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Collaborating Authors
Well Drilling
Abstract At the present time, it has become progressively more common for countries around the world to use tracer's methods of production logging in horizontal wells. The utilization of tracers/markers doesn't require well intervention with Coiled Tubing or tractors in order to obtain qualitative and quantitative data for inflow of reservoir fluid per interval. Tracer/marker technologies is a quantum leap in production logging as it is potentially capable of producing ten (10) to twenty (20) times more downhole data in a period of several years. The knowledge of downhole production in dynamics of years helps in developing oil and gas fields, locating neighboring wells to be drilled, optimization of horizontal lateral length or even a number of fracturing stages per well. The principal difference between these technologies and traditional methods of well surveys (WS) is their ability to monitor the operation of ports or intervals in a well over a long period of time, with a significant reduction in resources involved, a reduction in costs and an enhanced production safety. However, the question remains whether the claimed specifications of tracer technologies correspond to the actual ones. Sometimes, the decision on the implementation of tracer PLT is made with weak quality assurance measures causing subsequent compromise of project results as a whole. The value of this article is the development of a methodology for a comprehensive assessment of the operability, reliability and accuracy of operation for various tracer technologies available in the market. Based on results of this research being conducted, the article suggests recommendations from producer companies that can be used as technical criteria when selecting a contractor for tracer studies.
- North America > United States > Texas (0.28)
- Asia > Middle East (0.28)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Tracer test analysis (1.00)
- Production and Well Operations > Well Intervention (1.00)
Abstract The Karachaganak (KGK) field is situated within an environmentally sensitive location which includes a conservation area containing lakes, woodland and abundant wildlife. Additionally, surrounding the field there are several inhabited villages. As in other parts of the world, if well operations are not properly managed, there is the potential to directly impact this fragile environment, as a result of HC flaring with emissions containing both poisonous H2S and toxic SO2 during the well operations. Despite applying best-in-class environmental drilling and completion practices in the well construction processes, there remained the challenge of how to reduce emissions resulting from well clean-up activities in the field, with the eventual goal of achieving zero emissions. This paper outlines the transition of well clean-up and testing towards purely three phase "zero emission", broadly describing the evolution from conventional three phase flaring to a robust zero emissions approach. The transition required new technologies to be implemented in stages which were all subject to; high level design reviews and rigorous HAZOP activities to, both define and guarantee the safe operational envelope at field implementation stage. The result of this implementation are as follows: Maximizing oil recovery at highest value within optimal cost. Putting the newly drilled wells on production in advance and reviving suspended wells. Significantly reducing downtime. With to date a significant environmental impact reduction in the region of 95%. The project anticipates deploying the last of the enabling technologies in the field in 4 Quarter 2018, which should see Karachaganak Petroleum Operating b.v. (KPO) achieve its long term aim of "zero emissions" during well clean-up phases.
- Asia > Kazakhstan > West Kazakhstan > Uralsk Region > Precaspian Basin > Karachaganak Field (0.99)
- North America > Canada > Alberta > High Level Field > Amax Andex Et Al Highl 16-13-111-20 Well (0.98)
- Well Drilling (1.00)
- Health, Safety, Environment & Sustainability > Environment > Air emissions (1.00)
Acid Fracturing Depleted Carbonates Improving Very Low Reservoir Quality Inside Slim Horizontal Open Hole
Abd El Baky, Amr (Halliburton) | Al-Shuaibi, Nawaf (Kuwait Oil Company) | Alboueshi, Alaa Eldine (Halliburton) | Elmofti, Mohamed (Halliburton) | Elafify, Ebrahim (Kuwait Oil Company) | Alkhaldy, Meshal (Kuwait Oil Company) | Allam, Ahmed (Halliburton) | Eid, Walid (Halliburton) | Ashkanani, Anfal (Kuwait Oil Company)
Abstract The execution of pinpointed multi-stage acid fracturing inside 4-1/8-in. slim horizontal open hole sections is discussed. For the first time in Kuwait, pinpoint stimulation of 16 frac stages across a total 4,666 ft open hole while commingling three reservoir sections in very low reservoir quality carbonate rock was performed. Pumping rates were optimized while managing differential sticking hazards in the implementation of this frac procedure. Electric submersible pump completion deployment and well testing enhanced production by more than 100% over the anticipated rate. Stimulation parameters were optimized with 2-7/8-in. tubing as the frac string for greater reservoir penetration and productivity enhancement. Differential sticking was addressed by removing drilling filter cake prior to the frac job. Possible risks were evaluated, and mitigation plans were implemented which resulted in the successful application of multi-stage acid fracturing across the open hole.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Acidizing (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (0.90)
Evaluating Effectiveness of Stimulation Treatment in Karachaganak Multistage Wells
Kushkumbayeva, Gulmira (Karachaganak Petroleum Operating B.V.) | Zhumabayev, Bolat (Karachaganak Petroleum Operating B.V.) | Gabdullin, Daniyar (Karachaganak Petroleum Operating B.V.) | Burmantsev, Ruslan (Karachaganak Petroleum Operating B.V.) | Adeleke, Justus (Karachaganak Petroleum Operating B.V. / Shell) | Saada, Tamer (Karachaganak Petroleum Operating B.V. / Shell) | Burrafato, Giovanni (Karachaganak Petroleum Operating B.V. / Eni) | Brancolini, Alberto (Karachaganak Petroleum Operating B.V. / Eni)
Abstract The first objective of this paper is to present some correlations between formation acid response with stimulation type, reservoir quality, post stimulation injectivity index, productivity index and production logging flow contribution from each of the stimulated zones of wells in the Karachaganak field. The second objective is to provide recommendations on acid stimulation based on geological settings, lithology, petrophysical properties and presence of natural fractures in order to optimize hydrocarbon recovery in carbonate reservoirs in a cost effective manner. An evaluation of the technical assessment of multistage stimulation based on lithology, porosity, natural fractures, stimulation type, injectivity and the production logging data flow contribution of each zone is the methodology for acid effectiveness measurement. The zonal injectivity of each well generated in Excel describes the pre- and post-stimulation injectivity relative to the stimulation type (acid wash, high rate matrix and acid fracturing). Utilization of Python's matlab to read Excel injectivity analyses data for all the wells further enabled generation of plots for multivariable analyses of the impact of various parameters on productivity. This paper presents the cost effectiveness of stimulation treatment types. The observation and results of stimulation carried out in many wells shows that porosity, as a petrophysical parameter is not the sole driver of stimulation effectiveness as low porosity zones particularly limestone dominated can have enhanced natural permeability (vugs, fractures) and may have a chance to flow. The high rate matrix technique especially in high dolomitic formation showed better performance when compared to acid frac in the same formation type. Good porosity lithology zones with evidence of natural fractures and/or those that experienced significant mud losses treated with gentle acid wash or high rate matrix showed great productivity with production logging results. The zones close to the toe and the oil water contact treated with acid wash gave good productivity compared to acid frac that tend to intersect natural fractures and connect to the underlying aquifer. The holistic approach to stimulation results evaluation in carbonate reservoirs is new and will add to the body of knowledge on the most optimal and cost effective acid stimulation type for carbonate reservoirs.
- Asia > Middle East > Saudi Arabia (0.69)
- North America > United States > Texas (0.68)
- North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
- North America > United States > Texas > Permian Basin > Yates Formation (0.99)
- North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
- (22 more...)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)
- Well Completion > Hydraulic Fracturing > Multistage fracturing (1.00)
- Well Completion > Acidizing (1.00)
- (5 more...)
Research on Engineering Solutions for Presalt Formation Development and Depleted Salt Cavern Utilization in China and Middle Asia
Jin, Fu (CNPC Engineering Technology R&D Company Ltd) | Xi, Wang (CNPC Engineering Technology R&D Company Ltd) | Yixin, Gu (CNPC Engineering Technology R&D Company Ltd) | Shunyuan, Zhang (CNPC Engineering Technology R&D Company Ltd) | Bingshan, Liu (CNPC Engineering Technology R&D Company Ltd)
Abstract How to efficiently develop pre-salt oil and gas reservoirs has become a global engineering issue. Thick salt-gypsum formations are widely found in Middle Asia, where KazakhstanKenkyak Oilfield used to be an unconquerable challengein oil industry. Some regions are also well-known for their rich experiences in salt mining and many wells that have been abandoned due to distribution of thick salt domes are still found in old rig sites, hence people are trying to develop those depleted salt caverns to be underground gas (oil) storages. Salt-gypsum samples were collected from Kenkyak Oilfield to study their creep behaviors. A finite element model of mechanics was set up to analyze effects of mud density ranges on salt-gypsum borehole sizes with different in-situ stresses, in order to determine the most appropriate mud density to drill salt-gypsum intervals. An investigation was finalized to update information of depleted salt cavern utilization in the world to study relevant accidents in China and abroad. Successful experience of building Jintanunderground gas storages in China was analyzed and the first-order second moment shown performance function that is used to determine the volume convergence failure probability of salt underground storages was established, so that it is easier to reveal the relationship between volume convergence failure probability and internal pressure of gas and time. Engineering challenges arising from pre-salt formation development are mainly plastic creep of salt-gypsum intervals, complexity of pressure systems, as well as instant and stable creep. Salt domes that are as thick as 3000m (at the depth of 700m – 3700m) are widely found there, while conventional casing programs that used to be adopted during the former Soviet period greatly increase drilling costs. Based on the analysis of formation profiles and pressure systems, we combined the surface casing interval and the first technical casing interval, reaching the Carboniferous target with near-balance drilling techniques and 3 casing intervals. Some underground gas storages in USA or Europe collapsed or were ever faced by gas seepage, cavern shrinkage, surface subsidence or ecological disasters because of abnormal cavern shapes, interlayer collapse, bottom uplift even pillar destruction, etc. Natural gas is injected with high pressure into the cavern and then stored with constant pressure in it. Gas pressure is released when it is collected from underground but the salt cavern keeps running in low pressure eventually. In long-term constant internal pressure and short-term low pressure operation period, the salt cavern's volume convergence failure probability decreases with an increasing internal pressure. Besides, surrounding rocksare more capable of resisting to deformation and rock displacement if the internal gas pressure is improved. Drilling costs are saved due to casing program simplification, while ROP is improved due to cordwood turbo drill tools in Kenkyak Oilfield. As for Jintan underground gas storages, salt creep accelerates when caverns run in constant high pressure, but salt is more sensitive to internal pressure when caverns are operated with constant low pressure. The cavern's creep is also affected by the gas injection / discharge speed.
- Asia > China (1.00)
- Europe > Norway > Norwegian Sea (0.25)
- Geology > Structural Geology > Tectonics > Salt Tectonics (1.00)
- Geology > Mineral > Sulfate > Gypsum (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- North America > Canada > Alberta > Western Canada Sedimentary Basin > Alberta Basin > Cold Lake Field > Clearwater Formation > 995053 2D Cold Lake 2-10-63-2 Well (0.99)
- Asia > Kazakhstan > Caspian Depression > Caspian Basin (0.99)
- (3 more...)
Improved Methodology for LWD Response During Closed Hole Circulation Drilling
Bekkaliyev, Zharas (North Caspian Operating Company) | Nursaidova, Roza (North Caspian Operating Company) | Inanc, Feyzi (Baker Hughes, a GE company) | Salimova, Assel (Baker Hughes, a GE company) | Stefaniak, Andrew (North Caspian Operating Company)
Abstract We document a technology for environmental corrections during logging while drilling (LWD in wash down mode) operations in closed hole circulation drilling (CHCD). The technology documents a new way to estimate hole size (caliper) and other environmental corrections through implementation of a neural net model to identify zones of varying bore hole fluids followed by new algorithms to create final products. Results with new drill wells spurred a re-evaluation of historical wells ending in a new porosity estimation methodology. Initial quality checks of Neutron-Density cross-plot data for new wells drilled in CHCD mode indicated that applied environmental correction resulted in potential errors in porosity estimations. Investigation of static and dynamic annular pressure data suggested that mixed density annular fluids, drilling mud and sacrificial fluid, created varying logging conditions. A neural net model was developed to account for these conditions. From this analysis a set of lab test were completed and new algorithms were applied to develop a synthetic caliper. The results of this work provided internally consistent porosity estimation methodology in zones of wells that are typically difficult to evaluate due to complex drilling conditions. The products provide a more thorough understanding of the distribution of porosity in formation and understanding of potential non-matrix features (fractures/karst). The methodology allowed for re-examination of historical wells that were deemed unusable and unsuitable for porosity estimation. Both of these insights are being considered in the history match and prediction of the reservoir model. The integrated approach of the team demonstrates the value of the technical approach by the contractor and operator to deliver results for the project.
Abstract In most cases, interpretation of resistivity measurements is performed using 1D multilayered formation models that are used to fit data locally in real-time applications. While drilling high-angle or horizontal wells, more complex scenarios may occur, such as faults, pinch-outs, or unconformities. In these cases, resistivity logging data inversion should be performed using at least a 2D model, which is a more complex computational problem. This paper presents a neural networks approach for solving this problem exemplified by the application of a deep azimuthal resistivity tool for geosteering in the vicinity of a tectonic fault. The tool operational frequencies of 400 kHz and 2 MHz produce eight measurements with a coaxial arrangement of transmitters and receivers, and two azimuthally sensitive measurements with axial transmitters and transverse receivers. This paper considers a 2D model of a tectonic fault composed of three parallel layers on the one side of a displacement plane and the same three layers on the other side dislocated at a certain distance along the displacement plane. The model is described with nine independent parameters. The artificial neural networks (ANNs) were designed and trained to calculate the tool signals based on the model parameters. The training was carried out using a synthetic database of 4·10 elements containing the model parameters and corresponding tool signals. The database was calculated using distributed computations with in-house Pie2D software that used the boundary integral equation technique. To estimate the accuracy of the ANNs designed, the signals calculated with the networks were compared against the exact values obtained with Pie2D for an independent sample of 1.8·10 points. The comparison gave a good match for all 10 measurements, with the relative error comprising less than one standard tool measurement error for most points of the sample. Computation with the ANN required a few microseconds to calculate one signal, while the algorithm based on boundary integral equations required several minutes. The obtained acceleration of ~10 indicates many opportunities for modeling and inversion of logging-while-drilling data.
- North America > United States (0.68)
- Asia > Middle East > UAE (0.29)
Maximum Reservoir Contact in Horizontal Wells Achieved with Multilayer Bed Boundary Detection Technology, Case Study from Kyzylorda Region
Tyran, Serik (JV Kazgermunai LLP) | Giesemann, Carl (JV Kazgermunai LLP) | Lukpanov, Akimzhan (JV Kazgermunai LLP) | Yermekov, Milat (JV Kazgermunai LLP) | Abzhanov, Nariman (JV Kazgermunai LLP) | Popov, Timofey (Schlumberger) | Evdokimova, Inna (Schlumberger) | Kurmangaliyev, Daulet (Schlumberger) | Makhambetov, Amangeldi (Schlumberger) | Kozhakhmetov, Mirat (Schlumberger) | Leontyev, Dmitry (Schlumberger)
Abstract In general, the objective of horizontal drilling is to maximize reservoir contact within the target interval to achieve the planned well performance in a thin layer or when drilling within a thin oil deposit, when the distance between the reservoir top and the oil-water contact (OWC) is short and there is a risk or borehole exit into the overlying formation or water-bearing zone. In horizontal drilling, there always exist risks associated with geological uncertainties. If the structural dip is different from expected, lateral thickness or reservoir property variations exist; if subseismic faults are present, the horizontal well, drilled as per plan, may not achieve sufficient reservoir contact. As a result, the well may underperform. Well placement (or geosteering) is used in horizontal wells to accomplish geological objectives. The well placement process is an interactive approach to well construction, combining technology and people to deliver optimally placed wellbores in a given geological setting to maximize production or injection performance. In Akshabulak field, southern Kazakhstan, multilayer bed boundary detection technology was applied for geosteering in two horizontal wells.
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Exploration, development, structural geology (1.00)
New Approaches to Gas Condensate Field Development in Uzbekistan
Nazarov, Azizbek (Gazprom International) | Ten, Igor (JV UZLITI Engineering LLC) | Iskra, Artyom (JV UZLITI Engineering LLC) | Kryuchkova, Tatyana (Baker Hughes) | Golovatskiy, Yury (Baker Hughes) | Gryaznov, Andrey (Baker Hughes) | Ishimov, Ivan (Baker Hughes)
Abstract The paper considers new approaches to further development of mature gas-condensate fields, which are aimed at the maximum recovery of in-place reserves using the systems of horizontal wells. The gas-hydrodynamic simulations on the sector model of a depleted field were performed. Analysis of geological features of the fields of Uzbekistan is crucial to the planning of horizontal wells. As an example of how geological features are taken into account for effective further development of the fields, the reservoirs of Amudarya oil-and-gas basin are described. The questions of geosteering, well targeting along the formation and optimum completion of horizontal and multilateral wells, including with the use of inflow control devices, are addressed. Studies found the appropriateness of the operation of horizontal wells in comparison with vertical wells, which have several technological and economic advantages, such as the cost of such wells, simplified system of surface facilities, production rate as fraction of in-place gas reserves.
- North America > United States (1.00)
- Asia > Uzbekistan (0.87)
- Research Report > New Finding (0.88)
- Overview > Innovation (0.70)
- Asia > Uzbekistan > Amu-Darya Basin (0.99)
- Asia > China > Sichuan > Sichuan Basin > Moxi Block > Longwangmiao Formation (0.99)
- North America > United States > Louisiana > China Field (0.97)
- (3 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Gas-condensate reservoirs (1.00)
Successful Application of Different Managed Pressure Drilling Techniques in Russia: Identification of Challenges and Selection of the Optimum Approach
Borges, Sergio (Schlumberger) | Dobrokhleb, Pavel (Schlumberger) | Krivolapov, Dmitrii (Schlumberger) | Magda, Andrey (Schlumberger) | Soroka, Taras (Schlumberger) | Moiseenko, Ivan (Schlumberger)
Abstract The utilization of managed pressure drilling (MPD) techniques has grown significantly over the past three years in the Russian Federation. This paper describes the application of MPD surface back pressure technique using both single and multiphase drilling fluid systems in several oil and gas fields located in Russia. The Komi Republic is one of the biggest oil and gas producing areas in the European part of Russia and among Russia's top ten producers. Although the Yurkharovskoye oil and gas condensate field in Western Siberia is in the Tazov Peninsula, most of the field is situated offshore. That part of the field is developed from onshore locations using horizontal and extended reach development wells. In Eastern Siberia, the Yurubcheno-Tokhomskoye field is one of the biggest oilfields and presents highly fractured carbonates. Each field presents a different challenge and requires a specific approach. The application of MPD technology improved drilling performance and helped avoiding non-productive time. Utilization of reduced mud weight with MPD procedures using a semi-automated system helped reduce lost circulation and safely control background gas, thus avoiding well control events in the Lambeyshorkoye, Komandirshorkoye, and Alabushina fields. In the Yurkharovskoye field, a high-pressure, high-temperature well was successfully drilled to TD with application of a fully-automated MPD system, which facilitated precise control of bottomhole pressure during drilling, pumps-off events, and tripping operations. A multiphase MPD technique helped achieve planned TD in horizontal sections in Riphean formations of the Yurubcheno-Tokhomskoye field without catastrophic fluid losses. By injecting oil-base mud with nitrogen, the equivalent circulating density (ECD) was drastically reduced, lowering the volume of losses up to 5 times. In addition, near balance conditions increased the ROP while drilling. The first ever multi-lateral well drilled with multiphase MPD was successfully completed on Yurubcheno-Tokhomskoye field with minimal mud losses and no well control events. This paper will present details about how MPD technology makes it possible to drill formations with narrow mud weight windows where traditional approach was ineffective. The application of MPD technology helped successfully drill wells while reducing non-productive time, improving performance, and increasing the safety for personnel.
- Europe > Russia (1.00)
- Asia > Russia > Siberian Federal District > Krasnoyarsk Krai (1.00)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Gulf of Ob (0.67)
- Europe > Russia > Northwestern Federal District > Northwestern Federal District > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- Europe > Russia > Northwestern Federal District > Komi Republic > Nenets Autonomous Okrug > Timan-Pechora Basin (0.99)
- Asia > Russia > Ural Federal District > Yamalo-Nenets Autonomous Okrug > Gulf of Ob > West Siberian Basin > South Kara/Yamal Basin > Yurkharovskoye Field (0.99)
- (22 more...)
- Well Drilling > Pressure Management > Well control (1.00)
- Well Drilling > Pressure Management > Managed pressure drilling (1.00)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (1.00)