Executive Summary

This is my first executive summary as co-executive editor of SPE Reservoir Evaluation & Engineering (SPEREE). In September 2019, I took over the co-executive editor post from Jesús Salazar. I would like to thank Jesús for his contributions, leadership, and dedicated service to SPEREE journal. I also would like to thank Sheng Peng and Michael Altunbay, who agreed to serve as associate editors for SPEREE. Additionally, I would like to express my sincere appreciation to the staff at the editorial office and the associate editors and technical reviewers for their dedication to providing high-quality, innovative, technically sound, and timely publications.             

The May 2020 issue of SPEREE comes with 25 papers covering chemical flooding, reservoir simulation and history matching, field and case studies, pressure and rate transient analysis, geomechanics, and laboratory studies on wettability and imbibition. Find below concise descriptions of the articles contained in this issue.

Chemical EOR 

  • Effect of Live-Crude-Oil Composition on Optimal Salinity of a Surfactant Formulation: Experiments and Modeling investigates the effect of gas composition, pressure, and temperature on the phase behavior of a brine/surfactant/live-oil system and tries to develop an optimal surfactant formulation.
  • An Experimental Study of Emulsion Flow in Alkaline/Solvent Coinjection with Steam for Heavy-Oil/Bitumen Recovery presents experimental evidence on how oil-in-water emulsion could improve oil recovery during steam-assisted gravity-drainage processes.
  • Stability Improvement of Carbon Dioxide Foam Using Nanoparticles and Viscoelastic Surfactants for Enhanced-Oil-Recovery Applications uses mixtures of viscoelastic surfactants and nanoparticles to stabilize and enhance foam mobility, improving oil recovery by more than 25%.
  • Based on laboratory experiments, Role of Alkali Type in Chemical Loss and ASP-Flooding Enhanced Oil Recovery in Sandstone Formations shows that weak-base ASP chemicals cause less formation damage and increase oil recovery by more than 20%, compared to strong-base fluid systems.   
  • Does Polymer’s Viscoelasticity Influence Heavy-Oil Sweep Efficiency and Injectivity at 1 ft/D? illustrates that polymers with higher concentration and higher shear viscosity result in higher pressure drops and higher sweep efficiency at low displacement velocities, accelerating heavy-oil recovery.
  • Alkali-Cosolvent-Polymer Flooding of High-TAN Oil; Using Phase Experiments, Micromodels, and Corefloods for Injection-Agent Selection highlights that simultaneous alkali/polymer injection reduces adsorption of polymers, breaks up and mobilizes oil ganglia more effectively, and leads to higher oil recovery.

Reservoir Simulation and History Matching

  • Calibrating the Todd and Longstaff Mixing Parameter Value for Miscible Finite-Sized Slug WAG Injection for Application on a Field Scale explores the influence of slug size, WAG ratio, and recovery type on the optimum mixing parameter when a black oil simulator is used to mimic a miscible flooding process.
  • Using several different types of 2D and 3D finite elements, Two-Phase Compositional Flow Simulation in Complex Fractured Media by 3D Unstructured Gridding with Horizontal and Deviated Wells proposes higher-order numerical models for simulating multicomponent flow into complex wells, with capability to mimic hydraulic and CO2 fracturing.
  • Based on special connections between matrix and karst, Multiscale Integration for Karst-Reservoir Flow-Simulation Models develops an embedded discrete-karst model, which explicitly represents the karst features and reduces simulation time.
  • History Matching Under Geological Constraints Coupled with Multiobjective Optimization To Optimize MWAG Performance: A Case Study in a Giant Onshore Carbonate Reservoir in the Middle East reports how the uncertainties in fracture permeability and saturation distributions impact the history match and production forecasts during a miscible water-alternating-gas injection process.
  • A Multiphase, Multicomponent Reservoir-Simulation Framework for Miscible Gas and Steam Coinjection presents a workflow to integrate a thermal simulator and a compositional simulator. The integrated thermal/compositional simulator is used to investigate the feasibility and benefits of CO2/steam coinjection process. 

Field and Case Studies

  • Unique Infill Configuration To Unlock Additional Barrels in the Boscán Heavy-Oil Water-Injection Project proposes to drill additional rows of producers between the existing first and second rows of the producers to tap the bypassed oil in the unswept areas of a heavy-oil reservoir under waterflooding. The reservoir simulation modeling shows that the proposed infill pattern could unlock significant additional reserves.
  • Pioneer Field Pilot of Optimal Reservoir Management in Campos Basin applies an optimal injection procedure to find variable water-injection rates, maximizing the oil production from an offshore oilfield.
  • Atlanta Field: Producing Heavy and Viscous Oil in Ultradeepwater reports on the initial production phase, well allocation, artificial lift, dynamic reservoir simulation, and production history matching for Atlanta field. Additionally, initial prediction and expectations are compared with the actual field performance.

Transient Pressure and Rate Analysis 

  • Using the production data from transient-linear and boundary-dominated flow periods, A New Straight-Line Analysis Method for Estimating Fracture/Reservoir Properties Using Dynamic Fluid-in-Place Calculations presents simple, straight-line-plotting functions to predict the fracture properties and original fluid in place.
  • Comparison of the Methods for Analyzing Rate- and Pressure-Transient Data from Multistage Hydraulically Fractured Unconventional Gas Reservoirs examines and compares the existing graphical techniques to interpret gas production data from the hydraulically fractured horizontal wells in low-permeability formations.
  • Practical Solutions for Rate-Transient Analysis of Tight/Shale Reservoirs with Interfracture Induced Heterogeneity introduces forward and inverse solutions to analyze transient linear flow data influenced by reservoir heterogeneity.
  • Estimation of Effective Permeability, Fracture Spacing, Drainage Area, and Incremental Production from Field Data in Gas Shales with Nonnegligible Sorption modifies an existing three-parameter scaling solution to formulate the effect of gas sorption on gas production and applies the extended solution to the production histories of nearly 9,000 wells in the Marcellus Shale.
  • Quantifying Total Apparent Hydraulic Fracture Conductivity and Its Significant Degradation from Systematic Bottomhole Pressure Measurements in Permian Wells presents two methods to analyze successive pressure buildups in horizontal wells and time-lag of pulse interference between active and observation wells.

Geomechanical Applications 

  • Geomechanical Characterization of Unconventional Source Rocks Using Rebound-Hardness Test and Mineral Mapping proposes a new nondestructive method to measure rebound-hardness number on slabbed rock surface and uses empirical relations to predict unconfined-compressive strength from rebound-hardness.
  • Multimineral Modeling and Estimation of Brittleness Index of Shaly Sandstone in Upper Assam and Mizoram Areas, India compares four established models to predict brittleness index from multimineral modeling and conventional log data.

Experimental Wettability and Imbibition Studies

  • Using imbibition experiments, numerical simulation, history matching, tracer tests, and micro-CT scan, New Insights into Spontaneous Imbibition Processes in Unfractured and Fractured Carbonate Cores with Stress-Induced Apertures estimates fracture and matrix properties numerically.
  • By measuring contact angle and Amott index, Amino Acid as a Novel Wettability Modifier for Enhanced Waterflooding in Carbonate Reservoirs demonstrates that 5-wt% glycine added to brines could change the wettability of calcite surfaces and limestone cores.
  • Impact of Geochemical Properties on Wettability of Kerogen and Organic-Rich Mudrocks experimentally quantifies the influence of kerogen thermal maturity on the wettability of mudrocks, demonstrating higher water wettability at lower thermal maturity.
  • Joint Interpretation of Electrical Resistivity and T2 NMR Measurements To Estimate Wettability and Water Saturation introduces and verifies a multiphysics workflow coupling resistivity and NMR measurements, assessing wettability and saturation more accurately.

Turhan Yildiz, SPE Res Eval & Eng Executive Editor,
Red Rocks Engineering