Multilaterals are often cited as technology that can be implemented to maximize reservoir recovery rates. However, few operators have been willing to put multilaterals into practice. The most frequently cited reason for not considering multilaterals is risk. This paper presents a study of data from 22 years of actual multilateral well applications that demonstrate the reliability of the technology.For the purpose of this study, failure has been defined as the loss of either the lateral or main bore or the loss of the junction (and therefore access to both legs). In the context of this study, reliability has been defined as the ability to successfully construct and complete the multilateral junction. Where failures have occurred, a study to determine root cause(s) has been undertaken. The records of one multilateral service provider have been analyzed from more than 800 actual multilateral installations to determine success and failure rates. The reliability of multilaterals has been compared to the reliability rates of other wellbore completion and construction technologies.Multilateral technology (MLT), which was first implemented by Alexander Grigoryan in 1953, came into modern practice in the 1990s. Although it is not failure-free, the reliability of multilateral wells has improved remarkably during the past 22 years. This improvement in reliability has occurred as the complexities of multilateral installations have increased. This paper shows that successful completion rates of multilateral junctions have improved from slightly more than 87% for the period of 1995 to 1999 (with more than 100 junctions completed) to slightly more than 98% for the current five-year period (with more than 220 junctions completed). This improvement is the result of continuous planning, development of and adherence to procedures, management of change, communication, and continuous improvement. This is the first known study of multilateral reliability that encompasses a large body of data over a significant time period. The results presented should enable operators to make fact-based decisions about the reliability of MLT and about whether or not this technology should be considered for implementation into resource development plans.
7his paper was pre@ered for pmaanlalion at SPE Offshore Eu~1S9S hafd in Akdaan, Scafland 5-8 SaPtornb$f 199S. TM x was aafacfad fw presentation by en SPE program Committee foffowing r.sWaw of informalicm contained in en abstract aubmiied by the author(s). C.miente of the paper, a?. presented, heve nc4 bean reviewed by the Socii of Peft'Oi$Um Engineers end are aubluf to cwectkm by the author(s). The materiel, as p+aeenled, tis not necessarily roflecf any poeitlon of the society of Petroleum Enginsam, its ofkars, or members. Papers presented at SPE m@$f@$~. suWcf to fwbfkafti redew by EMorial Committees of the Sooiafy of Petroleum Engineers. Permission to copy is rasffiofed to an abahecf of not more than S00 words. Illustrafiis may nd be cc@ad. The abstractshould ccmtainconspicuous ecknMadgmWt of where and by whom the pspar was presented. Write Librarism SPE, P.O. Sox S2SSSS. Richardson, Tx. 7EOSMSS6, U.S.A., fax 01-214-S52-94S5.
The Wilcox formation in the Lower Tertiary is an interesting and challenging development. The industry is currently seeking ways to increase efficiencies, increase production, and optimize performance of this reservoir. This paper discusses the current status in generation V single-trip multizone completions as well as future prospects to predict industry options for the formation.This paper seeks to spur the industry into thinking about the future cost benefits and management of change necessary to design solutions for this unique development. Regarding Lower Tertiary wells, operators sometimes assume the wells are similar to the Wilcox formation in South Texas. However, studies indicate these wells should be treated like other Gulf of Mexico (GOM) wells, and they do require sand control. Is the industry willing to take these technical development risks? If unique solutions are proposed, what preparations are necessary, and how should planning proceed?There are unique solutions that operators can apply to the deepwater GOM as well as alternative solutions, processes, and procedures developed for land applications that can be adapted to the deepwater GOM. Land production has adopted the horizontal approach for efficiencies, but is this the correct approach for deep water? The multilateral approach is an interesting option that has been applied in other offshore environments, but is this a concept adaptable for the Lower Tertiary? How can monitoring and control be applied to these two concepts from land applications? How do operators take industry knowledge and apply it to the unique offshore environment of deepwater and subsea completions?The ultimate goal of this paper is to examine these questions and initiate the thought process of how the industry can optimize the returns from the Lower Tertiary by increasing production and recoverable reserves through technology and reservoir management.
The use of multilateral technology (MLT) reduces the number of production wells required to effectively drain a reservoir; consequently, it saves time and reduces costs. Fewer discrete surface locations significantly reduces both investment capital and footprint. Although reducing the infrastructure cost is the primary benefit of multilateral well architecture, in remote arctic environments, additional benefits include reduced project execution time (in this case, approximately 50 less days), which reduces the costs associated with the heating of fluids and equipment and the costs for cuttings disposal. To take full advantage of the benefits, the appropriate MLT must be selected to avoid introducing additional risk and nonproductive time (NPT) to the project. The requirements for the multilateral system in the Yamal-Nenets area included constructing a mechanically strong junction and preventing communication between the two reservoirs. The TAML Level 4 multilateral technology, which provides hydraulic and mechanical isolation of the connected wellbores, meets this requirement. Although this was the first time that this level of junction was used in the Yamal-Nenets area, it has been used extensively in various geographical areas during the last 10 years.
Снижение экологически ответственным способом капитальных и эксплуатационных затрат при разработке газовых месторождений на арктическом севере России посредством строительства многоствольных скважин Рене Керегуан и Андреас Гроссманн, общество инженеров-нефтяников, компания Халлибуртон Авторское право 2011 г., Общество инженеров нефтегазовой промышленности Этот доклад был подготовлен для презентации на Конференции SPE по разработке месторождений в осложненных условиях и Арктике 18-20 октября 2011 года в Москве, Россия.Данный доклад был выбран для проведения презентации Программным комитетом SPE по результатам экспертизы информации, содержащейся в представленном авторами реферате. Экспертиза содержания доклада Обществом инженеров нефтегазовой промышленности не выполнялась, и внесение исправлений и изменений является обязанностью авторов. Материал в том виде, в котором он представлен, не обязательно отражает точку зрения SPE, его должностных лиц или участников. Электронное копирование, распространение или хранение любой части данного доклада без предварительного письменного согласия SPE запрещается. Разрешение на воспроизведение в печатном виде распространяется только на реферат объемом не более 300 слов; при этом копировать иллюстрации не разрешается. Реферат должен содержать явно выраженную ссылку на авторское право SPE. Краткий обзорИспользование многоствольной технологии сокращает количество скважин, необходимых для эффективной эксплуатации газоносных пластов, таким образом экономя время и затраты. Меньшее количество обособленных площадок добычи приводит к значительному сокращению капитальных вложений и последствий воздействия на окружающую среду. Хотя сокращение расходов на инфраструктуру является основным преимуществом конструкции многоствольной скважины, в отдаленных арктических районах дополнительные выгоды заключаются в сокращении времени выполнения проекта ( в рассматриваемом случае -примерно на 50 дней), что приводит к снижению затрат на обогрев жидкостей и оборудования и снижает стоимость утилизации шлама выбуренной породы.Для того, чтобы полностью воспользоваться преимуществами, должна быть выбрана соответствующая многоствольная технология, во избежание возникновения дополнительных рисков и непроизводительного времени при реализации проекта. В Ямало-Ненецком АО многоствольная система должна была обеспечить прочное механическое соединение стволов и не допускать разобщения между продуктивными стволами.4 Уровень Технологии Многоствольных Скважин (TAML), обеспечивающий хорошую гидравлическую и механическую изоляцию соединенных скважин, соответствует этому требованию. Этот уровень соединения многоствольных скважин впервые использовался в Ямало-Ненецком АО, он широко применяется в различных географических районах последние 10 лет. ВведениеПри постоянном увеличении спроса на нефть и газ по всему миру, увеличивается интерес к Арктике как к потенциальному поставщику этих ресурсов. Однако экономически выгодная поставка природного газа с тех удаленных месторождений на европейские рынки остается сложной задачей, так...
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