Successful Implementation of High Viscosity Friction Reducer in Marcellus Shale Stimulation

2018 ◽  
Author(s):  
Matt Johnson ◽  
Adam Winkler ◽  
Carl Aften ◽  
Phil Sullivan ◽  
W. A. Hill ◽  
...  
Keyword(s):  
Marcellus Shale ◽  
High Viscosity ◽  
Successful Implementation ◽  
Friction Reducer

scholarly journals Settling of Spherical Particles in High Viscosity Friction Reducer Fracture Fluids

Energies ◽  
2021 ◽  
Vol 14 (9) ◽  
pp. 2462
Author(s):  
Ghith Biheri ◽  
Abdulmohsin Imqam
Keyword(s):  
Settling Velocity ◽  
Video Camera ◽  
High Viscosity ◽  
Wall Effect ◽  
Spherical Particles ◽  
Rheological Parameters ◽  
Fracture Fluid ◽  
Glass Model ◽  
Fracture Models ◽  
Friction Reducer

Investigating the key factors that impact fluid rheology and proppant static settling velocity in high viscosity friction reducers (HVFRs) is a critical aspect for successful proppant transport in hydraulic fracture treatment. In this study, the rheological properties of HVFRs were tested at various temperature ranges (i.e., 25, 50, 75, and 100 °C) and different HVFR concentrations (i.e., 1, 2, 4, and 8 gpt). Three sizes of spherical particle diameters (i.e., 2, 4, and 6 mm) were selected to measure the static settling velocity. The fracture fluid was tested in two fracture models: an unconfined glass model and a confined rectangular model with two fracture widths (7 and 10 mm). The settling velocity in the confined and unconfined models was measured using an advanced video camera. HVFR results exhibited acceptable thermal stability even at higher temperatures, also the viscosity and elasticity increased considerably with increasing concentration. Increasing the temperature cut the friction reducer efficiency to suspend the spherical particles for a significant time, and that was observed clearly at temperatures that reached 75 °C. Spherical particles freely settled in the unconfined model due to the absence of the wall effect, and the settling velocity decreased significantly as the HVFR concentration increased. Additionally, the fracture angularity substantially slowed the proppant settling velocity due to both the wall effect and several types of friction. This research provides insights into the rheological parameters of a high viscosity friction reducer as a fracturing fluid and its efficiency in transporting particles in bounded and unbounded fracture networks.

Regional Strategy for the Implementation of Natural Gas as a Transportation Fuel

2012 ◽  
Author(s):  
Nicholas Barnett ◽  
Annamarie Murray ◽  
Nicholas Ouellette ◽  
Michael Snyder
Keyword(s):  
Natural Gas ◽  
New Technologies ◽  
Marcellus Shale ◽  
Region Of Interest ◽  
Successful Implementation ◽  
Test Bed ◽  
Transportation Fuel ◽  
Demand Chain ◽  
The Future ◽  
City State

Natural gas as a transportation fuel is a practical and viable replacement for petroleum based fuels. To implement natural gas fuel technologies, strategic plans must be put in place by city, state, and national agencies to not only fund the technology with monetary investments but also fund the social change to encourage long term technology growth. With the discovery and exploration of the Marcellus Shale the potential for natural gas infiltration as a fuel into the transportation market has grown exponentially. The region of interest for this specific plan focuses on a 150 mile radius around the Pittsburgh metropolis as the initial test bed region of interest. This region lies upon the Marcellus Shale and therefore there is a positive push towards the use of natural gas fueled by local interest. This region has the intellectual knowhow from universities and government agencies alike to develop technologies from theoretical design to product deployment. To ensure an effective and successful strategy the methodology of this investigation was one which looked to the past, present and the future. Past strategies were studied to determine what key features lead to success, the present was explored to define what laws and regulations are in place which affects the new technologies, and the future benefits of a successful implementation were hypothesized based on economic theory. The proposed strategy is a closed loop operation; meaning one industrious customer is temporarily both the supply and the demand chain of the technology. Public and private investments are vital to a successful implementation in the region by steering social awareness and subsidizing the market.

Successful Implementation of a Modified Carbonate Emulsion Acid System Combined with an Engineered Diversion Approach Delivers Outstanding Results – A Case Study from the Moho Nord Deep Offshore Field in Congo

2021 ◽  
Author(s):  
Didier Caillon ◽  
Benjamin Groschaus ◽  
Wilfried Matsiona ◽  
Theben Boumba ◽  
Manfred Bledou ◽  
...  
Keyword(s):  
Particle System ◽  
High Viscosity ◽  
Successful Implementation ◽  
Acid System ◽  
Pumping Rate ◽  
Asphaltene Deposition ◽  
Acid Diversion ◽  
Republic Of The Congo ◽  
The Republic ◽  
Offshore Field

Abstract Moho Nord deep offshore field is located 80 kilometers offshore Pointe-Noire in the Republic of the Congo. The wells produce crude from the Albian age reservoir and lithology consists of alternating sequences of carbonates and sandstone layers with high heterogeneity and permeability contrast, including the presence vacuolar layers called "hyperdrains". This paper describes the application of a novel acid system and the methodology successfully applied to effectively acid stimulate the Albian drain. The combination of long perforation intervals with lithology and permeability contrasts, natural fractures, and the potential for asphaltene deposition resulted in adoption of a Modified Carbonate Emulsion Acid (MCEA) fluid system containing a solvent to provide asphaltene deposition prevention. The MCEA stimulation treatments were bullheaded from a stimulation vessel and an engineered diversion process was implemented for effective acid diversion using a combination of mechanical ball sealers and a degradable particle system (DPS). The selection of number of ball sealers and the DPS diverter design depended upon the interpretation of zone permeability profile from the logs, and the final distribution of perforations selected along the drain. A fluid placement simulator indicated low sealing efficiency of the ball sealers would lead to an overstimulation of the highest permeability areas. Subsequent simulations indicated that the DPS would provide better acid coverage with lower skin (S). Results and observations presented indicate that the decision to improve the acid diversion design and combine ball sealers with a DPS diversion technique to improve zonal coverage was validated. During the stimulation treatment execution, the high stimulation treatment efficiency was clearly apparent from the pressure responses to the acid and the diverter system which sealed off perforations and diverted the treatment to other layers with lower permeability. The MCEA also has proven to have self-diverting properties due to its high viscosity and low reaction rate which creates a better coverage of the drain, even with limited pumping rate, allowing live acid penetrating deeper into the formation. The production results reported from the 15 wells stimulation campaign (10 producers, 5 injectors) indicated that the productivity indexes (PI) exceeded expectations and resultant post-stimulation skin values ranged from −2.5 to −4.1. The Moho Nord deep offshore stimulation campaign yielded outstanding production results and showed significant validation for use of the MCEA system and the diversion methodology applied. On the producer wells the use of both chemical and mechanical diversion was valuable, as the DPS proved to complement the Ball Sealers for layers with lower injectivity and also at the high injection rates. High injectivity gain coupled with effective diversion was crucial for enhanced wormholing and good drain coverage.

Application of D-Limonene as the Green High Viscosity Friction Reducer in Hydraulic Fracturing

2021 ◽  
Author(s):  
Aminah Qayyimah Mohd Aji ◽  
Wan Nor Farahana Wan Nadhari ◽  
Cindy Dhevayani Savitri ◽  
Dzeti Farhah Mohshim ◽  
Belladonna Maulianda ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
High Viscosity ◽  
Friction Reducer

Review of Friction Reducers Performance Applied to the Marcellus Shale Region

2021 ◽  
Author(s):  
Morgan McIntyre ◽  
Cayman Kelly ◽  
Viacheslau Kudrashou ◽  
Mohammad Kazemi
Keyword(s):  
Divalent Cations ◽  
Marcellus Shale ◽  
Fluid Flows ◽  
High Viscosity ◽  
Total Dissolved Solids ◽  
Formation Damage ◽  
Source Water ◽  
Optimal Range ◽  
Comprehensive Review ◽  
Significant Performance

Abstract Polyacrylamide-based friction reducers (FRs) are widely used in hydraulic fracturing to reduce friction created within fluid as it flows through tubulars or other restrictions. These polymers generally add viscosity to the fluid to reduce the turbulence induced as fluid flows. Type and amount of total dissolved solids (TDS) in source water have significant impact on performance of FRs. This study investigates these effects and evaluates various types of FRs applied to the Marcellus Shale region. It was found that increase in salinity often causes significant performance degradation (Mantell et al., 2011). This is especially critical for application of FRs in Marcellus shale that is known for challenging brine contents. This effect is more pronounced for some divalent cations than for monovalent ones. Addition of surfactant systems can improve FR performance by extending the salt tolerance. Overall, it can be concluded that FR optimization for given water content and proppant can be done by adjusting FR type and/or concentration. For special applications, when higher proppant loading is desired, applying Viscosifying Friction Reducers (VFRs) and High Viscosity Friction Reducers (HVFRs) are proven to be preferable. It was demonstrated that slickwater viscosity tend to increase exponentially with VFR concentration increase. At the same time VFRs should be breakable to ensure high regained proppant conductivity and minimization of formation damage. Such result would further justify the transition from traditional gelled fluids to FR-based viscous slickwater. This comprehensive review explores the application of various types of FRs for Marcellus shale region. It defines the critical TDS levels, and types of cations that require changes in FR type or dosage. This data can benefit operators in (1) optimizing performance of the FR-based completion fluid; (2) avoiding formation damage associated with usage of unjustified additives; and (3) comparing/qualifying FRs based on their optimal range of application and economical dosage.

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