Day 1 Mon, June 25, 2018最新文献

{"title":"An Updated Fractional Flow Model of Low Salinity Water Flooding with Respect to the Impact of Salt Diffusion","authors":"H. Al-Ibadi, K. Stephen, E. Mackay","doi":"10.2118/191222-MS","DOIUrl":"https://doi.org/10.2118/191222-MS","url":null,"abstract":"\u0000 Low Salinity Water Flooding (LSWF) is an emergent technology developed to increase oil recovery. Many laboratory tests of LSWF have been carried out since the 1990's, but modelling at the reservoir scale is less well reported. Various descriptions of the functional relationship between salt concentration and relative permeability have been presented in the literature, as have the differences in the effective salinity range over which salt content takes effect. This paper focuses on these properties and their impact on the fractional flow of LSWF. We present observations that help characterise the flow behaviour in a more general form, simplifying the interpretation of results. We explain how numerical or physical diffusion of salt affects the velocity of the waterflood front, and how this can be predicted from fractional flow analysis.\u0000 We have considered various linear and non-linear shapes of the function relating salinity to relative permeability and different effective salinity ranges using a numerical simulator applied at the reservoir scale. The results are compared to fractional flow theory in which both salt and water movement is assumed to be shock-like in nature.\u0000 We observe that diffusion of the salt front is an important process that affects the fractional flow behaviour depending on the effective salinity range. The simulator solution matches the analytical predictions from fractional flow analysis under the condition that the mid-point of the effective salinity range is at the mid-point between the formation and injected salt concentrations. However, an effective behaviour similar to adsorption/desorption occurs when these mid-point concentrations are not coincidental. The outcome is that the fronts representing high and low salinity water travel with altered velocities and at different saturations.\u0000 We find that we can predict this behaviour from the input data alone as an augmented form of the fractional flow theory including the concept of retardation or acceleration as occurs for adsorption and desorption for other injectants. We use the analytical solution to the advection-diffusion equation and find that the changes in behaviour depends on the Peclet number.\u0000 The result of our work is that we have produced an updated form of the fractional flow model of LSWF, to include the impact of salt front diffusion on the movement of fluids. A new factor is introduced, similar to adsorption in polymer flooding. We have developed a new mathematical formula, empirically, to estimate the magnitude of this factor. The new form can be used to modify the effects that numerical or physical diffusion have on the breakthrough times of high and low salinity water fronts during LSFW. This will improve predictive ability and also reduce the requirement for full simulation.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125595879","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Bubble Population Balance Modeling to Predict Propagation Distance of CO2 Foams in Enhanced Oil Recovery Processes","authors":"M. Izadi, S. Kam","doi":"10.2118/191202-MS","DOIUrl":"https://doi.org/10.2118/191202-MS","url":null,"abstract":"\u0000 A mechanistic foam modeling technique based on bubble population balance, which honors three different foam states (weak-foam, strong-foam, and intermediate states) and two steady-state strong-foam flow regimes (high-quality regime and low-quality regime of the strong-foam state), is developed to investigate how CO2 foam behaves rheologically and propagates in a petroleum reservoir. The model parameters are first obtained from a fit to existing laboratory coreflood experimental data, and then the mechanistic model is applied to different types of CO2 foams, ranging from gaseous to supercritical CO2 foams, represented by various mobilization pressure gradients.\u0000 The results from the fit to existing coreflood data show that a reasonable match can be made satisfying multiple constraints such as hysteresis exerted by three foam states, non-Newtonian flow behavior caused by gas trapping and shear thinning rheology, and bubble stability at different capillary pressure environments. Among different sets of input parameters resulting in equally nice fits, an additional experimental data (for example, the onset of foam generation by increasing the total flow rate step by step at fixed foam quality) can help narrow down the range of input parameters further. When applied to field-scale scenarios, supercritical CO2 foams requiring low mobilization pressure gradient propagate much further than gaseous CO2 foams, far enough to make use of supercritical CO2 foams promising in the fields. This in turn proves theoretically why supercritical CO2 foams should be preferred in the field compared to gaseous CO2 foams. The model shows foams in the low-quality regime can propagate longer distance than foams in the high-quality regime because of better foam stability at lower capillary pressure environment.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"59 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117136764","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Exploiting Water Injection Techniques for Increasing Gas Recovery in Conventional Gas Reservoirs","authors":"Keval Darvesh Rambaran, Sarah Tammie Chin Chee Fat, L. Layne","doi":"10.2118/191206-MS","DOIUrl":"https://doi.org/10.2118/191206-MS","url":null,"abstract":"\u0000 Primary gas recovery for a volumetric reservoir ends when the reservoir pressure declines below the value required to flow gas to the surface at the sales line pressure. Secondary gas recovery techniques can then be employed to increase the recovery, once they are economically viable. The most common of these techniques is gas compression; but another feasible technique, which is rarely ever explored, is water injection. This paper evaluates the incremental benefit of water injection in a conventional gas reservoir when compared to gas compression.\u0000 This was achieved through analytical simulation of a retrograde gas-condensate reservoir located in the Columbus Basin off the south-east coast of Trinidad. The techniques which were applied here have been historically used in the waterflooding of oil reservoirs, and were tailored in this novel case for the use in gas reservoirs. The reservoir evaluated is a faulted sandstone formation of good quality that is divided into two hydrocarbon bearing segments. In one of the segments, production ended due to a decline in the reservoir pressure, indicating the end of primary gas recovery. Both reservoir and well modelling were done using the IPM Suite. In this paper, the scope was narrowed to focus on the application of analytical simulation as a means of quickly screening various production scenarios. Simple economic evaluations were done using the University's methodology and current economic metrics, with the operational and capital expenditures derived from offshore projects by operator companies within Trinidad.\u0000 The findings showed that while gas compression generated significantly higher internal rates of return, water injection provided similar net cash flows. Unlike gas compression, which improves the recovery by allowing the reservoir to produce at a lower tubing head pressure than the sales line pressure; water injection increases the reservoir pressure by filling the voidage space created as a result of the depletion process. Thus, the feasibility of water injection is dictated largely by the volume of water which is required, since gas is highly compressible.\u0000 The primary value of water injection as a secondary gas recovery technique stems from the use of high water rates from nearby producing wells under aquifer drive, which would otherwise be shut-in. The technique can also be managed as a water disposal option for adjacent fields, thus reducing company expenditure on treating the produced water from the wells mentioned above.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"2436 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-25","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130899769","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Polymer Flooding Application in Trinidad Heavy Oil Reservoirs","authors":"Rajiv Dukeran, M. Soroush, D. Alexander, A. Shahkarami, Donnie Boodlal","doi":"10.2118/191204-MS","DOIUrl":"https://doi.org/10.2118/191204-MS","url":null,"abstract":"\u0000 The objective of this paper is to assess the application of polymer flooding in Trinidad heavy oil reservoirs. Uncertainty analyses on several synthetic models have been performed to evaluate how variations in reservoir properties affect the oil recovery factor (RF) and Net Present Value (NPV).\u0000 Three (3) phases were conducted for the polymer flooding assessment. Phase 1 included a core flooding simulation to assess the oil viscosity sensitivity region and the ranges of polymer concentration for optimization. Phase 2 carried out uncertainty analysis using synthetic models to optimize polymer flooding with respect to NPV. Phase 3 discussed more detail analysis of parameters effects and confirmed the observations in previous cases using analytical approach.\u0000 Three types of polymer were used in the models, Flopaam 3130S, 3430S and 3630S. In core flooding simulation, optimal range of polymer concentration was estimated between 500ppm to 5000ppm. On recovery-viscosity plot, a high viscosity oil requires a higher polymer concentration to have higher recovery. Our results showed that this trend was not always true mainly due to the low reservoir fracture pressure, since a higher concentration and/or a higher molecular weight polymer require higher injection pressure. Uncertainty analysis in Phased 2 to 3 indicated that °API /viscosity, depth, permeability and polymer concentration had the highest effect on RF and NPV.\u0000 This paper also presents optimal polymer concentration versus oil viscosity for Trinidad oil reservoirs. Moreover, this work determines the reservoirs where the polymer flooding is applicable and recommend proxy models to estimate RF and NPV versus reservoir parameters.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132183828","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of Rotating Magnet Ranging System and An Innovative Concept of Heat Recycling in SAGD Operation","authors":"F. Jin, Z. Shunyuan, L. Bingshan, L. Bo, Chen Lisheng","doi":"10.2118/191169-MS","DOIUrl":"https://doi.org/10.2118/191169-MS","url":null,"abstract":"\u0000 As a kind of methodology to develop coalbed methane in China, RMRS (Rotating Magnet Ranging System) has been popular in SAGD operation in recent years. In Liaohe Oilfield SAGD (Steam Assisted Gravity Drainage) is becoming a more and more mature methodology. In a pair of parallel wells high pressure steam is injected into a horizontal well to drain heavy oil into the lower production well. However, not all thermal resources have not been exploited, such as heat of the hot production fluid, flue gas and hot brine separated by the steam-water separator in the boiler.\u0000 Trials and researches were finalized on many dual-horizontal wells in Liaohe Oilfield to learn about the present situation and technical capabilities, while thermodynamic models of various types were established and experimental means were applied to analyze thermal distribution and each of the thermal sources previously mentioned. Effects of various media, flow rates and temperatures on thermal utilization and heat deficit rates were studied on the assumption that one ton crude oil was produced per hour.\u0000 Waste heat of flue gas may be utilized to help combust air and the thermo-coil may be used as the air preheater, which improves boiler’s heat efficiency. The high temperature production fluid may be used to heat water in the boiler first and then used as the heat source of the absorption heat pump, so that heat is transferred from the low temperature heat source to the high temperature heat source and the low grade heat energy is recycled. As a high grade waste heat, the HPHT brine that is separated from moist steam in the boiler takes up twenty percent of the total water and shall not be only used to heat injected water. Instead, it may be used to achieve flash evaporation. Thus, waste water is heated and distilled water is recycled.\u0000 The waste heat recyling model applies thermo-coil air preheaters to recycle flue gas and flash evaporated hot brine to evaporate waste water. Beside, hot production fluid is recycled to heat boiler water. On a basis of the same fuel consumption volume, the recovery rate and marketability of crude oil are both improved.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115624304","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Shorebase Logistics for Deepwater Drilling Operations in Trinidad, Guyana and Suriname","authors":"J. Razack, Imtiaz Nazir-Khaleel, Shaun Rampersad, A. Zambrano, Shivani Chandarjeet, Sachin Choon","doi":"10.2118/191230-MS","DOIUrl":"https://doi.org/10.2118/191230-MS","url":null,"abstract":"\u0000 Since 2015, over a dozen deepwater exploration and appraisal wells have been drilled across Trinidad, Guyana and Suriname. By 2020, these three countries are expected to see at least another twenty-five deepwater wells being drilled. These include 17 development wells for Guyana's massive Liza field. Seismic exploration is also being conducted over unexplored deepwater blocks in Guyana and Suriname, which could pave the way for even more wells during this period.\u0000 A key element in the offshore drilling supply chain is the onshore supply base. This shorebase is the logistics hub for all drilling activity. Supply vessels commute between the rig and shorebase, where they are loaded with all drilling fluid, cement, drillpipe, logging tools, food supplies, and any other equipment needed by the rig. Fuel and potable water for the rig are also loaded at the shorebase. When the vessels return from the rig, they unload waste generated at the rig and demobilize tools, unused drillpipe and so on.\u0000 The shorebase must have the following: covered warehousing, flattened and reinforced laydown yard, offices for support staff, and quayside access with a dock that is long enough and with deep enough draft to accommodate the supply vessels when fully laden with cargo. The shorebase must also have sufficient crews for loading and unloading of materials, as well as heavy equipment such as cranes and forklifts. Vessels must also be able to access electric power and load potable water, drill water and fuel.\u0000 In Guyana and Suriname, natural deepwater ports do not exist due to sedimentation from several rivers like the Berbice, Essequibo, Demerara and Paramaribo. The severe draft restriction means that the large supply vessels required to take cargo to the rig cannot easily dock in Guyana or Suriname. Moreover, Trinidad has many major multinational service companies already set up, so the majority of equipment and materials needed for drilling must emanate from Trinidad. Further, since Trinidad has a mature oil and gas industry, there are several shorebases already set up to service drilling operations. As a consequence of these three main factors, the primary shorebase for all wells in Guyana and Suriname have been located in Trinidad.\u0000 With the Liza field being developed, ports are being renovated in Guyana while more service companies are aiming to set up there. However, until a deepwater shorebase is built in either Guyana or Suriname, the primary supply base for these wells must come from Trinidad. Secondary supply bases have been located in Guyana or Suriname, to facilitate smaller supply vessels and emergency support.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121956322","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An investigation into the Combination of Cyclic Steam Stimulation and Cyclic CO2 Stimulation for Heavy Oil Recovery in Trinidad and Tobago","authors":"J. Bobb, R. Hosein","doi":"10.2118/191161-MS","DOIUrl":"https://doi.org/10.2118/191161-MS","url":null,"abstract":"\u0000 More than four billion barrels of heavy oil remain in the oil fields of Trinidad. If these oil fields are exploited, the country's total oil production can increase significantly. However, heavy oil is difficult to produce, due to its high viscosity, and only a small fraction is recovered after primary recovery. Therefore, it is necessary to implement enhanced oil recovery (EOR) techniques to increase heavy oil production. Two of the most commonly used EOR techniques are cyclic steam stimulation (CSS) and cyclic CO2 stimulation (CCO2S). These processes have a long history of successful heavy oil recovery in Trinidad and Tobago when applied individually. However, very little research was found regarding the combination of both processes which was the basis for this study\u0000 A test reservoir, located in the southern basin on land Trinidad was selected and a computer simulation model was built, using the Computer Modelling Group (CMG) software to determine the production analysis. Sand, structure and pay maps were obtained and digitized, using the Didger Five software and then uploaded into the CMG software. Reservoir properties and production data were also uploaded. Wells were then added to the model at the exact location indicated on the structure map. Simulations were conducted using varying injection rates, slug size and soak times for CSS, CCO2S and combined CSS and CCO2S to determine optimal EOR performance and production.\u0000 The combination of CSS and CCO2S show an increase in recovery by 8.6% and to be profitable at oil prices higher than USD 14/bbl. It is also best used as a first step for other enhanced oil recovery techniques to further increase recovery. In addition, the results show that 8 out of 17 wells were more responsive to CSS and CCO2S when applied individually than when combined.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128757353","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Economical Mature Field Revitalization in Low Oil Prices Environment: A Ten Thousand Incremental Oil Production Case Story in the Drago Complex Field, Ecuador","authors":"A. Izurieta, D. Cuenca, L. Pozo, Wilson Padilla, J. Bustos","doi":"10.2118/191248-MS","DOIUrl":"https://doi.org/10.2118/191248-MS","url":null,"abstract":"\u0000 This paper presents the results of the most extensive hydraulic fracturing campaign on the same field in Ecuador, along with the methodology appliedto establish the real field production potential and an incremental oil production of 10,000 STB/d.\u0000 The study started with the review of pressure transient analysis (PTA), resulting in updated values of permeability, skin and reservoir pressure, then conventional and special well logs were revisited to get a consistent approach of reservoir pay intervals. The characterization of formation damage mechanism was performed to confirm and complement the results. Strategic execution of the hydraulic fracturing workovers was implemented for fast track execution and to maximize results.\u0000 The rigorous and fundamentals-based review showed that additional production potential, on most of the wells in the field, could be achieved by hydraulic fracturing due to the high skin values and the deep penetration nature of the damaged zone. The interventions schedule of producing and nonproducing wells resulted in short deferred production times. All planned jobs were designed with the goal of reaching the maximum production defined by hydraulic fracturing and complete nodal analysis. Most fracturing jobs resulted in folds of increase, FOI, from 2 to 13. The learning curve started from one stage tip screen out, TSO, and conventional long fractures, to two stage hydraulic fracturing, pulsed proppant and propped acid fracturing jobs. Economical evaluation showed that the whole stimulation campaign recovered the investment during the third month of execution.\u0000 The incremental production outcome from these jobs resulted in ten thousandstandardbarrels per day, 10,000 STB/d, the historical peak oil of the field and the most extensive hydraulic fracturing campaign in the country.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"21 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125427420","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Casing Centralization and Pipe Movement in Cementing Operations for Improved Displacement Efficiency","authors":"Jose H. Guzman, Francisco J Mavares, Eloy Monasterios, Luis Massirrubi","doi":"10.2118/191255-MS","DOIUrl":"https://doi.org/10.2118/191255-MS","url":null,"abstract":"\u0000 Casing centralization and reciprocation during a cementing operation can help improve the efficiency of annular mud displacement and provide a basis for analyzing the percentage of mud displacement efficiency. This information is necessary when developing a mitigation plan for any cementing operation's risk assessment when centralization and pipe movement are considered as operational variables.\u0000 A state-of-the-art, three-dimensional (3D) finite displacement efficiency simulator analyzes the percentage of mud displacement efficiency when these four main possible scenarios are considered: low, medium, and high centralization and casing reciprocation during the cementing operation. This paper discusses three case studies validated by a risk assessment process developed during the cementing job design stage in which higher standoff and casing reciprocation suggest improved mud displacement efficiency and low fluid channeling when the cementing operation is finished. Cement bond log (CBL) results are discussed and shared when high standoff and casing reciprocation scenarios are considered.\u0000 Results of this study include the following observations and conclusions: Casing reciprocation helps improve displacement efficiency, which can provide improved cement bonding.If casing reciprocation movement is not possible, high casing centralization standoff can be an effective design technique because it can be used to enhance mud displacement efficiency in cementing operations. Wellbore stability is not compromised by equivalent circulating density (ECD) increments resulting from the reduction of annular clear space when using centralizers.Design risk assessment should include a comparative scenario analysis to mitigate the potential risk of poor mud displacement efficiency when considering casing centralization with medium to high standoff and casing reciprocation.At some point, casing reciprocation will not be a factor of improvement for mud displacement efficiency when sufficient standoff is considered for cementing operation designs. This scenario can help mitigate any likelihood of poor mud displacement efficiency if the casing is not reciprocated because of operational factors.Even though high casing standoff yields high percent displacement efficiency, it is recommended to follow the primary cementing operation's field practices as discussed.\u0000 A comprehensive practical analysis to prepare a cementing risk assessment included in an operation's program is reviewed. It considers low and high casing centralization as well as pipe movement as variables to help improve cement placement.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"77 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125667747","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Adapting Fiscal Regimes to Entice Operators to Implement EOR Schemes","authors":"F. Núñez, Christian Ramírez, J. L. Bashbush, O. Espinola","doi":"10.2118/191241-MS","DOIUrl":"https://doi.org/10.2118/191241-MS","url":null,"abstract":"\u0000 To optimize profit from Oil and Gas production activities, the Operating companies are often constrained in one side by contract terms with the host governments and on the other side by the nature of the reservoir, its fluids, and the resulting economics associated to its production and development. Enhanced Oil Recovery (EOR) methodologies have shown to provide satisfactory results in increasing the recovery factor. Nonetheless, their applications are normally linked to important capital investments which might turn the economics of the project not favorable, unless enticements are offered to ease the way towards a win-win pre-arrangement.\u0000 This paper aims to contrast results from economic evaluations and assessments for the implementation of an EOR methodology in a type field and how to foster cooperation with regulatory bodies to adapt their fiscal conditions to stimulate implementation of EOR techniques. In that way the host country could benefit from higher investment, larger production, increased tax revenue and a better recovery factors while the operating company would be enticed to assemble a quality team to design viable alternatives to maximize recoveries, increase reserves while increasing their profitability.\u0000 The methodology proposed considers the calculation of economic and business indicators such as: Net Present Value, Internal Rate of Return, Payout time, Company take and Government take which are obtained considering typical fiscal regimes applicable for Enhanced Oil Recovery techniques as a function of production profiles and EOR methodologies. The analyses are benchmarked versus natural depletion of current development, comparing investment alternatives and technical and economic benefits of possible Enhanced Oil Recovery alternatives and their prudent implementation.\u0000 The implementation of EOR techniques for different fields are either incentivized or discouraged as a function of the different terms of typical fiscal regimes for hydrocarbon production. A proper analysis of the alternatives could be used as the basis of negotiations for the fiscal regime configuration to be applied. Provided the regulations are already intelligently designed and properly approved. Various production scenarios are analyzed to ascertain which EOR methodology may be more advantageous from the points of view of operating companies, national oil companies and government take.","PeriodicalId":352851,"journal":{"name":"Day 1 Mon, June 25, 2018","volume":"44 2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-06-22","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122217530","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}