiefer als letzten Monat und noch viel tiefer als vor 2 Monaten
für dich sind penny nichts, du bist zu ungeduldig das meine ich nett.
wann ein pennystartet, kann man nie voraus sagen. du weißt leider nie wie tief er geht, wenn ich ein glaskugel hätte, würde ich dir das sogar gern sagen.
limit or prohibit drilling activities on certain lands lying within wilderness, wetlands and other protected areas; and
require remedial measures to mitigate pollution from former and ongoing operations, such as requirements to close pits and plug abandoned wells.
the plugging and abandoning of wells; and
State laws regulate the size and shape of drilling and spacing units or proration units governing the pooling of natural gas properties. Some states allow forced pooling or integration of tracts to facilitate exploration while other states rely on voluntary pooling of lands and leases. These laws and regulations may limit the amount of natural gas we can produce from our wells or limit the number of wells or the locations at which we can drill. Moreover, Wyoming imposes conservation and severance taxes on the production and sale of natural gas within its jurisdiction.
Natural Gas Regulation. The availability, terms and cost of transportation significantly affect sales of natural gas. The interstate transportation and sale for resale of natural gas is subject to federal regulation, including regulation of the terms, conditions and rates for interstate transportation, storage and various other matters, primarily by the Federal Energy Regulatory Commission. Federal and state regulations govern the price and terms for access to natural gas pipeline transportation. The Federal Energy Regulatory Commission"s regulations for interstate natural gas transmission in some circumstances may also affect the intrastate transportation of natural gas.
Although natural gas prices are currently unregulated, Congress historically has been active in the area of natural gas regulation. We cannot predict whether new legislation to regulate natural gas might be proposed, what proposals, if any, might actually be enacted by Congress or the various state legislatures, and what effect, if any, the proposals might have on the operations of the underlying properties. Sales of condensate and natural gas liquids are not currently regulated and are made at market prices.
State Regulation. Wyoming regulates the drilling for, and the production, gathering and sale of, natural gas, including imposing severance and conservation taxes and requirements for obtaining drilling permits. Wyoming currently imposes a severance tax on natural gas producers at the rate of 6% of the value of the gross product extracted. Reduced rates may apply to certain types of wells and production methods, such as new wells, renewed wells, stripper production and tertiary production.
Wyoming also regulates the method of developing fields, the spacing and operation of wells and the prevention of waste of natural gas resources. States do not regulate wellhead prices or engage in other similar direct economic regulation, but there can be no assurance that they will not do so in the future. The effect of these regulations may be to limit the amounts of natural gas that may be produced from our wells, and to limit the number of wells or locations we can drill.
http://www.otcmarkets.com/stock/FNRC/filings
National Environmental Policy Act. Natural gas exploration and production activities on federal lands are subject to the National Environmental Policy Act, or NEPA. NEPA requires federal agencies, including the Department of Interior, to evaluate major agency actions having the potential to significantly impact the environment. In the course of such evaluations, an agency will prepare an Environmental Assessment that assesses the potential direct, indirect and cumulative impacts of a proposed project and, if necessary, will prepare a more detailed Environmental Impact Statement that may be made available for public review and comment. All of our current exploration and production activities, as well as proposed exploration and development plans, on federal lands require governmental permits that are subject to the requirements of NEPA. This process has the potential to delay the development of natural gas projects.
Pipeline Safety. Pipelines are subject to regulation by the U.S. Department of Transportation, or the DOT, pursuant to the Hazardous Liquid Pipeline Safety Act. The DOT, through the Office of Pipeline Safety, recently promulgated a series of rules which require pipeline operators to develop pipeline integrity management programs for transportation pipelines located in "high consequence areas." "High consequence areas" are currently defined as areas with specified population densities, buildings containing populations of limited mobility, and areas where people gather that are located along the route of a pipeline. Integrity management program elements include requirements for baseline assessments to identify potential threats to each pipeline segment, reassessments, and reporting and recordkeeping.
OSHA and Other Laws and Regulation. We are subject to the requirements of the federal Occupational Safety and Health Act, or OSHA, and comparable state statutes. These laws and the implementing regulations strictly govern the protection of the health and safety of employees. The OSHA hazard communication standard, EPA community right-to-know regulations under the Title III of CERCLA and similar state statutes require that we organize and/or disclose information about hazardous materials used or produced in our operations.
The Kyoto Protocol to the United Nations Framework Convention on Climate Change, or the Protocol, became effective in February 2005. Under the Protocol, participating nations are required to implement programs to reduce emissions of certain gases, generally referred to as greenhouse gases that are suspected of contributing to global warming. T he United States is not currently a participant in the Protocol, and Congress has not actively considered recent proposed legislation directed at reducing greenhouse gas emissions. Other states have also adopted legislation addressing greenhouse gas emissions from various sources, primarily power plants. The natural gas industry is a direct source of certain greenhouse gas emissions, namely carbon dioxide and methane, and future restrictions on such emissions could impact our future operations. It is not possible, at this time, to estimate accurately how regulations that may be adopted to address greenhouse gas emissions would impact our business.
We are not aware of any environmental issues or claims that will require material capital expenditure. However, accidental spills or releases may occur in the course of our operations, and we cannot assure that we will not incur substantial costs and liabilities as a result of such spills or releases, including those relating to claims for damage to property and persons. Moreover, we cannot assure that the passage of more stringent laws or regulations in the future will not have a negative impact on our business, financial condition, and results of operations.
Other Regulation of the Natural Gas Industry
The natural gas industry is extensively regulated by numerous federal, state and local authorities. Legislation affecting the natural gas industry is under constant review for amendment or expansion, frequently increasing the regulatory burden. Also, numerous departments and agencies, both federal and state, are authorized by statute to issue rules and regulations binding on the natural gas industry and its individual members, some of which carry substantial penalties for failure to comply. Although the regulatory burden on the natural gas industry increases the cost of doing business and, consequently, affects profitability, these burdens generally will not affect us any differently or to any greater or lesser extent than they affect other companies in the industry with similar types, quantities and locations of production.
Our operations are subject to various types of regulation at federal, state and local levels. These types of regulation include requiring permits for the drilling of wells, drilling bonds and reports concerning operations. Most states, and some counties and municipalities regulate one or more of the following:
These laws, rules and regulations may also restrict the rate of natural gas production below the rate that would otherwise be possible. The regulatory burden on the natural gas industry increases the cost of doing business in the industry and consequently affects profitability. Additionally, Congress and federal and state agencies frequently revise environmental laws and regulations, and the clear trend in environmental regulation is to place more restrictions and limitations on activities that may affect the environment. Any changes that result in more stringent and costly waste handling, disposal and cleanup requirements for the natural gas industry could have a significant impact on our operating costs.
The following is a summary of some of the existing laws, rules and regulations to which our business operations are subject.
Waste Handling. The Resource Conservation and Recovery Act, or RCRA, and comparable state statutes, regulate the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous wastes. Under the auspices of the federal Environmental Protection Agency, or EPA, the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Drilling fluids, produced waters, and most of the other wastes associated with the exploration, development, and production of crude oil or natural gas are currently regulated under RCRA"s non-hazardous waste provisions. However, it is possible that certain natural gas exploration and production wastes now classified as non-hazardous could be classified as hazardous wastes in the future. Any such change could result in an increase in our costs to manage and dispose of wastes, which could have a material adverse effect on our results of operations and financial position. Also, in the course of our operations, we generate some amounts of ordinary industrial wastes, such as paint wastes, waste solvents, and waste oils, that may be regulated as hazardous wastes.
Comprehensive Environmental Response, Compensation and Liability Act. The Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, also known as the Superfund law, imposes joint and several liability, without regard to fault or legality of conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include the current and past owner or operator of the site where the release occurred, and anyone who disposed or arranged for the disposal of a hazardous substance released at the site. Under CERCLA, such persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. In addition, it is not uncommon for neighboring landowners and other third-parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment.
Water Discharges. The Federal Water Pollution Control Act, or the Clean Water Act, and analogous state laws, impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks into waters of the United States. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by EPA or an analogous state agency. Spill prevention, control, and countermeasure requirements of federal laws require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture, or leak. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with discharge permits or other requirements of the Clean Water Act and analogous state laws and regulations.
Air Emissions. The Federal Clean Air Act, and comparable state laws, regulate emissions of various air pollutants through air emissions permitting programs and the imposition of other requirements. In addition, EPA has developed, and continues to develop, stringent regulations governing emissions of toxic air pollutants at specified sources. States can impose air emissions limitations that are more stringent than the federal standards imposed by EPA, and California air quality laws and regulations are in many instances more stringent than comparable federal laws and regulations. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with air permits or other requirements of the federal Clean Air Act and associated state laws and regulations.
CBM Recovery Characteristics
The primary variables that affect recovery of CBM are coal thickness, gas content and permeability. Coal thickness refers to the actual thickness of the coal layer and is used to estimate how many tons of coal underlie a section of land. The estimate of the number of tons per section is multiplied by the estimated gas content of such lands to estimate the gas in place for the section. Gas content in coal is measured in terms of standard cubic feet per ton. Sufficient coal permeability is a prerequisite for economic gas flow rates because gas and water must be able to flow to the wellbore. Most gas and water flow through the cleats and other fractures in the coal. Cleat spacing is influenced by a variety of factors and greatly affects permeability.
CBM wells are drilled by contractors hired by the using small truck mounted water well rigs. Wells are often completed in multiple zones. The production profile for the surrounding wells shows water production for a short period of time (from 0 to 120 days) before initial gas production. The lowering of the static water level reduces the coal formation pressure and allows the gas to release from the coal and migrate to the well bore.
Water production is a function of the volume and pressure of water in the coals. Wells on the Clabaugh properties are expected to produce less water (than wells in other areas) before achieving economic gas production rates, because the de-watering at the numerous wells operated by other companies in the vicinity have reduced formation pressures. We do expect, however, that wells in other areas where we may acquire properties will have to undergo longer periods of de-watering. De-watering CBM wells in some parts of the PRB can take up to 24 months (or longer) before commercial gas production, which results in delayed cash flow and overall increased costs per Mcf of production.
1st NRG Properties – Wells and Locations
The current Clabaugh Ranch field is comprised of Federal, and Fee leasehold.
The current development at Clabaugh Ranch is on approximately 6,025.29 gross acres as described in the following table:
Gross Acres Net to FNRC
Developed Undeveloped Developed Undeveloped
Fee 2,366.53 0 64.12 0
State 0.00 40.00 0.00 26.67
Federal 942.63 2,676.13 95.26 588.24
3,309.16 2,716.13 159.37 614.91
Gas Gathering, Transport and Compression
Natural gas produced from Clabaugh Ranch are first gathered through a low pressure system built by the working interest owners. There is a 12" trunk line which runs basically South to North down the center of the property; each individual well produces laterally into this trunk line. The trunk line then runs north about a mile where it delivers into the low pressure side of Big Horn Gas Gathering"s line. Big Horn has a gathering service contract, which provides low pressure gathering and compression. This first stage of gathering, by Wyoming law, is not a cost that is borne by the royalty and ORRIs and is therefore paid by the working interest owners. The low pressure gathering then delivers into the Big Horn Gas Gathering high pressure system. Big Horn delivers the gas into the Fort Union Gathering system at high pressure, about 1,100 lbs. Then transportation provided by Copano, an affiliate of Big Horn Gas Gathering, to deliver the natural gas to Glenrock, Wyoming a liquid marketing point. For the fiscal year ended 2012, these services cost the Company approximately $0.98/mcf.
Environmental Matters and Regulation
General. Our operations are subject to stringent and complex federal, state and local laws and regulations governing environmental protection as well as the discharge of materials into the environment. These laws and regulations may, among other things:
from a coal seam. In a process known as dewatering a submersible pump is set below the coal seam, and the water column is pumped down, reducing the pressure in the coals. As pressure in the coal bed formation is reduced, CBM is released through a process called desorption. CBM then moves into naturally occurring cracks, or cleats, in the coal, and then to the well bore. Cleats are natural fractures which have formed in the coals, when they were formed and ages of geological stresses. The cleats are generally filled with water, so the static water level above the coal must be reduced, which then lowers the reservoir pressure allowing desorption to occur. Thus, unlike producing from a conventional natural gas reservoir, reservoir pressure in a coal bed formation must generally be reduced to allow for production of CBM. Because of the necessity to remove water and reduce the pressure within the coal seam, CBM, unlike conventional hydrocarbons, often will not show immediately on initial production testing. Coal bed formations typically require extensive depressurization through dewatering before desorption can occur and the methane begins to flow at commercial rates.
Drilling and Production
CBM wells in the Powder River Basin are drilled with small truck mounted rig drilling through the base of the Fort Union Coals and then setting casing and cementing the well to the surface. The coal bed seams are then completed by perforating the casing at the target coal (or coals). Once the production casing has been cemented, the perforations and coal face is then cleaned out and flushed by pumping water at high rates into the coal seam. Once the well is completed, a submersible pump is run into the well on production tubing to pump produced water from the coal seam. As the coal dewaters, gas flows up the casing to the surface. At the wellhead, the gas and water are metered. The gas then flows to a central compressor station where it is compressed into a high-pressure pipeline for sale. The water is gathered through a pipeline for disposal. CBM production generally is continuous to ensure a constant low-pressure natural gas and water flow and to sustain a commercially viable operation.
We intend to use drilling, completion and production practices that utilize technological advances in cementing, multiple zone completions and programmable submersible pumps. These techniques minimize damage to coal zones, preserve the potential of coals behind pipe, and reduce cementing costs. Multiple zone completions allow for the successful perforation of multiple zones which reduces capital costs over the life of the wells. Programmable submersible pumps and telemetry provide efficient means to best manage production and detect problems on a real time basis.
Conventional gas wells are typically 8,000 to 20,000 feet deep and initially produce large volumes of gas relative to water. Natural gas normally does not require assistance to move to the surface, and over time, gas production declines and water production may increase. In contrast, CBM wells generally range from 300 to 4,000 feet. Our wells will be drilled to about 1,500 feet. In the early stages of CBM production, large quantities of water and low quantities of gas are produced. Water production is initiated to lower the down hole pressure which allows the methane to release from the coal. The water volumes eventually decline and gas quantities begin to rise. In most cases, assistance to bring the gas to surface is not needed for the final period of production.
Water Production and Management
Water production and disposal is a key issue in CBM development. CBM-produced water in Wyoming (whether from wells on fee State or BLM land) must have a beneficial use, which is generally defined as suitable for agricultural, irrigation, commercial, domestic, industrial, municipal, mining, hydropower production, recreational, stock watering and fisheries, wildlife and wetlands maintenance, or dust suppression. Currently, the management of CBM-produced water depends on the quality of the produced water. The water produced in CBM operations can vary from very high quality (potable, meaning that it meets state and federal drinking standards), to very low quality (having a very high concentration of dissolved solids, like sodium, making it unsuitable for reuse). Testing of the produced water determines the disposal method.
Produced water is handled by utilizing one or several of the following regulatory-approved methods: Surface discharge (to creeks and streams); containment in ponds; irrigation of surface lands; injection to shallow sand formations; enhanced evaporation systems; treatment through ion exchange or reverse osmosis; and/or sub-surface irrigation. The Clabaugh Ranch wells produce potable water. Pursuant to a surface and damage agreement between the operator, and the surface owner of the Fee acreage, a subsurface water collection system has been installed, which collects water from the wells and delivers it to two surface stations. From the stations, water is fed into an underground water drip disposal system. Water seeps into a shallow (above the first coal seam) alluvial sand formation. This process has been approved by Wyoming, as the properties have been shown (by drilling and analysis) to be capable of holding the water indefinitely.
In responding to this item, please clearly describe the assets, properties or facilities of the issuer, give the location of the principal plants and other property of the issuer and describe the condition of the properties. If the issuer does not have complete ownership or control of the property (for example, if others also own the property or if there is a mortgage on the property), describe the limitations on the ownership.
If the issuer leases any assets, properties or facilities, clearly describe them as above and the terms of their leases.
Overview
Our activity to date has been centered around the Clabaugh Ranch Field, a project developing coal bed methane reserves (CBM) located in the Powder River Basin of Wyoming. We acquired our interest in the field in August 2010 and the field currently has 42 drilled coal bed methane wells which produce approximately 1,000 to 800 MCFD. The target coal formations are part of the Tongue River Member of the Fort Union formation and all of the wells drilled have encountered developed coal seams in the Warner, Upper and Lower Smith, Wyodak/Anderson Lower, Gates and Wall formations. Well log analysis demonstrates gross pay zones of approximately 150-200 feet in the drilled wells of which the most significant being the Warner, Wyodak/Andersen, and Gates coals.
We believe these multiple coal zones will be valuable. Pursuant to approval from the Wyoming Oil and Gas Commission (the "WOGC"), gas production is comingled from three coals in the producing wells: the Upper and Lower Smith, and the Wyodak/Anderson Lower. When water levels from these coal seams subside, the intention is to perforate other behind pipe coal seams and begin producing from those coals as well. Using the same well bores and capital equipment (pumps, electricity, water and natural gas gathering systems) we expect will result in lower total development and operating costs per Mcf for the properties. We also expect cumulative recovery by simultaneous multiple seam production to be greater than single seam production and result in lower per Mcf operating costs and longer well lives.
The coal seams in the Powder River Basin that are targeted have been extensively mapped as a result of a variety of natural resource developments that have occurred in the region. Industry data from many wellbores drilled by others allows us to determine the extent, thickness, gas saturation, formation pressure and relative permeability of the coal seams. This reduces (but does not entirely eliminate) the risk of drilling unproductive wells, but there is extensive CBM production in the Basin.
Gas production from CBM wells usually is accompanied by production of significant volumes of water from the coals. Water quality varies with the chemical composition of the rocks in which the coals are embedded. Depending on water quality, and local land conditions and regulations, water disposal can be a relatively expensive cost of production. Disposal methods range from reinjection, treatment plants (reverse osmosis or ion exchange), and impoundment systems (ponds) to evaporation sprinklers, irrigation and surface disposal.
A subsurface irrigation system has been installed for water produced from the the Clabaugh properties. Water from the wells (which is potable) is piped to an underground system of dispersal pipes where water seeps down into the alluvial till just below the ground surface. This technique (originally developed as an underground irrigation method - designed to limit evaporation) has been approved by the Wyoming Department of Environmental Quality for use where core drilling shows the subsurface can hold the water. This method is much less expensive than treating the water, and avoids overflow issues associated with impoundment ponds. See "Water Production and Management," below.
Under an industry standard operating agreement, Mountain Hawk Energy, LLC conducts all drilling, completion, and production activities on the Clabaugh Ranch properties. Under terms of the Joint Operating Agreements ("JOA"), Mountain Hawk is reimbursed for third party drilling, completion, and related field expenses. The JOA agreements contain industry standard COPAS (Council of Petroleum Accountants Societies) accounting practices, which allow Mountain Hawk as operator to collect a fee of $1,250 per well while drilling, and approximately $445 per month as overhead reimbursement per producing well. In 2012 these COPAS the Company"s share of these charges totaled $6,171.51.
Overview of the CBM Industry and the Powder River Basin
CBM is natural gas that is trapped within buried coal and is stored, or adsorbed, onto the internal surfaces of the coal face. Geologists have long known that coal was the source for natural gas found in many conventional accumulations, but coal beds were not targeted for production due to high water content and minimal natural gas production. Following a West Virginia mine explosion in 1968, the U.S. Bureau of Mines began to examine ways of removing methane from coal prior to mining. The Bureau of Mines demonstrated that CBM can be produced when large volumes of water are pumped
The goal of this section is to provide a potential investor with a clear understanding of all assets, properties or facilities owned, used or leased by the issuer.
0.0027 Pivot Point, 14-3 Day Raw Stochastic at 30%, 14 Day %d Stochastic Stalls
Current Price 0.0026 Current Price
0.0025 14-3 Day Raw Stochastic at 20%
Pivot Point 1st Level Support 0.0023 3-10 Day MACD Oscillator Stalls
4 Week Low, Pivot Point 2nd Level Support 0.0022
13 Week Low, 52 Week Low 0.0015
Support/Resistance
Type Value Conf.
resist. 0.21 2
resist. 0.06 2
resist. 0.05 2
resist. 0.02 2
supp 0.00 35
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#UriKeK3XFyRiOO7E.99
wenn das so bleibt der hammer
Very Bullish
Date Candle
May-21-2013 Hammer
May-20-2013 Inverted Hammer
May-17-2013 Bearish Engulfing
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#4GPzi23acD1YmzTd.99
Support/Resistance
Type Value Conf.
resist. 0.21 2 das wäre doch genial
resist. 0.06 2
resist. 0.05 2
resist. 0.02 2
supp 0.00 35
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#PWVZFCrFm8U6uJJf.99
Marktausblick
Bärenmarkt-Rallies können zu bösartigen Umkehrungen werden und zu Problemen für die Halter von Short-Positionen werden, daher ist es besser, auf der Hut zu sein.
GO FNRC!!!
so seh ich das auch ungefähr
14,585,636
wir haben seit dem 13.05. Volumen unter 2 mio, kommt etwas volumen rein geht sie rauf
es wurde NICHT dilluiert
Share Structure
Market Value1 $659,144 a/o May 21, 2013
Shares Outstanding 244,127,586 a/o Mar 31, 2013
Float 207,434,355 a/o Mar 31, 2013
Authorized Shares 500,000,000 a/o Dec 31, 2012
Very Bullish
Date Candle
May-22-2013 Homing Pigeon
May-21-2013 Hammer
May-20-2013 Inverted Hammer
May-17-2013 Bearish Engulfing
Read more at http://www.stockta.com/cgi-bin/...&mode=stock#KwZUJuIH4Kgj4kKe.99
Angehängte Grafik:
sccaty484v.png (verkleinert auf 72%)
sccaty484v.png (verkleinert auf 72%)
also ich bleibe strong long und kaufe weiter nach.
Von den Millionen gehören ja sowieso einige mir, daher einfach halten...dann gehts dann plötzlich gewaltig aufwärts. 10cents wär gewaltig :O
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