Day 2 Wed, November 16, 2022最新文献

{"title":"Geochemical Atlas of Oils and Source Rocks and Oil-Source Rock Correlations: A Case Study of Oil and Ggas Fields in the Mangyshlak Basin (Kazakhstan)","authors":"Y. Seitkhaziyev, N. Sarsenbekov, R. Uteyev","doi":"10.2118/212078-ms","DOIUrl":"https://doi.org/10.2118/212078-ms","url":null,"abstract":"\u0000 This paper presents the results of fingerprinting and biomarker analysis of 183 crude oil samples derived from 19 oil and gas fields in the South Mangyshlak basin and Rock -Eval pyrolysis performed on 93 core samples from 12 fields of this basin.\u0000 Geochemical atlas was made based on the oil fingerprinting studies, according to which, the studied fields of the South- Mangyshlak basin can be divided into 3 groups:\u0000 same type of oils on the scale of groups of fields. This group includes Permian-Triassic oils of the Karaginskaya Saddle (Northern Karagiye, Atambay, Alatyube, Ashchiagar) and the Peschannomyssko-Rakushechnaya uplift zone (Oymasha), which have very similar oil fingerprinting either within each field or on the scale of these fields. oils of the same type within the same field. The second group includes oils from Pridorozhnoye, Airantakyr, Burmasha and Bekturly fields, each of which has its own unique oil fingerprinting of light aromatic hydrocarbons. different types of oils within the same field. This group includes oils from the rest of the studied Zhetybay- Uzen steps such as Asar, East Zhetybay, South Zhetybay, Aktas, Turkmenoy, Tasbulat, Uzen and Karamandybas fields, since within each of these fields were identified several different groups of oils that require a detailed study of their biomarkers to determine their genetic origin and trace hydrocarbon migration pathways.\u0000 The obtained results of oil fingerprinting are consistent with their biomarker compositions, according to which the oils of the first group, identified by their fingerprinting, were generated from marine shaly source rocks, while those of the second group were from shaly source rocks, deposited in whether marine or lacustrine environments. The biomarker composition of the third group oils exhibited that the oils within each of these fields have at least two genetic sources: the oils of the lower pay zones have shaly marine OM source, while those of the upper upper pay zones were formed by OM deposited in lacustrine environment. Their biomarkers clearly show a regular change in the contribution of lacustrine OM input to marine one with the depth increase of pay zones and within the field of this group thermally more mature oils of a marine source (23-24 horizons Uzen and Karamandybas, J-10 and J-11 fields of Asar, Zhetybay, Zhetybay East) were mixed with relatively lower mature oils of the upper lacustrine source (13-16 th pay zones in Uzen and Karamandybas, J-J-3a, J-4a in Asar field, J-5 in Zhetybay, J-1 in Zhetybay East) with their upward migration.\u0000 To characterize source rocks, where the studied oils were generated, Rock-Eval pyrolysis was performed on core samples of different ages, which revealed that in reality the reservoirs of the Asar, Zhetybay, Karamandybas, Uzen and Akkar fields can be considered synclinal, that means, it serves as both reservoir and source rock, which explains the different oil fingerprintings and the vertical and lateral differences ","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129622049","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":"World's First Application of Steel Body Bit in High Chloride Formation with Water Based Mud","authors":"Bekbolat Uandykov, Yerkin Kurmanbayev, Anzor Tagirov, Teymur Muratov","doi":"10.2118/212109-ms","DOIUrl":"https://doi.org/10.2118/212109-ms","url":null,"abstract":"\u0000 Operator in North Western Kazakhstan, onshore Karatobe Yuzhnyj field was engaged in a task of reducing the well construction time in particular the challenging 12 ¼ in. section. The main complexity of drilling the 12 ¼ in. section is the presence of corrosive salt deposits traditionally drilled with matrix bodydrill bits aggravated by drilling with water-based mud (WBM) system. While matrix body drill bit is the primary choice in salt saturated drilling fluid and corrosive environment, consequences of this choice have a significant impact on the bit's poor rate of penetration (ROP) response.\u0000 The long 12 ¼ in. section is usually drilled in 3-4 bit runs with relatively low ROP and poor bit performance primarily occurs due to bit balling in shale section and Weight On Bit (WOB) limitations in interbedded carbonate section.\u0000 During the planning stage for the drilling campaign the Operator engaged with Zhigermunaiservice LLP drill bit engineering group to develop a fit-for-purpose solution for ROP optimization. New 12 ¼ in. ZS56 steel body drill bit with unique hardfacing design, improved hydraulics and shaped PDC cutters was developed and delivered on time for the drilling campaign. During the very first run the newly designed steel body bit demonstrated an outstanding performance in drilling highly corrosive salt deposits and other lithological sequences thus delivering the section from shoe to TD at record ROP. This bit was re-used to drill four consequent wells with similar performance.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127779953","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":"First Trial of Constant Bottom Hole Pressure Drilling Application in Kazakhstan","authors":"A. Aliyeva, Tim Higginson, Yerlan Amanbayev, Mohammed Felioune, Waleed Ashour, Christian Click, Joe V. Williams, Kuat Uteev, Scott Azar, Chase Hinson, Alibek Katenov, Inzhu Issayeva, Dastan Takhanov, Adilzhan Naukhanov, Anvar Ismuhkambetov, Nurzhan Kamzayev, Rustam Zhakenov, Kuanysh Kabiyev","doi":"10.2118/212069-ms","DOIUrl":"https://doi.org/10.2118/212069-ms","url":null,"abstract":"\u0000 An increase in differential sticking events, due to depletion of the reservoir and high angle wells being actively drilled in recent years, was a primary driver to utilize Managed Pressure Drilling technology in the Tengiz field. MPD offers a more dynamic and rapid wellbore pressure control by being able to adjust the surface back pressure applied at the annulus for a given mud weight, decreasing the risk of differential sticking while maintaining constant bottom hole pressure conditions.\u0000 The paper describes the results of the first Managed Pressure Drilling application in the Tengiz field and experience gained during execution where drilling multiple formations together enabled the target depth to be reached without NPT. It further highlights the operational complexity and the challenges faced during the implementation of this technology while drilling formations with varying pore pressures. The reservoir hole section had different pressure intervals, which required higher mud weight and thus high potential of differentially stuck-pipe conditions. The successful field trial shows that the Constant Bottom Hole Pressure (CBHP) application provides flexibility to be able to manage annular pressures when applying surface back pressure using an MPD choke manifold.\u0000 The paper elaborates on the lessons learned and how CBHP was implemented continuously with regards to health, safety, and environment (HSE) during drilling operations. The short-term goals were to evaluate whether the application of MPD could avoid the risk of differential sticking and reduce pumps-off gas, enhance drilling performance by using lower ECD, reducing well control time by working as early kick detection tool and provide a potential for mud cost savings, along with a long-term goal of providing the option to optimize the casing design by reducing one liner section and combining drilling of two reservoir sections in one run.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"431 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132529898","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":"Challenges in Original Oil-In-Place Estimation: Selection of the Best Method for a Field with Non-Uniform Geological Parameters","authors":"Ismail Magomadov, Saad Balhasan, Shakier Khalifa, M. Awad, Saad Yaqoob","doi":"10.2118/212112-ms","DOIUrl":"https://doi.org/10.2118/212112-ms","url":null,"abstract":"\u0000 Accurate original oil in place (OOIP) estimation is a serious industry concern, not only due to the economic issues but also the further field life and success of the development. The uncertainty surrounding the EE-Pool resource size is due to the unique values of the reservoir areas and net pay. This uncertainty in the reservoir area and net pay has also affected the estimated reserves, resulting in wrongly predicted reservoir potential. In order to reduce technical and economic risks associated with the uncertainty of EE-Pool, a data analytics approach applying different methods of OOIP determination techniques was used. EE-Pool contains a heavy amount of data: production data, PVT data, pressure data, well testing data, rock properties data, and geological data. The value of OOIP from the Material Balance Equation (Straight-Line method) was estimated at 100-million stock tank barrels of oil (MMSTB) for both areas and has been determined as a reference value. Compared with the reference value of OOIP, the volumetric method demonstrated the worst result with 63-% error and 63 MMSTB. While the Monte Carlo Simulation combined with Crystal Ball provided the most optimistic results with 9.1-% error and 9.1 MMSTB of oil.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114145455","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":"Comparison and Optimization of the Various Stimulation Methods: Case Study of Aryskum and Karabulak Fields","authors":"D. Abdrazakov, Aimurat Kudalsha, A. Mukanov, Duman Kassenov","doi":"10.2118/212085-ms","DOIUrl":"https://doi.org/10.2118/212085-ms","url":null,"abstract":"\u0000 A comprehensive study of about 200 production stimulation treatments in carbonate and sandstone formations of Karabulak and Aryskum brownfields was performed. The stimulation methods analyzed in this study are propped fracturing, acid fracturing, matrix acidizing with different fluids (both in carbonates and in sandstones), ultrasound treatments, and thermobarochemical treatments. The analysis consists of literature review, modeling of actual treatments in advanced fracturing simulation and matrix treatment simulation, and modeling of alternative schedules and fluids. The quick semiquantitative laboratory method of scales analysis is suggested as part of the study. As a result of the study, the key factors in the production decrease after propped fracturing are revealed; the reasons for the inefficiency of some matrix treatments are explained; and the mechanism of acid fracturing in the given layers is explained and suggestions are provided. In addition, some rare production enhancement-related methods (ultrasound and thermobarochemical treatments) are discussed. An overall table of production stimulation methods is provided, and it can be applied for any fields with similar characteristics.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"64 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132605521","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":"Facies Modelling in Thin Bedded Heterogeneous Reservoir – A Case Study from Dunga Field Aptian Reservoir","authors":"Assel Ospanova, P. Pinto, Zhandos Takirov, Trevor Runge, S. Mukherjee, A. Melvin","doi":"10.2118/212080-ms","DOIUrl":"https://doi.org/10.2118/212080-ms","url":null,"abstract":"\u0000 The Dunga field Aptian reservoir is very thin bedded and heterogenous at a fine (cm) scale below log resolution and presents distinct challenges for reservoir modelling. This paper describes methods for upscaling detailed thin bed reservoir description and facies mapping from core and log data to build a 3D geological facies model.\u0000 The Dunga Field is penetrated by approximately 190 wells, of which 9 are cored. Field wide correlation of the main reservoir units is sub-seismic and below biostratigraphic resolution. A novel method using step outs (cluster correlations) from the key cored wells to the closely spaced vertical well penetrations has provided a more detailed correlation and mapping of reservoir units. The method has provided consistent and field wide definition of depositional trends and architecture of deltaic mouthbars which form the main reservoir sandbodies.\u0000 Facies modelling of the heterogeneous reservoir was built by integrating and upscaling detailed core data, well data and depositional trends. Four facies, identified from log and core evaluation, are modelled using stochastic method (SIS), where facies fraction was controlled by up-scaled cells. The variogram directions of facies model are guided by sand body depositional trends. Depth appropriate facies probability maps are used for modelling clean sand and heterolithics facies to guide facies distribution.\u0000 The detailed study carried out to build the 3D geological facies model is helping to achieve better production history matching and is being used for future well planning.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"43 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129994138","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":"Combination of WFT and Conventional Well Testing Methods to Effectively Reduce the Time for Hydrocarbons Exploration in Tight and Fractured Suprasalt Carbonates Field in West Kazakhstan","authors":"Zhin Shutang, V. Blinov, A. Filimonov, Gongwei Fu, Kirill Shteynbrenner, Zhan-Tore Onggarbay, M. Zhabagenov","doi":"10.2118/212154-ms","DOIUrl":"https://doi.org/10.2118/212154-ms","url":null,"abstract":"\u0000 Low-porosity post-salt carbonate reservoirs of Carbonian and Devonian age at Pre-Caspian Region of West Kazakhstan have complex pore structure which cause significant uncertainties in petrophysical properties estimation based on standard wireline logs and subsequently time-consuming and less informative tests in the production string. Therefore, an integrated approach was proposed and applied, involving advanced wireline formation testing methods (WFT) to refine the petrophysical logging results and to optimize the formation tester program and significantly reduce time for dynamic fluid Well Testing in exploration wells.\u0000 The new approach integrates methods of WFT using modern technologies which allow to test ultra-low permeability formations. Thus, uncertainties in petrophysical properties such as saturation and fluid contacts are significantly reduced with the use of WFT and allowed to put together optimized and effective formation testing program. The approach described below has helped to cut down the time for Well Testing and brought in valuable information to clarify geological structure and to evaluate oil and gas content of explored reservoirs horizons.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"103 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131871032","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 Production Management: New Challenges and Solutions","authors":"S.Yu. Polyanskiy, E. Yudin, Andrey Slabetsky, N. Smirnov, Alla Andrianova","doi":"10.2118/212086-ms","DOIUrl":"https://doi.org/10.2118/212086-ms","url":null,"abstract":"\u0000 The organization of the management of an oil and gas producing enterprise has not experienced major changes over the past few decades. At the same time, extractive enterprises face numerous problems and challenges:\u0000 - Deteriorating stock quality, oil price volatility and volatility of market in general,\u0000 These problems are accompanied by a decrease in the efficiency of production: an increase in the water content of the stock, an increase in the number of downtime and complications on the stock, the appearance of unproductive lifting-costs\u0000 All this leads to a drop in the economic efficiency of asset development.\u0000 Current challenges, such as flexible production management, its economic efficiency, deterioration of the structure and quality of the resource base, the need for system-based linking of a large amount of additional information about the field on the one hand and a huge variety of calculation and digital tools on the other, dictate the need for an integrated transformation of the principles of production management of an oil and gas producing enterprise.\u0000 We offer you to familiarize yourself with the approach to the organization of oil and gas production management based on an effective process model and integrated digital solutions, the purpose of which is to optimize the operation of the field and ensure the growth of free cash flow from production. (Figure 1)","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"130371483","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":"E-line Deployed Robotics and Stimulation Workflow for Pilot Horizontal Well","authors":"Angus W. Morrison, Campbell Kinnear, Saltanat Koishymanova, Dave Clayton","doi":"10.2118/212070-ms","DOIUrl":"https://doi.org/10.2118/212070-ms","url":null,"abstract":"\u0000 This paper will outline the challenges faced and solutions employed to enable selective stimulation of a pilot horizontal well in the Tengiz field by mechanical manipulation of fracturing sleeves utilizing an electric line deployed tractor system. Specifically, how the robotic system enabled successful and selective stimulation of nine acid fracturing stages in a challenging operational environment. The scope reviews the planning and execution methodology utilized to enable selective stimulation and production along the lateral section.\u0000 While evaluating the concept of drilling a horizontal well through a deeper, previously undeveloped reservoir horizon, it was identified that multiple acid fracturing stages would be required along a 1,000-meter lateral section. The well objectives were such that each of the acid fracturing zones required the ability to be selectively stimulated and produced (selective shut-off of zones post-production if required). This design utilized an open hole completion with compartmentalization via swell packers and fracturing sleeves. Due to the trajectory and horizontal nature of the well, electric line deployed robotics were selected to access the fracturing sleeves.\u0000 The well was successfully drilled and completed in 2019 and stimulated in early 2021. All zones were effectively accessed utilizing the selected intervention and stimulation methodology. This was the first use of a robotics intervention technique in the Tengiz field. It was also the first horizontal well drilled and completed into the target reservoir horizon. Intervention challenges included high pressure/high temperature, H2S, well restrictions, drilling muds (with weighting agents), and of course the trajectory of the well with ~ 1,000m lateral section to traverse. The successful outcome was a result of the conceptual engineering, planning and execution of the intervention and stimulation work scope. Formal surface integration test (SIT) was required to identify the best sleeve shifting options, which supported the procedure for the intervention scope. Valued lessons learned and best practices specific to the completion design, tractor deployment and stimulation strategy were gained through the testing and implementation scopes that will be utilized for future similar projects.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"41 5","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114032389","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 the Wellbore Imaging Tools in Tengiz Field","authors":"D. Issayev, Marat Sargunanov, Ruslan Manakhayev, Yegor Se, D. Thornton","doi":"10.2118/212160-ms","DOIUrl":"https://doi.org/10.2118/212160-ms","url":null,"abstract":"\u0000 This paper provides an overview of the borehole imaging tools (BIT) run in the Tengiz-Korolev field giant carbonate reservoirs located in Western Kazakhstan.\u0000 Borehole imaging tools have historically been run in Tengiz-Korolev fields both wireline-conveyed and in logging-while-drilling (LWD) conditions. These tools provide indirect images that are derived from a high-density grid of electrical, ultrasonic and formation density measurements. Understanding the distribution of vugs and fractures in carbonate reservoirs greatly enhances the correctness of any proposed flow modeling and, through better plans for drilling and completion, improves production. There have also been successful attempts in generating core-like images based on high-resolution electrical resistivity data recorded in Tengiz's unique \"non-conductive\" oil-based mud environment. Validation of existing core data with resistivity image log-based fracture picks was performed and encouraged the log-based fracture characterization workflow at wells. Incorporation of the BIT interpretation results confirmed the depositional settings and rock types of interest in both tight matrix and naturally fractured reservoirs.\u0000 Understanding the distribution of fractures and karst properties across the conceptual geological regions allowed for calibration of the static and dynamic models. On top of the reservoir model, the implementation of the BIT analysis results helped to constrain key subsurface uncertainties in the principal stresses of the Tengiz 3D mechanical earth model, which is of first order importance for fault reactivation and development of shear zones. The interpretation results allowed determination of the maximum horizontal stress direction from both drilling-induced tensile fractures and borehole breakouts in image-logged intervals.\u0000 Currently, the imaging tool is included in the standard well logging program of the field, and characterization of the field utilizing these datasets is ongoing.","PeriodicalId":131012,"journal":{"name":"Day 2 Wed, November 16, 2022","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-11-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124375548","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}