-Completion system selection
-Stimulation pumping schedule, including fluid and proppant, recommendations
-Fracture geometry simulations and reservoir simulations
-Analysis of conventional open hole logs, cased hole petrophysical analysis and specialty log interpretation
Multi-tier methodology of refrac candidate selection that considers:
-Field-wide well performance using production analysis and decline
-Individual wellbore evaluation for root causes of low-performance, which includes geologic, geomechanical, pressure integrity, and operational feasibility reviews.
Set up, calibrate and operate an advanced computerized fracturing simulator. Output can be used to:
-Diagnose stimulation problems
-Predict production and optimize economic output of a project
-Run reservoir simulation
-Make fluid system chemistry, proppant and execution recommendations
-Integration of RCA or other available core/XRD data to generate a continuous, calibrated geomechanical/petrophysical profile of a single well
-Modeling of offset wells through coupled facies attribute analysis
-Determination of limits on rock strength and elastic properties from geophysical logs and other data to create a geomechanical framework that accurately reflects formation properties
-Evaluate project geomechanics, fracture modeling and economic objectives to select a completion system that best meets operator objectives
-Recommendations for injection point spacing and grouping using available logs from the lateral section in combination with seismic data and treatment modeling. In the case of limited entry completions, this will include properly designed limited entry perforations to uniformly distribute treatment fluids.
-Analyze treatment effectiveness and diagnose well or equipment problems using digital data acquired from actual fracture and acid stimulation jobs. Where appropriate, perform net pressure analysis to calibrate stress, permeability and containment aspects of a computerized fracture model.
-This test is used to determine properties such as entry friction, permeability, pore pressure, closure stress and fluid efficiency, to be used in fracture and reservoir models to improve accuracy. By pumping a known volume of fluid into a well and monitoring the pressure decline, many properties of the reservoir and created fractures may be determined via graphical manipulation.
-Determine fracture azimuth, length and complexity (stimulated reservoir volume). This interpretation will then be used to calibrate the computerized fracture model’s results, including fracture length and height predictions
-Determine net present value (NPV) and rate of return (ROR) in order to optimize completion and stimulation options
-Advanced interpretation, clarification and/or understanding of Retina’s acoustic data and its relation to wellbore events. This can include using other data acquisition technologies in combination with Retina.
-Solutions to ensure a successful system installation by using modeling software and analytics to predict drilling and installation challenges associated with wellbore friction, as a result of directional deviations and dogleg severity.
-Provide recommendations for an appropriate stimulation chemical program that will meet well objectives while minimizing damage to the reservoir. Evaluation of stimulation fluid testing, cuttings analysis, core flow studies, log analysis, and historical treatment reviews.
-Geomechanics, fracture modeling and conductivity lab testing will be evaluated to select proppants that will provide adequate conductivity and strength for a stimulation treatment while meeting the cuhttp://dev.packersplus.com/global-technology-and-training-center/stomer’s economic objectives.
Contact our Fracture Sciences Manager for more information
Manager, Fracture Sciences Group
Office: +1 (303) 407-9910
Cell: +1 (720) 403-1248