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Susilo, Raden Yoliandri (bp Azerbaijan) | Yahyayeva, Narmina (bp Azerbaijan) | Saavedra, Luis (bp Azerbaijan) | Loboguerrero, Santiago (bp Azerbaijan) | Akhundova, Gumru (bp Azerbaijan) | Rasul-zade, Ali (bp Azerbaijan) | Whaley, Kevin (bp America)
Abstract Azeri-Chirag-Gunashli (ACG) is a giant field located in the Azerbaijan sector of the Caspian Sea. The major reservoir zones are multi layers sandstone formations with oil column up-to 1000m, and weakly consolidated where Open Hole Gravel Pack (OHGP) completions have become the standard design for production wells. Development began in 1997 and to date more than 130 high rate OHGPs have been installed. Once existing wells has been uneconomically to be produced, a Sidetrack or Up-Hole Recompletion (UHRC) will be performed. The standard 9-5/8" sidetrack technique will be done by drilling new section, installing and cemented a 7-5/8" liner, then drilling 6.5"x8" hole in pay zone followed by running 4" Shunted Screen and gravel packing. Previously C&P technique has been used for UHRC option but it was producing at limited drawdown and quickly sand up when water break through. Cased Hole Gravel Pack (CHGP) technique has been trialed as UHRC option in the past 2 years but has limitation of the number zone & length can be perforated which resulted in leaving some zones unperforated behind casing. A new concept of UHRC has been designed and successfully tested. This concept consists of sidetracking into the overburden, drilling to TD and removing 7-5/8" liner section. Shunted screen then deployed into open hole through a cased milled window followed by gravel pack operation. While standalone screens have been deployed through cased milled windows before, deploying shunted screens through a cased milled window followed by an OHGP is an industry 1st. This technique delivers the well 20 days earlier compare to standard Sidetrack OHGP well due to removal 7-5/8" production liner section. This technique is also give advantage over stacked CHGP option because can provide higher k*h access, can handle high levels of differential depletion within the completed interval and has the potential to unlock up lot more well candidates to allow and deplete the reserves from overlying reservoirs. This paper will also describe window and well design to deliver successful Shunt Tubes OHGP installation with this technique.
Nearly 30 years ago as the Soviet Union lay in tatters, Azerbaijan and Kazakhstan signed off on the Caspian's first oil and gas megaprojects, hoping to guarantee their independence by transforming the region's energy landscape and their role in it. Nursultan Nazarbayev, then president of Kazakhstan, took the first step in April 1993 by creating Tengizchevroil (TCO), a joint venture between Chevron and Kazakh state oil company KazMunaiGaz, to develop the super-giant Tengiz oil field and nearby Korolev field. Today, Chevron still holds 50% of the venture, ExxonMobil controls 25%, KazMunaiGaz, 20%, and LukArco, a subsidiary of Russia's Lukoil, 5%. A year and a half later, in September 1994, Azerbaijan's president, the late Heydar Aliyev, signed a production-sharing agreement (PSA) to develop the deepwater reserves of the Azeri, Chirag, and Gunashli (ACG) fields, attracting the participation of a "who's who" of the world's oil and gas elit 13 global companies representing eight countries. These and other signings had a knock-on effect as more upstream megaprojects popped up across the region in the late 1990s and throughout the early 2000s, attracting more international participation and the need to develop midstream infrastructure such as Azerbaijan's Baku‑Tbilisi-Ceyhan pipeline (BTC) export line to Turkey and Kazakhstan's Caspian Pipeline Consortium (CPC) to Russia's oil export terminal at Novorossiysk, as landlocked Central Asia devised ways to get its crude oil to market.
Whaley, Kevin (Bp) | Jackson, Phillip J (Bp) | Wolanski, Michael (Bp) | Aliyev, Tural (Bp) | Muradova, Gumru (Bp) | Eyyubov, Arziman (Bp) | Thomesen, Carl (Bp) | Samadov, Hidayat (Bp) | Kumar, Arunesh (Bp) | Chandran, Pavithiran (Bp) | Majidi, Reza (Bp)
Abstract Open Hole Gravel Pack (OHGP) completions have been the primary completion type for production wells in the Azeri-Chirag-Gunashli (ACG) field in Azerbaijan for 20 years. In recent years, it has been required to use well bore strengthening mud systems to allow drilling the more depleted parts of the field. This paper describes the major engineering effort that was undertaken to develop systems and techniques that would allow the successful installation of OHGP completions in this environment. OHGP completions have evolved over the last 3 decades, significantly increasing the window of suitable installation environments such that if a well could be drilled it could, in most cases, be completed as an OHGP if desired. Drilling fluids technology has also advanced to allow the drilling of highly depleted reservoirs with the development of well bore strengthening mud systems which use oversized solids in the mud system to prevent fracture propagation. This paper describes laboratory testing and development of well construction procedures to allow OHGPs to be successfully installed in wells drilled with well bore strengthening mud systems. Laboratory testing results showed that low levels of formation damage could be achieved in OHGPs using well bore strengthening mud systems that are comparable to those drilled with conventional mud systems. These drilling fluid formulations along with the rigorous mud conditioning and well clean-up practices that were developed were first implemented in mid-2019 and have now been used in 6 OHGP wells. All 6 wells showed that suitable levels of drilling mud cleanliness could be achieved with limited additional time added to the well construction process and operations and all of them have robust sand control reliability and technical limit skins. Historically it was thought that productive, reliable OHGP completions could not be delivered when using well bore strengthening mud systems due to the inability to effectively produce back filter cakes with large solids through the gravel pack and the ability to condition the mud system to allow sand screen deployment without plugging occurring. The engineering work and field results presented demonstrate that these hurdles can be overcome through appropriate fluid designs and well construction practices.
Davenport, Mike (BP Exploration Operating Company) | Guliyev, Rufat (BP Exploration Operating Company) | Sadikoglu, Kasim (BP Exploration Operating Company) | Gramin, Pavel (BP Exploration Operating Company) | Zett, Adrian (BP Exploration Operating Company)
Abstract The understanding of residual saturation in an oil field in mid-development is essential for estimating the cumulative production achievable, optimizing the future production mechanisms planned for infill targets, development of adjacent reservoir levels and optimizing the design of future facilities. The ACG (Azeri, Chirag, Gunashli) field is a giant oil field located about 120 km offshore in the South Caspian Sea, Azerbaijan. The field consists of multiple stacked clastic reservoirs including the Fasila and Balakhany formations, each with variable oil water contacts, and variable presence and fill level of gas caps. The Fasila reservoirs have been nearly fully developed. Both down flank water injection and crestal gas injection have been employed to drive oil towards producers. These two processes result in different residual oil “trapping” mechanisms which have been explored by logging and coring. Future development of overlying reservoirs can be optimized if we understand the effectiveness of these mechanisms to improve oil recovery and understand produced fluid compositions to enable facilities optimization to handle them. Established techniques to measure the residual oil saturation in a live field depletion, such as conventional open hole logging, pulsed neutron logging and direct core measurements have been employed. This paper investigates the methodology of each technique and the comparison of the magnitude and uncertainty of the saturations obtained. The sands in the ACG main reservoirs are relatively massive and high Net-to-Gross (NTG), however their clay content and distribution is quite variable leading to a range of rock types which behave differently under fluid sweep, and the presence of both intra reservoir sealing shales and lateral sand quality variations lead to a complex pattern of sweep behavior. It was considered that conventional core would be the principle measurement, with the most direct estimation of downhole fluid conditions as well as achieving all other coring objectives. Core was acquired on two pilot wells, one behind the water flood front and another behind the expanding crestal gas cap. Several innovative core analysis techniques were employed. A full conventional log suite was acquired in both wells as well as an open hole pass of a multi detector pulsed neutron log in the crestal gas swept well. The analysis of all this data has led to some interesting conclusions. Previous core flood experiments had led the team to believe gas is more efficient than water in terms of lowering residual oil saturation and reaching higher recovery factors. The new core demonstrated that such low residual oil saturations are achieved more slowly than originally thought, though it didn't change the view of efficiency of gas displacement relative to water. It is also likely that reservoir heterogeneity has had a bigger impact on the variation in residual oil saturation between layers than reservoir quality itself.
Hasanov, Zahid (BP) | Allahverdiyev, Parviz (BP) | Ibrahimov, Fuad (BP) | Mendoza, Alberto (LYTT Limited) | Thiruvenkatanathan, Pradyumna (LYTT Limited) | Noble, Lilia (LYTT Limited) | Stapley, Jonathan (LYTT Limited)
Abstract This paper discusses results from the first successful deployment of a predictive modelling technology that informs pressure optimization procedures to help minimize sand production and increase hydrocarbon production efficiency in sand prone oil wells. The technique takes variabilities in sand production observed through time across the reservoir section, inferred from downhole sand entry logs, alongside real-time sand transportation logs that monitor sand deposition in pipe as key inputs (both of which computed using a fiber optic Distributed Acoustic Sensor (DAS) based Downhole sand monitoring system). This data is then combined with other time series sensor inputs, like choke position, Down Hole Pressure (DHP) and surface flowline acoustic measurement (sand detector) to predict drawdown pressure envelopes to improve production efficiency. This paper details observations and initial field results from the first deployment of the capability in a highly deviated sand prone oil well completed with an open hole gravel pack (OHGP) completion in the BP-operated Azeri- Chirag- Gunashli (ACG) field located in the Azerbaijan sector of the Caspian Sea. The paper will detail observations and procedures used to increase oil production by over 25% and eliminate sanding risks using the technology. The proposed workflow is part of a comprehensive suite of downhole sand surveillance and management tools fueled by streaming analytics capabilities run on DAS data that have played a key role in managing sand production challenges in the ACG field. The technology has been applied numerous times for base protection, drawdown optimization and targeted remediation. In this instance, we discuss the use of the technology to (1) identify and inform the source of sand detected at surface e.g., formation or completion accumulation, (2) identify formation intervals at risk of sanding, and (3) design advisory operational procedures for production optimization.
Whenever one hears news about oil, probably, the first thing that comes to the mind is gasoline and everything associated with it: cars, airplanes, ferries, etc. However, almost nobody would guess that crude oil can actually be used directly as a cure without any preprocessing. Of course, you would like to first get rid of any sand or associated water from the crude, but otherwise the oil chemical structure is not changed, and no chemical additives are applied in the process. One of the very few world famous spots where a medical treatment by crude oil is performed is Naftalan. The city is located in central Azerbaijan in a close proximity to the Lesser Caucasus mountain range and approximately 50 km away from Ganja city (Figure 1).
Chevron's affiliate companies have sold their 9.57% interest in the Azeri-Chirag-Deepwater Gunashli (ACG) oil fields and Western Export Route Pipeline and its 8.9% interest in the Baku-Tbilisi-Ceyhan (BTC) oil pipeline. The ACG fields, located in Azerbaijan, produced 20,000 B/D in 2019. The $1.57-billion deal was concluded 16 April with MOL Hungarian Oil and Gas PLC. Jay Johnson, Chevron's executive vice president of upstream, said, "This sale is an important part of our divestment program, which is targeting before-tax proceeds of $5 to 10 billion between 2018 and 2020." In addition to Chevron's 9.57% interest in ACG, the remaining interest holders are: BP Exploration (Caspian Sea) Ltd. (operator, 30.37%);
BP and partners have sanctioned the Azeri Central East (ACE) project, the next stage of development of the giant Azeri-Chirag-Deepwater Gunashli (ACG) oilfield complex in the Azerbaijan sector of the Caspian Sea. The $6-billion development includes a new offshore platform and facilities designed to process up to 100,000 BOPD. The project is expected to achieve first production in 2023 and produce up to 300 million bbl over its lifetime. The extension of the ACG production sharing agreement (PSA) to 2049 was agreed in 2017 and this is the first major investment decision by the partnership since then. More than $36 billion has been invested into the development of the ACG area since the original PSA was signed in 1994.
Chevron has agreed to sell its 9.57% interest in the Azeri-Chirag-Gunashli (ACG) oil field off Azerbaijan and 8.9% stake in the Baku-Tbilisi-Ceyhan (BTC) pipeline to Hungary's MOL Group for $1.57 billion. Excluding the deal, Chevron since early last year has sold or is in the process of selling more than $5 billion in assets, including the pending $2-billion sale of almost all of its UK North Sea holdings to Israel's Delek Group, announced in May. Chevron and fellow US major ExxonMobil have recently parted with assets globally while narrowing their focus on regions such as the Permian Basin of West Texas and southeastern New Mexico. In its third-quarter earnings report, Chevron said its Permian production increased 35% during the quarter compared with a year ago. Chevron has had a stake in the ACG field since it started production in 1997. Operated by BP, the field, which consists of six offshore platforms, produced 584,000 B/D of oil last year and will add around 20,000 B/D net to MOL's production.
This article focuses on the completion design of a multiple-zone water-injection project (MZWIP) that was initiated in 2016 in the Azeri-Chirag-Gunashli (ACG) fields in the Azerbaijan sector of the Caspian Sea. The MZWIP has ultimately proved a unique method of using intelligent completion interval-control valves (ICVs) in place of traditional sand-control completions. Four years after MZWIP implementation, nine wells with a total of 25 zones are injecting at required rates with zonal-rate live reporting across all five ACG platforms. To achieve the multizone injection facility, the requirement for a standard ACG sand-control injector design was discounted and a nonstandard sand-management control technique developed using a cased and perforated (C&P) and downhole flow-control system (DHFC). During this program, BP ACG has successfully installed the world's first 10,000-psi four-zone inline variable-choke DHFC wells with full surveillance across each zone including pressure, temperature gauges, and fiber-optic distributed temperature sensors (DTS).