Bakken Amidon

Bakken – Amidon Oil Project BAKKEN – AMIDON OIL PROJECT

Business Plan 2012

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BAKKEN – AMIDON OIL PROJECT

Business Plan

Prepared By TerraGreen Energy Resources, LLC (“TGER”)

© Copyright 2012, TerraGreen Energy Resources, LLC, All rights reserved

By accepting a copy of this report, the recipient agrees not to reproduce it in whole or in part, not to use it for any other purpose than reading, and not to disclose any of its contents to third parties without written permission of TERRAGREEN ENERGY RESOURCES, LLC. The report is furnished for information purposes only. No representation or warranty is made by TERRAGREEN ENERGY RESOURCES, LLC, or any other entity as to the accuracy or completeness of the information, and nothing contained in the report is, or shall be, relied on as a promise or representation of the future.

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Table of Contents 1.0 Executive Summary

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2.0 Project Overview and Key Points

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3.0 Keys to Success

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4.0 Reservoir Properties

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5.0 Upside Potential

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6.0 Oil Marketing

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7.0 Financial Data

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8.0 Insurance Plan

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9.0 Management Team

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10.0 Confidentiality Clause

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Key Terms        

bbl – barrel of oil bbls – barrels of oil bopd – barrels of oil per day cp – centipoises md –milladarcie OOIP – original oil in place psi – per square inch WTI – West Texas Intermediate

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Executive Summary TerraGreen Energy Resources, LLC (TGER) will enter into a Joint Venture with Lazer Petroleum, LLC (LZP) and maintain a ____% interest in the reserves of___________________________. The reservers are located within 3,170 acres 2 miles due west of Amidon, North Dakota.

The joint venture involves the development plan of drilling and hydrojetting 6 wells with 3 4

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zones in each well. The total capital investment for this project is $29 million USD. The deal structure proposed is for the Equity Partner to receive % of the % and TGER will receive % of the % of the Proved Reserves. The reserves above the Proved schedule will be split % Equity partner and % TGER. An investment of $ is expected to generate a ROI of % in the first x years, and a capital gain of % if TGER should become a publicly traded company.

Return on Investment Per Well Red River Capital Investment Red River Oil Reserves Oil Price Net Interest 10% BFIT Cash 10% BFIT Profit/Investment 10% Payout Return on Investment

$ 4,500,000 711,500 STBO $ 92/BBl 82.5% $ 28,100,000 6.3 4.7 Mo +100%

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Project Overview and Key Points Geology The age of the Bakken Formation straddles the Devonian/Mississippian boundary and it was deposited approximately 360 million years ago. It is contained in the Williston Basin where stratigrapher Lawrence Sloss first proposed his cratonic sequence concept.

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The thickest portion of the Bakken (46m) is in north-western North Dakota and it thins evenly southeastwards toward the margins of the Williston Basin. The upper and lower members consist of hard, siliceous, black organic-rich shales. These form effective seals for the middle member, which consists of five highly variable lithologies, from several argillaceous siltstones to fine-grained sandstone and limestone, all with low primary permeability (0.04 mD average) and porosity (5% average). Directly below the Bakken Shale formation, there is a 270-foot thick formation known as the Three ForksSanish Formation. For some time, drillers believed that the Three Forks-Sanish Formation only contained oil that seeped out of the Bakken Shale. However, recent drilling results suggest that the Three Forks-Sanish Formation is a separate oil-bearing formation that could contain hydrocarbon resources rivaling those of the Bakken Shale.Depositionally, the Three Forks Formation consists of shallow marine to terrestrial sediments that transition from highly oxidising conditions to the anoxic conditions of the lower Bakken. The middle Bakken sedimentation is associated with the drop in sea level and influx of sedimentary material into the overlying Lodgepole Formation.

History Bakken Formation completion and stimulation has come a long way since its first oil production in 1955. The upper Bakken shale member was first targeted for production at the Elkhorn Ranch Field in 1976. Vertical wells were fracture-stimulated with sand and oil. The first horizontal wells were completed in 1987, however the play ended in the 1990s because of low oil prices. The real breakthrough came in 2000 when Richard Findley approached Lyco Energy Corporation to drill horizontal wells in Montana’s Elm Coulee Field targeting the middle Bakken member. The drilled program was a huge success with ultimate recoveries approaching 750,000 barrels of oil.

In 2005, EOG Resources utilised horizontal drilling combined with hydraulic fracturing to recover significant oil from the middle Bakken interval at the Ross Field in North Dakota. At that time the average rig count was 25 and production under 100,000 bpd. EOG quickly expanded into adjacent areas utilising multistage fracturing of horizontal wells and obtained rates exceeding 500 bpd per well.

Completion technology has kept improving and in 2011, Baker Hughes completed a successful 40stage stimulation (the largest to date) using a fracturing sleeve/packer completion system. Now the average rig count is 200 and production is approaching 500,000 bpd.

The North Dakota wells are completed on 640 acre (2.6 km 2) spacing for 5,000 ft (1,524m) horizontal wellbores to 1,280 acre (5.2 km2) spacing for 10,000 ft (3,048m) horizontal wellbores. Most wells are oriented in a northsouth or a north-west to south-east direction to take advantage of the induced fracture

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propagation. A cemented liner is required from the surface to the base of the curve to horizontal, to ensure the Bakken Formation is isolated from the overlying formations.

From this point a number of different completion methods have been employed. These methods range from a cemented liner throughout the horizontal well bore to openhole completions and combinations of both. The cemented liner completions utilise a ‘plug and perf’ stimulation that require time to trip perforation guns, but allow specific frac placement in the horizontal wellbore. The openhole completions only allow for single-stage fracturing which provide little control over fracture initiation and propagation. To gain more control in the fraccing process, uncemented, preperforated liners can be used with or without positive annular isolation. The use of swell packers set at various intervals along uncemented, preperforated liners allows for multi-stage fraccing. It is the most commonly used completion method allowing a high degree of fracture control and success in stimulation long-term production.

A recent report prepared for the U.S. Department of Energy by the Energy and Environmental Research Center (EERC) at the University of North Dakota in Grand Forks, North Dakota, had this to say about the Bakken: “It is expected that the play will continue to expand to the south-west (into South Dakota),

newly develop in the north-eastern and north-western corners of the basin in North Dakota, and fully develop in between… Currently, only about 15% of the play has been drilled, and recovery rates are less than 5%, providing a significant future of wells to be drilled and untouched hydrocarbons to be pursued through improved stimulation practices or enhanced oil recovery.”

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This potential has not been missed by companies operating in the area. At the last count there were at least 82 operators, and new ones are continually added, including Norwegian giant, Statoil, which entered the region in 2011. One of the most aggressive is the play’s largest lease holder and Bakken oil producer, Continental Resources. Their spokesman, Brian Engel, states, “The field could have up to 24 billion barrels of technically recoverable oil… the [2008] USGS estimate was fair and reasonable given the data available at the time of its report. Like Continental, the USGS utilised existing producing Bakken wells to estimate ultimate oil recoveries per well and the effective drainage area. The difference between the estimates is that recoveries on a per-well basis have increased substantially since June 2007. Since that time, approximately 1,680 new horizontal producing Bakken wells have been drilled, and these wells have been completed using almost exclusively single leg horizontal and multi-staged fracture stimulation technology.”

The USGS has certainly recognised this fact, saying that, “the new scientific information presented to us from technical experts clearly warrants a new resource assessment of the Bakken”. To this end, a new assessment got underway in October 2011 and should be out in September 2013.

Keys to Success The success of the Amidon Oil Field Project will be the result of:    

Enhanced stimulation of existing perforations with hydrojetting Identify productive zones that have been bypassed Improve waterflood sweep efficiency Extensive Industry experience from seasoned US professionals

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Reservoir Properties Amidon prospect is currently interpreted as a structural nose dipping to the N-NE approximately two to three miles west of the town of Amidon, North Dakota, the seat of Slope County. The extention of the Amidon structure south of the prospect is probable, but can only be confirmed with additional seismic.

Several wells were drilled on the Amidon structure, the most successful of which was the Holmevig # 1-21, located in the SW SW Section 21, Township 135 North, Range 101 West, on the west flank of the Amidon structure. This well produced from both the Ordivician Red River (11,000-11,010) and the Devonian Nisku (9,800-9,826) formations in the 70’s.

Cumulative production from the Red River was 15,064 STBO + 93623 Bbl Water with unreported gas.

After the well watered out, it was plugged back to the Nisku-Birdbear and produced an additional 4,611 STBO + 2774 Bbl Water, again with no reported gas.

The Red River formation underlies all of North Dakota and is a freshwater aquifer in Northern

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Wyoming and Southern Montana but becomes progressively more saline as it flows across North Dakota. It emerges at the salt springs along the banks of the Red River of the North in the Canadian Province of Manitoba. This formation is permeable and a prolific oil producer on structures.

The Nisku, or, as it’s known in North Dakota, the Birdbear, formation, produces from several benches in western north Dakota, and can produce from a closed structure, a nose with a stratigraphic pinchout updip, and stratigraphic traps. Nisku porosity at Amidon is lower on average than in the main producing areas of Beaver Creek/Centennial 50 miles to the NE, but the presence of a known structure increases the net pay and reserves. Accordingly, Amidon is expected to have a higher reserve/rate ratio than other Nisku Fields. It is unknown whether hydrodynamics (moving water) contribute to tilted oil water contacts in the Nisku/Birdbear formation.

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BAKKEN – AMIDON OIL PROJECT Amidon Acreage Position: Township 135 North – Range 101 West

Section 16 Section 20 Section 21 W ½ Section 22

Section 28 Section 29 Section 32 Section 33 Total Net Acres Leased:

Undivided 50% underlying 640 acres leased Undivided 50% underlying 480 acres leased Leased, unleased acreage Joins or goes Non-Consent (NC) Undivided 50% underlying 320 acres leased, abandoned Undivided 50% underlying 160 acres pending which quiet titled, Undivided 50% underlying the same 160 acres, pending, the remaining 160 acres unleased Leased in entirety Leased in entirety 600 acres leased, 40 acres pending Pending 3,170

Petroleum Reservoir Types Red River production is primarily due to water drive, and although there may be some cases where water influx cannot keep up with production, a solution gas expansion makes a contribution to pressure maintenance. Red River wells typically experience a rising water-oil ratio (WOR) throughout their lives, and may have the same bottom hole pressure when plugged and abandoned as when they were drilled.

Nisku production can be due to either water drive, solution gas expansion or a combination of the two depending on formation permeability and the degree of permeability barriers between the oil and watersaturated zones of the Nisku formation. Producing rates are sustained longer under water drive than solution gas, but water must be lifted along with the oil and disposal into injection wells adds to operating costs.

World Oil Prices In addition to improved recovery from these reservoirs, global oil prices are continuing to increase with time. World oil production has reached about 85 to 86 million bbls per day. This has remained relatively flat for the past 7 years. This is the first time in 25 years when world oil production has not increased over a seven year period. This may indicate that world oil production may have reached its maximum (http//www.EIA.gov). Matt Simmons, noted Investment Banker from Houston pointed this out all the way back in 2005. Since that time oil production has not significantly increased. World oil prices have been as high as $140 per bbl (WTI) in 2008, then the global economic meltdown. Presently in the global recession oil prices have remained high while world economies have declines. This demonstrates the high demand and growing dependency on oil around the world. As the world economics

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start to recover the price for oil should escalate to above $100 per bbl and as high as $125 per bbl. There does not appear to be much downward pressure on oil prices and upward pressure appears to be increasing. Matt Simmons was quoted as speculating that oil prices could climb to as high as $300 per bbl. Although this seems too high, remember that it was only about 10 years ago that oil prices were only about $25 per bbl.

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General Comments concerning a coming shortage of oil

Global Net Exports Summary or the Noose tightens: If we extrapolate the 2005 to 2010 rate of increase in consumption by the exporting countries out to 2020 and if we extrapolate Chindia's 2005 to 2010 rate of increase in net imports out to 2020, and if we assume a slight production decline among the 2005 top 33 net exporting countries (1.0%/year from 2010 to 2020), then for every ten barrels of oil that non-Chindia countries (net) imported in 2005, they would have to make do with four barrels in 2020.

According to Bryan Walsh, Time Magazine, March 2012 “The decline of major conventional oil fields-coupled with the rapidly rising demand from countries like China and India-means the spare production capacity that once cushioned prices is melting away, ushering in an era of volatile market swings.”

Bruce Stanley, Associated Press, November 2010 ”Global supplies of crude oil will peak as early as 2010 and then start to decline, ushering in an era of soaring energy prices and economic upheaval – or so said an international group of petroleum specialists meeting Friday”.

Below are a number of companies and government agencies which believe oil production is at or near its peak.

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Statistics

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Marketing Crude Transportation & Sales - Trucks There are multiple purchasers and sales points Amidon crude that will likely be hauled off by truck.

The API oil gravity of Red River crude is expected to be around 42 and that of the Nisku around 40 API. The nearest crude pipeline terminal accessible to all-weather trucking would be the Painted Canyon terminal near the Fryburg railroad siding approximately 5 miles west of Belfield and 1 mile south of Interstate 94. This terminal accesses Tesoro’s common carrier pipeline to the Tesoro refinery in Mandan, or the Little Missouri Pipeline/Butte Pipeline system which delivers crude south to Guernsey, Wyoming and thence to refineries in the east. Trucking distance from Amidon to Painted Canyon is 45 miles.

The Eland oil terminal four miles west of Dickinson loads rail cars which then haul to eastern and Gulf Coast refineries. Trucking distance from Amidon to Eland is 56 miles.

The Rhame oil terminal, immediately south of the town of Rhame in Bowman County, ND feeds either to rail cars or into the Plains Pipeline system to Baker, Montana and ultimately to eastern refineries via Butte Pipeline through Guernsey, Wyoming. Trucking distance from Amidon to Rhame is 36 miles.

Crude Transportation & Sales - Pipeline

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If a feeder pipeline were to be built from Amidon to the Butte Pipeline, it would likely follow this route: From, north along the east side of 142nd Avenue SW, northwest along the northeast side of the Burning Coal Vein Road, north and northwest along the east and northeast side of East River Road to a connection with the Little Missouri Pipeline near the junction of East River Road and the Tracy Mountain Road, located 10 air miles south of Medora, and 23 air miles east of Golva, North Dakota.

This route is approximately 23 miles long. At $50/foot, the cost of the pipeline would be 6.1 million dollars. With a net transportation savings of $2.50/bbl, production would have to average 2230 BOPD to pay out the cost of the pipeline in three years. A $250,000 crossing of the Little Missouri River is avoided with this route, and the pipeline remains unregulated, meaning annual inspections are not required.

An alternative route extends from the intersection of 65 th Street SW and 142nd Avenue SW in Slope County cross country to a crossing of the little Missouri River one mile downstream of the Deep Creek confluence, then cross-country to the intersection of Pipeline Road and the Little Missouri Pipeline in southwest Golden Valley county. This route is 20.5 miles long and with a river crossing would cost 5.7 million dollars, but be a regulated pipeline due to the river crossing. Production of 2100 BOPD would payout a pipeline cost in three years.

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Production Operations Wells completed in these formations generally flow for a few weeks or months and then are put on artificial lift, usually involving a downhole pump, a rod string and surface pumping unit. In some crooked-hole or high scaling environments a downhole pump operated by a surface hydraulic power oil pump may be used. Hydraulic pumping has the advantage of being able to displace downhole pump to surface hydraulically for replacement without well servicing trucks (pulling units), which are, and are expected to be, in short supply in the Williston Basin.

Electricity is available in this area and long term production equipment will almost certainly be electrified, saving on both maintenance costs and increasing the reliability of surface production operations.

Both Red River and Nisku natural gas are “sweet� and can be burned in treaters and engines, but the likelihood of low long-term natural gas prices would make a commercial gas pipeline connection currently uneconomic although there may be potential for residue gas sales to the town of Amidon two miles to the west. On-site electricity generation is growing in the area, and the proximity of power lines in Amidon may allow a co-generation market to develop in the future.

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Economics Amidon Red River Well economics are based on comparisons to other Red River production from small geologic structures in southwest North Dakota, primarily in Bowman, Slope, and Stark counties – the producing areas closest to Amidon. Variations of production relative to oil column, porosity, permeability and areal extent were all factored in to create the Amidon Red River model. The very best Red River production in this area, which occurs high up on the Cedar Creek Anticline, was not used as an Amidon analogy as the extreme one-of-a kind high oil column in that geologic structure is not representative of how the smaller Amidon structure will perform. The Amidon Red River Reserves were calculated using volumetrics and the producing rate was estimated by the analogous production in the fields already mentioned. The per-well economics of a typical Red River completion are summarized below:

Garry's Numbers Management Team Formed in 2008, TERRAGREEN ENERGY RESOURCES, LLC (“TGER”) is an integrated and environmentally conscious energy management company incorporated on May 5, 2009, and headquartered in Greenwood Village, Colorado. The company is registered in the state of Colorado under the EIN: 20-091261923.

TERRAGREEN ENERGY RESOURCES, LLC is classified as a Limited Liability Corporation.

The company currently holds all necessary licenses to conduct business in the United States, China and has approval processes pending for operations on a global basis.

TGER focuses its services on the domestic and international upstream and midstream segments of the oil and gas industry to deliver a high-quality acquisition program supplemented with integrated financial, operational, and technical management of acquired assets. The TGER team combines long experience in the industry with educational and professional credentials in engineering, technology, finance, accounting, business, and economics.

TGER offers management and staff to execute operations very efficiently with proven methods. State-of the art exploration technology combined with the latest drilling, well completion, production, and recovery technology is standard practice. This is the ordinary, day-to-day job of operations management and it must be executed flawlessly with disciplined cost management and a laser-like focus on operational excellence to increase reserves, production rates, and profits.

TERRAGREEN ENERGY RESOURCES, LLC is primarily involved in the following business areas in China: Location, acquisition, development and/or completion of oil and gas, and coal properties.

Purchase and Resale of oil and gas industry-related products and services 20

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Recently, TERRAGREEN ENERGY RESOURCES, LLC has been involved with several other minor projects in central Wyoming, North Dakota and in China.

Currently the company has 11 full-time employees, labor for various Projects has been arranged to be contracted as needed.

TerraGreen Energy Resources, LLC is structured and qualified to succeed in any environment with two complementary components to its management team: The first component is an experienced, efficient acquisition and business-development team that can move quickly, efficiently, and decisively to take advantage of changing financial, political, regulatory, and operational conditions. In the current environment, opportunities will arise quickly with many different characteristics and forms for investment and, in some cases, from unexpected quarters and sources. TerraGreen’s team has the experience and expertise to adapt to changing conditions and new opportunities and is nimble enough to pounce on these opportunities as soon as they become available and imaginative enough to recognize unusual opportunities and structure focused investment in creative ways.

The second component TerraGreen offers is management and staff to execute operations very efficiently with the latest drilling, well completion, production, and recovery technology. This is the ordinary, day-to-day job of operations management and it must be executed flawlessly with disciplined cost management and a laser-like focus on operational excellence to increase reserves, production rates, and profits. Cash flow from operations will be critical to give a high rate of return on investment as well as to fund ongoing development and expansion.

New technologies are available and are being developed for all stages of the exploration, drilling, development, production, and management process by many different organizations.

Because of the de-centralization of technological development, few companies realize the benefits of new technologies in improved operations. TerraGreen’s management has the technical background and credentials needed to survey and evaluate the technologies available and can recognize them, consolidate them into coherent management and operational procedures and methods, and realize their benefits in improved efficiencies and investment returns. It is expected that efficient application of new technologies will provide considerable improvement in recovery, production, and profits for many acquisitions and this upside will be a big component of success.

The company is managed by the principal of TERRAGREEN ENERGY RESOURCES, LLC whose individual areas of expertise cover many of the functional aspects of the business. Mr. Cunningham serves as the President of the company and is responsible for the day-to-day corporate operations.

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Mr. Brett Cunningham Managing Director, President Mr. Cunningham is a corporate operations and finance executive with 25 years of business experience. His background includes management, negotiations, operations, investor relations, and business analysis. Mr. Cunningham has practical knowledge of developing and growing companies and has developed specialized financing concepts for large projects. Mr. Cunningham has served in executive and management positions with Shell Oil, IBM Corporation, Scholastic Inc., Daqing-Denver, Inc. (a subsidiary of DPAB/China National Petroleum Corporation), Tatonka Oil and Gas, Inc., Advanced Well Control Systems, Inc., and TrueStar Petroleum Corporation. Mr. Cunningham holds dual undergraduate degrees in Computer Science and Psychology, The Colorado College / University of Denver, MBA, University of Denver Daniels College of Business and MIB Shaanxi Normal University candidate.

Mr. Garry Ward Managing Director, M&A and Engineering (China Country Manager) Mr. Ward's career spans 25 years in the petroleum industry, where his primary focus has been on the evaluation of oil and gas properties throughout the United States and includes eight years in China.. Mr. Ward was in charge of all technical evaluations for Floyd Oil Company from 1986 until the company sold its assets in 2000 and purchased over $200 million in assets.

Mr. Ward’s evaluation experience includes oil fields and waterfloods in West Texas, high pressure gas wells in Oklahoma and coalbed methane production in San Juan Basin, Powder River Basin and Arkoma Basin. Mr. Ward most recently served as the Sr. Vice President of Engineering for Far East Energy and was directly involved in the technical evaluation of the company’s CBM assets as well as all field operations.. Prior to joining Far East Energy, Mr. Ward was Reservoir Engineering Manager for 3TEC Energy, as Vice President of Engineering and Production for Floyd Oil Company. Mr. Ward holds a Master of Science degree in Petroleum Engineering from the University of Houston, is a registered professional engineer in the state of Texas and has been a member of the Society of Petroleum Engineers since 1978.

Mr. Paul Stroud Managing Director, Operations Mr. Stroud has more than 31 years of worldwide experience in the energy industry. He has an extensive background in onshore and offshore oil and gas operations, CBM wells, hot-water wells and high pressure steam wells. Mr. Stroud graduated from Sacramento State College and began his career as an engineer for Shell in 1971. After a period at UNOCAL Geothermal he established a consulting business, heading up projects for OESI in Hawaii, and Caithness Corporation in Indonesia. Mr. Stroud became Project Manager for JM Huber Corporation, for Gillette, and for Pinnacle Gas Resources, Inc.; an active CBM company located in Sheridan, 22

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Wyoming. Mr. Stroud has extensive experience in waterflood operations based in Long Beach, Huntington Beach and Kern County, California for a variety of companies including Shell Oil Company, Atlantic and other small companies.

Mr. Dave Weisgerber Managing Director, Drilling Operations Mr. Weisgerber has more than 34 years of experience in the drilling industry with a comprehensive background in natural gas, oil, CBM and high-pressure, high-temperature steam. Mr. Weisgerber is proficient in all methods of directional and horizontal orientation.

He is also an expert in all methods of circulating mediums, including air drilling, aerated fluids, stiff foam, inverted and fresh water systems. Mr. Weisgerber has spent the past 10 years working on projects in the Rockies for Huber, EnCana Oil & Gas and Pinnacle Gas Resources. Mr. Weisgerber has also worked on drilling projects in Indonesia, India and the Philippines.

Mr. Keith Reeves Managing Director, Geology & Exploration Mr. Reeves has more than 28 years of experience in the oil and gas industry. He is an expert in the areas of exploration, development and production geology which he has executed on a global basis – from the far reaches of Burma, to prolific oil & gas plays in the United States to successful methane gas discoveries in Botswana. Mr. Reeves has immense experience in acquisition prospect analysis with ranking, risk assessment, volumetrics and economic forecasting. Mr. Reeves holds a M.S., Geology; Sul Ross State University; 1987, a B.S., Geology; University of Arkansas; 1982 and is a Registered Professional Geologist, Washington, US. Mr. Reeves also has been educated in Basic Mandarin; Capital Mandarin, Beijing 2008.

Confidentiality Clause The information included in this business plan is strictly confidential. This information is provided on the understanding that it will not be disclosed to third parties without written permission from TGER.

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Amidon

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