PRODUCTS

Amros proprietary ShaleVision™ technology identifies the highest producing zones in shale plays using only open-hole log data, allowing operators to target the highest producing zones and avoid the cost of drilling low productive wells. Within 24 hours of receiving standard open-hole log data for a well, we develop a Production Profile, an Amros innovation that accurately predicts production along the entire well in barrels per day per 100 feet. When combined with data from surrounding wells, ShaleVision™ identifies the best formations and optimum trajectories for horizontal wells along with estimates of production.

The Figure below shows a segment of our proprietary Production Profile (brown line), along with brittleness (black) and water saturation (blue), with the best entry zone for horizontal well highlighted. This is calculated entirely from open-hole log data.

Production Maps Based on Production Profiles from vertical wells, ShaleVision™ identifies the best zones and provides production maps and trajectories for horizontal wells for these zones with a color scale that indicates production in Bbl/day per 100ft.

The production map below shows the production potential for Wolfcamp A for an underexplored area of about 200,000 acres. The map also shows the location of vertical wells that were used to generate the map. Map shows the increasing trend for production from NE to SW.

For example, a 7000 ft. horizontal well in the NE corner of Wolfcamp A will produce 520 Bbl./day and in the SW corner the initial production will be 800 Bbl./day.

These kind of maps allow operators to calculate the initial production of future horizontal wells in different locations to optimize their development plans and the value of their holdings.

Input Data:

Map showing vertical well positions
Corresponding open-hole log data (gamma ray, resistivity, neutron and density porosity)

The Technology Delivers:

Production Profiles
Locations of the best formations and zones
Production maps for the best formations
Recommended well trajectories
Recommended well spacing
Initial production estimates

The basic equation for the calculation of Production Profiles was distilled from a very unique set of data that included open-hole logs and permeability derived from hundreds of pressure build-up well tests. This is effective oil permeability in actual in situ conditions with actual overall pressure and the direction of differential pressure. This permeability defines actual well production and refers to the drainage area with a volume comparable to the log data average scale. The unique data set was instrumental in the development of the proprietary equation to correlate open-hole log data with effective oil permeability and actual production.

This equation was applied on the industrial scale in Russia for development of dozens conventional oil fields. Later in Houston it was adjusted and tuned for shale deposits. This is a basis of ShaleVision technology. If we know effective oil permeability, we know well production and we know where oil is coming from. Like Archie equation it has a few coefficients that can be tuned for different formations.

Milestones

August 2012

The first successful industrial test of ShaleVision™ - prediction of the best entry point for a horizontal well was confirmed by selective fracking.

August 2015

ShaleVision™ validated by a major oil company in blind analyses of historical log data.

September 2017

Successful project with Escopeta Oil & Gas. Amros identified the best formations and provided production maps for future development including trajectories and initial production estimates for horizontal wells.

Case Study

Escopeta Oil & Gas had planned to drill a single horizontal well in a shale play. Based on analyses of the Production Profiles of the pilot well and neighboring wells, Amros estimated that the horizontal well Escopeta had planned would have produced 200 barrels per day (bbl/d). At the same time, Amros identified four high producing zones at the same location with average initial production of 580 bbl/d each. The initial plan of drilling one horizontal well would have resulted in a cash loss of $1.3 Million in the first year.

With the Amros approach, including the cost of drilling and completion of two vertical and four horizontal wells, plus the cost of Amros services, the cashflow for the first year would be $20.2 Million.

Amros services yielded a cash benefit of $21.5 Million in the 1st year for Escopeta versus their original plan.

Amros identified the best formations and built production maps for these formations. In addition the trajectories and initial production for horizontal wells were identified. We can now identify the areas where we can drill up to 6 high producing horizontal wells in the same location. Danny S. Davis, President of Escopeta Oil & Gas Corporation

Escopeta Oil & Gas Reference Letter

PRODUCTS

Video

This website uses cookies.