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Collaborating Authors
SPE Middle East Oil and Gas Show and Conference
Environmental Friendly Water-Based Pre-Flush Formulation for Oil & Injector Wells' Acid Stimulation
Al Jaberi, Jaber (King Fahad University of Petroleum and Minerals) | Sultan, Abdullah (King Fahad University of Petroleum and Minerals) | Shamsan, Abdulmalek (King Fahad University of Petroleum and Minerals) | Hassan, Islam (Modern National Chemicals) | Marine, Hope (Modern National Chemicals) | Akram, Asad (Modern National Chemicals) | Saleh, Raed M (Taqa)
Abstract Aromatic based chemistries have been used extensively as additives in the pre-flush systems of acid stimulation programs. The need for these solvents stems from the requirement to displace oil or break asphaltic or waxy materials ahead of the main stimulation treatment. These chemicals while effective, are highly flammable, difficult to handle and have negative impact on the enviroment. Aromatic additives are always mixed with diesel-based pre-flush systems in acid stimulation jobs. If water is added to this system, the resultant emulsion damages the productivity of the formation. Water wetting surfactants typically of aqueous nature pose the same problems when mixed with diesel systems. The main challenge, however, is to mix these hydrocarbon-based fluids with water and surfactant to clean the wellbore and water-wet the formation face in preparation for the acid stimulation treatment. The objective of this work was to evaluate new environment-friendly water-based pre-flush formulations for oil and injector wells. The new aqueous Pre-flush formulations was developed to avoid the aformentioned problems with using diesel. The new Pre-flush formulations include between 10-15% blend of specialty surfactants and solvents, successfully homogenized with low-cost field water. These formulations are able to alter the wettability of the formation face by breaking the oily phase and separating it from the surface of the formation. The new formulations have high flash points and are biodegradable which results in easier handling and an environment-friendly alternative to existing diesel pre-flush systems. Wettability, stability and interfacial tension tests at reservoir conditions helped optimized the new formulation. The results showed excellent dissolving power for oily sludges and surfaces in addition to excellent stability and wettability. The new pre-flush formulations can enhance the reactivity of the acid with the formation and improve treatment results. It will enhance the flowback and post-treatment cleaning of the well.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.95)
Abstract This paper describes the application of high performance asynchronous stencil computations for 3D acoustic modeling on a synthetic land survey. Using the Finite-Difference Time-Domain (FDTD) method, a parallel Multicore Wavefront Diamond-tiling (MWD) stencil kernel (Malas et al. 2015, Malas et al. 2017) drives the high performance execution using temporal blocking to maximize data locality, while reducing the expensive horizontal data movement. As absorbing boundary conditions, we use Convolutional Perfectly Matched Layer (CPML), which have to be redesigned to not interrupt the asynchronous execution flow engendered by the MWD stencil kernel for the inner-domain points. The main idea consists in weakening the data dependencies by moving the CPML computations into the inner-computational loop of the MWD stencil kernel (Akbudak et al. 2019). In addition to handling the absorbing boundary conditions, applying the asynchronous MWD with CPML kernels to a realistic land survey requires the extraction of the wavefield value at each receiver position. We revisit the default extraction process and make it also compliant with the overall asynchrony of the 3D acoustic modeling. We report performance improvement up to 24% against the standard spatial blocking algorithm on Intel multicore chips using the synthetic land survey, which is representative of an area of interest in Saudi Arabia. While these results concur with previous performance campaign assessment, we can actually produce and assess the resulting 3D shot gather accuracy. To our knowledge, this is the first time the effectiveness of asynchronous MWD stencil kernel with CPML absorbing boundary conditions is demonstrated in an industrial seismic application.
- Geophysics > Seismic Surveying > Seismic Processing (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.47)
Application of Acid Activated Bentonite for Efficient Removal of Organic Pollutants from Industrial Phosphoric Acid: Kinetic and Thermodynamic Study
Ali, M. M. (Nuclear Materials Authority) | Attia, Azza A. (Zagazig University) | Taha, M. H. (Nuclear Materials Authority) | El-Maadawy, M. M. (Nuclear Materials Authority) | Abo-Raia, A. M. (Nuclear Materials Authority) | Abouria, Amr (Halliburton)
Abstract Environmental and health issues are critical challenges for sustainable development in the 21st century; therefore, this paper investigates a simple and cost-effective process for recovery of organic matter (OM) from phosphoric acid to provide environmentally acceptable P-fertilizer. This study analyzed the structural transformations and adsorption properties of Na-bentonite clay before and after chemical activation by sulfuric and hydrochloric acids. The untreated and treated clay samples have been used for adsorption of organic matter from high strength phosphoric acid. The experimental data exhibited that the clay treated with sulfuric acid caused highest organic matter adsorption capacity. The kinetic models of adsorption were analyzed by the pseudo-first order, pseudo-second order, Elovich kinetic and Morris-Weber models. The results indicated that the pseudo-second-order kinetic model is more appropriate than the others for natural bentonite; but, for chemical activated clays, pseudo-first order is fitting. Obtained adsorption thermodynamic parameters (ΔH°, ΔS°, and ΔG°) expose that the organic matter adsorption is an endothermic, physical, and spontaneous process.
Abstract The purpose of the paper is to present the results of using local sand resources in Saudi Arabia for the manufacture of resin coated proppant as a ceramic proppant alternative for deep conventional gas development. Crushed Miocene sandstone, old river sand and dune sand has been tested for a source to manufacture resin coated sand proppant. Compared to Northern White Sand in USA, each sand source has its own set of limitations such as angularity, low aspect ratio, clay, carbonate scale or iron oxide coating, and/or micro-fracture damage. Complete resin bonding to the particle surface required clean quartz surface free of sharp edges and no dust contamination. Conductivity testing of the resin coated sand at reservoir pressure and temperature reveals that over 95 wt% of the mesh sized sand particles should pass the room temperature crush test before coating.
- Geology > Mineral > Silicate (0.55)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.49)
Abstract The key factor for characterizing unconventional shale reservoirs is the total organic carbon (TOC). TOC is estimated conventionally by analysis cores samples which requires extensive lab work, thus it is time-consuming and costly. Several empirical models are suggested to estimate the TOC indirectly using conventional well logs. These models assume the TOC and well logs are linearly related, this assumption significantly reduces the TOC estimation accuracy. In this work, the design parameters of the artificial neural network (ANN) were optimized using self-adaptive differential evolution (SaDE) method to effectively predict the TOC from the conventional well log data. A new correlation for TOC calculation was developed, which is based on the optimized SaDE-ANN model. 460 data points of different well logs from Barnett formation were used to learn and validate the optimized SaDE-ANN model. The predictability of the SaDE-ANN correlation was compared with the available correlations for predicting the TOC using 29 data point from Duvernay formation. The TOC was estimated using the optimized SaDE-ANN model with an average absolute percentage error (AAPE) and correlation coefficient (R) of 6% and 0.98, respectively. The SaDE-ANN correlation developed for TOC prediction outperformed the recent models suggested by Wang et al. (2016) and Mahmoud et al. (2017). The new empirical equation reduced the AAPE in predicting the TOC by 67% compared to Mahmoud et al. (2017) model in Duvernay formation.
- North America > United States > Texas (1.00)
- North America > Canada (1.00)
- Geology > Geological Subdiscipline (0.94)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.69)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.40)
- North America > United States > West Virginia > Appalachian Basin (0.99)
- North America > United States > Virginia > Appalachian Basin (0.99)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- (16 more...)
Abstract Multiphase flow meters are available from sometime, however, there still remain unresolved challenges. Dependable flow sensing is essential for reservoir management and production optimization. Most commercial water-cut and multiphase flow meters have limitations while measuring over the full range of flow conditions. Exiting meters need recurrent calibration, and have significant capital and operational overheads. In this paper an ultrasonic tomography based meter for water hold-up measurement is presented and the the experiences and challenges of testing the system in the field are shared. The designed system has the potential to resolve the shortcomings of available multiphase metering solutions.
Abstract To optimize production of a supergiant field, operators require an integrated approach to production forecasting that incorporate subsurface models of multiple reservoirs, well performance, surface equipment and facility constraints. This helps asset managers plan and optimize production on a well-by-well basis to achieve maximum system deliverability. This paper addresses challenges of integrating huge amounts of data, model framework and automated workflows to identify opportunities in debottlenecking, production target sustainability and deliverability. The integrated production system model involves a simplistic bottom-up approach, in which advanced integration of subsurface and surface elements was facilitated through automated workflows within a digital oilfield system. These automated workflows enable converting multiple reservoir simulation output files to a standard format and mapping of common well names in simulation outputs and in well and facility models. An event-controlled scheduling process in a single working environment enabled analysis of production targets in realistic facility situations for future time steps. The decline in reservoir pressure is modeled, with new well performance in facility model based on changing reservoir conditions. This automated environment has been adapted to evaluate two giant onshore fields encompassing multiple reservoirs, thousands of wells and numerous distributed-process facilities. The forecasting process confirms deliverability of planned and sustainable production and identifies opportunities for additional field potential, thus facilitating CAPEX optimization for future well costs. The integrated asset forecast was successfully carried out over a five- year timeframe at monthly intervals. One of the most important results obtained from such a forecast simulation was obtaining the maximum feasible rates that can be expected from the asset for each month during the next five years. This collaborative solution has successfully demonstrated the value of data and software integration, and addressed the challenges in integrated production forecasting. The results prove that this is a powerful tool for short- and medium- term forecasting, enabling asset managers to plan field operations, drilling, workovers, and facility improvement projects This paper describes an integrated production forecasting setup. The case study explains process steps, challenges, simplification and results. The modeling and integration process enables the asset operator to plan remedial subsurface and surface projects to sustain planned rates over time. The forecasting process helps in quick business decision making, thus minimizing uncertainties in deliverability of future production mandates and highlights production-enhancement opportunities.
Abstract The wave velocity is defined theoretically by the Newton-Laplace equation, which relates the wave velocity, V, to the square root of the ratio of the elastic modulus, M, and density, ρ. Therefore, the equation indicates that the velocity is inversely proportional to density. However, the in-situ field measurements and laboratory experiments of compressional wave velocity through different rocks show otherwise, where the velocity is directly proportional to approximately the 4th power of density as stated by Gardner's numerical approximation. To clarify the apparent contrast between theory and observations, a new expression for the elastic modulus, M, is derived using Wyllie's time average equation and the Newton-Laplace equation. The new derived expression of the elastic modulus, M, provides dependence of M on density to approximately the 9 power, which subsequently results with the observed dependence of velocity on the 4 power of density. In addition, Gardner's equation is modified to accurately obtain the velocity over range of densities (from 1 g/cm to around 3 g/cm). The findings are tested on real velocity and density well-log data. The results validate the derived expression of the elastic modulus as well as the generalized form of Gardner's equation.
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.66)
Strategy Towards Unlocking and Accelerated Development of Low Permeability, Microporous Reservoirs-II
Kumar, Kamlesh (Petroleum Development Oman) | Awang, Zaidi (Petroleum Development Oman) | Azzazi, Mohamed (Petroleum Development Oman) | Hamdi, Abdullah (Petroleum Development Oman) | Hughes, Brendan (Petroleum Development Oman) | Abri, Said (Petroleum Development Oman)
Abstract The microporous rock types in Upper Shuaiba are low permeability (~ 1mD) rocks occurring in thin (2-5 m) formations within the extensive Upper Shuaiba carbonate formations in Lekhwair. These microporous rocks constitute a significant volume of hydrocarbon in-place. Unlike the higher quality rudist-rich and grainstone rock types, appraisal pilots in the microporous areas have shown poor performance with waterflood development, which is the preferred development concept in the entire Lekhwair field. Two work streams are active in parallel to identify a technically and commercially feasible development option: Phase 1, technology trials to enable a successful waterflood implementation, and Phase 2, further studies to screen the potential of enhanced oil recovery (EOR) techniques and other light tight oil development. The technology trial work stream, initially considered four initiatives targeting injectivity improvement. To date, trials are complete for abrasive jetting and designer acid stimulation, early results are available for Directional Acid Jetting, and evaluation of Fracture Aligned Sweep Technology (FAST) is ongoing with hydraulic fracturing evaluation accelerated to Phase 1 due to synergies with the FAST evaluation. Trial results to date: Abrasive Jetting: 7 trials complete, limited success in improving injectivity. Designer Acid Stimulation: 1 trial complete, no to limited injectivity improvement Directional Acid Jetting: implemented in 3 wells, injectivity improvement in early injection FAST: trial planning ongoing Hydraulic Fracturing: trial planning ongoing This paper discusses the encouraging results and learnings to date with regard to these new technology trials, and the early screening results for the implementation of gas injection as an alternate recovery mechanism.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Geological Subdiscipline > Stratigraphy (0.94)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.46)
Conformance Control Improvement by Coupling Microgel and Low Salinity Waterflooding in Fractured Reservoirs
Alhuraishawy, Ali K. (Missan Oil Company / Reservoir and Fields Development Directorate) | Sun, Xindi (Missouri University of Science and Technology) | Bai, Baojun (Missouri University of Science and Technology) | Wei, Mingzhen (Missouri University of Science and Technology) | Almansour, Abdullah (King Abdulaziz City for Science and Technology)
Abstract The recovery from fractured reservoirs is usually low. The areal heterogeneity is one result of the fractured reservoir. Low salinity waterflooding (LSWF) and preformed particle gel (PPG) have recently drawn great interest from the oil industry. LSWF can only increase displacement efficiency, and it has little or no effect on sweep efficiency whereas PPG can plug fractures and improve sweep efficiency, but they have little effect on displacement efficiency. The coupled method bypasses the limitations of each method when used individually and improves both displacement and sweep efficiency. The main objective of this study was to determine whether the coupling technologies can improve conformance control in fractured sandstone reservoirs. Before the study was conducted, the effects of low salinity waterflooding, number of fractures, and PPG strength were studied. The PPG was injected into the fracture at a flow rate of 2.0 ml/min. Brine was injected at a different flow rate after PPG placement to test the effect of flow rate on the PPG's plugging efficiency. Laboratory experiments showed that the oil recovery factor and the Frrw increased when the concentration of injected brine changed from conventional salinity to low salinity and the areal sweep efficiency was improved. However, the PPG extruded pressure decreased when the PPG swelled in a low-brine concentration. At a high-flow rate, there was no significant effect on the Frrw. Coupling two different EOR technologies can improve displacement and sweep efficiency and, in turn, enhance conformance control.
- Asia > Middle East (0.68)
- North America > United States > Oklahoma (0.47)