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Search: Acid treatment design
...Acid treatment design Once you determine that a well is a good candidate for matrix acidizing and have selected appropr...iate acids, you are ready to design the ...treatment. Essentially, the ...
Once you determine that a well is a good candidate for matrix acidizing and have selected appropriate acids, you are ready to design the treatment. Essentially, the design process is a systematic approach to estimating and calculating injection pressure and rate, volumes, and concentrations. If acid can easily reach nearby plugging solids, small volumes of 25 to 50 gal/ft of HF-type acid can dissolve this damage; however, with more severe damage, more time and volume are needed to reach the plugging solids. Effective acid diversion reduces acid volumes needed. The recommended steps in treatment design are: * Estimate safe injection pressures: determine present fracturing gradient, determine present bottomhole fracturing pressure, and determine allowable safe injection pressure at both the wellbore (at least 200 psi below fracturing pressure) and at the surface (tubing and wellhead pressure limitations).
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Geological Subdiscipline (0.77)
- Information Technology > Knowledge Management (0.41)
- Information Technology > Communications > Collaboration (0.41)
...well is a good candidate for matrix acidizing and have selected appropriate acids, you are ready to design the ...treatment. Essentially, the ...design process is a systematic approach to estimating and calculating injection pressure and rate, volumes...
Once you determine that a well is a good candidate for matrix acidizing and have selected appropriate acids, you are ready to design the treatment. Essentially, the design process is a systematic approach to estimating and calculating injection pressure and rate, volumes, and concentrations. If acid can easily reach nearby plugging solids, small volumes of 25 to 50 gal/ft of HF-type acid can dissolve this damage; however, with more severe damage, more time and volume are needed to reach the plugging solids. Effective acid diversion reduces acid volumes needed. Permeability and mineralogy determine the compatible concentration of HCl or acetic acid in the preflush stage and HF and HCl acid in the HF-/HCl-acid stage.
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.59)
- Geology > Geological Subdiscipline (0.54)
- Geology > Mineral (0.38)
- Information Technology > Knowledge Management (0.41)
- Information Technology > Communications > Collaboration (0.41)
...ктового коллектора на основе комплексного моделирования А.А. Мальцев 1,2 Sandstone (polymictic) acid treatment design 1 ООО «Газпромнефть НТЦ» optimization based on complex approach 2 Санкт-Петербургский горный...ft-ntc.ru Адрес для связи: Maltsev.AA@gazpromneft-ntc.ru Keywords: sandstone, acidizing, wellbore treatment, simulator, sandstone modelling, silica gel The well acidizing program is directly related to the ...efficiency of oil production. Common research that aimed at improving the efficiency of acid treatment in sandstone reservoir mainly includes the modification and adaptation of reagents to minimize form...
... Silin M.A., Neftepromyslovaya khimiya (Oilfield chemistry), Part 4. Kislotnaya obrabotka skvazhin (Acid treatment of wells): edited by Mishchenko I.T., Moscow: Interkontakt Nauka Publ., 2010, 703 p. 3. Blonsky A.,...
The well acidizing program is directly related to the efficiency of oil production. Common research that aimed at improving the efficiency of acid treatment in sandstone reservoir mainly includes the modification and adaptation of reagents to minimize formation damage that occurs due to the interaction of an acid with rock. To use new and unique acid compositions in real conditions is difficult because of organizational issues. Therefore, the traditional compositions based on a mixture of hydrochloric and hydrofluoric acids are commonly used on oilfields. The article is based on the approach of increasing the productivity of well by choosing the optimal design of treatment based on acidizing process modeling. The article describes aspects of practical implementation of the previously developed simulator of acid treatment of sandstone reservoirs, based on a numerical model of hydrodynamic and physicochemical processes in a porous medium based on unstructured PEBI-grids. The main uncertainties of the model are identified and analyzed. Here some issues that were included in current research: the density of colloidal silica formed as a result of the interaction between acid and rock, the influence of empirical parameters presented in main equations, and modeling of the mineralogical composition of the rock. The article describes an algorithm for static modeling of the near-wellbore zone for the purposes of acidizing modeling and an approach to optimize the treatment of near-wellbore zone based on the adaptation of the results of acid flow tests. The necessity of secondary and tertiary reactions modeling was approved. A number of calculations with the use of real data were carried out to determine the optimal volume of acid composition injection. Previous experience was analyzed and used for giving new recommendations to improve the acid treatment efficiency in researched and simulated conditions.
...SPE 168602 Acid Fracture ...Treatment Design with Three-Dimensional Simulation C.V. Oeth, A. D. Hill, and D. Zhu, Texas A&M University Copyrig...may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Acid fracture stimulation generates higher well production but requires engineering ...
... (3) 2 D The importance of the acid-etched width to the predicted conductivity is demonstrated in these correlations where the 2.5 co...nductivity is approximately proportional to w . It is important therefore that the acid-etched width be accurately i determined to understand the conductivity resultant from a particula...r acid fracture ...
...tched-fracture conductivities." Various commercial software packages are available to calculate the acid-etched width and Nierode-Kruk conductivity from an ...acid fracture ...treatment. These simulators prioritize solving the geomechanical propagation of the fracture, which depends o...
Abstract Acid fracture stimulation generates higher well production but requires engineering design for treatment optimization. To quantify the cost and benefit of a particular acid fracture treatment an engineer must predict the resulting fracture's conductivity distribution. Current practice is to estimate conductivity distribution utilizing two-dimensional models. Unfortunately, these models can misrepresent the amount of acid etching upon which the conductivity estimation is based. A new modeling tool has been developed to estimate fracture conductivity and is used to evaluate different acid fracture treatment designs. The tool uses three-dimensional flow simulation to resolve acid transport in a fracture. This approach includes resolution of the three-dimensional fluid velocity throughout the fracture, fluid pressure, the acid concentration profile, and the acid-etched width. By using a fine grid in the direction of transport to the fracture surfaces, convective and diffusive transport of acid to the fracture surfaces are modeled. The acid-etched width distribution and other formation information are used to calculate the resulting conductivity distributions for different treatment designs. The output acid-etched width and conductivity distributions for different acid fluid systems, fracture geometries, geologies, and completion designs are calculated. The industry lacks a reliable tool for acid fracture treatment design. The modeling tool presented in this paper attempts to address this problem with rigorous simulation of acid transport and etching in a fracture. The parametric study illustrates the benefits and drawbacks to this approach.
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.95)
...SPE 37434 Society of Petroleum Engineers The Evolution of Acid Fracturing ...Treatment Design in the Embar Carbonate, Oregon Basin Field, Wyoming F.R. Hail, SPE, and R.J. Whisonant, SPE, Mara... Richardson, TX 75083-3836, U.S.A, tax 01-972-952-9435. Abstract This paper describes stimulation treatment design changes and improvements over the past few years in the Embar carbonate formation in the Oregon B...
...ier exists between the porosity changes. Laboratory studies of Oregon Basin Embar core indicate an acid solubility of 94% at a bottomhole temperature of 1 10 F. Step-rate test work done in the early 19...ing water cuts average over 97% with gas/oil ratios (GORs) generally less than 450. Evolution of Acid Fracture ...Treatment Design Acidizing jobs have been performed in the Embar formation in Oregon Basin since the early 1940s, ...
...SPE 37434 THE EVOLUTION OF ACID FRACTURING ...TREATMENT DESIGN IN THE EMBAR CARBONATE 3 Because high pump rates increased the rate of pressure drop, pumping rat...es were decreased. The first attempt at a ramped pumped rate was in December 1995. This treatment was started at a rate of 8 bbl/min. The rate was increased each time the pressure stabilized unti...
Abstract This paper describes stimulation treatment design changes and improvements over the past few years in the Embar carbonate formation in the Oregon Basin Field of Park County, Wyoming. These design changes have increased productivity and reserves, reduced producing water/oil ratios (WORs), and decreased workover costs. The Embar is characterized by a low-permeability, low-porosity interval immediately above an interval with higher permeability and porosity. The lower Embar has largely been swept during waterflooding operations, with the upper Embar very near original oil saturation. Acid fracture treatments have been modified over time to allow for more effective stimulation of the upper Embar interval, resulting in the recovery of reserves that were not previously being depleted. This paper discusses the evolution of treatment design, the methodology behind the design changes, and the continued improvement in results. Treatment design has evolved from gelled acid to nitrogen-foamed acid at relatively high pump rates (12 to 15 bbl/min) to foamed acid at low pump rates (4 to 10 bbl/min). The acid used in most of the treatments has been 28% HCl. The intent of the current foamed acid treatments is to maximize stimulation of the highly oil-saturated upper Embar while minimizing stimulation of the more highly water-saturated lower Embar. Introduction Processed openhole logs from infill wells in the Oregon Basin Field indicated that the uppermost portion of one of the primary producing intervals was not being depleted by waterflooding operations, and the lower portions of the interval were exhibiting higher water saturations (Fig. 1). Acid fracturing techniques have been modified and optimized over the past few years to target the higher oil saturation interval through the use of nitrogen-foamed acid. The resulting treatments generate improved oil recoveries at reduced costs and have allowed a number of wells to be stimulated that would not have been if previous stimulation techniques had been used. This paper discusses the characteristics of the reservoir interval being stimulated, its fluid properties, and the evolution of treatment design over the last few years. It also discusses the reasoning behind the changes that were made and the result of the changes compared to previous gelled and ungelled acid treatments. The basic premise behind the nitrogen-foamed treatments is the use of gravity segregation within the created (or existing) fracture to more effectively stimulate the upper portion of the fracture. Additionally, treatment design has been modified to achieve a constant-to-slightly-increasing bottomhole pressure throughout the pumping of the treatment. Field and Reservoir Description The Oregon Basin Field is located in the Big Horn Basin of northwestern Wyoming. The field consists of two doubly plunging asymmetrical anticlines, called the North and South domes. The formation being treated with the acid fracture stimulations discussed in this paper is the Embar (or Phosphoria as it is called in other parts of the Big Horn Basin). It is productive in both domes and throughout the saddle area between the North and South domes. The Embar is unitized with and produced commingled with the underlying Tensleep sandstone throughout the field. The Embar interval in Oregon Basin has been waterflooded since the early 1960s, originally with peripheral injection and later being expanded to five-spot with some line drive. Portions of the field were polymer flooded in the 1980s. Although the field-wide waterflood has been highly successful, the natural fracturing in the field makes it less efficient, with very rapid breakthrough occurring in some directions. Cycling of water through high-porosity/high-permeability intervals, and induced or natural fractures has resulted in those intervals being very well swept, while the lower-porosity intervals are relatively undepleted. P. 407^
- North America > United States > Wyoming > Bighorn Basin > Oregon Basin Field > Tensleep Formation (0.99)
- North America > United States > Wyoming > Big Horn Basin > Oregon Basin Field > Tensleep Formation (0.99)
- North America > United States > Utah > Dinwoody Formation (0.99)
- (4 more...)
...SPE-172213-MS Optimizing Acid Stimulation ...Treatment Design in South Ghawar Power Water Injectors Wells Hasan Tammar, Mortada Alkadem, and Ahmed Jandal, Saudi...may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract Acid proved an efficient near wellbore skin damage removing agent in carbonate production and injection ...
...ion in wireline or major invoice operations. These nonacid soluble damaging materials can cover the acid-soluble deposits and act as a diffusion barrier. The solvents can be emulsified with ...acid to create an ...acid-in-solvent dispersion, to remove inorganic scale, rust or other plugging agents that were coated wi...
...SPE-172213-MS 6 Fig. 5 Well no. (AA-1) casing pickling operation parameters The treatment was pumped as per the program ...design. Fig. 6 highlights the reaction of the formation when organic solvent, 20% HCl, 20% SXE and 20% VDA... acid were injected into the formation. The sequence of pumped fluid during the job execution is also hig...
Abstract Acid proved an efficient near wellbore skin damage removing agent in carbonate production and injection wells. Nevertheless, improving acid stimulation design is a continuous need in oil industry. Formation analysis logs for some of South Ghawar power water injectors have shown a significant amount of residual oil dominating the open hole interval. This phenomenon results in wells transmissibility reduction, which reflects negatively on injection rate. A unique type of de-paraffin organic solvent was recently introduced to acid treatment design in South Ghawar PWIs to tackle injection impediment caused by high irreducible oil saturation. This solvent demonstrated a great capability in removing and flushing off residual oil, wax and asphaltene deposits in the reservoir matrix. Adding this solvent to pre-flush the rock enhanced the main acid treatment propagation into the reservoir, as well as water injection afterwards. This paper presents the influence of the organic solvent on some of South Ghawar horizontal and vertical PWIs performance after acid treatment. It will also compare the injectivity of wells — with similar parameters and properties — that were acidized without adding this organic solvent in treatment. Differences in results due to modification of this product will also be discussed.
- North America (0.68)
- Asia > Middle East > Saudi Arabia > Eastern Province (0.28)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Complex acid-solvent treatment design and practice for Jurassic-Cretaceous carbonate formation of the Varadero oilfield (the Republic of Cuba) (Russian)
Folomeev, A. E. (RN-BashNIPIneft LLC) | Khatmullin, A. R. (RN-BashNIPIneft LLC) | Imamutdinova, A. A. (RN-BashNIPIneft LLC) | Kashtanova, L. E. (RN-BashNIPIneft LLC) | Nazarova, S. V. (RN-BashNIPIneft LLC) | Sharifullin, A. R. (Ufa State Petroleum Technical University) | Mityukov, A. V. (RN-Exploration LLC) | Krylova, M. V. (RN-Exploration LLC) | Voloshin, A. I. (RN-BashNIPIneft LLC) | Pestana, F. S. E. (CEINPET) | Garrido, L. V. L. (CEINPET)
...рально-Восточный блок (Республика Куба) А.Е. Фоломеев 1 , к.т.н., А.Р. Хатмуллин 1 Complex acid-solvent ...treatment design and practice , for Jurassic-Cretaceous carbonate formation of the А.А. Имамутдинова 1 , Var...rosneft.ru, FolomeevAE@gmail.com 1 ООО «РН-БашНИПИнефть», 2 Уфимский гос. нефтяной Keywords: acid treatment, Varadero, the Republic of Cuba, matrix ...
...Фоломеев, Ю.А. Котенев, Р.М. Набиуллин // Нефтяное хозяйство. - 2016. - 4. - С. 112-117. 16. Gelled Acid vs. Self-Diverting Systems for Carbonate Matrix Stimulation: an Experimental and Field Study / A.E...ww.arlis.org/docs/vol1/A/289003955/289003955b.pdf 5. Gonsales P.E.O, Ramires A.B., Drilling strings design for construction of extended reach wells (on the example of Cuba), Neftegazovoe delo, 2019, V. 17, ...p://dx.doi.org/10.17122/ngdelo-2019-5-15-22 6. Gusakov V.N., Kashtanova L.E., Nazarova S.V. et al., Design of technologies for processing bottom-hole zone of Varadero oilfield (Cuba) (In Russ.), Neftyanoe k...
Foreign projects for Rosneft Oil Company are one of the key areas for the hydrocarbon resource base development. Currently, Rosneft is running projects in Myanmar, Egypt, Iraq, Cuba and offshore of Mozambique. One of the special projects is the Varadero field on the territory of the Republic of Cuba. The oil bearing capacity at the field is found in the Upper Jurassic and Lower Cretaceous carbonate formations. The Varadero oil is a typical representative of the naphthenic oils of the North Cuban Oil Basin by its physico-chemical properties. It is characterized by high viscosity and density, significant content of resin-asphaltene compounds and sulfur. One of the essential activities during oil production at the Varadero field is the well stimulation and mitigation response in well operation. In relation to the object under consideration, it is possible to distinguish the fight against the formation of high-viscosity oil-water emulsions, the deposition of high molecular weight components and oilfield equipment corrosion. To restore the wells productivity and keep oil production at required level, it is recommended to use complex acid treatment technologies with use of organic solvents. The article provides an algorithm for designing complex acid treatment technologies for the conditions of the Varadero field, based on a series of laboratory studies on the selection of acid compositions and solvents for cleaning the critical matrix from asphaltene deposits. The results of acid treatments are presented and an analysis of their effectiveness is performed.
- North America > Cuba > Matanzas > Varadero (1.00)
- Europe > United Kingdom > North Sea > Central North Sea (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.81)
- North America > Cuba > East Central Block > Varadero Field (0.99)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Upper Marrat Formation (0.94)
- Asia > Middle East > Kuwait > Jahra Governorate > Arabian Basin > Widyan Basin > North Kuwait Jurassic (NKJ) Fields > Marrat Formation > Sargelu Formation (0.94)
...SPE 166885 Approach to Optimization of Acid Treatment in Oil Reservoirs Volnov I.A., Suchok S.N., Obsharov P.A., LUKOIL Overseas Service B.V. Copyright...wledgment of SPE copyright. Abstract The mathematical model of two-phase displacement of oil by an acid aqueous solution in the neighborhood of a well and a hydraulic fracture [1] was used for investigat...ion processes of optimization acidizing and acid fracturing. It takes into account the kinetics of ...
...SPE 166885 3 r s dr r s S k 0 ln k ( r ) r r w r w In the case of acid hydraulic fracturing the skin-factor is estimated as follows [7]: ξ s 2r w d ξ S ln k 0 ξ ...s were made to determine the effect of injection rate on the skin-factor at the given volume of the acid solution. Fig. 1 demonstrates results obtained at the solution volume of 30 m3. Initially, a reduct...ion of the injection rate accompanied by a corresponding increase in treatment time causes the skin-factor to descend, i.e. the acidizing efficiency improves. However, the furthe...
...4 SPE 166885 maximum effect of acid treatment for a given solution. The calculations showed that in the case of ...acid hydraulic fracturing the significant slowing of the reaction rate may lead to large leakages of the... unreacted acid into the reservoir, extending the penetration zone but reducing the effects in the neighborhood of ...
Abstract The mathematical model of two-phase displacement of oil by an acid aqueous solution in the neighborhood of a well and a hydraulic fracture [1] was used for investigation processes of optimization acidizing and acid fracturing. It takes into account the kinetics of acid dissolution of a carbonate rock. The proposed model allows us to improve the process of searching and selecting the best design for acidizing and acid fracturing. The effect of well acidizing and acid fracturing are estimated. It is shown possibility to find the best value of such parameters as the speed of injection, speed of reaction and volume of acid mixture injected into a well during acidizing and acid fracturing. At given process parameters in the real case is shown importance of studying the process of interval treatment including the possibility of optimizing the design of each of the treated intervals. The control of such parameters as the injection rate, the chemical reaction rate and the volume of injected acid makes possible to reach the maximum treatment effect at the given solution volume. Also calculations showed that in the case of the acid fracturing the significant slowing of the reaction rate may lead to large leakage of unreacted acid into the reservoir, extending the penetration zone, but also reducing the effects near the fracture and thus worsening the result of treatment. The created model was applied to numerical calculations for real cases. Field and calculated data are in good agreement. Using of this approach allows us to find the ways for new possibilities in improving design of acid treatments and understand the current status of the proposed design.
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.49)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.41)
- Well Completion > Acidizing (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.49)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (0.41)
- Reservoir Description and Dynamics > Fluid Characterization > Phase behavior and PVT measurements (0.30)
...Society of Petroleum Engineers SPE 26185 Improved Acid Fracturing ...Treatment Designs Based on In-Situ Temperature Calculations L.P. Roodhart, Koninklijke/Shell E&P Laboratoriu...836, Richardson, TX 75083-3836, U.S.A. Telex, 163245 SPEUT. SUMMARY INTRODUCTION The objective of acid-fracturing well stimulation in Successful ...
...2 IMPROVED ACID-FRACTURING ...TREATMENT DESIGN BASED ON CALCULATION SPE 26185 OF IN-SITU TEMPERATURE PROFILE the fluid heats up as it travels thro...s well as by heat produced by the thermal conductivity taking the conductivities of both exothermic acid/rock reaction. the solid rock and of the fluid phase into account. It should be noted that the flu...
...4 IMPROVED ACID-FRACTURING ...TREATMENT DESIGN BASED ON CALCULATION SPE 26185 OF IN-SITU TEMPERATURE PROFILE cooling. It turns out that the rate o...y variations in the leakoff CASE HISTORIES rate. The second effect is of importance only if the An acid-fracturing technique based on viscous following dimensionless number is of the order of fingering w...
Summary Successful acid-fracturing treatment requires the creation of etched channels of sufficient width and length. This paper shows how the channel shape can be calculated using knowledge of the acid/rock reaction process, in-situ temperature and hydraulic profile. A simulator has been developed for this purpose, on the basis of an implicit finite-difference scheme permitting rigorous treatment of all relevant processes, such as the cooling of the rock adjacent to the fracture and the heat transfer between fracture and wall during and after pumping, is employed. Detailed knowledge of the temperatures of both the fracture fluid and the rock face allows quantitative description of the progress of the acid/rock reaction. Model calculations show that the channels etched in calcitic rock may be very wide near the wellbore because of turbulence effects. On the other hand, the etched channels may be too narrow in dolomitic rock, or rock with a low fracture toughness. This will impair well productivity, and should be avoided by modifying the pumping scheme. Two field examples of treatment design and evaluation using the new simulator are discussed. Introduction The objective of acid-fracturing well stimulation in carbonate rock is to facilitate the flow of reservoir fluids to the wellbore by creating long, conductive, acid etched channels. Acid, sometimes preceded by a viscous flush, is pumped downhole above fracturing pressure. The acid etches channels in the fracture walls, which are required to remain open after the treatment when the fracture has closed. The increase in productivity resulting from such treatment is strongly dependent on the width, length and conductivity of the channel formed. Viscous fingers may be formed depending on the mobility ratio of the fluid stages. Channel dimensions can only be predicted if the in-situ kinetics of the reaction between the rock and the acid is known. The reaction rate at any point on the fracture surface is critically dependent on the local temperature in the fracture during the treatment, which in turn depends on the in-situ energy exchange. The fluid velocity in a viscous finger is higher than that in the surrounding gel. This effects the local the energy balance and hence the local reaction rate. The in-situ heat transfer during acid fracturing is depicted in Fig. 1. Cold fluid is pumped into the fracture mouth, where it cools the fracture face and the interior of the rock adjacent to the fracture by both conduction and fluid leak-off. P. 477^
- North America > United States (0.68)
- North America > Canada > Alberta (0.28)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Geological Subdiscipline > Geomechanics (0.89)
...SPE 101344 Evaluation of Acid Treatment Results for Water-Injector Wells in Saudi Arabia M.S. Al-Harbi, SPE, A.M. Al-Dhafeeri, SPE, Y.A Al... Copyright 2006, Society of Petroleum Engineers fluid was used to improve the diversion process in acid This paper was prepared for presentation at the 2006 SPE Annual Technical Conference and stimulat...ion treatment of water injector wells. 2 In addition, Exhibition held in San Antonio, Texas, U.S.A., 24-27 S...
...2 SPE 101344 restore the Injectivity by creating deep "worm holes" using a retarded acid system. Table 1: ...Treatment details After tools rig up and wing valve closing, the following Stage Interval Fluid Description ...treatment in the sequence listed below in Table 1, were pump at maximum injection rate and below fracture pre...
...of Diesel Emulsified volume have Conclusions increasing in Injectivity index for tight formation as Acid treatment with stages using viscoelatic surfactant shown in figure 2. system was successfully conducted on b...al conclusions were obtained from this study: wells. 1. Increasing the volume of Diesel Emulsified Acid in ...acid treatment stages will lead to improve well's Diesel Emulsified VS II CHANGE Injectivity. Horizantal wells ...
Abstract Several acid treatments were conducted in the Ghawar filed to increase the well injectivity and to support the reservoir pressure in this area. Vertical and horizontal wells with an open hole completion in a carbonate reservoir were selected to be a candidate for post acid treatments evaluation study. These wells were stimulated using hydrochloric and emulsified acid with foamed viscoelastic-based water. Viscoelastic-based water system was used to enhance the diversion mechanism and the lifting process for the spent acid following the treatment. In this paper new correlations for acid treatment design were obtained from an extensive study of several case histories that can be used for optimizing future acid treatments design in the Ghawar field. This study was mainly utilized the results from the post acid treatment jobs in terms of HCl acid, emulsified acid and viscoelastic volume correlated with the well's injectivity. Based on the study results, there is a strong relationship between the emulsified acid volumes with the injectivity index for the selected wells. Introduction The objective of matrix acidizing treatment is to remove or bypass formation damage by pumping the alternating acid stages into reservoir formation below fracturing pressure. In a carbonate matrix acidizing, an acid program is designed to create a wormhaoles that can produce a high permeability region radically around the wellbore leading in exceeding the natural permeability of the reservoir. Foamed viscoelstic based-acid system was used for first field application to obtain an efficient diversion process of Saudi Aramco field operation. Viscoelastic surfactant fluid was used to improve the diversion process in acid stimulation treatment of water injectorwells. In addition, this chemical was successfully used to enhance the HCl viscosity during acid placement in horizonlly oil wells. However, Polymer-based acids are not recommended to be used any more as a divertor in acidizing treatments for Saudi Aramco fields especially into low reservoir quality such as low permeability formation, due to residue effect which it might cause formation plugging. Therefore, vicoelastic surfact-based fluid is wildly used in acidizing a corabonte reservoir as a divertor fluid in both a producer and an injector wells when acid reacts with a formation leading to increase HCl viscosity solution and it can divert live acid into less permeable zones. Minimizing formation damage that occurs in power water injection wells is a critical point for increasing well potential and Injectivity index. In this paper, several types of chemicals were used in stimulation treatment such as plain acid, Diesel Emulsified Acid, foam and surfactant. Different volumes were pumped in each acid stimulation jobs based on the pay zone intervals. However, the volume of each chemical should be optimized to obtain high rate of succeed in acid stimulation results. In this paper, we applied a statistical study to obtain a correlation between volume of chemicals and Injectivity index at the same condition such as type of well completion, formation properties, and type of techniques that used in the job. Based on collected data, we obtained a good correlation between the Injectivity index and injected chemicals. Wells History Several wells were drilled as open hole water injector. The lithology of the reservoir is manly calcite with small volume of dolomite. Some of these wells weredrilledand completed as horizontal with open hole section length 1500 ft- 2800 ft and other wells weredrilledand completed as vertical with open hole section length 200 ft- 350 ft. These power water injection wells are located in Ghawar field.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Middle East Government > Saudi Arabia Government (0.98)
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (0.81)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Lower Fadhili Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff D Formation (0.99)
- Asia > Middle East > Saudi Arabia > Eastern Province > Al-Ahsa Governorate > Arabian Basin > Widyan Basin > Ghawar Field > Khuff C Formation (0.99)
- (4 more...)