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Third EAGE/AAPG Workshop on Tight Reservoirs in the Middle East
- Conference date: October 4-7, 2015
- Location: Abu Dhabi, United Arab Emirates
- Published: 04 October 2015
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Study of Coalbed Methane (CBM) in Muara Air Lawai, Lahat, South Sumatra and Air Dingin, Sawahlunto, West Sumatra
More LessSummaryThis research was conducted in Muara Air Lawai, Lahat that belongs to the South Sumatera basin, which is one of major coal basins in Indonesia. To compare some samples were also collected from Air Dingin, Sawahlunto, a region in Ombilin basin which famous for its high rank coal. Coal samples were obtained from the core drilling in both areas of research. This research is aimed to determine the methane content in the coals in relation to basic coal characteristics inferred by proximate and petrographical analyses. Analysis of gas content in coal is peformed by measuring lost gas (Q1), desorbed or measured gas (Q2), and the residual gas (Q3), while the gas composition was measured by a gas chromatographer. Coal samples from Muara Air Lawai and Air Dingin are classified as lignite and bituminous coals, respectively. In general, variation of methane contents in both coals are related with moisture content, vitrinite mineral composition, and coal ranks. Methane content in Muara Air Lawai coal is around 0.001 – 0.664 m3/ton and interpreted to be biogenic, whereas that of Air Dingin coal (5.58 – 12.95 m3/ton) is suggested to be a mixture both biogenic and thermogenic methane.
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Measurement While Drilling System Improves Wellbore Placement
By C.V. ViensSummaryMany of the MWD and LWD systems that are utilized in the North America land market today were designed for drilling conventional wells and have limitations when applied to drilling and logging unconventional wells. An MWD/LWD system has been designed specifically for drilling and logging these unconventional wells. The system employs sensors and technology that are critical to efficient wellbore placement and address the needs of drilling and geology.
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Creating Success from a Tight Channel Sand
By M. ElasmarSummaryPetrophysical analyses of target intervals have dictated exploration and production decisions in major companies for decades. Hydraulic fracturing has been commercial since 1950 and millions of these stimulations have been completed worldwide since. Recent applications of the technology have allowed for production from low-permeability reservoirs. Tight sand exploration for gas production has defined pay as reservoirs with at least 3% gas-filled porosity generally surrounded by intervals with significantly higher porosity values, and similar cutoffs are also used for water saturation, permeability, and clay content. Well A was drilled into a seismically defined channel exploring for high-quality reservoir facies observed in offset wells. A relatively thick sand succession was encountered, but the channelized deposits contained almost no reservoir quality. Porosity of the channel sand averages 0.033% with very thin porosity streaks not exceeding 5%. Standard formation analyses indicated the zone would not produce economic amounts of hydrocarbons. Previous wells targeting the reservoir encountered similar results and were side-tracked to alternate targets, which proved to contain significantly improved reservoir quality. A hydraulic fracture stage was performed in an attempt to connect the wellbore with potential reservoir proximal within the channel. Following the stimulation, rates exceeding 10 million standard cubic feet of gas per day flowed during the testing period. Advanced seismic interpretation and a technical review identified a second seismic anomaly within several hundred feet of the wellbore. In addition to creating a permeable pathway for fluids in a reservoir with high storage, hydraulic fracturing can be utilized to access hydrocarbons stored in reservoir facies not defined by traditional formation evaluation techniques.
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Significance of Clay Mineralogy for Reservoir Quality Prediction
Authors H. El Hajj, W. Suzart, M. Al Tammar, T. Al-Ghamdi and A. Al-AbdullatifSummaryThis paper provides insight into the importance of knowing the minerals present in the reservoir, particularly the total clay percentage. It is vital to know the types and percentages of clays present for effective reservoir treatment and analysis. During the evolution of a petroliferous sedimentary basin, the clay minerals contained in the rocks undergo a series of changes in composition and crystal structure in response to tectonics and sedimentation. The amount and type of clay minerals are a function of the provenance of clastic minerals and of diagenetic reactions at shallow and greater depth in different tectonic and sedimentary settings. Clay minerals can be used to infer tectonic/structural regime, basin evolution history, and the timing of various geologic events.
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The Depositional Heterogeneity of the Organic-Rich Deposits of Oxfordian Age in Kuwait
Authors G. Gega and A. Al-faresSummaryNajmah Shale in Kuwait of Oxfordian age has become an important source of hydrocarbons. It is an excellent source rock (organic reach carbonates, misnamed shales). In the southern part of the basin, these “shales” are interbedded with turbidites and grain flow deposits. Despite the renewed interest in the geology of organic reach sediments, several practical problems render the study of this formation a challenging one. The advancement of technology & knowledge converged to transform this formation into a producing reservoir. Our aim is to characterize these different lithologies and to orient the exploration strategy in accordance with the new concepts.
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Regional Characterization of Middle Triassic-Middle Jurassic Tight Reservoirs in Abu Dhabi, UAE
Authors J. Hu, J. Witte and F.A. NevesSummaryWith an increasing demand of hydrocarbon resource from tight reservoirs, some of the exploration studies have been re-focused on the previously under-explored tight formations in Abu Dhabi.
The Middle Triassic to the Middle Jurassic formations, mainly Gulailah, Minjur, Marrat, Hamlah and Izhara from deeper to shallower, are the play fairways of tight hydrocarbon resource in Abu Dhabi. However, due to lack of systematic data integration, these tight formations were poorly mapped without a clear definition of their tight reservoirs. This paper is focused on re-mapping these tight formations on a regional scale and characterizing the tight reservoirs in the updated geological framework. The reservoirs were characterized in terms of geometry, quality and its controlling factors of deposition, diagenesis and hydrocarbon migration. This characterization was based on the unification of regional well correlation, reflection pattern interpretation of re-processed 3D PSTM seismic data and geochemical measurement results of cutting samples and fluid inclusions. As a result, a layer-cake to jigsaw-puzzle reservoir model is associated to the Middle Triassic to Middle Jurassic tight reservoirs.
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A Holistic Study to Optimize Production in Laminated Tight Clastic Reservoirs: Application of Unique Workflows in Egypt’s Western Desert
Authors A.L. Mahesh, K. Kanneganti, B.E. Mahmoud, Y. ElDarawy and C. FreddSummaryThe highly prosperous Western region of Egypt comprises the Bahariya Formation (Upper & Lower) and Abu Roash sands across multiple fields (such as the Abrar and Silah). These unconventional resource plays are extremely heterogeneous and exhibit variation, both vertically and spatially, over short distances. Such heterogeneity poses a challenge in optimizing completion and stimulation designs for wells targeting low and ultralow permeability plays. Simplistic workflows do not suffice for optimum stimulation. This paper discusses the application of suitable workflows that follow a data driven approach for stimulation design in such heterogeneous reservoirs.
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A New Strategy to Explore Tight Oil / Gas Reservoirs Fit for Purpose Acid Fracturing
By G. MahmoudSummaryOil and gas exploration in carbonate reservoirs typically utilize conventional techniques in perforation, matrix acidizing stimulation and well testing. Currently, oil companies have moved to more marginal reservoir targets. Application of these techniques has often yielded disappointing results and tighter zones are often abandoned for more promising target intervals.
With increases in oil and gas production targets, operators are being forced to investigate more marginal reservoir layers for reserves and production potential. The real challenge facing oil industry today is that successful exploration requires a change in drilling, completion and stimulation techniques currently utilized by operators.
Marginal reservoirs can have lots of resource potential and reserves, but may require horizontal well drilling, and/or multiple stage hydraulic fracturing to achieve economic production targets. This type of strategy is more expensive than conventional method(s) and is proven in some circles as potentially risky and many of these risks must be addressed and mitigated. In an effort to reduce risks and costs associated with the exploration process, a new stimulation strategy has been adopted for tight intervals to explore and appraise these intervals using vertical wells prior to going to horizontal wells.
This paper presents and analyzes oil exploration well case study in which a new strategy has been applied and evaluated. The study also demonstrates that this approach can lead to new resource discoveries, better reservoir understanding and improved well and completion design for future appraisal wells. Moreover, the paper highlights some of the additional challenges that this strategy may evoke and shows how these challenges may be overcome in the future.
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Retrospective Study and Multidisciplinary Optimization Workflow to Address Production Challenges in Ultralow Permeability, Tectonically Active, HPHT D
Authors K. Kanneganti, A.L. Mahesh, J. Salavarria, C. Fredd, E. Fidan, R.N. Srinivasa and M.N. AcharyaSummaryUsing the multidisciplinary unconventional workflow, the heterogeneity in reservoir quality and completion quality are evaluated, both spatially and at well level. The reservoir-centric stimulation design tool, capable of handling “Seismic-to-Simulation” workflow with the integration of stimulation, enabled optimization of drilling, completion, and stimulation designs in a holistic approach, with the optimal completion scheme to maximize appraisal and production opportunities.
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Structured Multidiscipline Data Acquisition and Integration for Optimum Unconventional Reservoir Drainage and Field Development
Authors A.S. Sultan, K.C. Kurison, L.Y. Yunsheng, R. A. Angelica and H.A. AlsahfySummaryUnconventional resources have gained prominence after their potential to produce hydrocarbons has been proved. Production from these resources became economically feasible as a result of combining horizontal drilling and multi-stage hydraulic fracturing reservoir stimulation along laterals targeting tight rocks with favorable petrophysical qualities. The extraction of hydrocarbons from these source rocks requires a step by step process starting with basin mapping, drilling coupled with geosteering, adequate cementing of the lateral in the wellbore and hydraulic fracturing completion. Each of these steps has key ingredients that need to be understood for a successful tight reservoir well.
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An Integrated Approach to Characterize Fracturing Sand
Authors B. Zoghbi, W. Razzaq, W. Suzart and M.S. AbdulAzizSummaryThe increase in exploration and development of unconventional and tight reservoirs worldwide has led to increased hydraulic fracturing activities and, as a consequence, increased demand for hydraulic fracturing sand. Hydraulic fracturing uses specially engineered fracturing fluid containing propping agent or silica sand that can withstand reservoir stresses and keep induced fractures open to help optimize hydrocarbon production. Sand used in hydraulic fracturing must be aligned with quality standards outlined by the International Organization for Standardization (ISO) and the American Petroleum Institute (API).
This paper discusses the design of a systematic workflow to characterize the geomechanical and geochemical properties of silica-rich formation from an outcrop to laboratory scale. This workflow includes processing, morphological and mineralogical studies by thin section and X-ray diffraction (XRD), and elemental analysis by X-ray fluorescence (XRF). In addition, the physical geomechanical properties are investigated for a complete analysis and to determine the sand’s compatibility in specific hydraulic fracturing applications.
This workflow helps operation and service companies determine the type of sand that best suits the targeted reservoir formation, which can help optimize reservoir productivity. Understanding the properties of the reservoir is important for designing and implementing the appropriate propping agent and hydraulic fracturing solution.
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Optimizing Wellbore Construction with Managed Pressure Drilling (MPD) and Managed Pressure Cementing (MPC)
By I. PoletzkySummaryManaged Pressure Drilling techniques have been gaining acceptance in recent years overcoming the drilling challenges related to pressure while attempting to minimize formation damage. For wells with a narrow margin between the pore and fracture pressures, the challenge does not end when the drilling has concluded. After total depth has been reached, addressing the surge/swab effect while tripping and running casing without MPD can create the pressure scenarios that led to using MPD in the first place. The surge/ swab pressures for small hole sizes can be extreme and may result in influxes or hole instability on the trip out to pick up casing. Running casing in the hole, in many instances, can result in hydraulic fracturing of the formation as the casing nears or enters the open-hole section. The magnitude of the losses and additional stresses within the rock may prevent getting the casing to bottom. After the casing is in place, the ECDs from the cementing process may easily exceed the fracture pressures, which could result in losses, poor zonal isolation, and remedial cement repair. The overall well construction process has been optimized with the successful implementation of MPD and MPC.
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