Academic literature on the topic 'Onshore produced water'
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Journal articles on the topic "Onshore produced water"
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Rubach, S., and I. F. Saur. "Onshore testing of produced water by electroflocculation." Filtration & Separation 34, no. 8 (October 1997): 877–82. http://dx.doi.org/10.1016/s0015-1882(97)81411-5.
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Wilson, Adam. "Produced-Water Reinjection - Case Study From Onshore Abu Dhabi." Journal of Petroleum Technology 68, no. 12 (December 1, 2016): 72–73. http://dx.doi.org/10.2118/1216-0072-jpt.
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Liu, Zhong Min, Yong Qing Jin, Guo Qing Yuan, and Malcolm J. Law. "The Treatment and Disposal of Produced Water from Onshore Oilfields." Applied Mechanics and Materials 361-363 (August 2013): 567–73. http://dx.doi.org/10.4028/www.scientific.net/amm.361-363.567.
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As the worldwide demand for crude oil and gas increases and the oilfields age, the annual production of produced water is rising dramatically. Environmental restrictions on the disposal of this waste water have become more stringent in recent years with the result that disposal costs are also raising rapidly. This paper examines the various options for the treatment of this produced water prior to its disposal together with the possible consequences of getting it wrong, such as corrosion and scaling of process piping and equipment, together with fouling of the oilfield rock formation and disposal wells.
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Feder, Judy. "Reuse of Produced Water Grows in the Oil and Gas Industry." Journal of Petroleum Technology 72, no. 12 (December 1, 2020): 60–61. http://dx.doi.org/10.2118/1220-0060-jpt.
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This article, written by JPT Technology Editor Judy Feder, contains highlights of paper SPE 199498, “Reuse of Produced Water in the Oil and Gas Industry,” by Madeleine Gray, International Petroleum Industry Environmental Conservation Association, prepared for the 2020 SPE International Conference and Exhibition on Health, Safety, Environment, and Sustainability, originally scheduled to be held in Bogota, Colombia, 28-30 July. The paper has not been peer reviewed. The onshore oil and gas industry investigates new and improved ways to manage the supply and disposal of produced water continually. Within oil and gas operations, produced water increasingly is being recycled and reused for enhanced oil recovery, drilling, and well stimulation. The growing global demand for water resources also is creating interest in reusing produced water outside oil and gas operations. The complete paper focuses on sources of produced water from conventional and unconventional onshore oil and gas operations and addresses the challenges and opportunities associated with reusing the produced water. Introduction Produced water is water that is brought to surface during oil and natural-gas production. It includes formation, flowback, and condensation water. Produced water varies in composition and volume from one formation to another and is often managed as a waste material requiring disposal. In recent years, increased demand for, and regional variability of, available water resources, along with sustainable water-supply planning, have driven interest in reusing produced water with or without treatment to meet requirements within the industry or by external users. Reuse of produced water can provide important economic, social, and environmental benefits, particularly in water-scarce regions. It can be used for hydraulic fracturing, waterflooding, and enhanced oil recovery, decreasing the demand for other sources of water. However, reuse for offsite, non-oilfield applications such as crop irrigation, wildlife and livestock consumption, industrial processes, and power generation, is subject to a variety of constraints and risks. Practical considerations for offsite reuse include supply and demand and regulatory, infrastructural, economic, legal, social, and environmental factors. Sources, Chemical Properties, and Management of Produced Water The information contained in the paper is based on an internal survey conducted by the International Petroleum Industry Environmental Conservation Association (IPIECA) of 14 of its member companies, interviews with selected external stakeholders covering a range of sectors and geographic regions, and a literature review of readily available information. The external stakeholders were identified from the membership survey as well as from IPIECA and consultant experience. Sources and Volumes. Onshore oil and gas operations generate millions of barrels of produced water each day world-wide. The composition and flow of produced water can differ dramatically from one source to another.
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Edalat, Arian, and Eric M. V. Hoek. "Techno-Economic Analysis of RO Desalination of Produced Water for Beneficial Reuse in California." Water 12, no. 7 (June 28, 2020): 1850. http://dx.doi.org/10.3390/w12071850.
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There is approximately 508.7 million cubic meters (3.2 million barrels) of oilfield-produced water generated per year across the oil fields of California. While less than 2% of this produced water receives advanced treatment for beneficial reuse, changing regulations and increasing scarcity of freshwater resources is expected to increase the demand for beneficial reuse. This paper reviews onshore-produced water quality across California, relevant standards and treatment objectives for beneficial reuse, identifies contaminants of concern, and treatment process design considerations. Lastly, we evaluate the capital and operating costs of an integrated membrane system for treating produced water based on data from a field pilot conducted in the coastal region of California.
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Bilstad, T., and E. Espedal. "Membrane separation of produced water." Water Science and Technology 34, no. 9 (November 1, 1996): 239–46. http://dx.doi.org/10.2166/wst.1996.0221.
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Each time regulatory agencies initiate more stringent environmental controls, treatment technologies are refined to meet the updated standards. Centrifuges and hydrocyclones are, by and large, producing satisfactory effluents for meeting current quality requirements for the offshore petroleum industries. The European standard for effluent from onshore petroleum activities, however, requires less than 5 mg/l total hydrocarbons (HC) and less than 10 mg/l suspended solids. Such low concentrations are out of reach for the above classical separation processes. The amount of produced water in the North Sea is projected to increase by a factor of 6 from 1990 to the year 2000; from 16 to 90 million cubic meters each year. Produced water is the predominant source for oil discharges. The synergistic effects of chemicals, oil and dissolved components in the produced water effluent are given increased attention, with expectations of tougher effluent criteria. Microfiltration (MF) and ultrafiltration (UF) pilot trials with produced water from the Snorre field in the North Sea showed that UF, but not MF, could meet more stringent effluent standards for total HC, suspended solids and dissolved constituents. Total HC in the produced water was typically 50 mg/l and was reduced to 2 mg/l in the UF permeate (96% removal). The aromatics benzene, toluene and xylene (BTX) were similarly reduced by 54% and the heavy metals copper (Cu) and zinc (Zn) by 95%. UF trials were performed with organic tubular membranes with typical transmembrane pressures between 6 and 10 bars. The feed velocities through the tubes were between 2 and 4 m/s. Flux varied from 140 to 550 l/m2/h (lmh) at a produced water temperature of 60°C and membrane molecular weight cut-off between 100,000 and 200,000 daltons. By recirculating UF retentate as membrane feed, a volume reduction (VR) of 24 was obtained in the trials; i.e., 96% permeate recovery. The limited volume of produced water available in the feed tank negated further volume reduction. Full-scale design is based on permeate recovery of 99%. No irreversible fouling of the membrane surface was experienced. The cleanwater flux was restored after chemical cleaning. The alkaline detergent Ultrasil 11 was chosen as the optimal cleaning agent.
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Dantas de Assunção, Marcus Vinicius, Mariana Almeida, and Prof Dra Marcela Marques Vieira. "Environmental Dynamic Efficiency Of Onshore Oil Fields Located At The Brazilian Coastal Basin." International Journal for Innovation Education and Research 8, no. 7 (July 1, 2020): 135–51. http://dx.doi.org/10.31686/ijier.vol8.iss7.2462.
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One of the main environmental concerns associated with the exploration and production of oil fields is related to the generation of produced water, this is a strategic challenge for companies since is resposible for the largest share of waste genretared by the oil industry. This theme is presented as multidisciplinary since it is a study with dynamic models in an environmental area linked to the oil industry. Thus, the present work aims to evaluate the performance of dynamic environmental sustainability, from the generation of produced water from onshore oil fields located at the coastal basins of Brazil with higher oil production. The data were made available by the ANP (National Petroleum Agency) from its website, totalizing 67 fields during the years 2014, 2015 and 2016. In addition, dynamic Data Envelopment Analysis was used to determine dynamic efficiency. The results showed a positive effect of the variables directional wells, vertical wells and age, the first two variable showed a fundamental role in determining environmental efficiencies. Therefore, the results allowed to state that there is a poor management of the technological resources in onshore fields of the Brazilian coastal basins, generating excessive amounts of produced water.
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Yaqub, Asim, Mohamed Hasnain Isa, Shamsul Rahman Mohamed Kutty, and Huma Ajab. "Kinetic Study of PAHs Degradation in Produced Water Using Ti/RuO2 Anode." Applied Mechanics and Materials 567 (June 2014): 80–85. http://dx.doi.org/10.4028/www.scientific.net/amm.567.80.
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Oil production offshore and onshore results in production of huge amount of water, called produced water (PW). PW is one of source of polycyclic aromatic hydrocarbons PAHs to the aquatic environment. Degradation kinetics of 16 priority PAHs were studied in PW treatment using Ti/RuO2anode in a batch setupat three different current densities 3.33, 6.67 and 10 mA/cm2. GC-MS was used for quantification of each PAH. Kinetics study confirmed that electrochemical degradation of all PAHs had follow first-order kinetic using Ti/ RuO2. Results showed that values of rate constantkwere increase by increasing current density.
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Hampson, Mathew, Heather Martin, Lucy Craddock, Thomas Wood, and Ellie Rylands. "The Elswick Field, Bowland Basin, UK Onshore." Geological Society, London, Memoirs 52, no. 1 (2020): 62–73. http://dx.doi.org/10.1144/m52-2017-29.
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AbstractThe Elswick Field is located within Exploration Licence EXL 269a (Cuadrilla Resources Ltd is the operator) on the Fylde peninsula, West Lancashire, UK. It is the first producing onshore gas field to be developed by hydraulic fracture stimulation in the region. Production from the single well field started in 1996 and has produced over 0.5 bcf for onsite electricity generation. Geologically, the field lies within a Tertiary domal structure within the Elswick Graben, Bowland Basin. The reservoir is the Permian Collyhurst Sandstone Formation: tight, low-porosity fluvial desert sandstones, alluvial fan conglomerates and argillaceous sandstones. The reservoir quality is primarily controlled by depositional processes further reduced by diagenesis. Depth to the reservoir is 3331 ft TVDSS with the gas–water contact at 3400 ft TVDSS and with a net pay thickness of 38 ft.
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Osipi, Sara R., Argimiro R. Secchi, and Cristiano P. Borges. "Cost assessment and retro-techno-economic analysis of desalination technologies in onshore produced water treatment." Desalination 430 (March 2018): 107–19. http://dx.doi.org/10.1016/j.desal.2017.12.015.
Full textDissertations / Theses on the topic "Onshore produced water"
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Souza, Paulo Sérgio Alves de. "Avaliação do reúso agrícola de águas oleosas da indústria de petróleo tratadas por eletrofloculação e osmose inversa: efeitos na germinação, no desenvolvimento de plântulas de girassol e em atributos do solo." Universidade do Estado do Rio de Janeiro, 2015. http://www.bdtd.uerj.br/tde_busca/arquivo.php?codArquivo=9451.
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A presente tese de doutorado teve como objetivo estabelecer parâmetros para avaliar a viabilidade do reúso agrícola de águas oleosas da indústria de petróleo, como as águas de produção (AP) de campos de exploração onshore do semiárido nordestino, na irrigação de culturas de girassol destinadas à produção de biodiesel. A AP foi produzida sinteticamente e tratada utilizando-se as técnicas de eletrofloculação (EF) e de osmose inversa (OI). Foram analisados os efeitos da AP não tratada, tratada por EF e por EF combinada com osmose inversa (EF+OI) na germinação, desenvolvimento e produção de biomassa de plântulas de girassol e também nos atributos de um solo característico do semiárido nordestino. Na melhor condição operacional do tratamento da AP por EF (28,6 A m-2 durante 4 min.) foram obtidas eficiências de remoção de óleos e graxas (O&G), demanda química de oxigênio (DQO), cor e turbidez superiores a 95%. O tratamento EF+OI promoveu a remoção do excesso de salinidade e de ferro oriundo da etapa de EF, enquadrando-se esses parâmetros dentro de níveis de referência recomendados para água de irrigação. Níveis de O&G e DQO superiores, respectivamente, a 337 mg L-1 e 1.321 mg O2 L-1 na AP bruta produziram efeitos tóxicos, reduzindo-se o índice de velocidade de germinação (IVG) e o percentual de plântulas normais do girassol. Por outro lado, os efluentes tratados por EF e EF+OI produziram efeitos similares no percentual de sementes germinadas, no IVG, no percentual de plântulas normais e na produção de biomassa do girassol. O uso da AP tratada por EF, com ou sem diluição, contribuiu significativamente para o aumento da salinidade e dos teores de sódio do solo, diferentemente da tratada por EF+OI, que produziu efeitos similares ao do controle (água destilada)This doctoral thesis aimed to provide subsidies to assess the viability of the agricultural reuse of oily water from oil industry, such as oilfield produced water (AP) from onshore exploration fields of northeast brazilian semi-arid, in inedible irrigation such as sunflower crops intended for biodiesel production. AP was produced synthetically and treated using the electroflocculation (EF) and reverse osmosis (OI) techniques. The effects of untreated AP, AP treated by EF and AP treated by EF combined with reverse osmosis (EF+OI) in germination, growth and biomass production of sunflower seedlings and also in the attributes of a characteristic soil of the northeastern brazilian semiarid were analyzed. In the best EF treatment operating condition (28.6 A m-2 during 4 min.) Oil and grease (O&G), chemical oxygen demand (COD), color and turbidity removal efficiencies obtained were higher than 95%. EF+OI treatment promoted the removal of salinity in excess and iron derived from EF step, fitting these parameters within the recommended reference levels for irrigation water. O&G and COD levels higher than, respectively, 337 mg L-1 and 1,321 mgO2 L-1 in raw AP produced toxic effects, reducing the germination speed index (IVG) and the percentage of normal sunflower seedlings. On the other hand, the use of EF+OI and EF treated effluent has produced similar effects on the percentage of germinated seeds, IVG, percentage of normal seedlings and biomass production of sunflower. The use of AP treated by EF, with or without dilution, contributed significantly to the increase in soil salinity and sodium contents. On the other hand, AP treated by EF+OI, has produced similar effects to the control (distilled water)
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de, Farias Lima Flávia. "Oilfield produced water treatment with electrocoagulation." Doctoral thesis, 2018. https://tud.qucosa.de/id/qucosa%3A35508.
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Produced water is the largest waste product by volume in the oil industry and its treatment in onshore or offshore fields poses bigger and different challenges than what water engineers are used to encounter. Process to achieve reuse quality of this water is very expensive with many technical hurdles to overcome making the optimization of the treatment steps necessary.
Electrocoagulation (EC) generates coagulants in-situ responsible for destabilizing oil droplets, suspended particles, and common pollutant in produced water. Furthermore, EC is a very efficient technology compared with traditional primary treatments used in the oil & gas industry and has several advantages such as: no hazardous chemical handling (which diminishes the risk of accident and logistic costs), high efficiency potential concerning boron removal, potential small footprint and less sludge generation.
In this research, the treatment of produced water using EC was investigated in a practical manner for the oilfield to aim for a cleaner effluent for further processing and help to achieve a reuse quality. For this, an EC cell was designed using different parameters normally used in the literature to fit this scenario. After preliminary tests, the treatment time was set to 3 seconds. Response surface method (RSM) was employed to optimize the operating conditions for TOC removal on a broad quality of synthetic produced water while varying: salinity, initial oil concentration and initial pH. TOC was chosen to be the main response because of its importance in legislation and sensibility on the method.
Furthermore, turbidity removal, change of pH value after EC in water with lack of buffer capacity, aluminum concentration and preliminary tests involving boron removal and influence of hydrogen carbonate were also studied. Real produced water was treated with EC to assess the optimum conditions obtained by the RSM showing the results were closely related. Finally, an estimation of volume required and operating cost for EC in the different types of produced water was made to assess how realistic it is for onshore and offshore applications.:ERKLÄRUNG DES PROMOVENDEN I
ACKNOLEDGEMENT III
ABSTRACT V
TABLE OF CONTENT VII
LIST OF FIGURES IX
LIST OF TABLES X
LIST OF EQUATIONS XII
ABBREVIATIONS XIV
1. INTRODUCTION 1
2. PRODUCED WATER 6
2.1 Characterization of Oilfield Produced Water 6
2.2 Produced Water Management 10
2.2.1 Discharge and Regulations 10
2.2.2 Efforts on Reuse 11
2.2.3 Cost 14
3. PRODUCED WATER TREATMENT 17
3.1 Most Common Primary Treatment 17
3.1.1 Hydrocyclones 17
3.1.2 Flotation unit 18
3.2 Further Water Treatment Technologies 19
3.2.1 Membrane Process 19
3.2.1.1 Microfiltration 19
3.2.1.2 Ultrafiltration 21
3.2.1.3 Nanofiltration 23
3.2.1.4 Reverse Osmosis 24
3.2.1.5 Forward osmosis 24
3.2.2 Electrodialysis 25
3.2.3 Biological treatment 28
3.2.3.1 Aerobic and anaerobic process 28
3.2.3.2 Combining membrane and bio-reactor 29
3.2.4 Oxidative process 30
3.2.4.1 Oxidation process 30
3.2.4.2 Anodic oxidation 32
3.2.5 Thermal technology 34
3.2.5.1 Evaporation 34
3.2.5.2 Eutectic freeze crystallization 35
3.2.6 Adsorption and ion-exchange 36
3.3 Electrocoagulation 39
3.3.1 Colloidal Stability Theory 39
3.3.2 Theory of Electrocoagulation 40
3.3.3 Mechanism of Abatement of Impurities 44
3.3.4 Operational parameters and efficiency 49
4. MATERIALS AND METHODS 51
4.1 Analytical Techniques and Synthetic Solutions 51
4.1.1 Analytical Techniques 51
4.1.2 Synthetic Produced Water 51
4.2 Design of Experiment and Models 54
4.3 Experimental Protocol for EC 56 4
.4 Development of the new Electrocoagulation cell 57
4.5 Real Produced water 58
5. RESULTS AND DISCUSSION 59
5.1 Designing EC Cell Process 59
5.1.1 Computational Fluid Dynamics for EC manufacturing 59
5.2 Preliminary Experiments 61
5.2.1 TOC Removal and Residence Time Determination 61
5.2.2 Aluminum Concentration 64
5.3 Models Quality and Range of Validity 66
5.3.1 TOC Removal 66
5.3.2 Turbidity Removal 69
5.3.3 Final pH value 71
5.3.4 Ionic Strength and Interpolation for Different Salinities 73
5.3.5 Partial Conclusions 76
5.4 Evolution of the Final pH Value 78
5.5 Operation Region for Effective Treatment of Produced Water with EC 80
5.5.1 Produced Water with Low Salinity 80
Organic Compounds Removal 80
Turbidity Removal 83
5.5.2 Produced Water with Medium Salinity 84 Organic Compounds Removal 84
Turbidity Removal 86
5.5.3 Produced Water with High Salinity 87
Organic Compounds Removal 87
5.6 Influence of Hydrogen Carbonate 90
5.7 Real Produced water 91
5.8 Boron Removal 93
5.9 Estimation of the Size for EC in Full scale 94
5.10 Produced Water with Very Low Salinity and EC 95
5.11 Estimation of Operation Cost 96
6. CONCLUSION AND RECOMMENDATIONS 98
6.1 Conclusion 98
6.2 Recommendations for Future Work 101
Scale up on EC for upstream 101
Further processing and reuse 101
Online optimization for EC 101
Recommendations for any research related to upstream produced water 101
BIBLIOGRAPHY 102
APPENDIX A 117
APPENDIX B 120
Conference papers on the topic "Onshore produced water"
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Trusmiyadi, Yadi, Farid Kurniawan, Rila Fitria, Esther Elias, and Ahyat Muhyinsyah. "Produced Water Treatment Improvements in Facing Indonesian Government Regulation on Onshore Disposed Waste Water." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/145651-ms.
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Ladmia, Abdelhak, Younes bin Darak Al Blooshi, Abdullah Alobedli, Dragoljub Zivanov, Myrat Kuliyev, Eric Deblais, Manal Al Beshr, et al. "Downhole Oil Water Separation to Handle Produced Water Study Case Onshore & Offshore Fields Abu Dhabi." In SPE Annual Technical Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205996-ms.
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Abstract The expected profiles of the water produced from the mature ADNOC fields in the coming years imply a 5-fold increase and the OPEX of the produced / injected water will increase considerably. This requires in-situ water separation and reinjection. The objective is to reduce the cost of handling produced water and to extend the well natural flow performance resulting in increased and accelerated production. The current practice of handling produced water is inexpensive in the short term, but it can affect the operating cost and the recovery in the long term as the expected water cut for the next 10-15 years is high. A new water management tool called downhole separation technology was developed. It separates Oil & Gas from produced water inside the wellbore and injects the produced water into the disposal wells. The Downhole Oil Water Separation Technology is one of the key development strategies that will reduce the handling Produced water, improve the recovery, and minimize field development cost by eliminating surface water treatment and disposal well. The main benefits for DHOWS are to accelerate Oil Offtake, reduce Production Cost, Lower Water Production and Improve facility Utilization. DHOWS require specific criteria to meet the objectives of the well. Multi-disciplined inputs are needed to properly install effective DHOWS, but robust design often brings strong performance. This paper describes the fundamental criteria and workflow for selecting the most suitable DHOWS design for new and sidetracked wells to deliver ADNOC production mandates cost effectively while meeting completion requirements and adhering to reservoir management guidelines.
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John, Udeme, Ibi-Ada Itotoi, Adeiza Isah, Anita Odiete, Erome Utunedi, Musa Mohamma, and Martins Ikhuehi. "Development of Injectivity Decline Modelling Tool: A Case Study of Onshore Niger Delta Produced Water Re-Injection Project." In SPE Nigeria Annual International Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/207087-ms.
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Abstract The largest component of operating costs in most matured assets utilizing 3rd party evacuation infrastructure is crude handling charges. In mature fields with significant water production, water volumes could easily account for over half of crude handling costs. Produced water re-injection for disposal has become a popular strategy for optimizing liquid handling cost as well as supporting environmental responsibility. Injectivity for water disposal wells have been demonstrated to decline with time, the most common factor being permeability reduction arising mostly from fines migration, suspended and dissolved solids in injected water, microbial activities, oil in water and cation concentrations, etc. Thus, Injection wells typically require intermittent stimulation to restore or improve injectivity. Fracturing has been demonstrated to prolong injectivity. However, sustainability is greatly affected by ability to keep fractures open after shut-ins and limited by environmental regulations. Understanding the key mechanisms that lead to injectivity decline will help optimize produced water reinjection systems, enable proactive intervention planning, thus improve injectivity and well availability. In this work we present the development of an injectivity modelling and simulation tool called IDS based on relatively recent injectivity models. Testing and validation of the tool using standard data and an active onshore Niger-Delta Produced Water Reinjection Project as a case study are presented. An outstanding feature of this simulator is its ability to estimate missing parameters or those whose values are not known to high fidelity via history matching. The resulting nonlinear regression problem is solved using a trust-region reflective approach. Decline mechanism regression parameters were similar for a well that had multiple injection periods. Transition time from deep bed to external cake is very sensitive to Total Suspended Solids (TSS) in injected water. Injectivity half-life could increase by as much as 100% for about a 100% drop in mean TSS concentration. The IDS tool was used to predict the injectivity half-life of Well A in the water disposal project.
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de Azevedo, Fa´bio Braga, Rafael Familiar Solano, Julian de Freitas Hallai, and Carlos Terencio Bomfimsilva. "Final Design and Installation Constraints of a Shallow Water Oil Pipeline at the Capixaba North Terminal Offshore Brazil." In ASME 2005 24th International Conference on Offshore Mechanics and Arctic Engineering. ASMEDC, 2005. http://dx.doi.org/10.1115/omae2005-67400.
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The Petrobras Capixaba North Terminal - TNC is located in the state of Espirito Santo, in Brazil and is being built to receive the heavy and high viscosity oil produced onshore in the Fazenda Alegre field. This oil shall be heated prior to be pumped into the pipelines and it will be exported through a monobuoy and a tanker system. The two export pipelines are being laid to connect the onshore Terminal to a subsea PLEM to be installed under the monobuoy. The pipelines and PLEM were designed to operate with oil containing H2S in cyclic high temperature. This paper addresses the special concerns defined by the design activity to cope with the TNC operation conditions. It also focuses the modifications imposed to the installation process to fulfill the design and operation requirements.
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Peter, Osode, Oluwatoyin Olusegun, Temitayo Ologun, and Obinna Anyanwu. "Produced Water Disposal in Deep Aquifers: Case History Review of Ughelli East-30 Pilot Injector." In SPE Nigeria Annual International Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/207094-ms.
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Abstract A water injector pilot well - Ughelli East-30, was drilled across high-permeability unconsolidated sandstone aquifers to dispose 30 Mbwpd of produced water in November 1998 and suspended in December 1998 due to lack of injectivity. Review of the failed pilot injection was performed as part of an extensive water management study for a cluster of onshore fields located in the western Niger Delta area. The technical investigation focused on the target disposal aquifer petrophysical parameters, produced water composition analysis, well completion design and injection performance result. Potential impairment mechanisms and failure risk factors for injectors with similar cased-hole, perforated completion design in analogue reservoirs were also investigated. The poor well injectivity performance was attributed to sub-optimal sand control completion design and the ‘water hammer’ effect which resulted in massive sand fill as evidenced by a sand bailing exercise during November 1999 riglessre-entry in the well. The 17-ft rat hole below the bottom aquifer sand perforations was also deemed to be inadequate for the sand fill which apparently bridged the perforations. Optimal completion requirements to prevent water injection failure in unconsolidated sandstone formation has been brought to the fore in this paper which is expected to steer engineers focus to those factors with high impact on water injection system performance.
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Avagianos, Josef, and Kostas Papamantellos. "New Technology Spiral SAW Pipes for Onshore and Offshore Oil and Gas Pipelines." In 2002 4th International Pipeline Conference. ASMEDC, 2002. http://dx.doi.org/10.1115/ipc2002-27185.
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The world production capacity on large-diameter welded pipe amounts to more than 12 million tons per year 20–25% are produced as spiral sub-arc welded (SAW) pipes, with the balance of 75–80% being longitudinal SAW pipes (from plates). For most spiral-weld producers, a sizeable portion of line pipe is for water transportation, rather than hydrocarbon. In the past, the relative structural weakness of spiral-welded pipe, due to larger welded area, limited the growth of its use in the oil industry. With the development of more advanced production technology, the acceptance of spiral-welded pipes in the oil and gas industry has increased significantly. In this paper, the principals of the spiral manufacturing technology from coil by the two-step-method are introduced and the innovations of Corinth Pipework’s production facility are outlined in detail, including the sophisticated NDT techniques and the Quality Management System.
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Wylde, Jonathan J. "Sulfide Scale Control in Produced Water Handling and Injection Systems: Best Practices and Global Experience Overview." In SPE International Oilfield Scale Conference and Exhibition. SPE, 2014. http://dx.doi.org/10.2118/spe-169776-ms.
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AbstractIron sulfide scale is found almost ubiquitously in maturing oilfield produced water handling and injection systems. Keeping injection systems clean of sulfide scale is becoming more of a shared challenge, but there are few examples where true root cause analysis has led to specific laboratory testing and development of bespoke removal and prevention methods. This paper aims to link these aspects by sharing the best practices from around the world with cutting edge techniques and chemistries used to maintain flow assurance and injectivity in produced water handling systems affected by iron sulfide scale.Discussion includes root causes analysis of iron sulfide scale formation and deposition mechanisms focusing on the interplay of pH, along with sources of iron and sulfide. The paper goes onto discuss laboratory and field evaluation of control methods. Finally, the root causes of iron sulfide scale formation and deposition mechanism, including the relative advantages and merits of the different techniques, including: Chelating agents (for iron sequestration)Surfactants (for water wetting)Biocide (to target SRB and biofilm)Corrosion inhibitor (to lower iron in system)Sulfide scale inhibitors (threshold inhibition of scale)Additionally, case histories are used to elaborate the theoretical discussion. The first case history is from an offshore oilfield water injection system, where fouling occurred due to changes in the flow assurance strategy further upstream and capture the lessons learned on the interplay of different production chemicals. The second case history concerns an onshore oilfield with a vast water injection system of over 3,000 wells supporting approximately 5,000 production wells.The paper concludes with a summary of the decades of experience of solving the most challenging sulfide scaling scenarios, as well as cutting-edge research on a new class of polymeric exotic sulfide scale inhibitor dispersant, effective as threshold concentrations against even lead and zinc sulfide.
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Alleyne, N. A., and V. Stoute. "Options for Monetising Deep Water Gas in Trinidad and Tobago." In SPE Energy Resources Conference. SPE, 2014. http://dx.doi.org/10.2118/spe-169926-ms.
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Abstract Notwithstanding the global thrust to develop renewable sources of energy, fossil fuels, coal, crude oil and natural gas are expected to play a significant role in meeting the world's energy needs for decades to come. Natural gas with the highest hydrogen concentration among the fossil fuels is the preferred fossil fuel from an environmental impact standpoint. Trinidad and Tobago, like the rest of the world, is taking its petroleum exploration activities into deep water, its onshore and continental shelf provinces being fully explored. The development of petroleum reservoirs in deep water has many challenges. This paper explores the unique challenges posed by developing deep water gas fields with a focus on the options available for monetising the natural gas produced from these fields. The options for getting gas to market are well known and include pipelines, liquefied natural gas (LNG), compressed natural gas (CNG), gas to solid petrochemicals (GTS), gas to liquids (GTL) and gas to wire (GTW). Most of these options are operating in Trinidad and Tobago. The paper evaluates the financial outcomes from applying the pipeline, LNG and CNG options, either offshore or onshore, for gas extracted from deep water fields across a range of reserve levels and well productivities. It aims to establish criteria for deciding which means of monetisation is preferred. The reserve and productivity ranges reflect typical values encountered in the deep water provinces in Latin America, North America and Africa. These provinces account for 85% of all the deep water fields and 74 % the deep water reserves which have been discovered worldwide. Because the paper focuses on the monetisation of natural gas, its findings will be applicable to any successful deep water exploration in Trinidad and Tobago because all situations, even the discovery of oil, will require that the associated gas be handled. The handling of gas has the potential of being on the critical path in deciding on the development of deep water fields in Trinidad and Tobago.
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Crippa, Stefano, Lorenzo Motta, Alessandro Paggi, Emanuele Paravicini Bagliani, Alessandro Elitropi, and Philippe Darcis. "New Generation of Heavy Wall Thicknesses Line Pipes for HPHT and Ultra-Deep Water Applications." In ASME 2018 37th International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2018. http://dx.doi.org/10.1115/omae2018-77803.
Full textAbstract:
Oil and Gas industry in the last decades has increased the use and need of heavy wall thickness line pipes, in particular for onshore / offshore high pressures and high temperatures (HP/HT) and offshore deep water / ultra-deep water applications. The paper presents the results achieved by Tenaris on seamless line pipes in grades X65/X70, according to API 5L / ISO 3183, with wall thickness in a range from 40 to 60 mm and diameter between 6 5/8” and 16”, produced by hot rolling process followed by quenching and tempering. Such line pipes are able to withstand very demanding conditions, like sour environment, very high pressure and wide temperature range. In this publication, the main outcomes of laboratory testing activities on the mentioned materials will be presented as part of heavy wall line pipe qualification. For this purpose, a special testing program, including mechanical and corrosion tests, has been executed. Material demonstrated an excellent behaviour, exhibiting both mechanical, toughness and stress corrosion properties suitable for the envisaged harsh applications.
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Zhang, Yong, Yang Wang, Yan Zhang, Lixin Zhao, Feng Li, Fengshan Wang, and Guoxing Zheng. "Design of Hydrocyclone With Axial Inlet and its Performance Used in Wellbore." In ASME 2014 33rd International Conference on Ocean, Offshore and Arctic Engineering. American Society of Mechanical Engineers, 2014. http://dx.doi.org/10.1115/omae2014-23537.
Full textAbstract:
With the increasing of the water ratio in produced fluid year by year, the cost of oil extraction will turn high gradually wherever in onshore oilfields or offshore oilfields. Downhole Oil/Water Separating System (DOWS) with hydrocyclone as the downhole separator is the key technology to separate most water from the produced fluid and reinject it into the suitable formation. This system can significantly reduce the oilfield produced water which is the universal puzzle all around the world. While how to decrease the diameter of the separator is a bottleneck problem to expand the flexibility of DOWS. There is a disk type inlet used for the conventional hydrocyclone which can bring fluid into the main body of hydrocyclone with the speed of rotation. The size of the disk type inlet will be bigger than the main body. And this is the main bottleneck for the miniaturization of hydrocyclone. So two new kinds of axial flow inlets were designed for the downhole separator in this paper. Helical structure was used as the unit of running fluid into hydrocyclone with the speed of rotation. It can make the diameter of the inlet and the main body of hydrocyclone to be equal. In the same time, it will simplify the arrangement of the flow path. The design, structure parameter optimization, the influence of separating efficiency of this inlet is discussed in this paper. And they show sharp separating capability as the downhole separators.