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Results
Effects of Near-Wellbore Supercharging and Hydro-Mechanical Coupling on Pressure Response for Formation Testing While Drilling
Peng, Nian (Southwest Petroleum University, Chengdu) | Ma, Tianshou (Southwest Petroleum University, Chengdu) | Chen, Ping (Southwest Petroleum University, Chengdu) | Qiao, Yu (Southwest Petroleum University, Chengdu)
Abstract Formation testing while drilling (FTWD) shows a great potential for characterizing reservoir type, estimating reserves, and determining reservoir energy. With the increasing in unconventional reservoirs, however, the utilization of FTWD has encountered some challenges. The near-wellbore formation prior to conducting the formation testing is usually supercharged due to the mud filtrate invasion during drilling. The supercharged pore pressure can directly influence the pressure response of FTWD. If the pressure response curves are misinterpreted, it may bring some mistakes or risks to engineering design. In addition, the formation testing process is a hydro-mechanical (H-M) coupling process, and the variation of pore pressure in formation can change the porosity and permeability of the rock, which will in turn affect the pressure response of formation testing while drilling. To clarify the effects of near-wellbore supercharging and H-M coupling on pressure response of FTWD, a three-dimensional simulation model of FTWD was built and the pressure responses with different parameters were analyzed. The simulated results indicated that: In the supercharged condition, the initial probe pressure is higher than the original pore pressure. And during the pressure recovery stage, the probe pressure rises above the original formation pressure in the early part of the build up and then decreases to reach the equilibrium state. Also, the supercharging effect can result in the overestimation of the original formation pressure. The H-M coupling can produce an extra coupling skin on the pressure response of FTWD, and H-M coupling can contribute to the underestimation of the original formation mobility. The results of this paper can help us to understand the pressure response behavior and improve the formation parameter interpretation accuracy of FTWD. Introduction Formation testing while drilling (FTWD), as shown in Fig. 1, has been widely used in offshore, extended reach, and horizontal wells as it is characterized by high precision and real-time performance (Di et al., 2014; Ma et al., 2015). The original formation properties, such as formation pressure and mobility, can be determined based on the pressure response curve of FTWD and those parameters are important for characterizing the type of reservoir, estimating the geological reserves, and determining the reservoir energy (Ma et al., 2018). However, as unconventional reservoirs increase, using FTWD data to evaluate the original formation properties has encountered some challenges.
Iron Carbonate Scale Inhibitor Selection for Low-Permeability, High-Temperature, Low-Pressure, and Low Water-Cut Gas Wells in Chalk Formation
Al-Ghamdi, Tawfik (Halliburton Multi-Chem Service) | Chen, Ping (Halliburton Multi-Chem Service) | Hagen, Thomas (Halliburton Multi-Chem Service) | Hamam, Mohamed (Halliburton Multi-Chem Service) | Shakeel, Muzzammil (Halliburton)
Abstract Scaling problems were identified in a typical tight carbonate gas reservoir. Selecting an effective iron carbonate scale inhibitor in low-permeability (≤ 1 mD), high-temperature, low-pressure, and low water-cut gas wells of this reservoir type can be challenging. The scale treatment strategy focused on the application of a downhole scale inhibitor squeeze treatment as one of the most effective methods for controlling scale deposition from the reservoir to the wells. The scaling index from the scale prediction work indicated a moderate to high scaling potential for siderite and calcite. This paper concentrates on the selection of a scale inhibitor to inhibit scale formation of siderite and calcite under downhole conditions. The approach used to select the most appropriate scale inhibitor formulation consisted of a series of laboratory screening tests, such as anaerobic dynamic scale loop tests and static compatibility tests. Based on the testing results, the performance of the selected scale inhibitor was evaluated under anaerobic dynamic conditions at high temperature and high pressure on a dynamic loop rig. The dynamic loop test results provide a low MIC of 5 ppm for the qualified scale inhibitor. Additionally, a coreflood experiment was conducted to evaluate potential formation damage to the limestone reservoir. The results indicate that the scale inhibitor brine at the tested concentrations did not cause damage to the core. The regained permeability of the core plug was greater than 90% after scale inhibitor injection under the reservoir conditions. The static compatibility tests were also conducted to evaluate 10% scale inhibitor compatibility with the brine as well as the field condensate to confirm that the selected scale inhibitor was fully compatible with the contacting fluids. The novelty of laboratory testing for the selected scale inhibitor to inhibit iron carbonate scale formation has led to a field trial, and a scale inhibitor squeeze treatment was performed successfully.
- Europe (0.94)
- North America > United States (0.69)
- Asia > Middle East (0.47)
- Geology > Mineral > Sulfide (0.69)
- Geology > Rock Type > Sedimentary Rock (0.48)
- Geology > Mineral > Carbonate Mineral > Calcite (0.46)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Mechanics of Hydraulic-Fracture Growth from a Wellbore Intersecting Natural Fractures
Liu, Yang (Southwest Petroleum University, University of Melbourne, and CSIRO Energy) | Chen, Ping (Southwest Petroleum University) | Wu, Bisheng (Tsinghua University) | Ma, Tianshou (Southwest Petroleum University) | Wu, Bailin (CSIRO Energy) | Zhang, Xi (CSIRO Energy) | Jeffrey, Robert G. (SCT Operations)
Summary The creation and propagation of hydraulic fractures (HFs) emanating from a well in a naturally fractured rock is important not only to the success of fracturing treatments, but also for interpretation of the data from diagnostic fracture injection tests (DFITs). In this paper, we consider the reservoir rock to consist of an impermeable rock matrix and a system of discrete natural fractures (NFs) that are permeable. The well is assumed to intersect two sets of NFs at their midpoints, and injection into the wellbore might open the NFs and/or create new fractures that extend along the maximum‐principal‐stress direction. Both new fractures and pre‐existing NFs can act as either a main HF or a fluid‐loss path. In this near‐well transient‐fracture analysis, the NFs are short segments characterized by size, orientation, and aperture. A fully coupled HF model is used to investigate the interaction between the fractures to determine how the fluid injected is distributed to the fractures for a range of stress, fluid‐injection‐rate, and NF‐geometry conditions. We find that a more‐isotropic stress condition and a lower value of the fluid‐viscosity/injection‐rate product favor propagation of NFs. These conditions cause the NFs to accept more fluid, and, as a result, the growth of new fractures is suppressed. The post‐shut‐in pressure responses for the cases with propagating new fractures and nonpropagating NFs are studied.
- Asia (0.93)
- Europe (0.92)
- North America > United States > Texas (0.68)
- North America > United States > California (0.67)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type (0.93)
Development of Novel Test Methodology to Understand the Mechanisms of Halite Inhibition and Environmentally Acceptable Halite Scale Inhibitors for High Temperature Application
Ho, Kimberley (Nalco Champion, an Ecolab Company) | Chen, Tao (Nalco Champion, an Ecolab Company) | Chen, Ping (Nalco Champion, an Ecolab Company) | Hagen, Thomas (Nalco Champion, an Ecolab Company) | Montgomerie, Harry (Nalco Champion, an Ecolab Company) | Benvie, Ronald (Nalco Champion, an Ecolab Company)
Abstract Halite deposition is most commonly observed in gas/gas condensate fields with low water cut, high TDS produced brines and high temperature. Halite is notoriously difficult to inhibit and there are limited studies focused on halite due to it being incredibly challenging to have an effective test methodology under laboratory conditions that reflect the field conditions. The mechanisms of halite inhibition are unclear. In the published literature, static jar testing is primarily used to evaluate the performance of halite inhibitors. It is not representative of dynamic field conditions and provides limited information of halite inhibition. A new methanol driven dynamic test methodology has been developed alongside a novel jar test procedure, which together provides an effective methodology to evaluate halite inhibition under both static and dynamic conditions and provides an insight into the understanding of the mechanisms of halite inhibition. Using these novel test methodologies, four short-listed inhibitor chemistries including environmentally acceptable inhibitors were assessed and categorised into two types based on the understanding of the mechanism. ➤ Nucleation/growth inhibitors. Inhibitors reduce the nucleation/growth of halite crystals and give good performance under both static and dynamic test conditions. ➤ Dispersion inhibitors. Inhibitor doesn't stop the nucleation/growth of halite crystals and gives poor performance under static conditions, but good performance under dynamic conditions due to dispersion effect. Both types of halite inhibitors have been successfully deployed in the fields through continuous injection or batch treatment. Coreflood tests were carried out to confirm the potential risk of formation damage during downhole batch treatment. Other deployment methods have been discussed such as through methanol injection line as both inhibitors are fully methanol compatible. This paper will give a comprehensive study of halite inhibition for challenged wells, including prediction, novel methodology, program of laboratory qualification, mechanism understanding and field deployment, coupled to the development of a chemical technology toolbox to design field halite applications. The value that a fuller understanding of halite control gives the industry is the ability to reduce/eliminate water wash application to control halite formation and so improve well operation time. If halite inhibition is considered at the capex phase of field development, provisions can be made for chemical injection facilities to maintain uninterrupted production.
- Europe > Norway (0.28)
- Europe > United Kingdom (0.28)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Development of a New Squeeze Scale Inhibitor for Mitigating Formation Damage for High TDS High Temperature Tight Carbonate Reservoir
Chen, Tao (Nalco Champion, an Ecolab Company) | Lewis, Jennifer (Nalco Champion, an Ecolab Company) | Chen, Ping (Nalco Champion, an Ecolab Company) | Benvie, Ronald (Nalco Champion, an Ecolab Company) | Hagen, Thomas (Nalco Champion, an Ecolab Company) | Montgomerie, Harry (Nalco Champion, an Ecolab Company)
Abstract The development of effective scale squeeze inhibitors in tight carbonate reservoirs with permeability less than 5md is still a big challenge, especially for high Total Dissolved Solids (TDS) and high temperature wells. The formation damage is one of the major considerations in high TDS, high temperature, and tight carbonate reservoirs as it can be caused due to fines mobilization, carbonate reservoir dissolution and collapse, and scale inhibitor compatibility issues. For the development of any scale inhibitor for squeeze application, the product must also demonstrate good inhibition performance, long squeeze life and accurate residual analysis at low concentrations. This paper will demonstrate a logical design procedure to develop a new scale inhibitor suitable for a challenging high TDS, high temperature tight carbonate reservoir through squeeze application. The new scale inhibitor has been shown to be nondamaging to tight carbonate reservoir material under high temperature high TDS conditions, along with excellent retention and release characteristics. The results of a comprehensive testing program, including compatibility, formation dissolution, dynamic tubing blockage and core flood tests will be presented that will highlight the development of a non-formation damage scale inhibitor suitable for the high TDS high temperature tight carbonate reservoir. In addition, the potential mechanisms of formation damage will be addressed. The impact of calcium tolerance, pH and molecular chemistry, carbonate reservoir dissolution and lab test procedure will be discussed compared to some traditional phosphonate and other polymeric scale inhibitors.
- Europe (1.00)
- North America > United States > Louisiana (0.28)
- Geology > Mineral (0.47)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.46)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Foamed Scale Inhibitor and Scale Dissolver Treatments for Improved Placement in a Subsea Norne Well
Selle, Olav Martin (Statoil ASA) | Nygård, Ole-Kristian (Statoil ASA) | Storås, Elisabeth (Statoil ASA) | Moen, Arild (Statoil ASA) | Chen, Ping (Champion Technologies) | Matheson, Rozenn (Champion Technologies) | Juliussen, Bjørn (Champion Technologies) | Håland, Torstein (Champion Technologies) | Mebratu, Amare (Halliburton) | Melien, Ingrid (Halliburton)
Copyright 2012, Society of Petroleum Engineers This paper was prepared for presentation at the SPE International Conference and Exhibition on Oilfield Scale held in Aberdeen, UK, 30-31 May 2012. This paper was selected for presentation by an SPE program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright. Abstract The success of chemical treatments to prevent or remove formation damage, depend on the placement efficiency. In down-hole scale control treatments, diversion techniques are applied for improved placement of scale dissolvers or scale inhibitors in the potentially productive intervals. Foamed scale treatment is a new diversion technology developed by the operator and two oil service companies. The new approach is to foam the scale inhibitor and scale dissolver solutions for improved placement of down-hole scale inhibitor squeezes and scale dissolver treatments. An additional benefit is that the gas used to create foam is perfectly suited for wells with low reservoir pressure and with no gas lift system in place. In theory the foamed fluid will enter the highly injective zones at a higher rate than the others so that the resistance to flow increases in the zones which have accepted the foamed fluid. The technical qualification of the foamed scale chemicals was divided into advanced bottle tests and dynamic flooding tests.
- Europe > Norway > Norwegian Sea (0.94)
- North America > United States (0.68)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Tofte Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Not Formation (0.99)
- Europe > Norway > Norwegian Sea > Halten Terrace > PL 128 > Block 6608/10 > Norne Field > Ile Formation (0.99)
- (16 more...)
Development of an Environmentally Friendly Polymer Scale Inhibitor for Tight Carbonate Reservoir Squeeze Treatment
Chen, Tao (Champion Technologies) | Benvie, Ronald (Champion Technologies) | Heath, Stephen Mark (Champion Technologies) | Chen, Ping | Hagen, Thomas Hille (Champion Technologies Ltd.) | Montgomerie, Harry (Champion Technologies)
Abstract A tight carbonate reservoir is one of the typical formations in the oil and gaswells. The unique feature of the subject reservoir is low permeability (2–5md). The formation damage, compatibility, residual analysis and squeeze lifeare still major challenges for the conventional scale inhibitor squeezetreatment in this kind of reservoir. The development of effective squeeze scale inhibitors to prevent the aboveproblems in BaSO4 scale scenario is still a big challenge, especially with theincreasing environmental constraints. For tight carbonate reservoirs, theformation damage is one of the major considerations since the formation damagecan be caused due to fines mobilization, carbonate reservoir dissolution andcompatibility issues. For the development of any product for squeezeapplication, the product must also demonstrate good performance on field scaleinhibition, long squeeze life and accurate residual analysis at lowconcentration. This paper will demonstrate a logical design procedure to develop anenvironmental friendly polymer scale inhibitor product suitable for challengingtight carbonate reservoir through squeeze application and will discuss themechanism of scale inhibitor retention with regard to selection and design ofsuitable scale squeeze inhibitors. Many scale inhibitors are either irreversibly retained in chalk reservoirs dueto uncontrolled precipitation reactions or are poorly adsorbed with bothprocesses resulting in short treatment lifetimes. A new polymeric scaleinhibitor chemistry, containing a special functional amine group to have a goodaffinity to the chalk reservoir, was developed to provide a balance betweenirreversible and poor retention and thus provide effective squeeze life. Theresults of a comprehensive testing program, including compatibility, formationdissolution, dynamic tubing blocking, static adsorption and core flood testswill be presented, that will highlight the development of polymer scaleinhibitor suitable for the tight carbonate reservoir, while meeting theenvironmental requirements for application in the UK and Scandinavia. Inaddition, a new residual detection method will be presented which willdemonstrate accurate scale inhibitor detection at low concentration (<1ppm)in high TDS water. Introduction Barium sulphate, BaSO4, is one of the most common scale deposits found inoilfields both in the North Sea and elsewhere. It can be deposited all alongthe water paths from injectors through the reservoir to the surface equipment1,2, 3. Barium sulphate is generally formed after seawater breakthrough, whenformation water containing barium mixes with seawater which is rich insulphate. Barium sulphate scale formation can impair production by blockage ofnear wellbore, tubing and flowlines, fouling of equipment and concealment ofcorrosion. The effects of scale can be dramatic and costs can beenormous4. Effective techniques are needed to solve the scale deposition and keepproducing wells healthy. In most cases, scale prevention through chemicalinhibition is the preferred method of maintaining well productivity. Scaleinhibitor squeeze treatments provide one of the most common and efficientmethods for preventing the formation of carbonate and sulphate scales in thenear wellbore and top facilities of production wells3.
- North America > United States > Texas (0.28)
- Europe > United Kingdom > North Sea (0.24)
- Europe > Norway > North Sea (0.24)
- (2 more...)
- Geology > Mineral (0.96)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (0.55)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > California > Sacramento Basin > 3 Formation (0.99)
- Europe > Russia > Volga Federal District > Perm Krai > Volga Urals Basin > Pavlovskoye Field (0.99)
Development of Non-Aqueous/Low Density Scale Inhibitor Package for Down-hole Squeeze Treatments
Chen, Ping (1 Champion Technologies) | Juliussen, Bjørn (1 Champion Technologies) | Vikane, Olav (1 Champion Technologies) | Montgomerie, Harry (1 Champion Technologies) | Benvie, Ronald (1 Champion Technologies) | Frøytlog, Cato (2 Statoil) | Haaland, Torstein (1 Champion Technologies)
Abstract Some of the wells in a North Sea field have a relatively low reservoir pressure. For those wells without gas lift installed, lifting heavy fluid out of the well when flowing back can be a problem. For this type of well, one of the options for the inhibitor squeeze treatments is to use a low density package to avoid pumping a large amount of relatively heavy brine based inhibitor. Through a research program, a polymer inhibitor and non aqueous solvent based package was developed for the squeeze treatments for the field. This paper will present the detailed discussions of the chemistry of the formulation package. A number of scale inhibitors were screened for the suitability with a low density solvent as a carrying fluid. Due to both environmental concern and different function groups attached on the inhibitors, very limited inhibitor candidates were found to be suitable for being formulated into the low density package. The paper will further present the laboratory evaluation results such as product compatibility, inhibitor partitioning from solvent to brine phase, inhibitor efficiency as well as core flood data. The paper will also present the field evaluation data. One well treated with this low density package squeezed a water based inhibitor with several times in the past. Due to the reservoir pressure depletion, the low density package was developed for the squeeze treatments. The same inhibitor used in the water based squeeze was formulated into the non-aqueous package. The field trial results show that none of the wells experienced lifting problems while back producing the inhibitor pill. In most of the wells, an improved oil production was seen and maintained for a while after the treatments. A possible mechanism for this will be discussed. In addition, a comparison was made between the treatments from the water based and non-aqueous squeezes.
- North America > United States > Texas (0.46)
- Europe > United Kingdom > North Sea (0.34)
- Europe > Norway > North Sea (0.34)
- (2 more...)
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.76)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (0.69)
- Europe > United Kingdom > North Sea > North Sea Basin (0.99)
- Europe > Norway > North Sea > North Sea Basin (0.99)
- Europe > Netherlands > North Sea > North Sea Basin (0.99)
- Europe > Denmark > North Sea > North Sea Basin (0.99)
Development of a New Polymer Inhibitor Chemistry for Downhole Squeeze Applications
Montgomerie, Harry (Champion Technologies) | Chen, Ping (Champion Technologies) | Hagen, Thomas Hille (Champion Technologies) | Vikane, Olav (Champion Technologies) | Matheson, Rozenn (Champion Technologies) | Leirvik, Vibeke (Champion Technologies) | Frøytlog, Cato (StatoilHydro) | Sæten, Jens Olav (StatoilHydro)
Summary Scale inhibitor squeeze treatments have regularly been conducted to prevent both sulphate and carbonate scale depositions in a specific North Sea field for more than 10 years. However, some wells, in which the fluid is producing from the "clean" sandstone formation, have experienced relatively short squeeze lives, when squeezing a conventional phosphonate scale inhibitor treatment. A research program has been conducted to develop a novel polymer scale inhibitor chemistry, which combines performance in a number of laboratory static and dynamic tests, with improved scale inhibitor adsorption properties on "clean" sandstone formations. Field trials have also been conducted with satisfactory results. This paper outlines the concept of how novel scale inhibitor chemistry was developed by incorporating a special monomer to make the final copolymer scale inhibitor. The monomer was introduced to enhance the inhibitor adsorption properties, because it carries a special functional group to improve the scale inhibitor affinity for the reservoir rock. This special functional group plays a key role for the newly developed scale inhibitor, to give improved and acceptable squeeze lives. A critical aspect of the program included optimizing the monomer content to achieve a good adsorption/desorption balance, to ensure that the scale inhibitor would be desorbed/released from the reservoir rock to meet the requirements of an acceptable squeeze program. An added bonus was that the environmental properties of the scale inhibitor polymer were also improved because of the introduction of the special monomer. A number of beaker and dynamic loop tests were conducted and the inhibitor showed an excellent efficiency in both sulphate and carbonate scale inhibition performance tests under the test conditions adopted. This paper also presents detailed laboratory and field data; the treatment design strategy and deployment method adopted for the scale inhibitor.
- North America > United States (0.68)
- Europe > Norway > North Sea (0.34)
- Europe > United Kingdom > North Sea (0.25)
- (2 more...)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.94)
- Geology > Mineral (0.69)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract Inhibitor squeeze treatments have been regularly carried out to prevent both sulphate and carbonate scale depositions in a North Sea field since 1990s. Some of the wells, in which the fluid is producing from the "clean" sandstone formation, had experienced a relatively short squeeze life when a conventional phosphonate scale inhibitor was squeezed. Through a research program, a polymer inhibitor was developed and a number of laboratory static and dynamic tests were conducted to evaluate the performances of the newly synthesized polymer inhibitor. Several field trials were also carried out with a satisfactory result. This paper outlines the idea of how the new inhibitor chemistry was developed and how a special monomer was introduced to make the co-polymer inhibitor. The monomer was introduced to enhance the inhibitor adsorption property since it carries a special function group to have a good affinity to the reservoir rock. This special function group plays a key role for the newly developed scale inhibitor to offer a good squeeze life. The amount of the monomer had to be optimized in order to achieve a good balance to make the inhibitor to be desorbed/released from the reservoir rock. In addition, the environmental property of the polymer was also improved due to the introduction of the special monomer. A number of beaker and dynamic loop tests were carried out and the inhibitor showed an excellent efficiency in both sulphate and carbonate scale inhibition under the test conditions. The paper also presents the detailed laboratory and field data. In addition, the treatment design strategy and deployment method of the scale inhibitor are discussed. Introduction Oilfield scale is a water-related problem and it is often associated with the production of brine in the field once wells start cutting water. In the North Sea, typical scale problems are related to the formation of BaSO4, SrSO4, CaSO4 and CaCO3. The severity of the problems and the need of novel solutions are highly dependent on the field operating conditions, which vary from mild scaling tendencies to the extreme. To prevent scale from forming in the system, a chemical inhibitor must be injected continuously and/or by periodic squeeze treatments. In the case of reservoir treatments to protect the critical near well bore area, squeeze treatments are normally the best option. For a squeeze treatment, a scale inhibitor at concentrations between 5–20% is normally injected into the formation through a producer after a preflush (Sorbie et al, 1993)1. After overflush and shut-in, the well production is resumed. The scale inhibitor is expected to flow back to the surface at required minimum concentration to prevent well and near well bore from scale precipitation. This normally lasts from one month to ~24 months depending on the inhibitor retention and release properties in the formation and the water cut in the well. Obviously, a successful treatment design should give a longer lifetime (reflecting the volume of produced water it protects) of the treatment for economic reasons.
- Geology > Mineral (0.55)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.54)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Energy > Oil & Gas > Upstream (1.00)