The Open Petroleum Engineering Journal最新文献

Effect of Mud Weight on Hole Cleaning During Oil and Gas Drilling Operations Effective Drilling Approach 油气钻井作业中泥浆比重对井眼清洁的影响

The Open Petroleum Engineering Journal Pub Date : 2019-05-31 DOI: 10.2174/1874834101212010014

K. Igwilo, E. Okoro, P. N. Ohia, Solomon A. Adenubi, N. Okoli, Temilade Adebayo

{"title":"Effect of Mud Weight on Hole Cleaning During Oil and Gas Drilling Operations Effective Drilling Approach","authors":"K. Igwilo, E. Okoro, P. N. Ohia, Solomon A. Adenubi, N. Okoli, Temilade Adebayo","doi":"10.2174/1874834101212010014","DOIUrl":"https://doi.org/10.2174/1874834101212010014","url":null,"abstract":"Introduction: A good hole cleaning operation is an important factor for every successful drilling program. Drilling mud should be formulated to suspend and transport cuttings effectively to minimize the number of drill cuttings in the hole. It is therefore, essential to determine the best weighing material that would be incorporated into the drilling mud for efficient hole cleaning given the well’s condition and formation type. Methods: This work is aimed to provide a detailed comparative analysis on the effect of drilling mud weight, using different concentrations of barite and calcium carbonate as weighing materials to determine optimum materials for hole cleaning. Results and Discussion: The results show that barite gave a lower annular pressure drop and therefore, a better Equivalent Circulating Density (ECD) compared to calcium carbonate, though, calcium carbonate gave better results in terms of transport efficiency and cutting concentration compared to barite. Conclusion: Barite is highly applicable in high-pressure reservoirs and calcium carbonate is applicable in depleted reservoirs. It can also serve as a bridging agent and can be used in reservoirs where it is necessary to minimize formation damage.","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"71 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-05-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130216203","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}

引用次数: 6

Analysis of Spatial Distribution Pattern of Reservoir Petrophysical Properties for Horizontal Well Performance Evaluation-A Case Study of Reservoir X 水平井动态评价中储层岩石物性空间分布规律分析——以X油藏为例

The Open Petroleum Engineering Journal Pub Date : 2019-04-23 DOI: 10.2174/1874834101912010001

Aidoo Borsah Abraham, A. Evans, Brantson Eric Thompson

{"title":"Analysis of Spatial Distribution Pattern of Reservoir Petrophysical Properties for Horizontal Well Performance Evaluation-A Case Study of Reservoir X","authors":"Aidoo Borsah Abraham, A. Evans, Brantson Eric Thompson","doi":"10.2174/1874834101912010001","DOIUrl":"https://doi.org/10.2174/1874834101912010001","url":null,"abstract":"\u0000 \u0000 Building a large number of static models to analyze reservoir performance is vital in reservoir development planning. For the purpose of maximizing oil recovery, reservoir behavior must be modelled properly to predict its performance. This requires the study of the variation of the reservoir petrophysical properties as a function of spatial location.\u0000 \u0000 \u0000 \u0000 In recent times, the method used to analyze reservoir behavior is the use of reservoir simulation. Hence, this study seeks to analyze the spatial distribution pattern of reservoir petrophysical properties such as porosity, permeability, thickness, saturation and ascertain its effect on cumulative oil production. Geostatistical techniques were used to distribute the petrophysical properties in building a 2D static model of the reservoir and construction of dynamic model to analyze reservoir performance. Vertical to horizontal permeability anisotropy ratio affects horizontal wells drilled in the 2D static reservoir. The performance of the horizontal wells appeared to be increasing steadily as kv/kh increases. At kv/kh value of 0.55, a higher cumulative oil production was observed compared to a kv/kh ratio of 0.4, 0.2, and 0.1. In addition, horizontal well length significantly affects cumulative oil production of the petroleum reservoir studied.\u0000 \u0000 \u0000 \u0000 At kv/kh of 0.55, the results of the analysis showed a rapid decrement in cumulative oil production as the horizontal well length decreases. Considering horizontal well length of 3000 ft, 2000 ft, and 1500 ft, a minimum cumulative oil production was obtained from a horizontal well length of 1500 ft.\u0000 \u0000 \u0000 \u0000 The geostatistical and reservoir simulation methods employed in this study will serve as an insight in analyzing horizontal well performance.\u0000","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"57 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2019-04-23","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121566591","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}

引用次数: 4

Study of Influences of Fracture Additives on Stability of Crude Oil Emulsion 裂缝添加剂对原油乳化液稳定性影响的研究

The Open Petroleum Engineering Journal Pub Date : 2018-11-29 DOI: 10.2174/1874834101811010118

H. Fang, Mingxia Wang, Xiaoyun Liu, W. Jin, X. Ma, X. Meng, Feng Yan

{"title":"Study of Influences of Fracture Additives on Stability of Crude Oil Emulsion","authors":"H. Fang, Mingxia Wang, Xiaoyun Liu, W. Jin, X. Ma, X. Meng, Feng Yan","doi":"10.2174/1874834101811010118","DOIUrl":"https://doi.org/10.2174/1874834101811010118","url":null,"abstract":"\u0000 \u0000 A hydraulic fracture is a key technology to increase production of the low permeability oil fields. Fracture additives such as gels, friction reducers, pH adjusters and clay stabilizers were injected into the underground. While more than 50% of the fracture fluid remains underground. The residue of fracture fluid comes out with the produced liquid (a mixture of crude oil and water) in the subsequent oil recovery process, which results in a highly stable crude oil-water emulsion.\u0000 \u0000 \u0000 \u0000 The stability and stable mechanism of the emulsion with fracture fluid have been experimentally investigated.\u0000 \u0000 \u0000 \u0000 The influences of fracture additives and components of crude oil on the stability of emulsion were investigated by bottle test and microscopic examination. The interfacial tension and modulus of dilation were explored by a spinning drop interfacial tension meter and an interface expansion rheometer, respectively.\u0000 \u0000 \u0000 \u0000 The fracture additives played the key role on the emulsion stability. On one hand, the interface energy of oil-water was reduced by friction reducer (IFT was decreased from 24.0 mN/m to 1.9 mN/m), which was a favor for the formation of an emulsion. On the other hand, the dilational modulus of crude oil-water film was increased by hydroxypropyl guar and pH adjuster (Na2CO3) to form a viscoelastic film, which resulted in a highly stable emulsion.\u0000 \u0000 \u0000 \u0000 The residual fracture fluid accompanied by produced liquid resulted in a highly stable emulsion. The emulsion with fracture additives was difficult to be broken, which may affect the normal production of the oil field. A positive strategy such as developing demulsifier with high efficient should be put onto the schedule.\u0000","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-11-29","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133346792","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}

引用次数: 0

Experimental Study of the Contamination Effects of Gachsaran Formation Fluid on the Heavy-weight Drilling Fluid Gachsaran地层流体对重钻井液污染效应的实验研究

The Open Petroleum Engineering Journal Pub Date : 2018-10-30 DOI: 10.2174/1874834101811010107

Naeimavi Majid, Khazali Fereydoon, Abdideh Mohammad, Zohreh Saadati

{"title":"Experimental Study of the Contamination Effects of Gachsaran Formation Fluid on the Heavy-weight Drilling Fluid","authors":"Naeimavi Majid, Khazali Fereydoon, Abdideh Mohammad, Zohreh Saadati","doi":"10.2174/1874834101811010107","DOIUrl":"https://doi.org/10.2174/1874834101811010107","url":null,"abstract":"Gachsaran Formation is the cap rock of Asmari oil reservoir located in southwestern of Iran. The formation consists of halite, anhydrite, and tachyhydrite, The most important feature of this formation is the presence of high-pressure fluid.Drilling companies have to use heavy-weighted mud to drill the high-pressure formation. Sometimes the weight of drilling fluid is used, up to 2.65(gr/cm3). Although heavy-weight mud prevents formation fluid to flow into the well, it is difficult to maintain and control its properties. If the hydrostatic pressure is insufficient, the formation connate fluid penetrates into the drilling mud and contaminates it.The study found that the symptoms of this contamination lead to an increase in calcium, magnesium, carbonates, and bicarbonates levels, as well as a decrease in pH. The drilling fluid rheology also affected by the contamination.Then, method of curing this event is discussed. Prevention, the best treatment for this event was introduced. It was also found that, as soon as contamination signs appear, immediately increase the drilling fluid weight as much as possible, and then adjust the pH between 10.5 and 11.5. The maintain method described is continued until section drilling ends.","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"14 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127871026","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}

引用次数: 5

Evaluating the Effects of Monovalent and Divalent Salts on the Rheological Properties of Water Based Mud 评价一价盐和二价盐对水基泥浆流变性能的影响

The Open Petroleum Engineering Journal Pub Date : 2018-10-18 DOI: 10.2174/1874834101811010098

O. K. Dankwa, Prince Opoku Appau, E. Broni-Bediako

{"title":"Evaluating the Effects of Monovalent and Divalent Salts on the Rheological Properties of Water Based Mud","authors":"O. K. Dankwa, Prince Opoku Appau, E. Broni-Bediako","doi":"10.2174/1874834101811010098","DOIUrl":"https://doi.org/10.2174/1874834101811010098","url":null,"abstract":"Drilling fluid selection plays a key role in preventing major problems encountered during drilling operations such as hole pack-off, stuck pipe and loss circulation. Mud contamination which results from the overtreatment of the mud system with additives or foreign material entering the mud system during drilling operations causes unwanted changes in the properties of the mud. This makes the mud system inefficient in performing its major roles. This research studies the effects of monovalent and divalent salts namely Potassium Chloride, Calcium Chloride, and Magnesium Chloride on the rheological properties of water-based mud system which is most vulnerable to contamination.Sixteen mud samples were formulated of which fifteen were contaminated each with different concentrations (0.75 g, 1.50 g, 2.50 g, 3.50 g, and 5.0 g) of the various salts at ambient temperature.The results showed that the rheological properties such as plastic viscosity, apparent viscosity and yield point of the mud samples decreased as the concentrations of various salts increase.It was concluded that increase in the concentration of the salts resulted in a decrease in the rheological properties of the mud samples. This indicates that with the monovalent and divalent salt contamination, there is a significant decline in the performance of drilling mud since the salts affect the dispersion, hydration and flocculation behaviour of the particles. The effect was more profound with CaCl2 and MgCl2 salts than the KCl salt.","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"92 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-10-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126191749","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}

引用次数: 10

Evaluation of the Percolation Sensitivity of Loose Sandstone Using Digital Core Technology 利用数字岩心技术评价松散砂岩渗流敏感性

The Open Petroleum Engineering Journal Pub Date : 2018-06-22 DOI: 10.2174/1874834101811010084

Jin Pang, Junnan Li, Jie Liang, Xiaolu Wang, Mingqing Kui

{"title":"Evaluation of the Percolation Sensitivity of Loose Sandstone Using Digital Core Technology","authors":"Jin Pang, Junnan Li, Jie Liang, Xiaolu Wang, Mingqing Kui","doi":"10.2174/1874834101811010084","DOIUrl":"https://doi.org/10.2174/1874834101811010084","url":null,"abstract":"The integrity of the extracted core in loose sandstone gas reservoirs is poor, and because hydration and collapse easily occur, it is difficult to evaluate the sensitivity characteristics accurately by the traditional core flooding experiments.We instead investigate the stress sensitivity and water sensitivity of the formation water soaking time using digital core technology.We take the core of a loose sandstone gas reservoir as a research object and begin by scanning the core samples with a CT scanner. A three-dimensional image of the core can be obtained, the digital information extracted, the pore structure of the porous media mapped directly to the network, and a digital core established using the principles of fractal geometry. The three-dimensional pore network model can also be extracted. Next, we can compare and correct the results calculated by the model based on the real core experimental results, and an objective and effective digital core model can be obtained.Finally, we can calculate the different effective stress, pore throat parameters (pore throat radius, shape factor, coordination number, pore-throat ratio) and relative permeability of different formation water injury times. The research results demonstrate that in sandstone gas reservoir development, as the effective stress continuously increases, the rock pore-throat parameters continue to decrease, and the permeability of the reservoir rock ultimately declines by more than 43.2%. Clay minerals will expand after the edge and bottom water intrude into the reservoir and soak it for a long time: the pore throat is significantly narrowed within 30 days, while after 30 days more, the pore throat undergoes any only slight further changes, and the final permeability decline of the reservoir rock is up to 5.7%. The research results provide important basic petrophysical data for the development of loose sandstone gas reservoirs which, in turn, provide a scientific basis for formulating a reasonable gas production rate in a gas reservoir.","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"123 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":"123329286","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}

引用次数: 1

Modelling of Sub-Sea Gas Transmission Pipeline to Predict Insulation Failure 海底输气管道保温失效预测建模

The Open Petroleum Engineering Journal Pub Date : 2018-05-31 DOI: 10.2174/1874834101811010067

Ode Samson Chinedu, O. Emmanuel, Ekeinde Evelyn Bose, Dosunmu Adewale

{"title":"Modelling of Sub-Sea Gas Transmission Pipeline to Predict Insulation Failure","authors":"Ode Samson Chinedu, O. Emmanuel, Ekeinde Evelyn Bose, Dosunmu Adewale","doi":"10.2174/1874834101811010067","DOIUrl":"https://doi.org/10.2174/1874834101811010067","url":null,"abstract":"\u0000 \u0000 Thermally insulated subsea production and transmission systems are becoming more common in deep-water/ offshore operations. Premature failures of the insulation materials for these gas transmission pipelines have had significant operational impacts. The ability to timely detect these failures within these systems has been a very difficult task for the oil and gas industries. Thus, periodic survey of the subsea transmission systems is the present practice. In addition, a new technology called optic-fibre Distributed Temperature Sensing system (DTS) is now being used to monitor subsea transmission pipeline temperatures; but this technology is rather very expensive.\u0000 \u0000 \u0000 \u0000 However, this study proposed a model which will not only predict premature insulation failure in these transmission pipelines; but will also predict the section of the transmission line where the failure had occurred.\u0000 \u0000 \u0000 \u0000 From this study, we deduced that in gas pipeline flow, exit temperature for the system increases exponentially with the distance of insulation failure and approaches the normal operation if the failure occurs towards the exit of the gas pipe. This model can also be used to check the readings of an optic-fibre distributed temperature sensors.\u0000 \u0000 \u0000 \u0000 After developing this model using classical visual basic and excel package, the model was validated by cross plotting the normal temperature profiles of the model and field data; and R-factor of 0.967 was obtained. Analysis of the results obtained from the model showed that insulation failure in subsea gas transmission pipeline can be predicted on a real-time basis by mere reading of the arrival temperature of a gas transmission line.\u0000","PeriodicalId":377053,"journal":{"name":"The Open Petroleum Engineering Journal","volume":"29 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-05-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128998939","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}

引用次数: 3

Analyzing Effects of Multi-Wall Carbon Nanotubes (MWCNT) & Polyethylene Glycol (PEG) on Performance of Water Base Mud (WBM) in Shale Formation 多壁碳纳米管(MWCNT)和聚乙二醇(PEG)对页岩地层水基泥浆(WBM)性能影响分析

The Open Petroleum Engineering Journal Pub Date : 2018-04-30 DOI: 10.2174/1874834101811010029

Koorosh Tookalloo, J. Heidarian, M. Soleymani, A. Rashidi, Mahdi Nazarisaram

引用次数: 3

Lattice Boltzmann Simulation of Natural Convection in a Fractured Petroleum Reservoir Domain: Single-Phase and Multi-Phases Investigations 裂缝性油藏区域自然对流的晶格玻尔兹曼模拟:单相和多相研究

The Open Petroleum Engineering Journal Pub Date : 2018-04-30 DOI: 10.2174/1874834101811010048

H. Kaydani, A. Mohebbi, A. Forghani

引用次数: 0

Wiper Trips Effect on Wellbore Instability Using Net Rising Velocity Methods 净上升速度法对刮水器起下钻井筒失稳的影响

The Open Petroleum Engineering Journal Pub Date : 2018-03-30 DOI: 10.2174/1874834101811010014

A. Darwesh, T. Rasmussen, N. Al‐Ansari

引用次数: 2