Entek Flows Rates of 9.5 MMcfd at GA A133 Discovery

- Entek Flows Rates of 9.5 MMcfd at GA A133 Discovery

Tuesday, August 16, 2011
Entek Energy Ltd.

Entek announced the development of its GA A133 gas discovery, made in 2010, has been completed and gas is flowing at the planned 9.5 MMcfd on restriction. At current gas prices this should net Entek around US $250,000 per month. Entek has a 38% working interest in the block which is operated by Peregrine Oil & Gas II, LLC.

The GA A133 block has gross reserves of approximately 10 BCF associated with the recent discovery, with additional reserves linked to previous gas discovered on the block to be targeted at a later date.

Due to proximity to analogue production the GA A133 discovery well was not tested. This is common practice in the Gulf of Mexico where numerous existing producing analogues give a high level of confidence. The well is performing as predicted based on wireline log interpretation and correlation with offset analogue production.

For the same reason the Company did not flow test its recent oil discovery in VR 342. In this case analogue studies based on numerous existing producing analogues (performed independently on Entek's request) suggest potential flow rates of 500-1000 BOPD with minimal decline for the first 3-4 years.

Development planning is currently underway for the VR 342 oil discovery based on the flow rates described above and the independently certified gross reserves of circa 7.5 MMBO (1P 2.5 MMbo; 2P 4.8 MMbo; 3P 7.5 MMbo) and 9.5 Bcfg (1P 3.8 Bcfg; 2P 6.3 Bcfg; 3P 9.5 Bcfg) or 9.1 MMboe.

Additional wells are expected to be drilled in first half of 2012. First oil production is anticipated in 3Q 2012. Entek has 50% working interest in the VR 342 block.

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Whiting Posts Production Rates for Williston Basin Wells

- Whiting Posts Production Rates for Williston Basin Wells

Thursday, August 04, 201
Whiting Petroleum Corp.

Whiting released information on six western Williston Basin areas within its Lewis & Clark prospect and three nearby prospects. The initial production rates from wells drilled in these nine areas averaged 1,471 barrels of oil equivalent (BOE) per day. Whiting believes that its drilling results at Lewis & Clark and Hidden Bench as well as non-operated drilling results at Missouri Breaks and Starbuck indicate that a large portion of its 1,102,302 gross acres and 680,137 net acres in the Williston Basin has been shown to be productive and have excellent initial production rates.

Eleven Whiting-operated Sanish Sand wells in our Pronghorn area had initial production rates averaging 1,298 BOE per day. This average excludes four delineation wells drilled to determine the southwest boundary of the Sanish Sand reservoir at Pronghorn.

In our Big Stick area, we have completed three wells with initial production rates averaging 1,043 BOE per day. At Demores, where two wells had initial production rates averaging 479 BOE per day, Whiting is changing the direction of its well bores to a north-south orientation to encounter more natural fractures. In its Beaver Creek area, Whiting has completed six wells that averaged 1,119 BOE per day. A recent well in the Beaver Creek area, the Dry Creek 44-20TFH, flowed 2,337 BOE per day from the Three Forks formation on August 2, 2011. The Company has completed one well in its O'Neil Creek area. The Mosser 11-27TFH well was completed in the Three Forks formation with an initial production rate of 193 BOE per day. Severe weather conditions which caused a shut-down of flow back operations post frac is believed to have resulted in the low initial production rate on this well.

At Missouri Breaks and Starbuck, another operator has drilled within the outline of our acreage position. One non-operated well at Missouri Breaks was completed flowing 2,962 BOE per day. Three non-operated wells at Starbuck had initial production rates averaging 1,264 BOE per day. Whiting currently has two operated wells waiting on completion at the Starbuck prospect with results expected within 30 days.

James J. Volker, Whiting's Chairman and CEO, commented, "We are very encouraged with our results at Lewis & Clark and Hidden Bench. We are also encouraged by the initial production rates of area non-operated wells and the shows encountered during drilling operations on our two operated wells at Starbuck. We plan to complete these wells in early September.

"We own 387,351 gross (254,818 net) acres in Lewis & Clark, which is more than three and a half times larger than our Sanish field. At Lewis & Clark, Whiting has a controlling interest in 164 1,280-acre spacing units with an average working interest of 64%. Based on production to date at Lewis & Clark, it appears that these wells have a relatively shallow decline rate. Therefore, we continue to believe that our wells at Lewis & Clark will have Estimated Ultimate Recoveries (EURs) in the 300,000 to 500,000 BOE range."

Mr. Volker added, "Based on IHS data, with its average of 100,000 BOE, we continue to be on top of the list in terms of cumulative production during the first six months from all Bakken wells drilled in North Dakota since January 2009. For companies with a sample of at least 10 wells, Whiting leads the pack by 15,000 to 70,000 BOE in the first six months. We hold more than 680,000 net acres in the Bakken/Three Forks Hydrocarbon System that we believe will generate increased production and reserve additions."

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Dragon Oil's Lam Well Tests Rates of 1,767 bopd

- Dragon Oil's Lam Well Tests Rates of 1,767 bopd

Thursday, July 07, 2011
Dragon Oil plc

Dragon Oil announced the completion and initial testing of the Dzheitune (Lam) B/157 development well. The Dzheitune (Lam) B/157 well was drilled to a depth of 2,900 meters and completed as a single producer by the Iran Khazar rig. The initial test result from the well was 1,767 barrels of oil per day ("bopd"). The Iran Khazar rig has skidded to the next slot and spudded the Dzheitune (Lam) B/159 well. The NIS rig is currently drilling the Dzheitune (Lam) 28/158 well.

Dr Abdul Jaleel Al Khalifa, Chief Executive Officer, commented, "We have put into production six wells within the 2011 drilling campaign, having today reported the completion and initial testing of the Dzheitune (Lam) B/157 development well. We are making good progress on the drilling program and will update the market on the production numbers for the first half of the year on July 21, 2011 in the trading statement."

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Penn Virginia Disappointed by Initial Marcellus Production Rates

- Penn Virginia Disappointed by Initial Marcellus Production Rates

Tuesday, June 28, 2011
Penn Virginia Corp.

Penn Virginia updated its activities in the Marcellus Shale.

Peak 24-hour production rates from our first three Marcellus horizontal wells, the Risser #A-1H, Risser #A-2H and Dunn #A-1H, were approximately 3.1, 2.8 and 4.0 million cubic feet (MMcf) per day, with an average rate over a 72-hour test period of 2.1, 1.7 and 2.7 MMcf per day, respectively. These three test wells are located in the central portion of our approximately 35,000 net acre position in Potter and Tioga Counties, Pennsylvania. Pipeline construction is in progress with sales expected to begin by early August. One additional well in the western portion of our acreage is currently waiting on completion. During the second half of 2011, we plan to test, initially with vertical wells, the eastern portion of our acreage, comprised of approximately 20,000 net acres.

H. Baird Whitehead, President and Chief Executive Officer, stated, "The Marcellus Shale test wells had initial production rates which fell short of our expectations. We will monitor longer term production once these wells are turned into the pipeline and determine if the reserves can support a development program in this immediate area. As important, we will begin testing our eastern acreage position during the second half of the year."

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Rockhopper Tests Flow Rates of 5508 bpd at Sea Lion Appraisal

- Rockhopper Tests Flow Rates of 5508 bpd at Sea Lion Appraisal

Monday, June 27, 2011
Rockhopper Exploration plc

Rockhopper provided the following update on the flow test carried out at well 14/10-5.

• Well flowed at commercially viable rates
• Well flowed at stabilized rates of 5508 stb/d
• Well achieved a maximum stabilized flow rate of 9036 stb/d

A total section of 86m, incorporating 79m of reservoir, was perforated between 2379m and 2465m (md) over the Sea Lion Main Fan Complex. No lower fan sands were perforated on this flow test.

The well flowed for a main 48 hour flow period at a stabilized rate of 5508 stb/d and 940 mscf/d of gas with a flowing well head pressure (WHP) of 783 psi on a 48/64 inch choke. The gas oil ratio (GOR) was 170 scf/stb over the 48 hour period. The well was flowed through a separator under artificial lift by means of a downhole electric submersible pump (ESP). The flowing wellhead temperature was 62 degrees C. This temperature is significantly higher than that achieved during the test of well 14/10-2 and demonstrates the highly effective nature of the Vacuum Insulated Tubing (VIT) used during the test at 14/10-5. It was not necessary to use any wax inhibitors or pour point suppressants and no water or H2S were produced during the test.

The well was flowed for a second main flow during which the final maximum flow rate of 9036 stb/d was achieved with a flowing WHP of 625 psi on a fixed 1 inch choke over a 2 hour period before shutting the well in for a final build up and injectivity tests. The GOR during the maximum rate flow period was 153 scf/stb.

During the test down hole pressures were recorded and both surface and downhole crude oil samples were collected and will now be analyzed by the Company.

Downhole mini DSTs (Drill Stem Test) were also performed on two of the three sands making up the 14m of net pay encountered in the well, which form part of the lower fan. These 2 sands had net pay of 8m and 4.5m. Interpretation of the results of the mini DST indicate that these 2 sands could have contributed an additional 800 stb/d flow rate using the same flow test techniques (artificial lift by ESP and thermal insulation by VIT) as used during the main DST performed on the upper fan in well 14/10-5.

The Board views the flow rates achieved as being commercially viable. Further appraisal drilling is being progressed over the coming months to continue to define the extent of the Sea Lion resource.

The Ocean Guardian drilling unit will now drill well 14/10-6, which will be the third appraisal well within the Sea Lion discovery area. 14/10-6 is located some 4.5km to the west of well 14/10-5 and is located within the Company's currently mapped mid-case area.

Sam Moody, Chief Executive of Rockhopper, commented, "This very positive well test result is another key milestone in establishing Sea Lion commerciality. We will now review the wealth of data gathered during the testing process and continue our preparations for the next appraisal well on the field."

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TAG Flows Rates of 8.8 MMcf/d at Sidewinder-2

- TAG Flows Rates of 8.8 MMcf/d at Sidewinder-2

Thursday, June 23, 2011
TAG Oil Ltd.

TAG Oil reported that a 4-Point Isochronal flow test was completed over the main discovery zone in the Sidewinder-2 discovery well, which achieved stabilized flow rates of 8.8 million cubic feet per day (~1467 BOE per day) with less than a 25% drawdown.

The results from Sidewinder-2 further strengthen the already robust project economics, with anticipated full-time commercial production commencing upon completion of the new Sidewinder production facilities in a few months time. The Sidewinder-2 well is the fourth Sidewinder well that has been flow tested, all of which have achieved excellent flow rates, as summarized below:

Sidewinder Discovery Flow Test Results

Sidewinder Well	Gas Flow Rate (MMcfpd)	BOE Flow Rate (boepd)	Final Drawdown Rate	Net O&G Encountered
Sidewinder-1	7.40	1,233	28%	14 meters
Sidewinder-2	8.80	1,467	25%	47 meters
Sidewinder-3	7.21	1,202	40%	15.4 meters
Sidewinder-4	6.98	1,163	25%	19 meters
Totals	30.39 MMcfpd	5,065 Boepd

The Sidewinder-2 exploration well was drilled to a depth of 1,597 meters (5,238 feet), intersecting the main Sidewinder discovery zone, as well as four other separate oil-and-gas charged zones of interest totaling 47 meters (157 feet) of net pay. The interpreted pay zones are primarily within the Miocene-aged Mt. Messenger Formation; however oil shows were also encountered in the shallower Urenui Formation.

The Sidewinder oil and gas discoveries are located in TAG Oil's Petroleum Exploration Permit 38748 (TAG 100%) in the Taranaki Basin, New Zealand, with further exploration drilling in the lightly-explored area scheduled to recommence in September 2011. TAG will continue to target the widespread high-impact prospects identified in the Mt. Messenger Formation.

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Egdon Posts Initial Production Rates at Keddington

- Egdon Posts Initial Production Rates at Keddington

Friday, May 27, 2011
Egdon Resources plc

Egdon provided an update on production testing of the Keddington-4 well in Egdon's operated license PEDL005 (Remainder) located in Lincolnshire.

The Keddington-4 well was drilled as a re-entry and horizontal sidetrack from the Keddington-1Z "donor" well, during April 2011 and encountered a total of 120 meters of the primary reservoir Unit 1 sandstone and 65 meters of Unit 2.

Site reinstatement works have been completed and the Keddington-4 well commenced pumping operations on Monday, May 23, 2011 at 08.30 hours. After initial recovery of kill-brine and oil-based drilling mud, the well began free-flowing oil and gas through an adjustable choke and the pump was shut-off. The well has been shut-in periodically to observe pressure behavior. Free-flowing production over a flowing period of 68 hours to 07.30 on May 27, 2011 has yielded 647 barrels of oil along with 1,106,300 cubic feet of gas on a minimum choke setting. The production rate for the 24 hours to 07.30 hours on May 27, 2011 was measured at 234 barrels of oil per day ("bopd") and 518,000 cubic feet of gas per day ("cfg/d"). No formation water has been observed to date.

It is intended to continue to produce the Keddington-4 well over the coming few weeks to determine the optimum rate and methods of producing the well. Production from the adjacent Keddington-3z well, which was producing at constrained rates of 100 bopd and 650,000 cfg/d prior to being shut-in during the drilling operations, will resume in the coming weeks once stable production has been established from Keddington-4.

We will provide further updates once stable oil and gas rates for the field are established.

Egdon holds a 75% operated interest in PEDL005(Remainder). The joint venture partners are Terrain Energy Limited (15%) and Alba Resources Limited (10%), a wholly owned subsidiary of Nautical Petroleum.

Commenting on the production testing operations, Egdon's Managing Director Mark Abbott said, "We are pleased by these initial production results from the Keddington-4 well. The good oil rates, lack of any observed formation water and current gas production from the well are all encouraging. We will continue to flow and monitor the well over the next few weeks as we look to define the optimum production strategy for the well and the field as a whole."

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Kenai Loop Flows Rates of 10 MMcfpd

- Kenai Loop Flows Rates of 10 MMcfpd

Thursday, May 26, 2011
Buccaneer Energy Ltd.

Buccaneer provided the following the initial results from flow testing operations at its 100% owned Kenai Loop # 1 well.

Highlights

• Successfully tested gas at a rate of 10 million cubic feet per day (1,250 BOEPD)1 on a 20/64" choke;
• Only 2 zones totaling 87' of pay perforated and tested in the Upper Tyonek;
• An additional 14 zones totaling 423' of gross pay in the Upper Tyonek and Beluga Formations to be tested at a later date;
• Results to date exceed expectations;
• Testing ongoing with additional results to be released.

1 Gas to Oil Ratio of 8:1

In the initial phase of the testing program, the Kenai Loop #1 has successfully tested gas to the surface at a rate of 10 million cubic feet per day on a 20/64" choke with a FTP (flowing tubing pressure) of 3,495 psi. Testing will continue to better predict long term deliverability.

Gas is being safely flared, smaller choke sizes were required causing some modifications to the testing program to limit the flare to approximately 100'.

The Company has up to 16 zones totaling 510' of gross pay identified by logs as test candidates in the Beluga and Upper Tyonek Formations. As the rig must be released back to Marathon on June 1, 2011, 2 of the 3 high graded zones in the Upper Tyonek Formation were chosen to be perforated and tested.

The 2 zones total 87' of gross pay were described as follows:

Zone 1 has an upper sand of 37' of gross pay which logs have confirmed as being quality reservoir with high porosity and good permeability. This upper sand package had a "gas kick" during drilling operations. There is an additional 12' of lower sand which is a lesser quality sand, but remains attractive. Only the upper portion of this zone is included in the testing program.

Zone 2 is an additional massive sandstone zone of approximately 50' of gross pay which logs indicate has good porosity and permeability.

Both zones were perforated simultaneously and resulted in an immediate build up of pressure. The testing program will continue over the next 48 hours to complete a 4 point test which has just been initiated. Additional details of the testing results will be made available after detailed analysis of the bottom hole pressure measurements.

Although testing is not yet complete, calculated Absolute Open Flow Potential (AOFP) is expected to exceed expectations, based on testing thus far.

Once testing is complete, these two zones will be completed and will be the initial producing interval for this well.

Depending on rig availability a second well is planned for the third quarter 2011. The Company is in the progress of formulating a development program for the field, including a production schedule, beyond the initially anticipated 2-3 wells.

Background

The closest wells to the Company's Kenai Loop # 1 well are the Cannery Loop # 3 and # 4 wells located in the Cannery Loop Field, which were drilled from the same surface location approximately 6,325 feet (1.2 miles) from the Kenai Loop # 1 well location.

The Cannery Loop # 3 and # 4 wells have produced a combined 25.5 BCF from pay zones whose equivalents are expected to be present in the Kenai Loop # 1 well, but separated from the Cannery Loop Field by geological deposition rather than fault. Drilling to date in the Kenai Loop # 1 well has confirmed that the formations encountered to date are likely separated from the Field.

There were 11 wells in the adjacent Cannery Loop Field which produced 175 BCF (21.9 MMBOE) One well produced from the Sterling Formation which is not one a target in Kenai Loop # 1 well, the other 10 wells produced from the Beluga and Upper Tyonek. The Upper Tyonek is the primary target Formation of the Kenai Loop #1 well.

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Unemployment Rates Decrease in Odessa, Midland

- Unemployment Rates Decrease in Odessa, Midland

Tuesday, May 24, 2011
Odessa American, Texas
by Jon Vanderlaan

The unemployment rate in the Permian Basin continued to fall last month as oilfield and service jobs have seen yet more increases in employees.

Willie Taylor, the executive director of the Permian Basin Texas Workforce Development Board, said as long as the oil and gas industry stays strong, the unemployment numbers will continue to drop.

"We don't want to use the 'boom' word right now, but our market is really great," he said.

Employment in the goods producing industry in Odessa, including mining (which includes oil) and manufacturing, increased by 1,300 jobs from April 2010 to April 2011, with service providing employment rising by 1,400 jobs.

Midland numbers reflect a similar increase with 1,200 service providing jobs added and 1,500 goods producing jobs added.

Taylor said as long as the oil and gas industry continues to do well, the unemployment rate will continue to lower. Forecasters predict the good market in those industries could last another three years, he said.

"We will continue to see (unemployment rates) drop as long as we got people coming in and going into the job market," he said. "We're looking at a strong economy and it's going to be around for quite some time."

Unemployment in the Odessa metropolitan statistical area dropped to 6.1 percent in April after a 6.3 percent unemployment rate in March. There was a 7.9 percent unemployment rate in April 2010.

The number of those employed has increased more than the 1,000 people that joined the workforce in Odessa, growing 2,350 from April 2010 to April 2011.The number of unemployed dropped by almost 1,300 people in the area to 4,466 people.

The Midland metropolitan statistical area saw a drop in unemployment during the past year from 5.3 percent to 4.4 percent, retaining its grip on the state's lowest unemployment for cities.

The Midland area had 2,221 people join the employment ranks from April 2010 to the same time this year to bring the total up to 75,202 people. The number of unemployed in the area dropped from 4,055 to 3,441, despite an increase of almost 1,600 people in the workforce.

The Texas Workforce Commission said Friday the state added 32,900 jobs, the seventh consecutive month of job growth in Texas.

The jobless rate dropped to 8.0 percent from 8.1 percent in March and 8.2 percent a year ago. The Texas unemployment rate remained well below the national rate of 9.0 percent.

The unemployment rate fell last month in more than three-quarters of nation's states, evidence that companies are feeling more confident in the U.S. economy.

The Labor Department said Friday that the unemployment rate dropped in 39 states in April. That's an improvement from March when 34 states had reported decreases. The rate rose in three states and the District of Columbia. It was unchanged in eight states.


Copyright (c) 2011, Odessa American, Texas

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Sefton Expects Improved Flow Rates at Tapia, Charges Ahead in Ks.

Sefton Expects Improved Flow Rates at Tapia, Charges Ahead in Ks.

Wednesday, April 06, 2011

Sefton Resources Inc.

Sefton updated on trading for its oil production assets in California and gas infrastructure assets in Kansas.

 

California

Sefton's 100% owned subsidiary TEG Oil & Gas USA, Inc ("TEG USA") is the operator of its operations in California at Tapia and Eureka Canyon.

As was announced on March 1, 2011, TEG USA commenced its pilot steam flood operations at the Hartje #10 well in March and is currently injecting steam at about 35% capacity which will be increased to approximately 75% to 80% capacity (normal operating levels) over the coming weeks. At that point, approximately 700 to 780 bbl of steam will be injected per day into the center of the oilfield.

TEG USA averaged approximately 123 bbl per day during March, which is regarded as the baseline primary oil production level and it is anticipated with the injection of steam into the Hartje #10 well this will rise as it did for the pilot cyclic steam program last year.
Local California oil is currently posting at a 4% premium to NYMEX futures, rather than the more typical 7%-9% deficit. This spread has averaged a positive $4.20, for a posting of just over $107/bbl average for the month of March.

The preparatory work for the steam flood sensitivity geologic modeling will be completed in early April ready for Dr. Farouk Ali to commence his steam flood modeling work, which will last several weeks and is expected to be completed in May 2011.

 

Kansas

Sefton's Assets in Kansas are in Leavenworth County, including the Vanguard pipeline and the recently acquired LAGGS pipeline, and Anderson County, being the Waverly facility. Additional assets along the LAGGS pipeline are currently undergoing due diligence and are expected to close by 30 April 2011.

 

Leavenworth County

Repairs to all of the 8" and the bulk of the 6" and 4" segments of the Vanguard Pipeline system have been completed and tested. Strategically, the 8" portion of the system is the most critical segment of the system and this segment will see the first volumes in 2011 with initial revenue from the Company's 100% owned subsidiary, TEG Midcontinent Inc and a third party expected to accelerate during the coming year
Testing and activation of the LAGGS pipeline have begun. Three areas for repair have been identified. The repairs will be made in the order of their operational importance.

It is anticipated that later in 2011 the two systems, Vanguard and LAGGS, will be connected together and, as a result, it will be possible to move gas to market at two separate points and to two separate markets. This will give Sefton the possibility of moving gas to the higher return market from month to month.

 

Anderson County

The Waverly facility consists of over 10 miles of pipeline, fifteen well bores, two salt water disposal wells and a dehydration facility capable of processing 10 million cubic feet of gas per day. The Waverly facility has an inactive tap with Post Rock (an interstate pipeline company) at the dehydration facility. Reactivation of the tap is expected to take place in early 2012.

Jim Ellerton, Acting Chairman and CEO of Sefton Resources said, "The Company is progressing well - we expect improved flow rates at Tapia and the prospect of still further increases once we can implement the recommendations of Dr. Farouk Ali's report. At the same time, we have continued to make progress in Kansas and this will continue further in the coming months so that we can activate the assets as soon as is possible. We are cash generative, profitable and actively increasing our investor profile and believe this will position us well for the future."