Volume 10: Petroleum Technology最新文献

{"title":"Jet Cleaning Processes in the Plug and Abandonment of Oil and Gas Wells: An Experimental Study on Horizontal Miscible Jets","authors":"Hossein Hassanzadeh, Elliott Cournoyer, S. Taghavi","doi":"10.1115/omae2022-79424","DOIUrl":"https://doi.org/10.1115/omae2022-79424","url":null,"abstract":"\u0000 The plug and abandonment (P&A) operation is considered as one of the essential stages during life cycle of oil and gas wells. During the P&A operation, each well needs to go through the specific steps; these may include accessing behind the casing (i.e. annulus), cleaning the target area (i.e. inside and outside the casing), and installing the cement plug barriers in the target area. The jetting process is one of the efficient approaches in the cleaning step of P&A operation, where an injection fluid pushes and removes unwanted fluids/materials. To achieve an efficient jet cleaning process, studies on the effects of different parameters (e.g. operational parameters, fluid properties, and geometrical parameters) seem crucial.\u0000 In this paper, we experimentally study the characteristics of horizontal miscible jets, to develop an understanding about fundamental aspects of the jet cleaning process in P&A operation. We analyze the effects of the injection velocity, the perforation diameter, and the rheological parameters on jet characteristics, such as the laminar length and the mixing index. Based on our results, increasing the injection velocity leads to a decrease in the laminar length. Also, the mixing index before the perforated wall increases by decreasing the perforation diameter. In addition, using a non-Newtonian ambient fluid results in decreasing the mixing index.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"88 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125037508","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":"A Green and Environmentally Friendly Chelated Retarding Acid for Acidification of Sandstone Reservoirs","authors":"Liu Wei, Wang Qing, Xu Changfeng, Zhang Mengchuan, Kong Xinmin, Yao Erdong, Que Junren","doi":"10.1115/omae2022-79271","DOIUrl":"https://doi.org/10.1115/omae2022-79271","url":null,"abstract":"\u0000 Matrix acidizing is the main method to relieve formation damage in sandstone reservoirs. However, many problems in conventional mud acid acidification need to be carefully considered, such as fast acid-rock reaction, short effective action time, excessive dissolution near the well zone, and the secondary sedimentations from fluorosilicic acid, aluminosilicate, calcium fluoride and other pollution of the reservoir.\u0000 In this paper, a green and degradable amino acid chelating agent is investigated. This new type of sandstone chelating retarded acid system have features of chelating metal ions and slow proton release. The chelating ability of new retarder acid to calcium and iron metal ions was determined by complexometric titration. The retarding performance of chelating retarder acid were studied by core flow instrument and microscopic scanning electron microscopy. The results show that the new acid system is manifested by strong chelating ability to iron and calcium ions, low corrosion rate, good retarding performance. The permeability is increased by 225% after acidification. The results of electron microscopy scanning of the core surface before and after acidification show that the new acid solution acidification can effectively enlarge the pore-throat without generating secondary precipitations, which is a good choice for sandstone acidification practice.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"40 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132459263","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":"Oil and Gas Technologies as Key Elements for a Viable Deep Sea Mining Industry","authors":"E. Tjåland, S. Ellefmo, Kurt Aasly, Tor Berge Gjersvik, C. Fichler","doi":"10.1115/omae2022-81273","DOIUrl":"https://doi.org/10.1115/omae2022-81273","url":null,"abstract":"\u0000 Deep-marine mineral deposits, including polymetallic nodules, seafloor massive sulfides, and cobalt rich manganese crusts, are known down to 6000 meters water depths. Challenges of such extreme water depths, long distances from supply bases and the need for cost-effective technical solutions, share many similarities with challenges in the oil and gas industry. As in the case of oil and gas, the resource estimation of mineral resources depends to a large extent on geophysical measurements, including seismic and electro-magnetic measurements. Production of deep-marine mineral deposits can draw on experiences from oil and gas production from ultradeep water depths, and transportation of ore from the sea bottom can use riser technology employed in oil and gas projects. Floating Production Storage and Offloading vessels used by the oil and gas industry can be utilized to store ore from seabed mining before transport to onshore mineral processing facilities or, less likely, for mineral processing on the seabed, or onboard the Floating Production Storage and Offloading vessel. However, the large sea depths and the high investments needed to achieve a minimal ecological footprint, will need many innovations and new solutions. Such challenges are similar to what the oil and gas industry has developed for oil and gas exploration and production in deep water. Here we show how technologies from the oil and gas industry can be applied for deep sea mineral extraction.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129248734","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":"Long-Term Mechanical Properties of Barrier Materials for Cementing Operations – Analysis of Morphology and Micro-Structure","authors":"M. Kamali, M. Khalifeh, A. Saasen, Paulo Henrique Silva Santos Moreira","doi":"10.1115/omae2022-78634","DOIUrl":"https://doi.org/10.1115/omae2022-78634","url":null,"abstract":"\u0000 In the oil and gas and geothermal industry, a barrier material is pumped behind the casing to fill the annular gap between the casing and formation/outer casing. After placement, this slurry is solidified rapidly, and it functions to seal the annular space and protects the casing during the lifecycle of the well. In this article, four different barrier materials namely expansive cement, non-cement pozzolan-based material, geopolymer, and thermosetting resin are examined under equal conditions.\u0000 The long-term mechanical properties of the candidate materials were tested by measuring uniaxial compressive strength (UCS), tensile strength, and Young’s modulus. These properties were measured at seven different time intervals, from one day to nine months after curing at a bottomhole static temperature of 90 °C and pressure of 170 bars. The change in the mechanical properties was further investigated by using scanning electron microscopy (SEM), and energy-dispersive X-ray spectroscopy (EDS) techniques. The results were benchmarked with the properties of the API neat class G cement as non-commercial reference material.\u0000 Our results show that the neat class G cement had a consistent behavior in most of the test period, and its UCS was dropped by 23 % after nine months compared to six months. The expansive cement had no significant change in mechanical properties, but the expansive crystal can weaken the structure, especially close to the boundaries with the cement matrix. The pozzolanic material and geopolymer did not develop early strength. The pozzolanic material reached a plateau after seven days, while the geopolymer developed strength up to six months. The thermosetting resin had the highest UCS and tensile strength up to one month, but its mechanical properties were started to deteriorate from seven days after curing.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129293462","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":"Safety Evaluation Technique of Annular Pressure in Offshore High-Temperature High-Pressure Gas Wells","authors":"Yanjun Li, Shujie Liu, D. Gao, Zhi Zhang, Yang Long","doi":"10.1115/omae2022-80748","DOIUrl":"https://doi.org/10.1115/omae2022-80748","url":null,"abstract":"\u0000 The high-temperature high-pressure (HTHP) nature gas reserves in the South China Sea are 15 trillion cubic meters, accounting for approximately one-third of the total oil and gas resources in the South China Sea. There are many leak risk points of the HTHP wellbore, so it is very difficult to guarantee the wellbore integrity, and the annular pressure seriously threatens the test and construction security. Based on the safety assessment technology study of the annular pressure offshore HTHP gas fields, this paper designed the whole-life-cycle annular pressure management model and operation measures, developed the risk assessment technology of wellbore integrity, compiled the annular pressure diagnosis model, developed the calculation software of annular pressure critical control value, etc. And then, the critical control value of wellbore pressure can be calculated much more quickly and accurately for different production time, which could better manage the wellbore pressure risk and ensure the wellbore integrity. The safety assessment technology study result in the paper has been applied successfully in Yingqiong (YQ) Basin and achieved “zero” annular pressure during the on-site drilling, completion, and production operations.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"61 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126020351","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":"Optimization of Oil Recovery and CO2 Sequestration in Tight Reservoirs During CO2 WAG Flooding With Hydraulic Fracture","authors":"Baozhen Li, Jian Zhang, Xiaodong Kang, Liqi Wang, En-Gao Tang, Wensheng Zhou","doi":"10.1115/omae2022-81340","DOIUrl":"https://doi.org/10.1115/omae2022-81340","url":null,"abstract":"\u0000 Tight oil reserves are of great significance in oil exploration and development in China. CO2 flooding is promising in tight reservoirs due to its high mobility and better injectivity, and water alternative gas (WAG) flooding could improve sweep efficiency and oil recovery, which is extensively used. However, its injectivity in tight reservoirs is limited. The feasibility of improving CO2-water alternations performance in tight reservoirs by hydraulic fracturing was investigated in this study.\u0000 In this paper, numerical reservoir simulation was conducted to simulate CO2 WAG flood process with typical reservoir characteristics and hydraulic fracture properties of the YC formation. The optimization of hydraulic fracturing during CO2 alternative water injection process were performed with numerical simulation, response surface and multiple response optimization method, which could be done with acceptable accuracy by performing a limited number of runs, hence, reducing the engineering time, effort and money. With the simplified equation between the NPV or CO2 storage and different hydraulic fracture parameters, operators can determine the best combination of all the factors for different objectives. The results show that moderate fracture length, large fracture height and small water-gas ratio could achieve the optimal economic benefits and CO2 storage in low permeability reservoirs.\u0000 This work can provide a better understanding of the physical mechanisms and key parameters affecting the effectiveness of CO2 WAG flooding for enhanced oil recovery in the tight formation.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124895731","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":"Development of a Permeability Reduction Model Using Deep Learning for CO2 Hydrate Storage","authors":"Alan Junji Yamaguchi, Toru Sato, T. Tobase, Xinran Wei, Lin Huang, Jia Zhang, J. Bian, Tie-Yan Liu","doi":"10.1115/omae2022-78523","DOIUrl":"https://doi.org/10.1115/omae2022-78523","url":null,"abstract":"\u0000 Global warming is an important environmental issue, and carbon capture and storage (CCS) is a major technology to reduce the emission of greenhouse gases. Captured carbon dioxide (CO2) can be stored in aquifers onshore or offshore seabed regions. Nevertheless, a small risk exists in which CO2 may leak due to natural phenomena opening cracks in the caprock. The natural formation of CO2 hydrates may create a new impermeable layer managing to block a possible leakage. It is of utmost necessity to understand and evaluate the permeability change due to the hydrate formation. Numerical simulation on different spatial scales has been essential for this purpose. The main objective of this study is to create a new framework for permeability reduction due to CO2 hydrate formation. Using machine learning, a multiscale approach links a large reservoir scale hydrate formation model with a microscale model. Detailed information from the hydrate shape can be obtained from the microscopic range to predict the new permeability reduction coefficient. Initial results have shown that this approach can obtain the permeability change due to CO2 hydrate formation with reasonable accuracy.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124940239","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":"Dynamics of Gas Kick Migration in the Annulus While Drilling/Circulating","authors":"C. Obi, K. Manikonda, Luis Abril, A. Hasan, M. A. Rahman","doi":"10.1115/omae2022-79570","DOIUrl":"https://doi.org/10.1115/omae2022-79570","url":null,"abstract":"\u0000 Multiphase flow pattern during gas kick is made more complex while drilling or circulating out the kick (dynamic conditions). The additional pressure losses due to friction when circulating significantly change the flow pattern in the annulus. This pattern also evolves as the fluid migrates up the wellbore due to changing in-situ conditions and fluid properties. The effects of this scenario on flow pattern evolution have been investigated using water as the continuous phase, air, and carbon dioxide as the kicked fluid.\u0000 Experiments were carried out in a 140 ft high tower lab fitted with pressure gauges and digital cameras for visualization. We triggered gas kicks at 80 psi and 90 psi injection pressures and, an average liquid flow rate of about 7-gpm and 15-gpm. The gas rate ranged from about 0.05 ft3/min to 0.5 ft3/min for both air and carbon dioxide injection. The gas injection time ranged from 30 to 500 seconds for air and carbon dioxide to simulate kicks of different gas-liquid mass ratios of about 0.1 ft3/ft3 to 0.3 ft3/ft3. We observed that the fluid distribution, pressure gradient in the annulus of a 2.875-in drill pipe and a 5.5-in outer casing is more complex when circulating drilling fluid than in a shut-in scenario.\u0000 The effect of the initial kick pressure on the initial flow pattern observed (Taylor bubble) can be considered negligible. This is due to the fixed 2 in diameter of the gas injection line. The average gas-liquid flow rate and the duration of gas injection significantly affect the flow pattern observed after the “Initial Taylor bubble” (in space). The complexity of this flow behavior is more significant during carbon dioxide kicks than air kicks due to the solubility of carbon dioxide in water. The turbulence following the initial Taylor bubble increased with the average liquid flow rate. This is due to the additional momentum from liquid flow. Similarly, the duration of the kick did not affect the initial Taylor bubble observed but the “After Taylor bubble” flow significantly. These observations are more pronounced during carbon dioxide injection when the liquid is saturated, towards the surface as carbon dioxide begins to come out of solution.\u0000 This study shows the need to account for the “After Taylor bubble” flow effects when modeling gas kick behavior. Incorporating the physics of this scenario will significantly improve gas kick models and blow-out mitigation in drilling time.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125203917","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":"Pressure Build-Up in Closed Wells During Kick Migration and Fluid Compressibility Effects","authors":"M. Agonafir, J. Petersen, K. Fjelde","doi":"10.1115/omae2022-79700","DOIUrl":"https://doi.org/10.1115/omae2022-79700","url":null,"abstract":"\u0000 If a kick is migrating in a closed well, this will lead to pressures building up in the well. It has earlier been shown that for Non-Newtonian fluids, suspension effects will make it impossible to deduce a unique gas velocity from the pressure build-up behavior.\u0000 In this work, it will be shown that also for Newtonian fluids, the pressure build-up will depend on both kick size and well volumes. Both very small kicks sizes typically seen in MPD operations and larger kick sizes handled in conventional well control operations will be considered. It will be demonstrated that both the shape of the pressure build-up and the final pressure levels achieved will vary significantly. It is especially when considering very small kick sizes that one starts to see large changes in the profile of the pressure build-up. The main reason for the differences is related to the fact that the liquid phase is compressible and this will again have consequences for how much a gas kick can expand and what pressures it can bring to surface.\u0000 An analytical model will be developed that shows directly which parameters have impact on the pressure build-up behavior. Simple closure laws for gas density, fluid density and gas slip will be chosen. The model will be verified against two transient models which are based on the Drift-Flux formulation. It is demonstrated that the pressure build-up and final pressure level will depend on initial kick volume, initial fluid volume, liquid compressibility and fluid density. The effect of numerical diffusion when comparing the two transient models will also briefly be discussed.\u0000 The purpose of the paper is to increase fundamental knowledge about two phase flow dynamics and show that an analytical model for the situation considered here can give results that are comparable with the results achieved with more complex transient flow models.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"216 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133575459","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":"Offshore Energy Hubs in the Decarbonisation of the Norwegian Continental Shelf","authors":"Hongyu Zhang, A. Tomasgard, B. Knudsen, I. Grossmann","doi":"10.1115/omae2022-78551","DOIUrl":"https://doi.org/10.1115/omae2022-78551","url":null,"abstract":"\u0000 This paper studies the investment planning of a decarbonised Norwegian continental shelf energy system considering the connection and interfaces with the European energy system. A multi-horizon stochastic mixed-integer linear programming model is developed for such a problem. We consider short-term uncertainties, including wind and solar capacity factors, energy load, platform production profiles, and hydro power production limits. Hydrogen based energy hubs are considered both onshore and offshore for potential renewable power generation, distribution and storage. Future hydrogen market or demand is not included in the model. The results of multi-period planning towards 2050 show that: (a) offshore energy hubs are essentially wind power generation, conversion and distribution hubs, (b) a combination of offshore wind and power from shore may be a cost-efficient pathway for cutting emissions from the Norwegian continental shelf, (c) a total of 1.6 GW offshore wind may be needed to achieve a near zero emission Norwegian continental shelf energy system, 80% of which may be added in the first investment period and (d) offshore grid design is important for decarbonisation by distributing wind power efficiently; all five offshore platform clusters are connected to at least three other clusters by 2040, and they are fully connected by 2050.","PeriodicalId":363084,"journal":{"name":"Volume 10: Petroleum Technology","volume":"59 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-06-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132616110","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}