Poweltec

France
France

Time filter

Source Type

Al-Hashmi A.R.,Sultan Qaboos University | Luckham P.F.,Imperial College London | Al-Maamari R.S.,Sultan Qaboos University | Zaitoun A.,Poweltec | Al-Sharji H.H.,Petroleum Development Oman
Colloids and Surfaces A: Physicochemical and Engineering Aspects | Year: 2012

This study investigates the effect of two alkali metal cations (Li+, K+) on the adsorption of high-molecular-weight, nonionic polyacrylamide on glass surfaces using a colloidal force probe. The effect of two different anions (Cl-, NO3 -) on polymer adsorption is also presented. There is a general consensus that hydrogen bonding is the main mechanism by which nonionic polyacrylamides adsorb to silica and glass surfaces. In the current study, the adsorption of the polymer is found to result in repulsion on approach as early as 20min of incubation in polymer solutions using both 0.27M lithium and potassium chlorides. On the other hand, adhesion on retraction occurs in both solutions but with higher magnitudes for the polymer solution prepared in potassium chloride. Adhesion on retraction in potassium chloride solutions occurs even after 24h of incubation, whilst the adhesion disappears in lithium chloride after 24h of incubation. The force at hard contact measured in the potassium chloride solution is generally one order of magnitude lower than those measured in lithium chloride. This indicates that the adsorbed polymer molecules in potassium chloride solutions attain flatter conformation than the ones in lithium chloride. This is attributed to the higher ability of the potassium cation to increase the adsorption energy of the polymer to the glass surface. This higher adsorption energy results in the adsorbed amount of the polymer in KCl being higher than in LiCl. Because of their lower hydration and larger size compared to lithium, potassium cations decrease the hydration of the glass surface and they have the ability to bind with the oxygen atoms in the polymer molecule to the negatively-charged sites on the glass surface. With potassium nitrate, the approach-retraction measurements indicate different adsorption kinetics of polyacrylamide compared to potassium chloride. The nitrate enhances the extension of the adsorbed polymer molecules away from the surface, reflected by the longer ranged steric repulsion in the approach measurements conducted during 24h of incubation. This is probably attributed to the large size of the nitrate anion, its lower hydration and different chemical structure, which allow it to form H-bonds with the polymer. Hence, the polymer is prohibited from forming H-bonds with the surface allowing it to extend away from the surface. This also negatively affects the adsorbed amount, which is found to be lower than in LiCl. © 2012 Elsevier B.V.


Al-Hashmi A.R.,Sultan Qaboos University | Luckham P.F.,Imperial College London | Heng J.Y.Y.,Imperial College London | Al-Maamari R.S.,Sultan Qaboos University | And 3 more authors.
Energy and Fuels | Year: 2013

High-molecular-weight (HMW) polyacrylamide and its derivatives are widely used in oilfield applications ranging from drilling fluids, enhanced oil recovery (EOR), and treatment of oil sand tailings. In these applications the adsorption characteristics of these polymers are essential since it would affect their applicability and efficiency. In this study, adsorption of three high-molecular-weight polymers (nonionic (NPAM), partially hydrolyzed (HPAM), and sulfonated (SPAM) polyacrylamides on silica surfaces from 2% KCl) is characterized using a quartz crystal microbalance with dissipation monitoring (QCM-D) and an AFM-based colloidal probe apparatus. QCM-D measurements show that semiequilibrium for adsorption on silica surfaces is reached within 3 h. The adsorbed amount and adsorption rate are highest for NPAM and lowest for SPAM. AFM experiments revealed that after 20 min of incubation in solution, HPAM induced bridging attraction on approach (i.e., compression). On the other hand, only a weak attraction is observed in the NPAM solution. However, SPAM shows only steric repulsion on approach after 20 min of incubation commencing at a separation of around 250 nm. Significant adhesion on retraction was observed after 20 min of incubation in NPAM and HPAM. However, only slight adhesion was observed in SPAM in the same time frame. After incubation in polymer solutions for 20 h, all polymers induced steric repulsion on approach and the absence of adhesion on retraction at different separations, indicating full surface coverage and different effective hydrodynamic layer thickness (EHT). On the basis of the AFM measurements after 20 h of incubation, the EHT of the adsorbed layers in NPAM, HPAM, and SPAM is 125, 30, and 175 nm, respectively. We believe that the results in this study will lead to enhanced understanding of the polymers under investigation with respect to their use in EOR applications. Moreover, this study gives clues on the differences between the three polymers under consideration with respect to their flocculating power, which is employed in the oil sand tailings treatments. © 2013 American Chemical Society.


Al Hashmi A.R.,Sultan Qaboos University | Al Maamari R.S.,Sultan Qaboos University | Al Shabibi I.S.,Sultan Qaboos University | Mansoor A.M.,Sultan Qaboos University | And 2 more authors.
Journal of Petroleum Science and Engineering | Year: 2013

High-molecular-weight partially hydrolyzed polyacrylamides are widely used in enhanced oil recovery. Mechanical degradation of these polymers as a result of flow through pumps, chokes, valves and at the sand face has been recently reported to have a negative impact on the application. This study presents capillary flow measurements of high-molecular-weight hydrolyzed polyacrylamide (degree of hydrolysis=27.8%) in 2wt% potassium chloride aqueous solvent. Flow was conducted at different flow rates through three different lengths of 125-μm stainless steel capillaries to investigate the apparent rheology and mechanical degradation. The apparent rheology was indicated by mobility reduction while the mechanical degradation was measured by the loss in viscosity of the solution effluent. The entry point contribution in the overall mobility reduction and degradation was evaluated by extrapolation. In the investigated range of shear rates, the polymer solution generally shows an initial apparent thickening behaviour up to 15,000s-1, above which the behaviour becomes thinning. After the evaluation of the entry point contribution to the overall mobility reduction, the initial thickening behaviour is found to be due to the coil-stretch transition at the entry point. The flow in the bulk of the capillaries is found purely thinning in the whole shear rate range investigated. The total degradation is found to be almost constant, below 20%, up to the shear rate of 15,000s-1. The degradation starts to increase above 15,000s-1 due to the effect of shear in the bulk of the capillaries. The entry point degradation seem to contribute negligibly (below 5%) to the overall degradation up to 100,000s-1, above which it sharply increases its effect on polymer degradation reaching 42% at 850,000s-1. We believe that the results of this study will improve the execution of the polymer enhanced oil recovery by minimizing polymer mechanical degradation. High shear devices such as pumps, chokes, valves can have a detrimental effect on the mechanical stability of the polymer and hence should be utilized with caution. Also, more mechanically stable polymers can be utilized. Moreover, in the light of the current study, it is expected that the elongational flow of polymer at the sand face and the flow of polymer through perforations and/or fractures can also degrade the polymer, which need to be evaluated. © 2013 Elsevier B.V.


Dupuis G.,Poweltec | Bouillot J.,Poweltec | Templier A.,Poweltec | Zaitoun A.,Poweltec
Society of Petroleum Engineers - Abu Dhabi International Petroleum Exhibition and Conference, ADIPEC 2015 | Year: 2015

This paper relates the successful water shut-off treatment of a heavy-oil Omani well combining the use of microgel and gel. As many sandstone reservoir with strong aquifer in Southern Oman, this vertical well faced early water breakthrough along with sand production. Water cut increased dramatically until reaching 100%. The average permeability was around 500 mD but effective permeability ranged from milli Darcy to several Darcy. Due to well characteristics (several perforation intervals, gravel pack, etc⋯), it was not possible to identify and isolate the water production zones, which oriented the strategy towards the use of RPM products (Relative Permeability Modifiers). The treatment consisted of microgel and gel injections which were bullheaded into the whole open interval. After the treatment, the water cut dropped from 100% to 85% and sand production was stopped over a period of time superior to one year. The treatment was cost effective, producing more than 9000 bbl of extra oil in one year. In this paper, we describe the treatment design methodology combining laboratory study and near wellbore simulations, and the optimization of injection sequences. Finally, the treatment execution is detailed followed by the presentation of the results obtained since the realization of the operations. The results show that combining low-risk approach and low-cost RPM technology is an attractive way to restore productivity of watered out wells, in which conventional water shut-off zone isolation is not feasible. Copyright 2015, Society of Petroleum Engineers.


A process for the treatment of a rock formation or cavity, including the step of injecting, into the rock formation or cavity, a water solution of a water-soluble thermo-thickening polymer, the thermo-thickening polymer being able to form a gel at a threshold temperature (T_(g)), an inner temperature (T_(int)) of the rock formation or cavity being equal or superior to the threshold temperature (T_(g)), the process being characterized in that the thermo-thickening polymer is a cellulose chain, partially etherified with C_(1)-C_(6 )alkyl or hydroxyalkyl groups, or a polyacrylamide-based copolymer including N-isopropylacrylamide and/or N-vinylpyrrolidone groups. Such a process is advantageous for water shutoff in gas- or oilfields, or to solve to water channelling problems between injection wells and production wells.


Trademark
Poweltec | Date: 2012-12-14

Chemical products for use in industry, science, agriculture; unprocessed artificial resins, unprocessed plastics; fire extinguishing compositions; catalysts, adsorbents, catalyst supports, chemical additives and chemical reagents other than for medical or veterinary use; chemical products for drilling, extraction, production, treatment of gas, petroleum, water and fluids. Evaluations, assessments and research in the fields of science and technology provided by engineers; design and development of computers and software; research and development of new products for others; technical project study; scientific and technological services relating to drilling, extraction, production or treatment of gas, petroleum, water and fluids.


Trademark
Poweltec | Date: 2012-12-14

Chemical products for use in industry, science, agriculture; unprocessed artificial resins, unprocessed plastics; fire extinguishing compositions; catalysts, adsorbents, catalyst supports, chemical additives and chemical reagents other than for medical or veterinary use; chemical products for drilling, extraction, production, treatment of gas, petroleum, water and fluids.


Trademark
Poweltec | Date: 2013-06-12

Chemical products used in industry, science, agriculture, unprocessed artificial resins, unprocessed plastics; fire extinguishing compositions; catalysts, adsorbents, catalyst carriers, chemical additives and chemical reagents other than for medical or veterinary use, chemical products used for drilling, extraction, production, treatment of gas, petroleum, water and fluids. Building materials, not of metal; non-metallic rigid pipes for building; asphalt, pitch and bitumen; non-metallic transportable buildings; monuments not of metal; buildings, not of metal; building glass; concrete; cement; sands; silicas. Construction; construction information; construction consultation; building construction supervision; installation, maintenance and repair of machines for drilling, extraction, production or treatment of gas, petroleum, water and fluids; shipbuilding; drilling works; drilling work supervision.


Trademark
Poweltec | Date: 2013-06-12

Chemical products used in industry, science, agriculture, unprocessed artificial resins, unprocessed plastics; fire extinguishing compositions; catalysts, adsorbents, catalyst carriers, chemical additives and chemical reagents other than for medical or veterinary use, chemical products used for drilling, extraction, production, treatment of gas, petroleum, water and fluids. Building materials, not of metal; non-metallic rigid pipes for building; asphalt, pitch and bitumen; non-metallic transportable buildings; monuments, not of metal; buildings, not of metal; building glass; concrete; cement; sands; silicas. Construction; construction information; construction consultation; building construction supervision; installation, maintenance and repair of machines for drilling, extraction, production or treatment of gas, petroleum, water and fluids; shipbuilding; drilling works; drilling work supervision.


Dupuis G.,Poweltec | Lesuffleur T.,Poweltec | Desbois M.,Poweltec | Bouillot J.,Poweltec | Zaitoun A.,Poweltec
Society of Petroleum Engineers - SPE EOR Conference at Oil and Gas West Asia, OGWA 2016 | Year: 2016

SMG Microgels are pre-gelled polymers having a narrow size distribution and behaving like large polymer molecules whose stability is strongly enhanced by internal crosslinks. The largest species have a size of around 2 μm, which makes them suitable for Water Shutoff and Conformance Control applications in matrix reservoirs. SMG Microgels have been firstly used as water shutoff agents in gas storage wells and showed high efficiency to reduce water production while enhancing gas production. This paper reports a Conformance project which has been recently deployed in a heterogeneous sandstone reservoir. The pilot pattern consisted of one central injector, surrounded by 7 offset producers, with a spacing between 150 and 450 m. Reservoir permeability ranges between 10 and 1,000 mD with an average of 125 mD. Reservoir temperature is 48°C and salinity is 8,000 ppm TDS. Soft SMG with size around 2 μm was chosen regarding reservoir conditions. Microgel size prevented invasion of lowest permeability zones and created flow resistance in highest permeability zones by adsorption on the rock. Microgel slug corresponded to 0.1 Pore Volume and was 10,000 m3. Microgel injection proceeded over a period of 3 months. WHP remained below max pressure authorized of 1,500 psi. Closest producers responded within 3 months after microgel injection, with noticeable increase in oil rate along with a reduction of a few points of water cut. After one year 6 offset producers upon 7 were responding to the treatment. Three producers showed strong increase and sustained oil production, three had low response and one well lost both water and oil, showing diversion to the other wells. The trend remains steadily established in the pattern. After one year, 10,000 bbl of additional oil has been produced, along with a reduction of water production of 125,000 bbl. Copyright 2016, Society of Petroleum Engineers.

Loading Poweltec collaborators
Loading Poweltec collaborators