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Results
Understanding the Co-deposition of Calcium Sulphate and Barium Sulphate and Developing Environmental Acceptable Scale Inhibitors Applied in HTHP Wells
Liu, Xuan (aSouth West Petroleum University) | Chen, Tao (bChampion Technologies) | Chen, Ping (bChampion Technologies) | Montgomerie, Harry (bChampion Technologies) | Hagen, Thomas (bChampion Technologies) | Wang, Bin (aSouth West Petroleum University) | Yang, Xu (aSouth West Petroleum University)
Abstract Calcium sulphate and barium sulphate are two major scales experienced in the oil and gas fields, especially when sea water breakthrough in the waterflood supported HTHP wells. Normally, studies have been focused on a single scale component. Seldom studies have focused on the co-deposition of calcium sulphate and barium sulphate. The importance of interference between calcium sulphate and barium sulphate deposition in the field, especially for the HTHP wells, has been ignored. In this paper, the interference between calcium sulphate and barium sulphate deposition has been studied based on a field case in the North Sea. The mechanisms of co-deposition have been addressed using both scale prediction and laboratory tests. Environmentally acceptable scale inhibitors have also been developed. The scaling tendency and mass deposition of calcium sulphate and barium sulphate have been predicted with sea water breakthrough at different levels. The difference between calcium sulphate and barium sulphate, and the consequences of both types of scale deposition are discussed. Dynamic scale loop tests have been carried out. It demonstrated that a small amount of barium sulphate deposit substantially accelerates the co-deposition of barium sulphate and calcium sulphate. Linked to the scale prediction, the mechanism of co-deposition of calcium sulphate and barium sulphate has been addressed. Several scale inhibitors, including phosphonate and polymer based inhibitors, along with an amine based polymer have been tested under the worst case scaling condition. Environmentally acceptable scale inhibitors have been developed and are suitable for squeeze application. This paper will give a comprehensive study of co-deposition of calcium sulphate and barium sulphate, including scale prediction, laboratory evaluation, mechanism discussion and inhibitor selection. It will contribute to understand calcium sulphate and barium sulphate scale deposition in HTHP wells and find effective inhibitors for field application.
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Understanding Mechanisms of Scale inhibition Using Newly Developed Test Method and Developing Synergistic Combined Scale Inhibitors
Liu, Xuan (aSouth West Petroleum University) | Chen, Tao (bChampion Technologies) | Chen, Ping (bChampion Technologies) | Montgomerie, Harry (bChampion Technologies) | Hagen, Thomas (bChampion Technologies) | Wang, Bin (aSouth West Petroleum University) | Yang, Xu (aSouth West Petroleum University)
Abstract Static jar and dynamic loop tests are two major test methods used in the oilfield scale industry to evaluate the performance of scale inhibitors. The minimum inhibitor concentration (MIC) under the test conditions can be determined, but with a certain amount of assumptions and theoretical analysis of the mechanism of scale inhibition, especially for scale inhibitors with dispersive effects. Unlike these traditional test methods, a newly developed test method, using an ultrasonic technique along with turbidity measurement, has been used to evaluate scale inhibitors and understand the inhibition mechanisms. In comparison with traditional test methods, this test method provides a quick and effective way to understand the scale inhibitors, including the effect of scale inhibitors on the induction, nucleation and growth stages of scale formation, and also the dispersion functions of scale inhibitors. Several typical commercial scale inhibitors, including phosphonate and polymer based chemistries have been tested using this newly developed test method. Different scale inhibitors demonstrated different inhibition mechanisms and will be addressed in detail in this paper. Results showed a polymer based scale inhibitor has good inhibition on the induction time of scale formation and a phosphoric based scale inhibitor showed a major dispersive effect on scale inhibition. The combined formulation based on these two inhibitors has been evaluated and a synergistic effect was observed and later confirmed by both the traditional static jar test and dynamic loop test, where the mixture of 75% polymer based scale inhibitor and 25% phosphoric based scale inhibitor showed much better performance than both neat scale inhibitors. In this paper, this newly developed test method will be introduced in detail and the benefits and limitations will also be discussed. By understanding the mechanism of the scale inhibitors, this technique might provide a new and alternative route of developing and formulating scale inhibitors.
Development of Test Method and Environmentally Acceptable Inhibitors for Zinc Sulfide Deposited in Oil and Gas Fields
Wang, Bin (South West Petroleum University) | Chen, Tao (Champion Technologies) | Chen, Ping (Champion Technologies) | Montgomerie, Harry (Champion Technologies) | Hagen, Thomas (Champion Technologies) | Liu, Xuan (South West Petroleum University) | Yang, Xu (South West Petroleum University)
Abstract Zinc sulfide (ZnS) is an exotic scale formed in the oil and gas fields, especially in HT/HP wells. It is relatively difficult to test ZnS formation and inhibition in the laboratory using traditional static jar and dynamic loop tests due to the oxidization during the test and its naturally ‘soft’ scale characteristic. Limited studies have been focused on ZnS and the detailed inhibition mechanisms are still unknown. In this paper, a newly developed stress test method has been applied to evaluate the performance and mechanisms of ZnS inhibition. Compared with the traditional test methods, it shows good reproducibility and provides a quick and effective way to evaluate the performance of inhibitors and information to understand the mechanisms of inhibition. More than 15 typical scale inhibitors, representing several different types, have been tested using this newly developed method. The ZnS scale inhibitors were classified as three types based on the inhibition mechanisms from this work: Type 1: Dispersion and nucleation inhibitors. These scale inhibitors showed nucleation and growth inhibition effect at low concentrations of sulfide and dispersion effect at high concentrations of sulfide. Type 2: Nucleation and growth scale inhibitors. These scale inhibitors inhibit nucleation and growth of ZnS formation, where the test can be stressed further. Type 3: Scale inhibitors with poor performance on ZnS inhibition. The turbidity and stress curve did not change obviously in the presence of scale inhibitors. This paper will give a comprehensive study of ZnS formation and inhibition, including scale prediction, development of test method and inhibitors, insight into the mechanism of ZnS inhibition and identification of environmentally acceptable inhibitors.
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 29/5b > Elgin Franklin Field > Fulmar Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 22/30c > Elgin Franklin Field > Fulmar Formation (0.99)
- Europe > United Kingdom > North Sea > Central North Sea > Central Graben > Block 22/30b > Elgin Franklin Field > Fulmar Formation (0.99)
New Polymer Chemistry for Squeeze Application in Tight Carbonate Reservoirs
Chen, Tao (Champion Technologies Ltd) | Heath, Steve (Champion Technologies Ltd) | Benvie, Ronald (Champion Technologies Ltd) | Chen, Ping (Champion Technologies Ltd) | Montgomerie, Harry (Champion Technologies Ltd) | Hagen, Thomas (Champion Technologies Ltd)
Abstract The development of effective scale squeeze inhibitors in carbonate reservoirs is still a big challenge, especially with the increasing environmental constraints. For tight carbonate reservoirs, formation damage is one of the major considerations as it can be caused due to fines mobilization, carbonate reservoir dissolution and collapse, and scale inhibitor compatibility issues. For the development of any product for squeeze application, the product must also demonstrate good inhibition performance, long squeeze life and accurate residual analysis at low concentrations as well as being suitable for improved placement techniques if required. Many scale inhibitors are either irreversibly retained in chalk reservoirs due to uncontrolled precipitation reactions or are poorly adsorbed with both processes resulting in short treatment lifetimes. Some new, readily detectable, polymeric scale inhibitor chemistry, containing a special functional amine group to have a good affinity to the chalk reservoir, was developed to provide a balance between irreversible and poor retention and thus provide effective squeeze life. The results of a comprehensive testing program, including compatibility, formation dissolution, dynamic tubing blocking, static adsorption and core flood tests will be presented, that will highlight the design and development of a polymeric scale inhibitor suitable for tight carbonate reservoirs while meeting the environmental requirements for application in the UK and Scandinavia. The new polymer has been shown to demonstrate excellent retention and release characteristics while also being non-damaging to carbonate reservoir material. The impact of calcium tolerance, pH and molecular chemistry will be discussed with regard to the design and performance of the new polymer when compared to some environmentally friendly phosphonate chemistry and other polymeric scale inhibitors. This paper will demonstrate a logical design procedure to develop an environmentally acceptable polymeric scale inhibitor product whose chemistry has been optimised for squeeze application in tight carbonate reservoirs. In addition, discussions on the mechanisms of scale inhibitor retention and formation damage with regard to selection, design and optimization of suitable scale squeeze inhibitors in tight carbonate reservoirs will be addressed.
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
New Environmentally Acceptable Chemistry and Evaluation Methods for Scale Inhibitor Testing Under Turbulent Flow and Harsh Scaling Conditions
Benvie, Ronald (Champion Technologies Ltd) | Chen, Tao (Champion Technologies Ltd) | Heath, Steve (Champion Technologies Ltd) | Chen, Ping (Champion Technologies Ltd) | Montgomerie, Harry (Champion Technologies Ltd) | Hagen, Thomas (Champion Technologies Ltd)
Abstract Dynamic scale loop tests are one of the major test methods used in the oilfield scale industry to evaluate the minimum inhibitor concentration (MIC) performance of scale inhibitors under laminar flow conditions. However, this laminar flow condition may not often be representative of field flow conditions especially around chokes, downhole safety valves and in wells with ESP and ICD completions where the flow is turbulent. Under these turbulent flow conditions the MIC derived by standard dynamic loop test may be too low to inhibit scale formation and very seldom has focus been placed on the effect of turbulence on MIC of scale inhibitors. It is possible to modify existing dynamic scale loop equipment to achieve turbulent flow conditions. However, the turbulent flow conditions imparted by the higher flow rate and narrow test coils still cannot match the really high Reynolds numbers experienced in real field conditions so a different approach was adopted to more closely replicate field conditions. This consisted of installing an adjustable small bore valve in the dynamic loop rig which closely simulates the turbulent environment around chokes and downhole safety valves. This new methodology and testing under turbulent and laminar conditions (at lower Reynolds numbers) was used to gain an understanding of the impact of flow on scale deposition and MIC and this information was used to design and identify new environmentally friendly P containing scale squeeze inhibitors that demonstrated excellent performance under turbulent flow conditions. This paper will give a comprehensive study of the effect of flow condition on the scale formation and inhibition and, in addition, will detail how this methodology and new chemistry can be coupled to a chemical technology toolbox, that also implements techniques for advanced scale inhibitor analysis and improved scale inhibitor retention, to design optimum scale squeeze packages for harsh scaling conditions.
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Novel Scale Squeeze Technology and Treatment Designs for Improving Scale Inhibitor Retention and Treatment Lifetimes - Use of Ionic Polymers in the Overflush
Heath, Steve (Champion Technologies Ltd) | Juliussen, Bjorn (Champion Technologies Ltd) | Chen, Ping (Champion Technologies Ltd) | Chen, Tao (Champion Technologies Ltd) | Benvie, Ronald (Champion Technologies Ltd)
Abstract A common method to prevent scale forming in oil production wells is to inject scale inhibitor into the formation in so called squeeze treatments. Conventional scale inhibitor treatments with a brine pre-flush, main scale inhibitor pill and brine over flush stages are often not considered to be economically efficient as a large proportion of the scale inhibitor introduced into the squeeze treatment is returned almost immediately and therefore does not serve to provide long term scale protection. Various techniques have been used successfully to increase the proportion of scale inhibitor retention in the well during squeeze treatments. For example, it has been reported previously in many papers where poly amino acids and poly quaternary amines have been injected into a well as part of the pre flush process and have significantly improved scale inhibitor retention and scale squeeze lifetimes. It has now been found that scale inhibitor treatment lifetimes can be improved by incorporating an ionic polymer such as a poly amino acid or poly quaternary amine in the over flush stage of the squeeze treatment. Indeed this method has been found to further extend the treatment lifetimes when combined with the same additives in the pre-flush stage of the scale squeeze treatment. The new scale squeeze design technology can be considered very flexible as it can be applied with most scale inhibitor chemistries including both phosphonates and polymers with minimal formation damage potential compared to most precipitation scale squeeze treatments. It should be applicable over a wide temperature range from 30°C to 200°C and, in addition, the treatment strategy also lends itself to both aqueous and non-aqueous deployment and hybrid treatments and could provide extra protection against fines production in water sensitive wells depending upon the ionic polymer deployed. Initial field treatments have demonstrated the potential to extend treatment lifetimes by retaining up to 20 to 50% more useful chemical in the treatment reservoir. This paper will highlight the proposed mechanisms of how the ionic polymer additives can improve squeeze treatment lifetimes as part of the over flush and will present field data for treatments on two wells in an HP/HT field at 165°C that demonstrated improved chemical retention and scale inhibitor returns compared to treatments without the ionic polymer additive in the over flush.
- Water & Waste Management > Water Management > Water & Sanitation Products (1.00)
- Water & Waste Management > Water Management > Constituents > Salts/Sulphates/Scales (1.00)
- Materials > Chemicals > Specialty Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
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)