i like this stock.

Our Sister Company Entek posted the following update:
2011 Niobrara Appraisal Program Update


Entek provides the following update on its 2011 Niobrara Appraisal Program.

This release also contains new information in relation to recent industry results in the Niobrara Play and the Company’s future work program.

Three vertical appraisal wells were successfully drilled through the Niobrara section and completed on budget in 2011. All of these wells intersected multiple naturally fractured oil charged zones within the Niobrara shale.

The wells have not been fracture stimulated, and were drilled as appraisal wells to identify the most productive zones within the Niobrara and to obtain technical information necessary to design and execute effective fracture stimulation treatments in 2012.

All of these unfracced wells are producing 40° API, light high quality oil, with no associated water from the Niobrara, with initial production of about 10 BOPD and Gas Oil Ratio (GOR) of between 1000 and 2000 scf/bbl. Data collected from the wells during completion indicates that only limited connection has been made to natural fractures close to the well bore, as expected from the small scale oil break downs performed. Full fracture stimulation planned for 2012 will be designed to open more of the perforations and connect to a much more significant fracture network further away from the well bore, which should result in increased flow rates and ultimate oil recovery.

A vast amount of data was collected from the 2011 appraisal program,
significantly advancing our understanding of the Niobrara Shale, including the oil breakdown pressure information considered critical to designing effective fracture stimulations. This data is now under evaluation to design the most effective completion and fracture stimulation configurations for each of the oil charged zones within the Niobrara.

All the wells were completed to facilitate re-entry and fracture stimulation in 2012, or alternatively sidetracking into horizontal section for future completion.GRB Drilling Activity.

In the Green River Basin (GRB) to the south of Entek’s acreage (approximately 25 miles), Gulfport, Shell and Quicksilver have recently publically disclosed information from their respective 2011 drilling programs.
* Gulfport has drilled 3 vertical appraisal wells, has installed pumps and is currently commencing production operations. No information on oil production rates is available at this point.

* Shell, using 2 rigs, embarked on a significant program including at least 2 horizontal wells, with initial production reports expected in early 2012. In addition to their new wells Shell is understood to have
stimulated/recompleted two existing vertical Niobrara wells which are currently producing between 80 and 100 BOPD.

*Quicksilver drilled 6 vertical wells and 1 horizontal well in 2011 and experimented with various fracture stimulation designs. To date they have publically discussed flow rates from a number of their vertical wells with around 100 BOPD from single fracture stimulated intervals in each well, a positive result given the multiple stacked productive zones that exist in the Niobrara in the GRB. Quicksilver have also published a type curve for vertical wells with initial production of 70 BOPD with an estimated ultimate recovery of 225,000 BO, which has a very respectable 30% IRR.

It is not unreasonable to anticipate that the Entek’s unstimulated wells, once effectively fracture stimulated,will perform similarly to those recently announced by both Quicksilver and Shell. Significantly, Quicksilver have also recently announced the flow rate results of their first horizontal well in the GRB. The well is producing at a rate of over 500 BOPD on restriction, maintaining good pressure after a month of
production from effectively a 1,500 ft fracture stimulated lateral section.

Based on experience and results from more mature shale plays Quicksilver expects future production wells in the GRB to have lateral sections of up to 6,000 ft which will be fully fracture stimulated, where significantly higher rates can be expected.

In summary, the drilling activity in the GRB Niobrara Shale Play is evidence that experienced US shale companies are committing substantial expenditure to accelerate proving the potential of the play around
Entek's acreage, and that their efforts are being met with success. Quicksilver and Shell have successfully shown that the Niobrara Shale in the GRB can be effectively fracture stimulated resulting in substantial oil production potential. Based on industry activity and results, Entek believes acreage values should rise significantly within the next 12 months.

Forward Plan
The Company is working the data from the 2011 appraisal program and planning the 2012 work program, with fracture stimulation of the existing wells, new vertical appraisal wells and horizontal wells being considered.

Access for operations other than production opens up again on the 1st of July for wells located on Federal lands. The Company is hopeful of gaining early access between March and July to perform fracture stimulation on the existing wells. New operations can take place on Fee and State leases all year round as these are not subject to
the same seasonal restrictions as Federal lands.

The Company will operate and control over 110,000 gross acres, approximately 91,000 net acres, covering the Niobrara Play in Colorado and Wyoming following the closing of a recently announced acquisition (ASX Release dated 22 December 2011).

Entek holds a 55% working interest in the existing Niobrara project, with Emerald Oil & Gas NL (Emerald)holding the remaining 45%. Under the Area of Mutual Interest Agreement between Entek and Emerald, 45%
of the new acreage acquisition will be offered to Emerald for proportionate consideration. If Emerald takes up its 45% interest, Entek will have over 50,000 net acres in the Niobrara shale play; should Emerald not participate, Entek will have closer to 60,000 net acres in the play.

The map below represents the geographic extent of the gross acreage position including the new leases.Commenting on the recent Company and industry results, Entek’s Executive Director, Trent Spry said:
“The flow rates of our three wells are in line with expectations for unstimulated wells. Once fracture stimulated we expect these wells to perform similarly to those recently announced by Shell and Quicksilver in the Green River Basin.

Entek’s 2011 strategy has yielded vast amounts of data significantly advancing our understanding of the Niobrara Shale, while other companies in the play have undertaken early horizontal drilling and significant fracture stimulation programs, trialing alternative fluid types, breakdowns and stimulation methods including
larger oil and gas fracture stimulations.

Industry results in 2011 have been very encouraging, effectively proving that the Niobrara in the Green River Basin is at least as productive as in the DJ Basin where the play is more mature.
Entek is now in a position to more effectively apply the technology being demonstrated by others to unlock the play and we will be working diligently with our consultants, contractors and working interest partner over the coming months to plan our 2012 program”.
Further information on the Company is available at: www.entekenergy.com.au

Our sister company, ENTEK SIGNIFICANTLY INCREASES LEASE HOLDING IN NIOBRARA SHALE PLAY. I believe this is significant in relationship to our holdings

Entek is pleased to announce that it has entered into an agreement to acquire an acreage package of over 28,000 gross acres (around 19,000 net acres) adjacent to its existing lease position covering the highly prospective Niobrara Shale Oil Play in the Green River Basin. The consideration of around US$2.5 million is subject to Entek finalising its due diligence process.

On closing of this acquisition the Company will operate and control over 110,000 gross acres, approximately 91,000 net acres, covering the Niobrara Play in Colorado and Wyoming. Entek holds a 55% working interest in the existing Niobrara project, with Emerald Oil & Gas NL (Emerald) holding the remaining 45%. Under the Area of Mutual Interest (AMI) Agreement between Entek and Emerald, 45% of the new acreage will be offered to Emerald for proportionate consideration. If Emerald takes up its 45% interest, Entek will have over 50,000 net acres in the Niobrara shale play; should Emerald not participate, Entek will have closer to 60,000 net acres in the play.

The map below represents the geographic extent of the gross acreage position including the new leases. 2 ENTEK SIGNIFICANTLY INCEASES LEASE HOLDING IN NIOBRARA SHALE PLAY

Commenting on the acquisition, Entek’s Executive Director, Trent Spry, said: “This is a fantastic result built on relationships that we have nurtured over the past 18 months. The transaction pricing is a result of negotiations around Entek’s dominant acreage position and the benefits of consolidating the new leases for both parties by way of the vendor retaining a royalty interest in these leases and delivering to Entek an 80% net revenue interest. This has resulted in a significantly lower price per acre paid compared to market.

The Company’s lease acquisition strategy this year has resulted in close to a doubling of its acreage holding. The addition of this acreage builds on Entek’s already dominant position in the area. Having control of over 110,000 acres in the Niobrara Shale Play affords Entek great flexibility when planning the future development of the play. A land holding of this significance is likely to attract the attention of large companies with an appetite for unconventional resource assets.
Similar to our existing lease holdings, the newly acquired leases are a mixture of Federal, State and Fee leases with significant remaining lease term or existing renewal options. The Company’s dominant, long term lease position allows for time to appraise the acreage prior to moving into a large scale development phase.

The timing of this acquisition is ideal given the encouragement we have seen from our 2011 appraisal wells as well as early results from nearby industry activity.”

Our sister company Enteck provided the following 2011 Niobrara Appraisal Program Update:

Entek provides the following update on its 2011 Niobrara Appraisal Program.

Three vertical Niobrara appraisal wells were successfully drilled and completed on budget in 2011. The wells were designed as appraisal wells to identify the most productive zones within the Niobrara and to gather technical information necessary to design and execute effective fracture stimulation treatments for the 2012 drilling program, where both directional and horizontal wells are being planned.

The 2011 wells intersected multiple naturally fractured oil bearing zones within the Niobrara shale as well as penetrating the hydrocarbon bearing Frontier Formation which was tested in the Battle Mountain 14-10 well at over 20 BOPD and 200 MCFGD.

Following the installation of production facilities at all three well sites, pumping operations have recently been commenced. The wells are all producing 40O API oil with no water from the Niobrara. To date consistent rates have not been achieved as the Company trials different downhole pump configurations and surface production systems. Production updates will be provided once stabilised production rates have been achieved over the next few weeks.

Individual zones in the wells were treated with water based and CO2 based mini fracture stimulation treatments as well as oil breakdowns to establish communication of the natural fracture systems with the wellbore. The small size of these treatments mean that the wells are understimulated relative to wells designed for oil production and are demonstrating the results of connection to natural fractures in the immediate area of the wellbore only. Data gathered while drilling, logging, testing and completing each well is being analysed to determine the contribution from each of the Niobrara zones. A vast amount of data was collected from the 2011 appraisal program significantly advancing our understanding of the Niobrara Shale in the Company’s area of interest. In addition to drilling three new wells this year, the Butter Lake 32-10 vertical well has been re-entered and suspended ready for side tracking and fracture stimulation next year based on the results seen in the 2011 wells. The Butter Lake 32-10 well flowed oil at an average rate of 35 BOPD, interpreted to be from a single un-stimulated Niobrara zone with significant formation damage and completion limitations.

The fractured igneous intrusive reservoirs that are present in this area will be further evaluated in 2012. The Company’s Focus Ranch 12-1 well (which was tested in 2009 at a cumulative rate of 240 BOPD and 2.75 MMCFD) has already indicated the potential of the igneous intrusive reservoirs in the area.

Information on industry results to date has been scarce, as a competitive environment exists and companies generally disclose as little as possible until required to do so by regulation.
In the Green River Basin (GRB), around the Craig Dome area located approximately 30 miles to the South of Entek’s acreage, Gulfport, Shell and Quicksilver have publically disclosed information.
Gulfport has drilled 3 vertical appraisal wells, has installed pumps and is currently commencing production operations. No information on oil production rates is yet available.

Quicksilver has drilled 6 vertical wells and 1 horizontal well in 2011 and have experimented with various fracture stimulation designs. To date they have only publically announced flow rates from two wells between 50 and 100 BOPD from single fracture stimulated intervals in each well, a positive result given the multiple stacked potentially productive zones that exist in the Niobrara in this area.Quicksilver have established a type curve for vertical wells with initial production (IP) of 70 BOPD with an estimated ultimate recovery (EUR) of 225,000 BO, which has a very respectable 30% IRR.

Shell commenced a significant drilling program using 2 rigs, which they intend to complete by the end of 2011. A number of wells including at least 2 horizontal wells from the same drill pad have been drilled to date, with initial production expected in December and January. In addition to their new wells, Shell upgraded two existing Niobrara wells which are currently producing between 80 and 100 BOPD.

While in the North Park Basin, only 50 miles to the East of Entek’s acreage the latest well, Silver Spur Minerals 35-2 (believed to be vertical with a possible short lateral section and fracture stimulated) has reported an initial rate of 245 BOPD. In close proximity EOG had previously drilled four horizontal wells that reported initial rates of between 223 BOPD and 550 BOPD. It is believed that EOG has been following up these wells with a drilling program this year. No information on oil production rates from this year’s wells is yet available.

The drilling activity is evidence that experienced US shale companies are committing substantial expenditure to accelerate proving the potential of the GRB Niobrara shale play around the Company's acreage. The result to date, based on limited production information available, is very encouraging. Based on this activity, Entek believes acreage values will rise significantly within the next 12 months.

It is also worth noting that several vertical Niobrara wells in the GRB have produced at rates of several hundred BOPD. This includes a vertical, unstimulated well in the Sierra Madre Field. The Sierra Madre 12-20 well owned by Anadarko is approximately 8 miles from the wells drilled by Entek this year, had initial production of around 550 BOPD, has recovered in excess of 355,000 BO and is still on production. Similarly, another vertical unstimulated well in the Buck Peak Field 30 miles to the south initially produced at 480 BOPD and has recovered over 1.3 million BO.

Entek currently controls close to 86,000 gross acres, approximately 72,000 net acres, covering the Niobrara Shale Oil Play. Entek is Operator and holds a 55% working interest (approx. 40,000 net acres) in the project with Emerald Oil & Gas NL (“Emerald”) holding 45%.
Commenting on the recent production testing, Entek’s Executive Director, Trent Spry, said:
“We are encouraged by the results we have seen so far this year and will report stabilised production rates as they become available.
The Green River Basin is an exciting area to have such a dominant position in the Niobrara Shale Oil Play given the high rate, high recovery vertical unstimulated well results historically seen in the basin including Sierra Madre and Buck Peak.

With the vast amount of data collected from the 2011 appraisal program significantly advancing our understanding of the Niobrara Shale we are in a position to compare our results with those of other companies in the greater Green River Basin, who have been trialing alternative fluid types, breakdowns and stimulation methods including larger oil and gas fracture stimulations which are at a significantly higher cost compared to the program run by Entek. During 2011 each company has invested considerable capital in trailing alternatives that will result in the unlocking of the Niobrara in this area in the coming year.
The 2011 wells drilled by Entek were designed to deliberately allow re-entry for future fracture stimulations optimized after analysis of recent industry results. These wells also allow for horizontal drilling out of the existing well bores.

This year Entek, as a relatively small company, has effectively placed itself in a position to be able to benefit in a cost effective manner from the technical work, including larger fracture stimulation trials, performed by larger companies to unlock the potential of the Niobrara Sale Play.

The Company is maintaining its strategy to acquire more acreage in this highly prospective area.”

Further information on the Company is available at: www.entekenergy.com.au

Robert Salna is CEO of a gold exploration company now.

Mr. Bentley:

Currently the stock is not trading on the market. In 2008 we were kicked off the Pinks because we hadn't filed our audited financials.

Recently the news has been getting better because Niobrara is heating up. Our sister company Entek has recently drilled 3 wells and will be reporting the results within 2 weeks. If they show promise, I expect that Mr. Salna will rehire the auditors and file the financials. At that point there will be a lot of interest in us both from small individual investors as well as larger companies. If so, I'm sure at that point DVPC will file the current and back audited financials and start trading on the pinks.

Just recently Hartley gave an initial buy recommendation on Emerald Oil & Gas which is another sister company. That should give you some insight on the possibility of Slater Dome.

I have shares, but with the latest turn of events I plan on keeping what I have. In the past I've bought from another previous poster of this board. To do so you would need to trust the other person on the end of the trade and he would need to request certificates from the transfer agent and assign over to you for your check. If you find such a person and you decide not to go through with it, let me know because I'm interested in buying more.

Hey JMan,

I see you have been posting updates for DVPC. Any idea how I might go about purchasing shares of Dover Petroleum Corp?

Latest Update from our Sister Company Entek

C&C Cattle 18-8[/b – Four zones in the Niobrara were completed with oil breakdowns & a CO2 based mini-frac. Pumping operations are about to commence, comingled from the Niobrara only.

Slater Dome (SD) Federal 24-9 – Five target zones in the Niobrara were completed with oil breakdowns & water based mini-frac. Production tubing is currently being run; following this the pumping unit will be set.

BattleMountain 14-10 – Four target zones in the Niobrara were completed with oil breakdowns, CO2 & water based mini-fracs. Plugs set between each breakdown are currently being drilled out.

Data gathered while testing and completing each well will be analysed to determine the flow rate contribution from each of the Niobrara zones.

Niobrara Shale Oil – Next Steps
* 2011 wells now completed and being tested directly to sales
* Initial flow rates from all wells expected by second week of December
* 2012Work Program to be agreed & announced early 2012
* Perform optimised fracture stimulation treatment to the wells early in next year’s work program, based on knowledge gained in 2011 (both internal & industry)
* Continue efforts to pursue ‘bolt on’ acreage opportunities
* Explore strategic alliances & partnerships with Industry Leaders

Here is the latest update from Entek regarding our sister companies Entek & Emerald:

ENTEK INCREASES ACREAGE POSITION IN NIOBRARA SHALE OIL PROJECT
During 2011 Entek has continued to acquire acreage within the Niobrara Shale Oil Project area in the Green River Basin. As a result the Company now controls close to 86,000 gross acres, approximately 72,000 net acres, covering the Niobrara Shale Oil Play.

Entek is Operator and holds a 55% working interest (approx. 40,000 net acres) in the project with Emerald Oil & Gas NL holding 45%.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

On 9/22/11, our sister company Entek provided the following update on the Niobrara Shale Oil Project Appraisal Program in the
Green River Basin.

Battle Mountain 14-10L – As predicted, in addition to potentially productive zones above and below, the well encountered three benches in the Niobrara shale. The highly prospective upper and middle benches, from which oil is produced in the greater area, and the previously untested lower bench. For operational reasons the decision was made on this first well to test all zones of interest from the bottom up. A fracture stimulation operation was successfully completed on the Frontier Formation with the first treatment. The fracture stimulation on the lower Niobrara bench carried out since the last update has only been partially successful and results will now be analysed by Halliburton and independent experts. The next fracture stimulation on this well, scheduled for mid-late October, will target one of the remaining Niobrara benches. Depending on
post-frac analysis results, the lower bench may also be re-stimulated before producing the well with production from all zones co-mingled.

Slater Dome (SD) Federal 24-9DLST – The well reached its total depth of 8,105 ft after penetrating the Niobrara and Frontier target zones. Wire-line logs have been successfully run and the well is currently running casing. Preliminary interpretation of the well log data is encouraging
and will now be reviewed to design a fracture stimulation program for all prospective intervals. The next scheduled timing for the frac operation is expected around mid-late October. The DHS
18 rig will be released upon completion of casing and cementing the well.

C&C Cattle 18-8 – The well reached its total depth of 6,700 ft after penetrating the Niobrara and Frontier target zones. The total depth is shallower than planned due to the target formations coming in higher than expected. Wire-line logs have been successfully run and casing set. The
casing is currently being cemented. As with the 24-9 well, the encouraging data from the well will be reviewed and a fracture stimulation program will be designed for all prospective intervals. The next scheduled timing for the frac operation is expected around mid-late October. The DHS 19 rig will be released upon completion of casing and cementing the well.

Please Note – This release will be the last weekly appraisal program update. In future, updates will be provided as and when results determine.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Our sister company Entek posted the following message on September 15th, 2011 which provides an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L – The fracture stimulation program will commence around the 20th September 2011 after Halliburton completes work for another operator.

Slater Dome (SD) Federal 24-9DLST – Following last week’s decision to sidetrack the well, the new wellbore is at a depth of 6,650 ft, immediately above the Niobrara Formation. Wire-line logs have been run, and intermediate casing set, with the current operation cementing casing. The well is expected to drill out into the target Niobrara Shale within 48 hours. The planned total depth for the well is around 8,500 ft.

C&C Cattle 18-8 – The well is currently at a depth of 3,500 ft and drilling ahead. The planned total depth for the well is 8,000 ft.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Our sister company Entek posted the following update on September 9, 2011 regarding the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L – Pressure analysis has been performed on the first of the Niobrara zones to be tested in the well to refine the fracture stimulation program, which is on schedule for around 15th September 2011.

Slater Dome (SD) Federal 24-9DL – The decision was made to cease recovery operation in the original open-hole and to re-drill the Niobrara section in the well. A cement plug was set in the original open-hole section and the new sidetrack hole is currently being drilled at a depth of 4,700 ft, with total depth expected to be reached within the week, after which the well will be wire-line logged and cased and cemented in preparation for testing.

C&C Cattle 18-8 – DHS Rig 19 is set up on location and is expected to spud the well within the next 24 hours. The decision to bring in a second drill rig for the third well, while DHS Rig 18 completes the 24-9 well, will ensure we have all three wells prepared for the October and November fracture stimulation dates.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Our sister company Entek submitted the following update:

Entek is pleased to provide an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L – The Frontier (secondary objective) has been successfully fracture stimulated. Limited testing has been performed before completion and testing operations start on the lowest of the Niobrara Benches in the well. Test results suggest the discovery of an oil prone sweet-spot in the Frontier Formation which is part of the Mowry Shale Resource Play. The play has been a secondary target across the Company’s acreage since it tested hydrocarbons at an initial rate of 1.2 MMCFD and 10 BOPD in the Focus Ranch 12-1 well and since has shown significant oil and gas shows in each well where penetrated across the acreage. Test results suggest that the 14 ft perforated zone in the Battle Mountain 14-10 well will be
capable of around 20 BOPD and over 100 MCFD. It is most likely that the production from the Frontier will be comingled with production from the Niobrara once planned completion and testing operations in the well are complete. In the future the Frontier, like the Niobrara, is likely
to become a candidate for horizontal drilling. The Company will provide an update as the appraisal program continues on the potential of the Frontier and Mowry Shale Resource Play across its acreage position.

The completion program for the Niobrara (primary objective), which includes fracture stimulation and testing, will be initiated this week with fracture stimulation planned around 15th September.

Slater Dome (SD) Federal 24-9DL – The well has successfully reached its total depth of 8,300 ft after penetrating both the Niobrara and Frontier Formations. The well had significant oil and gas shows whilst drilling and was prepared for logging, with good hole condition reported. Whilst pulling out of hole to run wireline logs a drill string connection mechanically failed. Operations are continuing to remove the drill string from the hole prior to logging.

C&C Cattle 18-8 – Location preparation is complete. It is anticipated that the rig will be mobilized from the 24-9 location to the 18-8 location over the next week. An additional rig is on standby to
mobilize to the 18-8 location if operations on the 24-9 well take longer than expected.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Update from our sister company, Entek:

Entek is pleased to provide an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L – The well is currently being prepared for testing in the Frontier Sandstone secondary objective. The completion procedure, which includes testing and fracture stimulation for the potential Niobrara pay zones is currently being refined by Halliburton. Completion operations for the Niobrara are expected to start in September 2011.

Slater Dome (SD) Federal 24-9DL - The well has been spudded and is currently drilling the surface hole section at 400 ft. Casing is planned to be set at 2,500 ft before drilling the remainder of the well. The planned total depth of the well is 8,627 ft.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Entek, our sister Company posted the following on 8/11/11

Entek is pleased to provide an update on the Niobrara Shale Oil Project Appraisal Program in the Green River Basin.

Battle Mountain 14-10L[url][/url][tag]insert-text-here[/tag] – The well is currently being prepared for testing in the Frontier Sandstone secondary objective. The completion procedure, which includes testing and fracture stimulation for the potential Niobrara pay zones is currently being refined by Halliburton.
Completion operations for the Niobrara are expected to start in September 2011.

Slater Dome (SD) Federal 24-9DL [url][/url][tag]insert-text-here[/tag]– The well has been spudded and is currently drilling the
surface hole section at 400 ft. Casing is planned to be set at 2,500 ft before drilling the remainder of the well. The planned total depth of the well is 8,627 ft.

NIOBRARA SHALE OIL PROJECT APPRAISAL PROGRAM UPDATE

Our sister company Entek posted the following update on 8/4/11:

Battle Mountain 14-10L – The well has reached its total depth of 7,500 ft. Wire-line logs have been run and the well has been successfully cased and cemented ready for completion.

Preliminary interpretation of wire-line logs and correlation to offset wells show that the Niobrara section in this well contains significant potential pay zones (‘benches’), as expected.

In addition the Frontier Sandstone exhibits hydrocarbon saturation and is also being considered as a pay zone for fracture stimulation and completion. The fracture stimulation program is currently being designed with Halliburton and is expected to start in August 2011.

Please see the latest note posted today from our sister company:

ENTEK COMMENCES 2011 NIOBRARA SHALE OIL PROJECT APPRAISAL
PROGRAM IN THE GREEN RIVER BASIN

Entek is pleased to announce the commencement of its Green River Basin work program for 2011.

DHS Rig-18 has spudded the Battle Mountain 14-10L well, which is the first of a minimum 3 well Niobrara Shale Oil appraisal drilling program in 2011. Battle Mountain 14-10L was selected from 7 currently permitted well locations based on close proximity to the Battle Mountain 14-15 well which flowed oil last year against all odds from a severely damage well bore (drilled by the previous operator). Subsequent wells in the program will be located based on drilling results, local operating season constraints and field operational considerations.

Entek holds a 55% interest in the Green River Basin Joint Venture (GRBJV) with Emerald Oil & Gas NL (ASX:EMR) holding 45%. Entek is the Operator of the GRBJV. As a result of continued leasing activity and ongoing lease maintenance the GRBJV now controls close to 80,000 gross acres, approximately 60,000 net acres, covering the Niobrara Shale Oil Play.

The wells planned in the 2011 appraisal program will be drilled vertically to intersect the oilprone Niobrara Shale which can be up to 1,100 ft thick in the area. The wells are expected to penetrate the brittle naturally fractured bench intervals within the Niobrara section that have been proven as porous and permeable reservoirs in offset wells. As an example the Sierra Madre 12-20 well owned by Anadarko which is approximately 8 miles from the 14-10 well, had initial production of around 550 BOPD, has recovered in excess of 355,000 BO and is still on production.

In addition, the fractured igneous intrusive reservoirs that are present in this area will be further evaluated. The Company’s Focus Ranch 12-1 well (which was tested in 2009 at a cumulative rate of 240 BOPD and 2.75 MMCFD) has already indicated the potential of the igneous intrusive reservoirs in the area.

The primary objectives of the 2011 vertical well appraisal program are to:
* establish deliverability and commercial production of the oil prone Niobrara Shale;

* identify the most prospective Niobrara intervals;

* gather technical information necessary to design and execute effective fracture stimulation treatments; and

* select which intervals to target with both vertical and horizontal wells in 2012 as part of the continued appraisal and development program.

The Company is working closely with Halliburton to design fracture stimulation treatments for at least one interval in each well this year with scheduled slots available from August.

Initial flow test results from these wells are not expected to be available immediately after reaching total depth and logging. Rather, weekly announcements will be made each Thursday morning where drilling progress, fracture stimulation, testing and completion operations for each well will be updated as these operations will be occurring concurrently across all wells in the work program.

Interested parties are directed to review the Investor Presentation (to be presented to institutional investors from July) that was released to the ASX on 14 July, 2011 for further information on the Niobrara Shale Oil Project in the Green River Basin as well as the Company’s update on its recent successful oil discovery in the Gulf of Mexico.

CEO and Managing Director Trent Spry commented:
“It is exciting to have commenced our 2011 Green River Basin appraisal program. I am certain that our appraisal efforts in 2011 will provide the Company with the information and confidence it needs to accelerate appraisal and development in 2012.

We are seeing increased industry activity across leasing, well permitting (both vertical and horizontal), and acreage acquisitions and transactions in the area as the attention shifts from the DJ Basin to the Green River Basin this year.

Industry activity and success will provide valuable information on the Niobrara in the GRB and is expected to have a significant impact on acreage value. I look forward to providing further updates from now until the end of the year on what is an exciting time for the Company”

ENTEK COMMENCES OIL SALES WITH 1,000 BARREL LIFTING

Entek Energy Limited (Entek or the Company) is pleased to advise that the first tanker load of crude oil has been uplifted from the Entek operated Slater Dome Central Distribution Facility.

Approximately 1,000 barrels of oil has been accumulated from well operations and production. The majority of this oil has come from the Niobrara Formation with the remainder from the shallower Deep Creek reservoir producing in the CF&I well.

CEO and Managing Director Trent Spry stated: “This initial lifting heralds the commencement of oil sales from Entek’s extensive acreage within the Green River Basin, where multiple plays are anticipated to contribute to an upward trending production profile as the Company moves forward with its development plans.”

Entek our sister Company just posted this message:

GREEN RIVER BASIN RESERVES & CONTINGENT RESOURCE UPDATE

Highlights
• Contingent Resources increased to 187 Million Barrels of Oil (MMBO) and 191 Billion Cubic Feet of Gas (BCFG) using a conservative 4% recovery factor (recovery factors as high as 17% have been achieved in the Niobrara Play elsewhere)
• Reserves increased to 12.2 MMBO and 105 BCFG
Entek Energy Limited (Entek or the Company) is pleased to report a significant increase in Reserves and Contingent Resources for its Green River Basin acreage. This update does not include reserves for the Company’s Gulf of Mexico portfolio.

The Company is confident that the potential of its Niobrara play is now better defined as a result of the 2010 work program which has de-risked the play to the point where Proven Reserves and Contingent Resources can be classified.

The results have confirmed the Company’s belief that the Sand Wash Basin Niobrara play is one of the best continuous oil resource plays in North America. This is further substantiated by the recent increase in company acquisition and leasing activity levels in the area. The gross acreage Contingent Resource Assessment across Enteks’s acreage and the Focus Ranch 12-1 well Reserves Report are summarized below.

Contingent Resource: 187 MMBO and 191 BCFG* (conservative 4% recovery factor)

Focus Ranch 12-1 Reserves: 12.2 MMBO and 105 BCFG** (total P1, P2 and P3 reserve)

Trent Spry, CEO and Managing Director of Entek stated; “this significant increase in resources and reserves provides independent verification of the value proposition for Entek. The drilling to date significantly derisks the project and we look forward to further resource and reserve increases throughout 2011 as Entek increases drilling and production in 2011.”

Further detail supporting these estimates follow.

Independent Contingent Resources Assessment
The Contingent Resource Assessment was performed by Ahlbrandt Consulting (Thomas Ahlbrandt PhD) and Hoyer Petrophysics, Inc.. An explanation of the results follows, extracted from the executive overview of the report.

The Niobrara resource play in the Sand Wash Basin is three times thicker (1,000 feet plus including the Carlile) compared to the Denver Julesburg (DJ) Basin, with thicker reservoir pay intervals that occur in three benches with an aggregate thickness of 50-60 feet as contrasted with a typical DJ Niobrara pay zone of
15-30 feet.

If the fractured horizons are included the pay interval in the Niobrara on the Entek acreage averages 369 feet with fractures in the igneous sills adding another 100 feet of potential pay. This
calculates to 68 million barrels of in place oil per section (640 acres) where igneous sill reservoirs are present or 2.7 to 5.8 million barrels of oil recoverable of contingent resource per 640 acres, depending upon recovery factor of 4% or 12%. (constant 4% recovery used for igneous sill reservoirs).

Where no sills are present the potential oil recovery for a section is 1.5 MMBO at 4% recovery factor to 4.6 MMBO at 12%
recovery factor. Assuming only 4% recovery across the acreage position the Total Contingent Resource associated with the
approximately 60,000 acres that Entek is farming into is 187 MMBO and 191 BCF of gas from the Niobrara alone. This is considered conservative as recovery factors as high as 17% have been seen in the sweet spots where a high degree of natural fracturing occurs, for example at the Buck Peak Field. A 12% recovery factor was used in the assessment as a high estimate.

This resource potential of the Entek acreage is significant and supported by the 18 analogous fields in the area which are used for estimating recoverable volumes. The demonstration of production within the Entek acreage and from the adjacent Sierra Madre Field (operated by Anadarko) is very encouraging for
the future of the Entek project in the Sand Wash Basin.

The Company is now planning its 2011 Exploration and Development Plan, integrating the knowledge from this year’s work program and drilling success. The priority in 2011 is to further de-risk the Niobrara play, and to convert a significant amount of the Contingent Resource potential of the acreage into reserves and additional production.

Independent Reserves Report: Focus Ranch 12-1
Independent Reserves Reports have been commissioned for three wells:
• Focus Ranch 12-1: which flow tested 240 BOPD and 2.75 MMCFD.
• Butter Lake 32-10: which has an average Initial Production (IP) of 25 BOPD, and
• Battle Mountain 14-15A: which has an average IP of 12 BOPD.
The Focus Ranch 12-1 Reserves Report is the first to be completed, with the other two still underway. The reports are being provided by Chris Hansen P.E. The following is extracted from the executive overview of the Focus Ranch 12-1 Reserves Report. An estimation of proved, probable, and possible recoverable oil and gas reserves has been conducted based on the analysis for the Focus Ranch 12-1 well, located in northern Routt County, within the Sand Wash Basin of northwestern Colorado.

The productive intervals in the well include the Frontier Sandstone, Carlile Shale, calcitic and siliceous benches of the Niobrara, and unique to the area, the presence of highly fractured, intrusive igneous sills within the Niobrara. These sills contribute significantly to the performance of the subject well as demonstrated by flow tests.

The results of this evaluation show that the Focus Ranch 12-1 wellbore has Proved Reserves (PDNP) of 233,699 STBO of oil and condensate, and 2.115 BCF of natural gas, along with Probable Reserves of 14,439 STBO and 0.025 BCF.

Total Proved Reserves (P1) attributable to the FR 12-1, including eight direct offsets (PUD) to the FR 12-1, are 2,103,290 STBO and 19.04 BCF. Total Probable Reserves (P2) reported herein are
the Probable Reserves in the FR 12-1 wellbore and the first row offsets, plus the Proved plus Probable Reserves of the FR 12-1 assigned to the second row offsets (16 wells), which totals 4,100,149 STBO and 34.47 BCF. Possible reserves were not estimated for the FR 12-1 wellbore, however, Possible Reserves are
reported herein as the Proved plus Probable Reserves of the FR 12-1 wellbore assigned to third row offsets (24 wells). Total Possible (P3) reserves are 5,995,302 STBO and 51.364 BCF. Total P1, P2 and P3 reserve categories are therefore 12.158 MMSTBO and 104.867 BCF.

The 12-1 well demonstrates the potential of vertical Niobrara completions in the Company’s acreage. The reserves associated with the 12-1 well have increased the Company’s oil reserves significantly and this increase will continue as other wells are evaluated and as the 2011 Exploration and Development plan
gets underway.

16 November 2010

ENTEK SUCCESSFULLY STARTS ‘NIOBRARA’ OIL & GAS PRODUCTION
Entek Energy Limited (Entek or the Company) wishes to provide the following update on its recent production and exploitation work on relevant wells within its Green River Basin acreage.

Butter Lake 32-10 (32-10) - Entek is pleased to announce that the successful acidizing and perforating operations on the 32-10 well have resulted in early flow of approximately 25 BOPD of 44 degree API oil and 30 MCFD of gas and there remains an expectation that as the well continues to clean-up these rates may increase. The well is now officially in production operations.

The Company believes that it has now resolved the technical issues that inhibited the flow of hydrocarbons (both oil and gas) from the 32-10 well. The lessons learned will be used to optimise next season’s Exploration and Development Plan. Following the improved flow of hydrocarbons from the 32-10 well, additional zones may yet be targeted to further increase the rate of production. Currently only 70 feet has been perforated, out of a total of 370 feet of potentially productive hydrocarbon zones in the Niobrara Formation (Niobrara) identified from log
interpretation.

Battle Mountain 14-15A (14-15) - The Company is pleased to announce that successful acidizing operations on the 14-15 well have resulted in early flow of approximately 12 BOPD of between 34 and 39 degree API oil. A gas rate has yet to be measured. It is believed that this well bore is still significantly damaged and that the current flow rate is not representative of the well’s full potential, which was evidenced by the strong oil and gas indications while drilling. The well is on production and will continue to be monitored with the results being used to optimize next season’s Exploration and Development Plan.

Robidoux 13-15T (13-15) – During recent operations on the 13-15 well, an additional 35 barrels of high quality Niobrara sourced oil was returned bringing the total recovered from the 13-15 well during operations this season to over 50 barrels of oil. The 44 degree API oil is essentially the same as that recovered from the 32-10 well. The Niobrara section of this well is open hole (uncased). Poor hole conditions, related to last years drilling operations, have resulted in the well being shut in.

Based on the oil and gas flow rates from the 32-10 and 14-15 wells and the recovery of oil from the 13-15 well, supported by the recent petrophysical interpretation analysed as part of the resource assessment, the 13-15 well is believed to have the potential to be the most oil-productive well drilled to date on the acreage outside of the Focus Ranch Unit. Therefore the decision has been made not to continue with the perforating program in the shallow section of the well (shallow oil and gas potential is described below), but to preserve the existing shallow part of the well bore to enable a sidetrack to re-drill the Niobrara section next season.

Shallow Oil and Gas Potential
The 13-15 well has hydrocarbon indications from petrophysical and mud logs in the Deep Creek and Morapas Sandstones. The adjacent CF&I well produces oil and gas from the Deep Creek Sandstone.
Numerous additional wells on the Slater Dome structure have highlighted its shallow potential (both oil and gas). The shallow oil and gas potential of the Deep Creek, Shannon and Morapas sandstones will be evaluated, including further detailed well log interpretation and mapping over the Slater Dome structure
to determine potential recoverable reserves and the best well locations for production testing. Results will be incorporated into the planning of next season’s Exploration and Development Plan.

The Savery Creek Field which is located adjacent to Entek’s acreage, has recovered 7.2 BCF of gas. The Taylor 1 well within the Savery Creek Field had an initial production rate of 3.5 MMCFD and recovered 3.5 BCF of gas from the Deep Creek Sandstone.
The Sierra Madre Field which is adjacent to Entek’s acreage, is operated by Anadarko and is an analogue to Entek’s Slater Dome Field. The Sierra Madre Field shallow conventional reservoirs have, to date, produced 1.5 MMBO and 4.5 BCFG, mainly from the Shannon Sandstone as well as from the Niobrara Formation.

Independent Contingent Resource Assessment
In parallel with the field activities and results described above, Entek has commissioned an Independent Contingent Resource Assessment of the Company’s Green River Basin acreage, focused on the “Continuous Oil Plays” (as defined by the USGS) in the Niobrara, Mancos and Carlile Formations. The assessment is nearing completion and results will be released after internal review and within two weeks. These promising initial results from the Butter Lake 32-10 and Battle Mountain 14-15A wells, which
demonstrate oil deliverability from the Niobrara, have significantly de-risked the play and the anticipated
estimates of Contingent Resource.

Previously this assessment was referred to as a Prospective Resource Assessment. However, the independent consultants believe the resource is correctly classified as a Contingent Resource because of the Reserves associated with the Focus Ranch 12-1, Butter Lake 32-10 (32-10), and Battle Mountain 14-5 wells, together with the production status of the 32-10 well and the adjacent Sierra Madre field. (The definition of reserves and resources will be included in the final report.)

Vertical vs Horizontal Well Performance
In response to numerous queries from shareholders and analysts the Company has included below a brief description of the industry’s understanding of the well performance of vertical wells and horizontal wells from the same formation.
Vertical un-stimulated wells in the Niobrara show a range of Initial Production (IP) rates from 10 BOPD to 500 BOPD and 20 MCFD to 350 MCFD. The range represents matrix dominated production (low IP) and production from zones with a high degree of natural fracturing. Targeting the zones with a high degree of
natural fracturing is the key to finding the ‘Sweet Spots’. Vertical wells generally react well to fracture stimulation where commonly a vertical well with 30 BOPD will result in an enhanced IP of at least 150 BOPD after stimulation. Horizontal wells with fracture stimulation have shown a range of IPs from 250 BOPD to 1500 BOPD. Two good examples of vertical vs horizontal well performance from the Niobrara are;

• a comparison of the vertical un-stimulated well which had IP of 47 BOPD and 23 MCFD of gas located near EOGs Jake ‘horizontal’ well which had an IP of 1558 BOPD and 339 MCFD of gas and
• from the Silo Field where a vertical well IP of 22 BOPD (with no gas reported) is associated with a horizontal well with an IP of 395 BOPD and 172 MCFD of gas.

The Company’s 2011 Exploration and Development Plan will target sweet spots with vertical unstimulated wells, with the objective of achieving IPs of over 100 BOPD. Vertical wells will be evaluated for fracture stimulation based on initial results. Horizontal wells will be planned from the vertical well
locations.

Our newest partner Entek has been drilling both on Slater Dome and the Focus Ranch. Here is their latest summary of Niobrara results. More to come, but for once it does look encouraging.


BUTTER LAKE 32-10 & NIOBRARA CONTINUOUS OIL PLAY UPDATE
Entek Energy Limited (“Entek” or the “Company”) advises that the Butter Lake 32-10 well (“32-10”)
has flowed hydrocarbons during initial cleanup. Further details are set out below.

Butter Lake 32-10 (32-10) Update
• The well has been flowed for initial cleanup, and is now shut in as the rig moves off location. Since
being shut in, the well has shown further indications of influx, with increases in wellbore fluid level
and well head pressures.
• Further cleanup of the well is likely to be required before a stabilized flow can be determined.
Testing and analysis will continue over at least the next two weeks.
• Entek is cautiously optimistic with the results of the 32-10 well to date and is continuing its testing
and analysis program.
Niobrara Oil Resource Play Update
The Butter Lake 32-10 well represents the fifth well in Entek’s Niobrara Continuous Oil Play, all of which have
encountered hydrocarbons. All five wells are being reviewed to optimize completions to maximize
production potential.
Although the Niobrara Formation has been producing from vertical wells for decades it is commanding
industry attention of large oil and gas companies as a result of significant recent production outcomes and is
currently one of the most sought after and prospective oil resource plays.

Entek engaged the services of Dr Thomas Ahlbrandt* to evaluate the prospectivity of its Niobrara
Continuous Oil Play within its portfolio. The following are comments from his report.


Three continuous Upper Cretaceous oil resource plays (Niobrara, Mancos and Carlile (Basal
Niobrara) exist on Entek acreage and are productive in the region.


The Niobrara is thick, 900-1,800 feet and has a higher detrital composition relative to the DJ Basin —
good for enhancing brittleness (fracability). The shales are fractured in response to their tectonic
setting related to regional shear zones and extension.


The recent U. S. Geological Survey (USGS) assessment of the recoverable oil from the Niobrara
Continuous Oil Play, where Entek is focused, is about 2.5 times that of the Niobrara Continuous Oil
Play in the DJ Basin where there is the current industry focus.


Vertical testing and additional rock parameters are needed prior to attempting a horizontal well
which will most likely be in the Niobrara. Entek now has five key wells across its acreage to
undertake this work.

Page 2 of 4

The resource potential of the Niobrara Continuous Oil Play has been assessed by the USGS to have
more potential than the Niobrara oil resource play in the DJ Basin.
Entek is conducting a prospective resource study across its Niobrara Continuous Oil Play acreage utilizing the
five key wells described above and adjacent analogue wells from Anadarko’s Sierra Madre Field which has
been in production since the early 1990’s.
* Dr. Thomas S. Ahlbrandt – Career Summary
Dr. Ahlbrandt is a globally recognized petroleum geologist with over forty years of experience in oil and gas
exploration, research and assessment. He has over twenty years of experience with major and independent
oil companies and another twenty years of service with the U.S. Geological Survey (USGS). In industry he has
served in many capacities including CEO and Vice President of Exploration and Chief Geologist at companies,
and has discovered petroleum in four basins both in the U.S. and internationally at previous positions. At the
USGS he managed geoscience groups ranging to 350 employees and from 1987-2006 held senior energy
management positions in the USGS both at their headquarters in Reston, Virgina from 1987-1991 and from
1991-2006 at their regional office in Denver, CO. He is an internationally recognized expert on petroleum
focused in the Middle East, North Africa, Alaska and the Rocky Mountain region as demonstrated by his 235
publications. His global experience includes major organizations including currently serving as a Vice
Chairman of a United Nations Committee (Ad Hoc Group of Experts on Reserve and Resource Terminology),
AAPG, and the USGS where he was the USGS World Energy Project Chief assessing the oil and gas potential
of the world. This major work was published both by the USGS and as Memoir 86 of AAPG (senior author).
He has presented many papers to organizations including OPEC, IEA, EIA, and AAPG and many media outlets.
He has numerous awards from AAPG, RMAG, USGS and the University of Wyoming.

Page 3 of 4
BUTTER LAKE FEDERAL 32-10
The well targeted the Niobrara Formation and Frontier Formation within the Focus Ranch Unit.
The Total Depth (TD) was 8,830’ within the Frontier Formation, which has tested gas and liquid hydrocarbons
from the Focus Ranch 12-1 well.
The well targeted a closed structure bounded by a fault to the north with structural reversal at shallow levels
including the Deep Creek Sand. The Mancos Shale also exhibits structural closure that would create
potential hydrocarbon traps in the Shannon Sand and Marapos Sand (that are units within the Mancos
Shale). The deepest reservoir that was penetrated within structural closure was the Frontier Formation.
Within the Niobrara Formation primary target there are three brittle benches (or ‘units’) that act as
continuous hydrocarbon reservoirs when fractured. Fracturing of these benches is expected to occur
associated with faults, igneous sill intrusions and the structural deformation at this location.
The average production rates for Niobrara wells throughout the Sand Wash Basin where Entek’s acreage is
located are 101 BOPD and 165 MCFD. Estimated Ultimate Recovery (EUR) for those averages are 260,000
BO and 1.1 BCF per well. Initial production rates have been as high as 500 BOPD from vertical wells adjacent
to Entek’s acreage. The Focus Ranch 12-1 southeast of this location had combined initial rates of 2.75
MMCFD and 240 BOPD. Independent reserves estimate associated with the 12-1 well range from 2.6*
MMBO to 3.2** MMBO of condensate and oil and 7.6* BCF to 20** BCF of gas.
* Based on a report by American Energy Advisors (Feb 2009). The report
assumes 12 wells will be required to produce the reserves.
** Based on a report by APEX Petroleum Engineers (Oct 2008) and assumes
an estimated GOR of 6250 from tests performed at the Focus Ranch 12-1
well. The report assumes reserves associated with one 320 acre section.
GLOSSARY
A$ Australian dollar
BCF Billion cubic feet (of natural gas)
BOPD Barrels of oil per day
MCFD Cubic feet of gas per day x 1,000
MMCFD Cubic feet of gas per day x 1,000,000
MMBO Barrels of oil x 1,000,000
US$ United States dollars
Page 4 of 4
FOR FURTHER INFORMATION
RUSSELL BRIMAGE - CHIEF EXECUTIVE OFFICER
+ 61 8 9213 4388 INFO@ENTEKENERGY.COM.AU
Competent Person’s Statement:
Information in this report that relates to Hydrocarbon Reserves and or Resources is based on information compiled by
Mr Russell Brimage, Chief Executive Officer of Entek Energy Limited who has consented to the inclusion of that
information in the form and context in which it appears. Mr Brimage has over 30 years experience in the application of
engineering to the petroleum industry in oil and gas exploration and production, both in Australia and internationally,
as either an employee or consultant to oil companies operating in the upstream petroleum industry. Mr Brimage
directs the Company’s operations with the help of various professional consultants, appropriately qualified and
experienced in their respective fields within the upstream petroleum industry. He is also an Associate Member of the
Society of Petroleum Engineers.

Hello,
I’m french and I have 40.000 Dover Pet since 2004. Is there any chance to get any money with class action. If I understand, there is no market anymore for this share ?
It is not very easy to get information when you leave in France and when you have an account in french bank.
Thank you for your answer.
Daniel

exactly wes

Frankly, I don't think it ever will......the CEO is not a very forthcoming character IMHO.....meaning he could care less what happens. Dover Petroleum owes him money advanced plus interest and it will all end up being his if he stalls long enough.

any news ?

no trading since a long time.

But, What would be the value here, when this resumes trading ?


TIA

and the saga continues...

New Filing for our sister company: NFEI Re: Involuntary Chapter 7

FORM 8-K
CURRENT REPORT

March 5, 2010:

NEW FRONTIER ENERGY, INC
1801 Broadway, Suite 920
Denver, CO 80202


Item 8.01 - Other Events

On March 5, 2010, a petition for involuntary Chapter 7 bankruptcy entitled In re New Frontier Energy, Inc. (Case No. 10-14517HRT) was filed against New Frontier Energy, Inc. (the “Company”) in the United States Bankruptcy Court, District of Colorado by five alleged creditors (the “Petitioners”). The Petitioners have alleged that they have debts that are not the subject of a bona fide dispute . The Petitioners are seeking liquidation and the appointment of a receiver.

The Company believes that certain of the Petitioners claims are without merit or are otherwise in dispute. The Company intends to aggressively contest the involuntary bankruptcy petition and pursue all available grounds for dismissal and to seek all available remedies against the Petitioners whose claims are subject to a bone fide dispute.


SIGNATURES


NEW FRONTIER ENERGY, INC.

Date: March 9, 2010 By: /s/ Samyak Veera
Samyak Veera, Chairman

If you have shares you don't want, let me know. I may be willing to buy from you, if you are willing to ask for stock certificates from your broker.

For all intent purposes it does not trade. We were left high and dry. Lesson learned, move on.

A little over a year ago I did. It was accomplished by asking for the stock certificates from your stock broker and transferring title to the shares through the transfer agent.

Clearly, it takes some time and trust between the parties, but it can be done.

You can't add, it no longer trades.

I still think that is some value here. However I don't think it will be realized for quite a while. It's a gamble especially with our sister company (NFEI) going through all of its changes. I'm still holding and might even add to my position.

Don't ever bet on this guy treating anyone fairly....

Have you heard anything about Dover Petroleum recently? I think whenever we come out of the recession there will be a need for NG.

I would have thought that if he had stated the Audit had already begun some time back, then it would have been in everyone's best interest to get it completed and over and done with. Still hanging on to a slim hope here it seems.

Don't think he is planning to complete until/unless we become viable again. NFEI has hunkered-down and is not drilling, until gas prices go up and I think we and they will not spend any money until that fact occurs.

Anyone heard how our CEO is getting along with our company Audit ??

NFEI 10K Released 5/28/09:

Slater Dome Field:

At February 28, 2009, there were no recoverable reserves from the Company’s wells in the Slater Dome Field due to the existing economic and operating, conditions, i.e. prices and costs as of February 28, 2009. The Company did not drill any wells during the fiscal year ended February 28, 2009. At February 29, 2008 our estimated proved reserves in the Slater Dome Field totaled 15,561 MCF of gas to our interest. The Company drilled eight wells in the Slater Dome Field during the fiscal year ended February 28, 2008 with no dry holes. At February 28, 2007, our estimated proved reserves in the Slater Dome Field totaled 12,114 MCF of gas to our interest. The Company did not drill any wells during the fiscal year ended February 28, 2007.

During the fiscal year ended February 28, 2009, the Slater Dome Field produced 229,629 MCF of gas, of which 38,939 MCF was used in operations and 190,690 MCF was sold.

We do not intend to drill any additional wells in the Slater Dome Field during the next fiscal year ending February 28, 2010.

Also in the 10k is this about the field:

The Slater Dome Field is the primary oil and gas property where most of our capital resources have been employed and we are substantially dependent upon this one property, which causes our risk to be concentrated.

Our plan of operation includes efforts to further develop the Slater Dome Field. If the development of this property is not successful, we will be forced to seek additional opportunities. Substantially all of our current capital investment has been spent on the development of the Slater Dome Field. If we are unable to further develop the Slater Dome Field, assuming we have sufficient capital resources, we will be forced to seek additional investments. Investigating and locating suitable properties for acquisition is expensive and time-consuming. Even if we are successful in identifying one or more additional properties for acquisition, there is no assurance that we can obtain such properties at reasonable prices or that we will have sufficient capital to finance the acquisitions. As a result of our dependence on a single property, we may be disproportionately exposed to the impact of delays or interruptions of production from these wells or increased expenses caused by significant governmental regulation, transportation capacity constraints, the availability and capacity of compression and gas processing facilities, curtailment of production or interruption of transportation of natural gas produced from the Slater Dome Field. Our substantial dependence on a single property for cash flow increases the risk of our future success.

We have incurred losses from operations and negative cash flow that is likely to continue until we can economically produce oil or natural gas.

We have a history of losses from operations and negative cash flow that is likely to continue until we economically produce oil or natural gas. A significant portion of our cash flow since inception has come from equity and debt investments. Unless we economically produce oil and gas in the future, these losses will continue. If we continue to experience losses from operations and negative cash flow as we have in the past, there can be no assurance that we will be able to continue operations as anticipated, if at all. Further, the price of our Common Stock may be adversely affected.

We will need to raise additional capital to continue operations, and we may not be able to raise capital on terms acceptable to us or at all.

The continued operation of our business will require an immediate capital infusion and we will need to seek additional capital, likely through debt or equity financings, to continue operations. The oil and natural gas industry is capital intensive. We have made and, subject to the receipt of financing, expect to continue to make substantial capital expenditures in our business and operations for the exploration for and development, production and acquisition of oil and natural gas reserves. To date, we have financed capital expenditures primarily with sales of our equity securities, debt financing and cash generated by operations. To accomplish our plan of operations, we will be required to seek additional financing. There can be no assurance as to the availability or terms of any additional financing.

Even if additional capital is needed, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. The failure to obtain additional financing could result in a curtailment of our operations, which in turn could lead to a possible loss of properties and a decline in our natural gas and oil reserves and may result in us having to cease operations.

22


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The Company’s Independent Auditors have issued a Going Concern opinion for our February 28, 2009 financial statements.

The independent auditor’s report accompanying the Company’s audited February 28, 2009 consolidated financial statements contain an explanatory paragraph expressing substantial doubt about the Company’s ability to continue as a going concern. The audited February 28, 2009 consolidated financial statements have been prepared “assuming that the Company will continue as a going concern,” which contemplates that the Company will realize its assets and satisfy its liabilities and commitments in the ordinary course of business. There can be no assurance that the Company will be able to generate sufficient positive cash flow from operations to address all of its cash flow needs, and to continue as a going concern. If the Company does not continue as a going concern, it will have to cease operations and you would likely lose all of your investment in the Company.

We have not obtained a reserve report of oil and gas reserves for the fiscal year ended February 28, 2009 and no assurance of the accuracy of the estimates of oil and gas reserves for the fiscal years ended February 29, 2008 and February 28, 2007.

At February 28, 2009, there were no recoverable reserves from the Company’s wells due to the existing economic and operating, conditions, i.e. prices and costs as of February 28, 2009. We obtained a report on the estimated reserves on our leases on the Slater Dome Field during the fiscal years ended February 29, 2008 and February 28, 2007. Reserve estimates are based upon various assumptions, including assumptions relating to oil and gas prices, drilling and operating expenses, production levels, capital expenditures, taxes and availability of funds. No one can measure underground accumulations of oil and natural gas in an exact way. As a result, estimated quantities of proved reserves, projections of future production rates and the timing of development expenditures may be incorrect. Any significant variance from these assumptions to actual figures could greatly affect our estimates of reserves, the economically recoverable quantities of oil and natural gas attributable to any particular group of properties, the classifications of reserves based on risk of recovery and estimates of the future net cash flows.

Further, the present value of future net cash flows from our proved reserves is not necessarily the same as the current market value of our estimated oil and natural gas reserves. Actual future net cash flows from our oil and natural gas properties also will be affected by factors such as:

• Actual prices we receive for oil and natural gas;

• The amount and timing of actual production;

• Supply of, and demand for, oil and natural gas; and

• Changes in governmental regulations or taxation.


The timing of both our production and our incurrence of expenses in connection with the development and production of oil and natural gas properties will affect the timing of actual future net cash flows from proved reserves and thus their actual present value. In addition, the 10% discount factor used when calculating discounted future net cash flows may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the oil and natural gas industry in general. Actual future production, oil and gas prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable oil and gas reserves will most likely vary from those estimates, and any significant variance could have a material adverse effect on our future results from operations.

23


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We cannot predict the future price of oil and natural gas and an extended decline in prices could hurt our profitability, financial condition and ability to grow.

Our revenues, profitability and liquidity, future rate of growth and carrying value of our oil and gas properties are heavily dependent upon prevailing prices for natural gas and oil, which can be extremely volatile and in recent years have been depressed by excess total domestic and imported supplies. Prices in the Rocky Mountain region of the Unites States, and in particular Colorado, have been more adversely affected by the market volatility than other regions of the country, due to insufficient pipeline capacity and the resulting excess supply. Prices also are affected by actions of federal, state and local agencies, the United States and foreign governments, international cartels, levels of consumer demand, weather conditions, and the price and availability of alternative fuels. In addition, sales of oil and natural gas are seasonal in nature, leading to substantial differences in cash flow at various times throughout the year. These external factors and the volatile nature of the energy markets make it difficult to estimate future prices of oil and natural gas. Any substantial or extended decline in the price of oil and/or natural gas would have a material adverse effect on our financial condition and results of operations.

Declining economic conditions could negatively impact our business.


Our operations are affected by local, national and worldwide economic conditions. The consequences of a potential or prolonged recession may include a lower level of economic activity and uncertainty regarding energy prices and the capital and commodity markets. A lower level of economic activity might result in a decline in energy consumption, which may adversely affect our revenues and future growth. Instability in the financial markets, as a result of recession or otherwise, also may affect the cost of capital and our ability to raise capital.

Unless we replace our oil and natural gas reserves, our reserves and production will decline, which would adversely affect our business, financial condition and results of operations.

Bottom-line it isn't pretty from either NFEI nor Sea Dragon perspectives.

Attached is a note from Sea Dragon posted 6/9/09 which highlights that they will not continue to drill the East Wadi concession:



SEA DRAGON ENERGY INC. - Letter to the Shareholders.

June 5, 2009-- Dear Shareholders: 2008 marked a year for major changes to the markets and the Oil Industry. With Oil prices coming down from over $140 to $35 per barrel and the chaos of the recessionary down-turn Sea Dragon had a successful year being able to go public and raise its required working capital for development of the exploration lease. Amidst the changing times, Sea Dragon:
·

successfully raised C$35 million from an Initial Public Offering and was listed on the on the Toronto Stock Exchange Ventures Market with the call sign "SDX"; commenced drilling the East Wadi Araba North Dahab prospect; and put together a board of directors with an excellent reputation and track record and cultivated a team of experienced consultants and staff.

While it was disappointing that we did not encounter hydro-carbons in sufficient quantity to be commercially viable, we did meet the commitments under the concession agreement in a timely manner and drilled two separate prospects. While we therefore believe that we have met the commitments on East Wadi Araba concession, the results of our testing program and the lack of any successful exploration drilling from the adjacent block leads us to believe that we should not continue to develop this concession area.

Looking forward
The economic landscape has changed dramatically from this time last year. The global economic crisis and the drop in oil and gas prices demand that we adopt a conservative strategy while at the same time create investment opportunities. Your Company has therefore decided to pursue a strategy of evaluating opportunities for direct ownership in producing or near to producing assets primarily in Egypt and the African continent. We believe that this strategy will take advantage of attractively priced properties that are now available due to the current market conditions and allow us to exploit the expertise and reputation of our board and management in this part of the world.

Financially, we are in a strong position. Since Sea Dragon has retained some of the proceeds from the IPO and, because we have no debt or significant spending commitments, we can patiently review the many opportunities available to us and take advantage of those that are most attractive and fit our strategy. We intend to grow our Company over time by building a solid foundation of earnings and reserves and then adding to them.

We believe that we can acquire producing oil properties so as to build our reserve base, provide cash flow and give Sea Dragon a stable base with which to continue its operations. Once this is in place the Company feels that it will be able to pursue potential upside development of those producing assets as well as looking to add to the portfolio of producing assets. While we have not closed an acquisition as of this date, we have or are in the midst of evaluating at least six serious proposals. From this we have concluded that attractive opportunities exist, and that financing for the right opportunity is available; the recent firming of the price of oil has encouraged financiers to once again look at carefully considered prospects.

We will be keen to share with you the upside potential of the deals we are currently negotiating very soon.
We thank you for you for your support and we thank the management and board of directors for their hard work this past year during very difficult market conditions.

For further information please contact:

David Thompson
President, CEO and Director

Thanks Wes, Doesn't look too promising here as you say, may have to just put it behind us. One puzzling thing is, that it is still stated within my brokerage account with a value attached to it at its last trading price of .027¢, that goes to make up a part of my trading account balance. Was wondering when do we have an opportunity to right it off as a tax loss ?? Anyhow, was liking the look of that Chemtura Corporation (CEMJQ.PK) you are following, seems to have some possible prospects going forward, may purchase a small position there.
Wish you well

Cheers
farside

Nope, I have 400,000 shares of this pig myself. Fortunately had sold close to 1 million shares a couple weeks prior to trading stop because another stock caught my eye. Other wise I would really have bit the dust on this one. The other stock did well so have written off this POS in my mind long ago.

We can't dwell on the losers. Fortunately, the last 4 weeks has seen my total account up 70% so have been doing some liquidating and getting more cash. These runs are very suspect IMHO.

Do I hear any bids on 100,000 shares ??

If we want to trade among ourselves, you can always ask for stock certificates and transfer ownership through the transfer agent.

no clue

OKay here's a new question, just wondering, how long do we wait with this derelict DVPC stock sitting in our brokerage accounts, Until we can consider writing it off as a tax loss ?? when it seems there isn't even a glimmer of hope on the horozon of ever selling again ?? would like to know if anyone may have some insight here. Thankyou.

lol



that was answered last year

Westeff He may have Total Control, But does he have a concience? at least a working order concience that is ?? I wonder.

Westeff, what exactly does Salna have total control over ??

I wonder how the "financials" are coming along. Must be just about done right? Sarcasm.

He has no incentive to do anything because he has total control now.