​Unlock Shale Potential​


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

ShaleVision™ Deliverable for New and/or Old Wells

  • A Production Profile with recommended fracking stages and brittleness
  • Locations of the best formations and zones
  • Production maps for the best formations
  • Recommended trajectories for horizontal wells with 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 relative 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 relative permeability and actual production. 

This equation was used to successfully develop hundreds of thousands of wells in conventional reservoirs in the Unites States, Russia, Canada, Mexico and Kazakhstan. With the recent growth in shale development in the US, it has been modified for shale plays and validated in more than 100 wells in the Permian Basin. 

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 Technology separates low and high producing zones, allowing operators to drill only the 10% to 20% of horizontal wells with top production. It unlocks the potential of shale plays with minimum cost and lower environmental impact.

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 maps below show the production potential for Wolfcamp A and Atoka Shale for the same location in an underexplored area of about 200,000 acres. The maps also indicate the location of vertical wells that were used to generate the maps. Each 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.

For Atoka Shale the initial production in the NE corner will be 450 Bbl./day, and for the SW corner it will be 590 Bbl./day.

These 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.

                    Wolfcamp A                                                                                   Atoka Shale                                                                                                  

The Initial Production (IP) estimate for the horizontal well (850 Bbl./day) was calculated assuming a 7,000 ft. lateral and was based on a correlation with the production profile of a neighboring vertical well. This is one of four high potential horizontal wells identified by the Production Profile for the entire well.


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The chart shows the strong correlation between production predicted by ShaleVisionTM based on log data and actual production for vertical wells in the Permian basin. Each dot represents a single well with multiple fracking stages.


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