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Collaborating Authors
Novel Approach for Produced Water Utilisation in Multi-Stage Fracturing Treatments in Western Siberia
Kiselev, Nikita (Schlumberge) | Vernigora, Denis (Schlumberge) | Borisenko, Alexey (Expert) | Rapeyko, Vitaly (Schlumberger) | Zotov, Kirill (Schlumberger) | Miklin, Yuriy (RN-Uvatneftegaz) | Prokhorov, Alexey (RN-Peer Review and Technical Development Center) | Denis, Zolnikov (RN-Peer Review and Technical Development Center)
Abstract Massive implementation of multi-stage fracturing treatments increased demands in water. Huge number of oil fields haven't got access to the fresh water sources. This fact forces service companies to utilize high TDS water sources for hydraulic fracturing. Currently available solutions for preparation of crosslinked fluid based on high TDS water involve implementation of organometallic systems which are too expensive and operationally complicated. This paper describes approach for preparation of borate- based fluid utilising high TDS water. Thorough laboratory optimization of the fracturing fluid has been performed and novel approach for fracturing fluid composition has been involved to develop next generation of robust borate fracturing fluids being able to withstand high TDS of the water. Fluid was evaluated in terms of both stability and viscosity recovery after application of high shear stress. Optimized fluid formulation has been used during multi-stage fracturing treatment with 7 stages. High TDS water of Cenomanian formations was utilized as a water source. During treatments as high as 700 kgPA proppant concentration has been reached. During optimization novel approach involving implementation of low boron containing fluid with massive content of alkali was introduced. Low boron content is required for preventing syneresis in high ionic strength media caused by Debye-Huckel effect. High alkali concentration meantime required to keep fluid at high pH and avoid weakening of bonds between borates and polymer. Too high alkali concentration worsens viscosity recovery after high shear stress application and this fact dictates implementation of both immediate and delayed alkali compounds. Pre-job water treatment is also important. Addition of reagents being able to convert natural radical oxidizing aids in less damaging forms is imperative. During the treatment fluid was additionally tuned to reduce frictional losses in tubing by compensating effect of proppant on the rate of crosslinking components diffusion. And treatment design was modified to address increased efficiency of the fluid caused by filter-cake enhancement by delayed alkali. The study showed availability of approaches which allow to implement high TDS water sources for preparation of borate crosslinked fluids confirmed by successful field implementation. These practices can be widely used in industry for performing multi-stage fracturing treatments in areas with lack of fresh water sources and to shorten water preparation cycle time.
- Europe > Russia (0.30)
- Europe > Netherlands > North Sea > Dutch Sector (0.24)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.34)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.98)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.98)
Abstract Currently, Russia experienced a rapid growth in horizontal wells drilling. The most popular method of completion is hydraulic fracturing. About 99% of hydraulic fracturing fluids are prepared using water. This fact undoubtedly increases the importance of technology and practices of collecting and utilizing water from underground and surface sources. The current direction of development of multi-stage hydraulic fracturing is increasing the number of stages and the volume of the proppant. So the main task of fracturing companies in Russia is to optimize the process of collecting and preparing water without increasing the cost of hydraulic fracturing. The use of organometallic fluids fracturing is the most common solution for use of unconventional water sources. However, due to the high cost of organometallic liquids, borate fluids will be considered in this work. Existing quality control requirements applied to hydraulic fracturing fluids cannot be directly used to study the rheological properties of fluids based on alternative sources of water — produced water from artesian wells and low temperature water. In connection with the foregoing, in the framework of this work, a new approach to testing and quality control of hydraulic fracturing fluids is presented. In case of using water with low temperature (15 degC in summer, 25 degC in winter), it is crucial to maintain the required recovery rate of fluid viscosity after application of high shear rates when passing through perforations in the near wellbore zone. In the case of the use of artesian water, it will be crucial to maintain the necessary stability of the liquid in a highly mineralized medium. During the hydraulic fracturing campaign in 2017-2019, pilot works were carried out using low temperature water and water from artesian wells. Implementation of water with a lower temperature leads to a reduction in the time of preparation for hydraulic fracturing by 33-50% reduction in heating time for the fluid. As a result, this practice leads to an increase in the monthly amount of work and the production of hydraulic fracturing fleets. Extended laboratory studies revealed that, developed for low temperature conditions, the hydraulic fracturing fluid not only satisfies the parameters for transferring and holding the proppant in the NWB zone, but even surpasses the liquid prepared by the traditional method (25 degC in summer, 35 degC in winter). The main goal of optimization of hydraulic fracturing fluid prepared using artesian water was to reduce the negative impact of some ions, primarily iron ions and hydrocarbonate ions. The presence of these ions in the hydraulic fracturing fluid leads to deterioration of the thermal stability of the hydraulic fracturing fluid. However, following the recommendations developed for the preparation of a fracturing fluid based on artesian water, it is possible to significantly reduce the influence of both one and other ions. The use of artesian water in the area of pads located near artesian wells, has reduced the time of water transportation by 50%. Pilot treatments were successfully carried out, showing a satisfactory level of production after hydraulic fracturing, comparable to similar work using conventional surface water preparation techniques using the standard procedure. Reduction of preparation time, optimization of resources required for water treatment, and reduction of negative environmental impact confirm the significant economic benefits of the methodology described in this paper. This approach, using the environmentally safe "green" chemistry as part of a hydraulic fracturing fluid, allows operators to minimize the negative impact of production factors on the environment and confirm the effectiveness and environmental friendliness of hydraulic fracturing technology as a well workover.
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > P’nyang Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Elk-Antelope Field (0.97)
- Oceania > Papua New Guinea > Papuan Peninsula > Central Province > National Capital District > Petroleum Retention License 15 > Angore Field (0.97)
- (9 more...)
Abstract BACKGROUND A problem that many exploration and production companies face is how much impaired flowback and/or production brine can safely be reused on future completions; and what chemicals should be included in the fracturing fluid design to mitigate any concerns. The main focus will pertain to slickwater fluid designs. METHODS The authors used geochemical modeling hardware/software in combination with cuttings and sequential flowback analyses to acquire a full understanding of the shale constituents and mineralogy that disbands in formation. One can also determine the efficacy of the scale, clay, and iron control chemistries associated with the fracturing fluid design with sequential flow back analyses. Friction flow loop and rheology data confirm the homogeneity of the fracturing chemistries chosen for the application. RESULTS The data obtained from the cuttings analyses and sequential flowback studies confirm a correlation between the shale geology and flowback characteristics. This information confirms proper scale control selection and loading which will allow for a scale free formation. Microbiocide efficacy studies performed throughout the project indicate the propensity for microbiological activity and the successfulness of mitigation strategies. Friction flow loop data confirms the compatibility of the fracturing fluid constituents and the efficacy of those chemistries in stressed water conditions. CONCLUSION Studying geochemical formulary and water quality to develop a database for both well production and water quality of the producing well is critical in understanding water reuse. This data will allow the operator to make better decisions concerning optimal fracturing fluid design for slickwater application and proper reuse of water on subsequent hydraulic fracturing.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (0.51)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.45)
ABSTRACT: In recent years, service companies often use a low viscous, fiber-laden fracturing fluid. The added fibers not only assist in the transport of proppant based on mechanical suspension but also prevent proppant settling during fracture closure. Although the chemical composition of the fibers used is not described, their characteristics suggest that they are made of PLA materials. In our experiments, we tested both PGA and PLA fibrous materials using a small scale slotted equipment. The results showed that mixing fibers with a small amount of polymer significantly helped transporting proppant. From the preliminary tests, PLA fibers crumbled and tended to induce proppant screen-out often; thus, only PGA materials were used for the proppant transport experiments. Since the PGA materials were cost prohibitive, we determined the optimum concentration of PGA fibers by changing the polymer concentration of frac fluid and injection rate. We concluded that the suitable amount of fibers is around 0.567 kg (1.25 lbs) / 3785.4 liters (1000 gallons) of slick water. This concentration is economically feasible given that the total fluid injection volume is large for hydraulic fracturing applications.
Efficient Hydraulic Fracturing Treatments Using Produced Formation Water in Western Siberia
Fedorov, Andrey Vladimirovich (Schlumberger) | Fedorov, A.. (Schlumberger) | Fu, D-K.. (Schlumberger) | Mullen, K.. (Schlumberger) | Kochmar, L.. (Schlumberger) | Lungwitz, B.. (Schlumberger) | Dessinges, M.. (Schlumberger)
Abstract An appropriate fracturing fluid is one of the key elements for success of hydraulic fracturing treatments. In western Siberia, borate crosslinked polymer fluid has been widely used because of the high viscosity required for placement of large-size proppants. The first step to obtain the viscosity is to hydrate or dissolve a dry form of polymer and prepare a linear gel. This operation requires a minimum temperature of 25°C. Because the average temperature is below 20°C all year and as low as – 40°C in the winter (Fig. 1), this temperature requirement, coupled with the lack of freshwater sources in some locations, presents both logistical and operational challenges.Figure 1: Average temperature in Tyumen Region, W. Siberia Water produced from the Cenoman formation is readily available in many locations in western Siberia (Blackbourn Report 2010). With temperatures ranging from 35 to 50°C, Cenoman water could be an ideal source for preparing fracturing fluids. However, the water contains boron and a high level of magnesium and calcium that cause undesirable instant crosslinking of linear gel and shear and thermal instability. To eliminate the impacts of those elements, we introduced a chelating additive to the water to sequester the cations species and optimized the initial fluid pH to improve thermal stability. The concentration of chelating agent is further adjustable to ensure consistency in crosslinking delay time and to provide shear insensitivity. Using Cenoman water and equipment for continuous mixing of fracturing fluid has greatly improved the operational efficiency and service quality of fracturing treatments in western Siberia. The time to complete a single fracturing treatment was reduced from 2 days to less than 1 day. In some cases, two treatments were performed in 1 day. As of December 2008, more than 500 fracturing treatments had been performed using Cenoman water with an average of over 94% proppant-placement rate.
- North America > United States > Texas (0.28)
- Europe > Norway > Norwegian Sea (0.24)
- Asia > Russia > Ural Federal District > Tyumen Oblast > Tyumen (0.24)
- 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...)