Tag Archives: Energy

Atomic Energy of Canada Limited going for voluntary disclousure

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CHALK RIVER, ON, May 26 /CNW/ – The following information bulletin is in accordance with Atomic Energy of Canada Limited’s (AECL) ongoing commitment to voluntary public disclosure of events related to the Chalk River Laboratories (CRL).

AECL reports that the final and most challenging weld repair was applied to the NRU vessel over the weekend. Ninety-three per cent of the NRU weld repair activities are now complete.

Non-destructive examination (NDE) of the final repair site is currently underway and the NDE data collected will be used to confirm the success of the final repair.

Activities related to the start-up phase of the NRU return-to-service project are ongoing in parallel to NDE activities. There are 19 start-up procedures involving more than 1,000 subset activities required to safely return the reactor to high power.

More information on the return to service of the NRU is available at NRUCanada.ca.

Guidance on the duration of the shutdown continues to be founded on the best evidence available, including the most up-to-date analysis of inspection data, progress on repair strategies and critical path requirements for restart after an extended shutdown. It is estimated that NRU will resume isotope production by the end of July. Further guidance on the return-to-service date will be provided when more information becomes available.

AECL is working diligently to return the NRU to service as quickly and safely as possible. Efforts are being driven by more than 300 highly qualified AECL staff and industry partners involved in the vessel repairs and return-to-service activities.

The CNSC safety inspectors continue to provide independent regulatory oversight of AECL activities at the Chalk River site.

There is no threat to workers, the public, the environment or nuclear safety related to this event.

IROC Energy Services Corp. announces increased net income

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Total revenue for IROC from continuing operations increased 16% to $16.2 million for the three months ended March 31, 2010 as compared to $14.0 million in the comparable period of the prior year. – Gross margin from continuing operations increased 17% to $5.6 million for the three months ended March 31, 2010 as compared to $4.8 million in the comparable period of the prior year. – EBITDAS from continuing operations increased 31% to $3.4 million for the three months ended March 31, 2010 as compared to $2.6 million in the comparable period of the prior year. – Net income from continuing operations increased 539% to $524 thousand for the three months ended March 31, 2010 as compared to $82 thousand in the comparable period of the prior year. – The Corporation paid a cash dividend of $0.02 per common share on January 29, 2010. OPERATIONS ———-

IROC’s continuing operations are reported in three segments; the Drilling and Production Services segment, the Technology Services segment and Corporate Services. The following is a discussion of the reporting segments in which IROC operates.

DRILLING AND PRODUCTION SERVICES

The Drilling and Production Services segment provides services and rental equipment to oil and gas exploration, development and production companies with most of our customers and operations being located in western Canada, in the provinces of Alberta and Saskatchewan.

The Drilling and Production Services segment consists of two divisions:

Eagle Well Servicing (“Eagle”) contracts service rigs to oil and gas companies to perform various completion, work-over and maintenance services on oil and natural gas wells. Eagle has offices and equipment in Red Deer, Grande Prairie and Lloydminster in Alberta and an office and equipment in Estevan, Saskatchewan with equipment being used in those geographic areas.

Aero Rental Services (“Aero”) provides rental equipment for surface pressure control in drilling and work-over operations and tubular handling equipment used for the work over, re-entry and completion operations. Aero has an office in Red Deer, Alberta with equipment being rented for use primarily in Alberta. Aero’s results are directly affected by the level of new well drilling activity.

This segment generated revenue of $13.5 million, or 83% of the Corporation’s total revenue, for the three month period ended March 31, 2010.

Eagle currently has a fleet of 36 service rigs with our fleet amongst the newest in the industry. All Eagle’s service rigs are internally guyed (no requirement for external anchors) which reduces set up time and corresponding costs when compared to anchored rigs.

Service rig utilization, as measured by IROC’s internal methodology, improved in the quarter to 55%. This is the best utilization since the third quarter of 2008 and is the third consecutive quarter of improvement. This trend is attributed to the improving environment in the energy sector due to improved and stabilizing oil prices. Natural gas focussed activity continues to be constrained at current price levels. Pricing for services continues to be very competitive and, notwithstanding the increases in utilization, has not been able to recover to year ago levels.

Aero rentals has followed a similar trend over the past three quarters with improving gross margin returns on capital used for rental equipment.

TECHNOLOGY SERVICES

The Technology Services segment is comprised solely of our Canada Tech division. Canada Tech develops, manufactures and sells or rents a wide line of tools and systems that measure pressures, temperatures and other attributes in the down-hole and surface environment of oil and gas wells.

This segment generated revenue of $2.7 million, or 17% of the Corporation’s total revenue, for the three month period ended March 31, 2010. During the quarter 25% of Canada Tech’s sales were to Canadian customers, 25% were to the customers located in the United States and 50% were to international customers.

Canada Tech’s customers require data that is reliable, consistent and accurate. Our products utilize new and superior technology enabling our gauges and systems to operate in higher temperatures and more challenging environments. Canada Tech’s competitive advantage continues to be the ability to look at each well individually and adapt a system to match the needs of the customer within the well parameters.

Canada Tech differs from our other divisions in that the capital requirement is smaller and the value of the division is contained in its patents and proprietary technology. A significant portion of Canada Tech’s costs are fixed and as such increased sales volumes have a magnified effect on the EBITDAS of IROC. We expect improved performance from this division in the coming quarters as we increase sales to international markets and introduce new products and technology both domestically and internationally.

Canada Tech’s operations were consolidated in our Calgary facility in the current quarter and we expect to start to see the benefit of reduced overall costs as we continue through the year. Previously, Canada Tech had offices and facilities in both Red Deer, and Calgary, Alberta.

CORPORATE SERVICES

IROC’s non-operating segment, Corporate Services, captures general and administrative expenses associated with supporting each of the reporting segments operations noted above, plus costs associated with being a public company. Also, included in Corporate Services is interest expense for debt servicing and income tax expense.

Gran Tierra Energy Announces Positive Initial Moqueta-1 Exploration Well

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Oil and gas shows and potential pay on electric logs results in testing program design

CALGARY, June 7 /CNW/ – Gran Tierra Energy Inc. (NYSE Amex: GTE, TSX: GTE), a company focused on oil exploration and production in South America, today announced initial drilling results from Moqueta-1. Oil and gas shows were recorded through the Villeta T Sandstone and the Caballos Formation with electric logs indicating a total potential hydrocarbon net pay of 108 feet in the two primary reservoir zones combined. In additional to the two primary reservoir targets, the Villeta Lower U Sandstone also recorded hydrocarbon shows with a potential hydrocarbon net pay of 25 feet. As a result of these initial indications, a program is being designed to test the fluid content and productivity of the zones. This test program is expected to start immediately and take approximately three weeks to complete.

“We are extremely pleased with the initial results from the first well in our 2010 exploration program,” said Dana Coffield, President and Chief Executive Officer of Gran Tierra Energy Inc. “In light of these early positive results, a comprehensive flow test program is being designed and implemented for the prospective zones. In addition, the existing well pad is being prepared for drilling of a delineation well with a deviated well bore in the event the flow test is successful.”

Moqueta-1 Exploration Well, Chaza Block

The Moqueta-1 exploration well, located 5 kilometers north of the Costayaco Field, spud on May 16, 2010, and reached total measured depth (MD) in basement at 4,080 feet or 4,073 feet true vertical depth (TVD) on May 29, 2010. The same sandstone reservoir sequences encountered in the Costayaco Field were found in Moqueta-1, including the Villeta T Sandstone and the underlying Caballos Formation. Oil and gas shows were encountered in both reservoirs during drilling. Log interpretations from data acquired after drilling indicate the presence of reservoir sandstones in the T Sandstone beginning at 3,684 feet MD (3,677 feet TVD) with an approximate potential net pay thickness of 55 feet, and in the Caballos Formation beginning at 3,825 feet MD (3,818 feet TVD) with approximately 53 feet of potential net pay interpreted from the well logs. No oil-water contact is evident on the well logs in any of the reservoir zones.

Pressure gradient data obtained with the wireline testing tool indicates the U sand is gas bearing with approximately 25 feet of potential net gas pay. In addition, the entire T Sandstone and the uppermost Caballos sandstone also appears gas bearing. The Lower Caballos interval appears to have a gross oil column of 40 feet, of which 26 feet appears to be net oil pay. No gas-water or oil-water contact is apparent from the pressure gradient data. Subject to successful testing and subsequent delineation drilling, there remains potential for additional oil down-dip.

Moqueta-1 is the first of seven exploration wells budgeted for 2010 in the Putumayo Basin of Colombia. Taruka-1 in the Piedemonte Sur block is the next exploration well scheduled to be drilled in the 2010 program and Gran Tierra Energy expects to utilize the same drilling rig as is currently being used at Moqueta-1.

Other Colombia Operations

Costayaco-11 has been drilled in the northern portion of the Costayaco field, and is expected to be used as a Caballos producer and as a water-injector to provide pressure maintenance in the T-Sandstone reservoir.

Two seismic acquisition programs are ongoing. The 92 square kilometer 3D Rumiyaco program in the Rumiyaco Block and the 76 square kilometer 3D Florida West program in the Azar block are being acquired to support drilling prospects for 2010 and 2011. Additional seismic programs are budgeted for the Putumayo area in preparation for 2011 exploration drilling.

Peru Operations Update

Gran Tierra Energy is initiating seismic crew mobilization to Block 128 to begin 480 kilometers of 2D seismic data acquisition on Blocks 122 and 128. Exploration drilling on up to four prospects in Blocks 122 and 128 is expected to take place in the third and fourth quarter of 2010.

Argentina Operations Update

The re-entry and sidetrack of the VM.x-1001 well in the Valle Morado Block in the Noroeste Basin is ahead of schedule and is expected to commence drilling in July. Operations for access road improvements and location construction are approximately 60% complete. This sidetrack is planned to be drilled to 20,177 feet MD (or 19,964 feet TVD) to test the productive capacity of the Valle Morado gas field.

In the Santa Victoria block, the contractor tendering process has been completed for a 150 km2 3D and 188 km 2D seismic acquisition program in the third quarter of 2010 to define structural and stratigraphic traps in a gas-condensate trend identified from existing seismic data. Environmental impact assessment permit approvals are nearly complete. Seismic data acquisition is expected to be initiated in August, 2010. This data is expected to be used for mapping potential exploration drilling opportunities for 2011.

About Gran Tierra Energy Inc.

Gran Tierra Energy Inc. is an international oil and gas exploration and production company, headquartered in Calgary, Canada, incorporated in the United States, trading on the NYSE Amex Exchange (GTE) and the Toronto Stock Exchange (GTE), and operating in South America. Gran Tierra Energy holds interests in producing and prospective properties in Argentina, Colombia and Peru, and has opened a business development office in Rio de Janeiro, Brazil. Gran Tierra Energy has a strategy that focuses on establishing a portfolio of producing properties, plus production enhancement and exploration opportunities to provide a base for future growth.

Gran Tierra Energy’s Securities and Exchange Commission filings are available on a web site maintained by the Securities and Exchange Commission at http://www.sec.gov and on SEDAR at http://www.sedar.com.

Forward Looking Statements:

This news release contains certain forward-looking information and forward-looking statements (collectively, “forward-looking statements”) under the meaning of applicable securities laws, including Canadian Securities Administrators’ National Instrument 51-102 – Continuous Disclosure Obligations and the United States Private Securities Litigation Reform Act of 1995. The use of the words “expect”, “plan” and “scheduled” identify forward-looking statements. In particular, but without limiting the foregoing, this news release contains forward-looking statements regarding: the expected timing of the Moqueta-1 test program, the expected drilling of Taruka-1, the expected use of Costayaco-11, the expected commencement of drilling of VM.x-1001, and the expected timing of initiation of the acquisition of seismic data in the Santa Victoria block and its expected use.

The forward-looking statements contained in this news release are subject to risks, uncertainties and other factors that could cause actual results or outcomes to differ materially from those contemplated by the forward-looking statements, including, among others: Gran Tierra Energy’s operations are located in South America, and unexpected problems can arise due to guerilla activity, technical difficulties and operational difficulties which impact or delay its testing and drilling operations; geographic, political and weather conditions can impede testing and drilling operations; and the risk that current global economic and credit market conditions may impact oil prices and oil consumption more than Gran Tierra Energy currently predicts, which could cause Gran Tierra Energy to modify its exploration activities. Further information on potential factors that could affect Gran Tierra Energy are included in risks detailed from time to time in Gran Tierra Energy’s Securities and Exchange Commission filings, including, without limitation, under the caption “Risk Factors” in Gran Tierra Energy’s Quarterly Report on Form 10-Q filed May 10, 2010.

Arrow Energy, Australia Takeover Proposal By Shell, PetroChina Remains On Track

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SYDNEY -(Dow Jones)- Arrow Energy Ltd. (AOE.AU) said Monday that a proposed A$3.44 billion takeover of the bulk of its Australian assets by Royal Dutch ShellPLC (RDSB.LN) and PetroChina Corp. (PTR) remains on track to be sealed by lateJuly.

In a slideshow presentation lodged with the Australian Securities Exchange,Arrow said its shareholders are still expected to vote on the pair’s A$4.70 pershare cash offer on July 14, with a related court ruling expected July 29 andlast day of trading in Arrow shares expected July 30.

Arrow on Monday also released a scheme booklet explaining the deal toshareholders, which it said has been court approved and lodged with thesecurities regulator.

Nalcor Energy – Oil and Gas update on Nalcor et al Seamus well and Parsons

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Pond area drilling program

ST. JOHN’S, NL, May 26 /CNW/ – Nalcor Energy – Oil and Gas (Nalcor) announced today the first well of its Parsons Pond Drilling Program, Nalcor et al Seamus, which spud on February 16, 2010, has reached the planned total drilling depth of 3,160 meters.

“We reached our final drilling depth this past week on the first well of our three well program in the Parsons Pond area,” said Jim Keating, VP Nalcor Energy – Oil and Gas. “We encountered gas during drilling and intend to conduct testing to further assess the potential.”

The extent of flow characteristics and overall volumes of gas in place have yet to be determined. The well will be suspended to allow for further analysis of the data and to prepare testing plans. Next steps are the coordination and mobilization of necessary testing equipment. Testing will be conducted during the summer months and further information will be released following completion and analysis of the results.

Nalcor’s main operational objective was to gain information from this well which will allow further insight and assessment of the petroleum potential of this area. “The information obtained to date has already advanced our understanding of this basin,” said Keating. “The geological and geophysical prognosis of formation depths and stratigraphy anticipated from our pre-well analysis proved to be accurate.”

“Our top priorities on this drilling program continue to be safety and the environment. We drilled this well with no incidents and I’d like to commend our employees, contractors and partners for their diligence and commitment,” he noted.

“The drilling program is progressing according to plan,” said Keating, “and our investment in the local area continues. To date, we’ve invested over $1.6 million in local and provincial goods and services and the majority of the rig crew are from the local area.”

Nalcor Energy – Oil and Gas is now preparing for the drilling of the second well of the planned three well program. It is anticipated that the drilling of Nalcor et al Finnegan will commence this summer.

The company has also received approval from the Environmental Review Process, relating to the third well in the program, Nalcor et al Darcy. New road construction required for this location will now start mid summer and drilling is anticipated to commence in the fall of 2010.

Nalcor Energy – Oil and Gas has an average of 67 per cent gross working interest in three onshore exploration permits in the Parsons Pond area, on the Island’s west coast. In addition to Nalcor, there are four other partners with varying holdings in the three permits: Leprechaun Resources Ltd.; Deer Lake Oil and Gas Inc.; Investcan Energy Corporation; and Vulcan Minerals Inc.

Nalcor Energy – Oil and Gas is also a working interest partner in the White Rose, Hibernia Southern extension and Hebron offshore projects.

For further information: Media Contact: Dawn Dalley, Manager Corporate Communications, (709) 737-1315, c. (709) 727-7715, e. ddalley