The Municipal Securities Rulemaking Board warned investors Wednesday to be aware of the terms of certain types of direct-pay municipal bonds to better understand if they are affected by the federal budget sequestration.
The alert also reminds broker-dealers and municipal securities dealers of their customer protection obligations under MSRB rules in connection with customer transactions relating to direct-pay bonds.
The MSRB notes that because the terms of direct-pay bonds "may vary considerably from issue to issue, investors, dealers and other market professionals should know the facts about their particular direct-pay bonds and should not make investment or pricing decisions based solely on other direct-pay bonds which may have dissimilar features or on generalized characterizations reported in the press or in other published reports."
As a result of the sequestration that took effect March 1, the Internal Revenue Service reduced refundable credits payable to issuers with respect to their Build America Bonds (BABs), Qualified School Construction Bonds (QSCBs), Qualified Zone Academy Bonds (QZABs), New Clean Renewable Energy Bonds (New CREBs) and Qualified Energy Conservation Bonds (QECBs) for which the issuer elected to receive a direct credit subsidy from the federal government, collectively known as “direct-pay bonds.”
5 Best Tech Stocks To Watch For 2015: Maverick Minerals Corp (MVRM)
Maverick Minerals Corporation (Maverick), incorporated on August 27, 1998, is an exploration-stage company. The Company is engaged in the acquisition, exploration, and development of prospective oils and gas properties and mineral properties. During the year ended December 31, 2011, the Company's business focus was to implement the terms of the Farmout Agreement pursuant to which were to earn an interest in certain oil and gas mineral leases located in Fort Bend and Wharton Counties, Texas.
The Company�� subsidiary includes Eskota Energy Corporation. On January 22, 2011, the Company completed drilling of its Initial Test Well on the Company's 4,513 acre Farm-Out property in Fort Bend County, Texas. As of December 31, 2011, the Company had not generated any revenues.
Advisors' Opinion:- [By Peter Graham]
On Friday, small cap mining stocks Maverick Minerals Corp (OTCMKTS: MVRM) and Liberty Coal Energy Corp (OTCMKTS: LBTG) plus oil stock Gray Fox Petroleum Corp (OTCBB: GFOX) sank 30.9%, 16.67% and 11.2%, respectively. However, only one of these stocks appears to have been the subject of some kind of paid promotion in the form of an investment in some shares. So will these three small cap mining or oil stocks keep coming up empty for investors this week? Here is a closer look:
Maverick Minerals Corp (OTCMKTS: MVRM) Has Been Quiet LatelySmall cap Maverick Minerals Corp is an exploration stage company involved in the acquisition, exploration, and development of prospective oil and gas properties and mineral properties. On Friday, Maverick Minerals Corp sank 30.9% to $0.38 for a market cap of $6.13 million plus MVRM is up 280% over the past year and up 322.2% over the past five years according to Google Finance.
Top 5 Energy Stocks To Invest In Right Now: Access Midstream Partners LP (ACMP)
Access Midstream Partners, L.P., formerly Chesapeake Midstream Partners, L.L.C. (Partnership), incorporated on January 21, 2010, owns, operates, develops and acquires natural gas, natural gas liquids (NGLs) and oil gathering systems and other midstream energy assets. The Company is focused on natural gas and NGL gathering. The Company provides its midstream services to Chesapeake Energy Corporation (Chesapeake), Total E&P USA, Inc. (Total), Mitsui & Co. (Mitsui), Anadarko Petroleum Corporation (Anadarko), Statoil ASA (Statoil) and other producers under long-term, fixed-fee contracts. On December 20, 2012, the Company acquired from Chesapeake Midstream Development, L.P. (CMD), a wholly owned subsidiary of Chesapeake, and certain of CMD's affiliates, 100% of interests in Chesapeake Midstream Operating, L.L.C. (CMO). As a result of the CMO Acquisition, the Partnership owns certain midstream assets in the Eagle Ford, Utica and Niobrara regions. The CMO Acquisition also extended the Company's assets and operations in the Haynesville, Marcellus and Mid-Continent regions.
The Company operates assets in Barnett Shale region in north-central Texas; Eagle Ford Shale region in South Texas; Haynesville Shale region in northwest Louisiana; Marcellus Shale region in Pennsylvania and West Virginia; Niobrara Shale region in eastern Wyoming; Utica Shale region in eastern Ohio, and Mid-Continent region, which includes the Anadarko, Arkoma, Delaware and Permian Basins. The Company's gathering systems collect natural gas and NGLs from unconventional plays. The Company generates its revenues through long-term, fixed-fee gas gathering, treating and compression contracts and through processing contracts.
Barnett Shale Region
The Company's gathering systems in its Barnett Shale region are located in Tarrant, Johnson and Dallas counties in Texas in the Core and Tier 1 areas of the Barnett Shale and consist of 25 interconnected gathering systems and 850 miles of pipeline. During the year! ended December 31, 2012, average throughput on the Company's Barnett Shale gathering system was 1.195 billion cubic feet per day. The Company connects its gathering systems to receipt points that are either at the individual wellhead or at central receipts points into which production from multiple wells are gathered. The Company's Barnett Shale gathering system is connected to the three downstream transportation pipelines: Atmos Pipeline Texas, Energy Transfer Pipeline Texas and Enterprise Texas Pipeline. Natural gas delivered into Atmos Pipeline Texas pipeline system serves the greater Dallas/Fort Worth metropolitan area and south, east and west Texas markets at the Katy, Carthage and Waha hubs. Natural gas delivered into Energy Transfer Pipeline Texas pipeline system serves the greater Dallas/Fort Worth metropolitan area and southeastern and northeastern the United States markets supplied by the Midcontinent Express Pipeline, Centerpoint CP Expansion Pipeline and Gulf South 42-inch Expansion Pipeline. Natural gas delivered into Enterprise Texas Pipeline pipeline system serves the greater Dallas/Fort Worth metropolitan area and southeastern and northeastern the United States markets supplied by the Gulf Crossing Pipeline.
Eagle Ford Shale Region
The Company's gathering systems in its Eagle Ford Shale region are located in Dimmit, La Salle, Frio, Zavala, McMullen and Webb counties in Texas and consist of 10 gathering systems and 618 miles of pipeline. During 2012, gross throughput for these assets was 0.169 billion cubic feet per day. The Company connects its gathering systems to central receipt points into which production from multiple wells is gathered. The Company's Eagle Ford gathering systems are connected to six downstream transportation pipelines, which include Enterprise, Camino Real, West Texas Gas, Regency Gas Service, Eagle Ford Gathering and Enerfin. The Company processes gas at Yoakum or other Enterprise plants and transports residue to Wharton residue header w! ith conne! ctions to numerous interstate pipelines.
Haynesville Shale Region
The Company's Springridge gas gathering system in the Haynesville Shale region is located in Caddo and DeSoto Parishes, Louisiana, in one of the core areas of the Haynesville Shale and consists of 263 miles of pipeline. During 2012, average throughput on the Company's Springridge gathering system was 0.359 billion cubic feet per day. The Company connects its gathering system to receipt points that are at central receipt points into which production from multiple wells is gathered. The Company's Springridge gathering system is connected to three downstream transportation pipelines: Centerpoint Energy Gas Transmission, ETC Tiger Pipeline and Texas Gas Transmission Pipeline. The Company's Mansfield gas gathering system in the Haynesville Shale region is located in DeSoto and Sabine Parishes, Louisiana, in one of the areas of the Haynesville Shale and, as of December 31, 2012, consist of 304 miles of pipeline. During 2012, average throughput on the Company's Mansfield gathering system was 0.720 billion cubic feet per day. The Company connects its gathering system to receipt points that are at central receipt points into which production from multiple wells is gathered and treated. The Company's Mansfield gathering system is connected to two downstream transportation pipelines: Enterprise Accadian Pipeline and Gulf South Pipeline. Natural gas delivered into Enterprise Accadian pipeline can move to on-system markets in the Midwest and to off-system markets in the Northeast through interconnections with third-party pipelines. Natural gas delivered into Gulf South pipeline can move to on-system markets in the Midwest and to off-system markets in the Northeast through interconnections with third-party pipelines.
Marcellus Shale Region
Through Appalachia Midstream, the Company operates 100% of and own an approximate average 47% interests in 10 gas gathering systems that consist of approximately 5! 49 miles ! of gathering pipeline in the Marcellus Shale region. The Company's volumes in the region are gathered from northern Pennsylvania, southwestern Pennsylvania and the northwestern panhandle of West Virginia, in core areas of the Marcellus Shale. The Company operates these smaller systems in northeast and central West Virginia, southeast Pennsylvania, northwest Maryland, north central Virginia, and south central New York. During 2012, gross throughput for Appalachia Midstream assets was just over 1.8 billion cubic feet per day. The Company's Marcellus gathering systems' delivery points include Caiman Energy, Central New York Oil & Gas, Columbia Gas Transmission, MarkWest, NiSource Midstream, PVR and Tennessee Gas Pipeline. Natural gas is delivered into a 16-inch pipeline and delivered to the Caiman Energy Fort Beeler processing plant where the liquids are extracted from the gas stream. The natural gas is then delivered into the TETCo interstate pipeline for ultimate delivery to the Northeast region of the United States. Natural gas delivered into Central New York Oil & Gas 30-inch diameter pipeline can be delivered to Stagecoach Storage, Millennium Pipeline, or Tennessee Gas Pipeline's Line 300. In Columbia Gas Transmission lean natural gas is delivered into two 36-inch interstate pipelines for delivery to the Mid-Atlantic and Northeast regions of the United States. Natural gas is delivered into a MarkWest pipeline for delivery to the MarkWest Houston processing plant where the liquids are extracted from the gas stream. In NiSource Midstream natural gas is delivered into a 20-inch diameter pipeline and delivered to the MarkWest Majorsville processing plant where the liquids are extracted from the rich gas stream. In PVR natural gas is delivered into the 24-inch diameter Wyoming pipeline and the Hirkey Compressor Station. In Tennessee Gas Pipeline natural gas is delivered into this looped 30-inch diameter pipeline (TGP Line 300) at three different locations can be received in the Northeast at points along th! e 300 Lin! e path, interconnections with other pipelines in northern New Jersey, as well as an existing delivery point in White Plains, New York.
Niobrara Shale Region
The Company's gathering systems in the Niobrara Shale region are located in Converse County, Wyoming and consist of two interconnected gathering systems and 79 miles of pipeline. During 2012, average throughput in the Company's Niobrara Shale region was 0.013 billion cubic feet per day. The Company connects its gathering systems to receipt points,which are either at the individual wellhead or at central receipts points into which production from multiple wells are gathered. The Company's Niobrara gathering systems are connected to two downstream transportation pipelines: Tallgrass/Douglas Pipeline and North Finn/DCP Inlet Pipeline. Natural gas delivered into Tallgrass/Douglas pipeline is sent to the Tallgrass processing facility; after processing, natural gas is delivered to Cheyenne Hub, Rockies Express Pipeline, or Trailblazer Pipeline through Tallgrass Interstate Gas Transmission.
Utica Shale Region
The Company's gathering systems in the Utica Shale region are located in northeast Ohio and consist of 67 miles of pipeline. The Company's Utica gathering systems are connected to two downstream transportation pipelines: Dominion East Ohio (Blue Racer) and Dominion Transmission, Inc.
Mid-Continent Region
The Company's Mid-Continent gathering systems extend across portions of Oklahoma, Texas, Arkansas and Kansas. Included in the Company's Mid-Continent region are three treating facilities located in Beckham and Grady Counties, Oklahoma, and Reeves County, Texas, which are designed to remove contaminants from the natural gas stream.
Anadarko Basin and Northwest Oklahoma
The Company's assets within the Anadarko Basin and Northwest Oklahoma are located in northwestern Oklahoma and the northeastern portion of the Texas Panhandle and consist of appro! ximately ! 1,578 miles of pipeline. During 2012, the Company's Anadarko Basin and Northwest Oklahoma region gathering systems had an average throughput of 0.457 billion cubic feet per day. Within the Anadarko Basin and Northwest Oklahoma, the Company is focused on servicing Chesapeake's production from the Colony Granite Wash, Texas Panhandle Granite Wash and Mississippi Lime plays. Natural gas production from these areas of the Anadarko Basin and Northwest Oklahoma contains NGLs. In addition, the Company operates an amine treater with sulfur removal capabilities at its Mayfield facility in Beckham County, Oklahoma. The Company's Mayfield gathering and treating system gathers Deep Springer natural gas production and treats the natural gas to remove carbon dioxide and hydrogen sulfide to meet the specifications of downstream transportation pipelines.
The Company's Anadarko Basin and Northwest Oklahoma systems are connected to a transportation pipelines transporting natural gas out of the region, including pipelines owned by Enbridge and Atlas Pipelines, as well as local market pipelines such as those owned by Enogex. These pipelines provide access to Midwest and northeastern the United States markets, as well as intrastate markets.
Permian Basin
The Company's Permian Basin assets are located in west Texas and consist of approximately 358 miles of pipeline across the Permian and Delaware basins. During 2012, average throughput on the Company's gathering systems was 0.076 billion cubic feet per day. The Company's Permian Basin gathering systems are connected to pipelines in the area owned by Southern Union, Enterprise, West Texas Gas, CDP Midstream and Regency. Natural gas delivered into these transportation pipelines is re-delivered into the Waha hub and El Paso Gas Transmission. The Waha hub serves the Texas intrastate electric power plants and heating market, as well as the Houston Ship Channel chemical and refining markets. El Paso Gas Transmission serves western the United ! States ma! rkets.
Other Mid-Continent Regions
The Company's other Mid-Continent region assets consist of systems in the Ardmore Basin in Oklahoma, the Arkoma Basin in eastern Oklahoma and western Arkansas and the East Texas and Gulf Coast regions of Texas. The other Mid-Continent assets include approximately 648 miles of pipeline. These gathering systems are localized systems gathering specific production for re-delivery into established pipeline markets. During 2012, average throughput on these gathering systems was 0.031 billion cubic feet per day.
The Company competes with Energy Transfer Partners, Crosstex Energy, Crestwood Midstream Partners, Freedom Pipeline, Peregrine Pipeline, XTO Energy, EOG Resources, DFW Mid-Stream, Enbridge Energy Partners, DCP Midstream, Enterprise Products Partners Inc., Regency Energy Partners, Texstar Midstream Operating, West Texas Gas Inc., TGGT Holdings, Kinderhawk Field Services, CenterPoint Field Services, Williams Partners, Penn Virginia Resource Partners, Caiman Energy, MarkWest Energy Partners, Kinder Morgan, Dominion Transmission (Blue Racer), Enogex and Atlas Pipeline Partners.
Advisors' Opinion:- [By Robert Rapier]
Next week�� issue will tackle the three remaining questions: one on MLP equivalents in Canada and Australia, one on Enbridge Energy Partners (NYSE: EEP) �and TC Pipelines (NYSE: TCP), and a third query on Access Midstream Partners (NYSE: ACMP), Crestwood Midstream Partners (NYSE: CMLP) and Mid-Con Energy Partners (Nasdaq: MCEP).
- [By Robert Rapier]
That�� the neat trick�Williams�(NYSE: WMB) pulled off today in converting its equity investment in�Access Midstream Partners�(NYSE: ACMP) into full control that will allow it to use ACMP�� surplus �cash flow to offset the deficit at its fully sponsored�Williams Partners�(NYSE: WPZ) MLP, which is to be folded into Access. Williams shareholders get stepped up dividend growth and strategic control of valuable assets.
- [By Marc Bastow]
Natural gas and gas liquids owner and operator Access Midstream Partners (ACMP) raised its quarterly distribution 23.5% to 55.5 cents per unit for its Common and Class C units, payable on Feb. 14 to unit holders of record as of Feb. 7.
ACMP Dividend Yield: 3.96% - [By Aaron Levitt]
While you can debate whether beaten-down natural gas producer Chesapeake (CHK) is a buy or just junk, its former MLP subsidiary Access Midstream Partners (ACMP) is very much in the ��uy, buy, buy!��camp.
Top 5 Energy Stocks To Invest In Right Now: Baytex Energy Corp (BTE)
Baytex Energy Corp. (Baytex), incorporated on October 22, 2010, through its subsidiaries, are engaged in the business of acquiring, developing, exploiting and holding interests in petroleum and natural gas properties and related assets in Canada (in the provinces of British Columbia, Alberta and Saskatchewan) and in the United States (in the states of North Dakota and Wyoming). The Company acts as the financing vehicle for its subsidiaries by providing access to debt and equity capital markets. As of December 31, 2011, its primary assets are Baytex Energy Ltd. (Baytex Energy), which it owns. On February 3, 2011, the Company acquired heavy oil assets located in the Reno area of northern Alberta and the Lloydminster area of western Saskatchewan. On August 9, 2011, the Company acquired natural gas assets located in the Brewster area of west central Alberta. During the year ended December 31, 2011, it completed two dispositions of undeveloped lands; in the Kaybob South area of west central Alberta, it sold six sections of leasehold, including five sections with Duvernay rights, and in the Dodsland area in southwest Saskatchewan, it sold 32,600 net acres of leasehold in the halo of the field.
During 2011, the Company�� production averaged 50,132 barrel of oil equivalent per day, from its properties in Canada. During 2011, production averaged 50,132 barrel of oil equivalent per day. During 2011, light oil and natural gas liquid (NGL) production was 6,769 barrels per day. During 2011, heavy oil production was 35,252 barrels per day. During 2011, natural gas production was 48.7 million cubic feet per day. Its crude oil and natural gas operations are organized into three business units: Alberta/B.C., Saskatchewan and United States. Each business unit has a portfolio of mineral leases, operated and non-operated properties and development prospects. These plays include the Bakken/Three Forks in the Williston Basin of North Dakota and southeast Saskatchewan and the Viking in southwestern Saskatche! wan and eastern Alberta.
Saskatchewan Business Unit
As of December 31, 2011, the Saskatchewan Business Unit accounted for more than 38% of production. The Saskatchewan Business Unit's heavy oil operations include cold primary and thermal (steam-assisted gravity drainage) production. Production is generated from vertical, slant and horizontal wells using progressive cavity pumps capable of handling heavy oil combined with gas, water and sand. Once produced, the oil is delivered to markets in both Canada and the United States on pipelines, tanker trucks or railways. Heavy crude is blended with light-hydrocarbon diluents (such as condensate) prior to being introduced into a sales pipeline. The blended crude oil is then sold by Baytex. During 2011, production in the Saskatchewan Business Unit averaged approximately 20,958 barrels of oil equivalent per day, which was comprised of 19,828 barrels per day of heavy oil, 154 barrels per day of light oil and 5,860 thousand cubic feet per day of natural gas. During 2011, Baytex drilled 93 (87.9 net) wells in the Saskatchewan Business Unit resulting in 84 (78.9 net) oil wells, four stratigraphic test wells, four service wells, and one dry and abandoned well.
The Company�� Ardmore, Alberta is developed in the Sparky, McLaren and Colony formations. During 2011, average production was approximately 652 barrels per day of heavy oil and 158 thousand cubic feet per day of natural gas. During 2011, one well was drilled. As of December 31, 2011, Baytex had 34,000 net undeveloped acres in this area. Its Carruthers property consists of separate North and South oil pools in the Cummings formation. During 2011, 13 wells were drilled. During 2011, average production was approximately 2,444 barrels per day of heavy oil and 489 thousand cubic feet per day of natural gas. As of December 31, 2011, Baytex had 10,600 net undeveloped acres in this area. During 2011, the Company�� Celtic, Saskatchewan producing property produced averaged 3,013 ! barrels p! er day of heavy oil and 538 thousand cubic feet per day of natural gas. During 2011, Baytex drilled seven oil wells in the area. The Company�� Cold Lake, Alberta is a heavy oil property. Production is from the Colony, Upper McLaren, Rex and Sparky formations. During 2011, average oil production was approximately 270 barrels per day. During 2011, Baytex had 11,300 net undeveloped acres in this area.
During 2011, in Kerrobert SAGD project, the Company placed two new well pairs on production. During 2011, average production from the Kerrobert area was approximately 3,350 barrels per day of heavy oil, 154 barrels per day of light oil, and 1,999 thousand cubic feet per day of natural gas. During 2011, Baytex drilled five oil wells and eight service wells in this area. As of December 31, 2011, Baytex had 38,600 net undeveloped acres in this area. Lindbergh is a non-operated heavy oil property. Baytex has a 21.25% working interest in this property. During 2011, average production in this area was approximately 673 barrels per day of heavy oil and 71 thousand cubic feet per day of natural gas. During 2011, four wells were drilled in this area. As of December 31, 2011, Baytex had 800 net undeveloped acres in this area. During 2011, its Marsden/Epping/Macklin/Silverdale, Saskatchewan produced approximately 2,102 barrels per day of oil and 290 thousand cubic feet per day of natural gas. During 2011, nine oil wells were drilled in this area. Its Tangleflags is characterized by multiple-zone reservoirs with production from the Colony, McLaren, Waseca, Sparky, General Petroleum and Lloydminster formations. During 2011, Baytex drilled 11 horizontal oil wells in the Lloydminster formation. During 2011, average production was approximately 1,763 barrels per day of heavy oil and 543 thousand cubic feet per day of natural gas.
Alberta/B.C. Business Unit
The Alberta/B.C. Business Unit possesses a range of light oil, heavy oil and natural gas properties. During 2011, the Alberta/B.C.! Business! Unit produced light and heavy gravity crude oil, natural gas, and natural gas liquids from fields in Alberta and British Columbia and accounted for approximately 58% of production. During 2011, production from this business unit averaged 27,833 barrel of oil equivalent per day, which was comprised of 15,425 barrels per day of heavy oil, 5,282 barrels per day of light oil and NGL and 42.8 million cubic feet per day of natural gas. During 2011, the Alberta/B.C. Business Unit participated in the drilling of 71 wells resulting in 61 oil wells, one natural gas well, seven stratigraphic test wells, one service well and one dry and abandoned well. As of December 31, 2011, its net undeveloped lands in this business unit totaled approximately 474,000 acres. During 2011, production from Bon Accord area was averaged approximately 905 barrels per day of light oil and 1,742 million cubic feet per day of natural gas. Natural gas is processed at two Baytex-operated plants and oil is treated at three Baytex-operated batteries. During 2011, in this area, Baytex drilled 11 horizontal Viking oil wells. As of December 31, 2011, Baytex had 18,300 net undeveloped acres in this area.
The Company�� Darwin/Nina/Goodfish/Lafond, Alberta produces natural gas from the Bluesky formation. During 2011, production averaged approximately 3,746 million cubic feet per day of natural gas. As of December 31, 2011, Baytex had 27,300 net undeveloped acres in this area. During 2011, the Company�� Leahurst, Alberta produced averaged approximately 2,633 million cubic feet per day of natural gas and 13 barrels per day of NGL from this multi-zone, year-round access area. Natural gas production from the Edmonton, Belly River, Viking and Mannville formations is processed. Baytex holds a total of 263 net sections of oil sands leases in the Peace River oil sands area, which includes the legacy Seal area and the Reno area. During 2011, production from the Peace River area was 15,425 barrels per day, which was comprised of 13,746 barr! els per d! ay from Seal and 1,679 barrels per day from Reno. During 2011, Baytex drilled 25 cold horizontal production wells and seven stratigraphic test wells at Seal and two cold horizontal production wells at Reno. The Peace River area includes 152,500 net undeveloped acres, including 57,000 net undeveloped acres at Seal and 95,500 net undeveloped acres at Reno.
During 2011, the Company�� Pembina production averaged 2,633 barrels per day of light oil and NGL and 22,428 million cubic feet per day of natural gas. During 2011, Baytex participated in drilling 19 wells in this area, resulting in 17 oil wells, one natural gas well, and one dry and abandoned well. During 2011, Pembina area drilling included five operated and 12 non-operated Cardium horizontal wells and completed with multi-stage fracture stimulations. During 2011, the Company�� production from Red Earth area averaged approximately 42 million cubic feet per day of natural gas and 522 barrels per day of light oil and NGL. During 2011, the Company�� Richdale/Sedalia property�� production averaged approximately 3,845 million cubic feet per day of natural gas and eight barrels per day of NGL. During 2011, the Company�� production from Stoddart area averaged approximately 4,498 million cubic feet per day of natural gas and 713 barrels per day of oil and NGL. During 2011, production from Turin was averaged approximately 345 barrels per day of oil and NGL and 856 million cubic feet per day of natural gas. Production is from the Second White Specks, Milk River, Bow Island, Mannville, Sawtooth and Livingstone formations.
United States Business Unit
During 2011, the Company focused its activities on the light oil resource play located in the Divide and Williams Counties of North Dakota. Production is from horizontal wells using multi-stage hydraulic fracturing in the Bakken and Three Forks formations. As of December 31, 2011, Baytex owned approximately 61,000 (24,800 net) developed acres. During 2011, Baytex parti! cipated i! n the drilling of 34 Bakken/Three Forks oil wells. During 2011, net production from the United States properties averaged 1,341 barrels of oil equivalent per day.
Advisors' Opinion:- [By Stephan Dube]
Peace River's most notable producers:
PennWest Exploration (PWE), see article here.Royal Dutch Shell (RDS.A), see article here.Baytex (BTE), see article here.Strata Oil and Gas (SOIGF.PK), see article here.Petrobank Energy & Resources (PBEGF.PK), see article here.Cold Lake's most notable producers:
- [By GURUFOCUS]
Canadian Trusts- Baytex Energy Trust (BTE) | Yield: 6.1%
- Enerplus Resources Fund (ERF) | Yield: 5.6%
- Pengrowth Energy Trust (PGH) | Yield: 7.1% - [By Robert Rapier]
There are a number of quality Canadian E&P companies that are attractive at current prices. Among my favorites are Baytex Energy (NYSE: BTE, TSE: BTE), Cenovus Energy (NYSE: CVE, TSE: CVE) and Canadian Natural Resources (NYSE: CNQ, TSE: CNQ) I also like Peyto Exploration & Development (TSE: PEY, OTC: PEYUF) for aggressive investors. We have often discussed putting Peyto in one of the portfolios, but I would ideally like it a bit cheaper.
Top 5 Energy Stocks To Invest In Right Now: Emerald Oil Inc (EOX)
Emerald Oil, Inc. (Emerald) incorporated on May 31, 2011, is an independent oil and natural gas exploration and production company. The Company focuses on developing oil wells in the Williston Basin of North Dakota and Montana primarily targeting the Bakken and three forks shale oil formations. Emerald controls approximately 35,000 net acres in the Williston Basin. In February 2014, Emerald Oil Inc acquired core Bakken and Three Forks producing properties and undeveloped leasehold in McKenzie and Williams Counties, North Dakota.
Emerald holds positions in the Rocky Mountain oil and natural gas plays. It has approximately 14,500 net acres in the Sand Wash Basin in northwest Colorado prospective for oil in the Niobrara formation. It has approximately 33,500 net acres in central Montana prospective for oil in the Heath formation. The Company also has approximately 72,800 net acres in the Tiger Ridge Field located in Blaine, Hill, and Chouteau Counties, Montana, prospective for natural gas, and another approximate 1,700 net acres in the Denver-Julesburg (DJ) Basin in Weld County, Colorado, prospective for oil in the Niobrara formation.
Advisors' Opinion:- [By Bret Jensen]
Emerald Oil (EOX) is a small (~$330mm) capitalization Bakken producer that I think has significant upside. It has fast growing production with sales tracking to better than a 70% gain this fiscal year and analysts' consensus for FY2014 have revenue more than doubling. A beneficial owner obviously finds the shares attractive as the entity took more than a $16mm stake in the firm in late May.
- [By Monica Gerson]
Emerald Oil (NYSE: EOX) is projected to post a Q4 loss at $0.02 per share on revenue of $18.04 million.
Callon Petroleum Company (NYSE: CPE) is estimated to post its Q4 earnings at $0.00 per share on revenue of $26.83 million.
- [By John Udovich]
Small cap Triangle Petroleum Corporation (NYSEMKT: TPLM), just like its peers Emerald Oil Inc (NYSEMKT: EOX) and Kodiak Oil & Gas Corp (NYSE: KOG), is focused on the Williston Basin�� Bakken and Three Forks formations and the company is scheduled to release second quarter fiscal year 2014 financial results after the close of trading�next Monday.�And the last time earnings were reported, shares jumped around 10% plus management gave some rosy commentary for investors. With that in mind, should investors in Triangle Petroleum Corporation be ready for another earnings report that excites the bulls?
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