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Collaborating Authors
Fracturing materials (fluids, proppant)
Abstract Burgos is the first major unassociated gas basin in Mexico. It covers an area of 50,000 km and contains complex, sandstone reservoirs, which are highly compartmentalized and made up of several small, independent blocks characterized by low permeability. This basin is considered a tight-gas reservoir. Sustaining a high production level in this area requires a large number of wells to be drilled and hydraulically fracture stimulated. Historically, the initial well productivity is high, but declines quickly. This phenomenon seems as if it could be associated with the loss of fracture conductivity shortly after the well is put on production. Proppants that are factory coated with a partially cured resin, generally referred to as resin coated proppants (RCPs) have been used in the industry to reduce proppant flowback and to improve fracture conductivity. A more recent methodology is to coat proppants on location using liquid-resin systems (LRSs). This method uses a specific type of hydrophobic material to resin-coat proppants, and has often been used in the industry specifically to prevent post-frac proppant flowback. The proppant is coated on-the-fly on location with the LRS material. This technology has also proven to both initially increase and also to better sustain fracture conductivity over time. The use of liquid resins for proppant coating in the Burgos basin to enhance and maintain conductivity in several fields has shown to lead to better well performance than when using the factory-coated RCPs. Production data from a LSR treated well after almost two years of production is presented and compared to a well with similar petrophysical characteristics completed in the same productive block in the same formation using the same volume of a RCP type proppant. The similar conditions initially present in these wells will forcefully support the superior behavior of LRSs when compared to conventional RCPs when placed using identical treatment designs.
- North America > Mexico > Tamaulipas (0.61)
- North America > Mexico > Nuevo León (0.61)
- North America > Mexico > Coahuila (0.61)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- North America > United States > Texas > East Gulf Coast Tertiary Basin > Wilcox Formation (0.99)
- North America > United States > Mississippi > East Gulf Coast Tertiary Basin > Wilcox Formation (0.99)
- North America > United States > Louisiana > East Gulf Coast Tertiary Basin > Wilcox Formation (0.99)
- (5 more...)
Abstract A hydraulic fracturing stimulation campaign has been successfully conducted in Rimau block. The stimulation was applied in tight KTLS sandstone formation with permeability within the range of 5-10 mD and also conducted in medium permeability multilayer LTAF sandstone (>10 mD) to bypass nearby wellbore damage. The purpose of this paper is to share best practices and lessons learnt from the hydraulic fracturing campaign, which commenced in 2003. The campaign was divided into three stages, with the aim of continuous improvement. The first stage was conducted in 2003, when a trial with a generalized design was conducted. Later, the second stage was conducted during the period 2004-2009, when a hydraulic fracturing campaign with improved design was carried out. Finally, the third stage was conducted from 2010-onwards, when the campaign was improved by emphasizing operational excellence and technological diversification. Beginning with Stage 1, hydraulic fracturing was performed in 13 wells in KTLS using typical fracturing design. An increase in production from each characteristic of formation was observed. Following the success story of Stage 1, a campaign was conducted in Stage 2 by proposing a plan of development for 50 wells to generate an optimization of the fracturing design. Stage 3 consisted of performing further optimization through technology diversification to overcome pressure depletion and operational collaborations. Furthermore, fracturing was also applied to higher permeability sandstone formations to bypass nearby wellbore damage. The continuous improvement during all stages resulted in an increase in oil recovery of 10 to 25% in tight formation and 30% in higher permeability formation, with an oil gain ranging from 80-500 BOPD and a typical yearly decline of 40%. In the future, hydraulic fracturing will be applied to face further challenging conditions, such as tight gas, tight oil and shale gas.
- Asia > Indonesia > Sumatra > South Sumatra Basin > South Sumatra Basin > Rimau Block > Kaji Semoga Field > Telisa Formation (0.99)
- Asia > Indonesia > Sumatra > South Sumatra Basin > South Sumatra Basin > Rimau Block > Kaji Semoga Field > Talang Akar Formation (0.99)
- Asia > Indonesia > Sumatra > South Sumatra Basin > South Sumatra Basin > Rimau Block > Kaji Semoga Field > Baturaja Formation (0.99)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
- (2 more...)
Abstract Unconventional reservoir has become the hotspot of development in petroleum industry. In shale reservoir, some fracture is only propped by a monolayer 100mesh proppant. Fracture width is very small and under the condition of low rock hardness and high effective closure stress, the fracture will heal after a period of time, especially after the rock has been exposed to the fracturing fluids, causing weakening of the rock frame. In these reservoirs, proppant embedment becomes more serious. This paper purposes two embedment mechanisms, elastic deformation and creep deformation, and develops the corresponding models by combining simplified physical processes with elastic theory. Then with time integral, pressure dependent embedment depth is achieved. This paper provides a more reasonable method for calculating embedment. For fracturing engineer, it will give them a way to know how worse the matter will be. Finally, the model could couple with fracture propagation model and production prediction model to get a better result. According to the results of analysis in the paper, in shale formation, proppant will cause creep deformation of rock, which will decrease fracture width with time. Optimization of fracturing fluid and treatment procedure are required to reduce the influence of creep deformation. Poisson's Ratio do have an effect on proppant embedment but very little. The mechanisms described in the paper provide a new understanding about embedment. It provides us a tool to determine how much the degree will be.
- North America > United States > Texas (0.69)
- Asia (0.69)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.95)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.94)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.94)
- (6 more...)
Abstract In-situ crosslinked gelled hydrochloric (HCl) acid systems have been extensively used in matrix acidizing and acid fracturing treatments to help achieve acid diversion. These systems also help control fluid leakoff and help retard the acid reaction to allow deeper acid penetration. Presently, in-situ crosslinked gelled acid systems are generally comprised of acrylamide-based polymers, an iron crosslinker, and a breaker chemical, in addition to other additives, with HCl acid. Many iron-based crosslinker systemscan form iron depositions, precipitation/sludge, and/or scale formation during or after the acidizing treatment when the acid spends, which can causeformation damage. In addition, thismight also lead to increased operating costsbecause of the need for sludge- and/or scale-removal treatments. To overcome these issues, a new non-iron-based composition was developed for in-situ gelled acid systems that can work in 5 to 20% HCl acid at temperatures up to 300°F. The new composition performs identicallyto that of iron-crosslinker systems but can avoid problems associated with scale formation and precipitation. The new non-iron-based composition crosslinks the polymer in the pH range of 1.5 to 3, which helps withdiverting the next acid stage into tight or damaged zones. The gelation or crosslinking can be observed as acid reacts with a carbonate formation and the pH rises above 1.5. Further, as acid continues to spend on the formation and when the pH becomes greater than 3, the gel shows a reduction in crosslinked viscosity. This newly developed system does not require any reducing agent or breaker aid because the crosslinked gel shows a complete break with acid spending. The crosslinked-gel stability of this systemfor temperatures up to 300°F is evaluated and discussed in this paper. The effect of corrosion inhibitors, along with other additives, on this new crosslinked system is also described.
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (21 more...)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Well Completion > Hydraulic Fracturing > Fracturing materials (fluids, proppant) (1.00)
- Well Completion > Acidizing (1.00)
- (2 more...)