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Results
Production Enhancement in the Egyptian Western Desert using the Channel Fracturing Technique โ A Field Case Study
Samir, M.. (Sahara Oil & Gas Company) | Kamal, M.. (Sahara Oil & Gas Company) | Mathur, A.. (Schlumberger) | Semary, M.. (Schlumberger) | Yosry, M.. (Schlumberger) | Bernechea, J. M. (Schlumberger) | Kamar, A.. (Schlumberger) | Mokhtar, A.. (Schlumberger)
Abstract The Abrar field in the Egyptian Western Desert produces mainly from the Abu Roash formation that is characterized as a complex, thin-bedded sequence with heterogeneous laminated siltstones. Hydraulic fracturing has traditionally been employed to produce hydrocarbons from these marginal reservoirs. This paper describes the application for the first time of a novel channel fracturing technique combined with rod-shaped proppant in selected production targets in the Abrar field. The channel fracturing technique introduces channels within the proppant pack that increase conductivity and effective half-length leading to increased productivity. Rod-shaped proppant when used as tail-in in fracturing treatments increases near-wellbore fracture conductivity and prevents proppant flowback due to its particular geometry. Many sedimentary features of hydrocarbons in the Western Desert in Egypt are characterized as multi-layered, deltaic, thinly and tight laminated sandstones and siltstones consisting of sands with limited lateral and vertical extension with an average permeability of 1-3 mD and Young's modulus in the order of 2.5 โ 3.0 million psi. The channel fracturing technique was first introduced in the Egyptian Western Desert in late 2011. Since then several wells have been fractured using this technique and the production evaluation of these wells has been compared to offset wells fractured with conventional hydraulic fracturing techniques. Further, the application of rod-shaped proppant has provided excellent proppant flowback control as demonstrated by zero proppant flowback. Initial and long-term normalized production of the wells fractured with this technique increased significantly over offsets fractured conventionally. The positive results from implementation of this combined stimulation technique have led to a vigorous expansion of its utilization throughout Egypt's Western Desert area.
- North America > Mexico > Tamaulipas > Burgos Basin (0.99)
- North America > Mexico > Nuevo Leon > Burgos Basin (0.99)
- North America > Mexico > Coahuila > Burgos Basin (0.99)
- (8 more...)
Abstract Thermal oil recovery methods have been widely used not only in heavy oil reservoirs, but also in light oil reservoir with Waterflooding to improve oil recovery. The Steamflooding could be considered as an effective way to enhance the oil displacement especially in heterogeneous reservoirs The field, of 58-years of production history, is located in South of Iraq. It has 40 producing wells. There was an infinite active aquifer located at the east and west flanks. The strength of this aquifer from the west flank is much larger than its in the east flank because the reservoir permeability at the eastern boundaries is lower than as at the western one for all the layers; therefore, Twenty injection wells were drilled at the east flank to maintain the aquifer water approaching to the reservoir. The average surface area for this reservoir is 142 km and average formation depth of 10350 ft subsea with a maximum vertical oil column of 350 ft. Average porosity is 21%. The oil is 34ยฐAPI with an average initial bubble point pressure of 2660 psia. Current reservoir pressure is approximately 4200 psia and the reservoir temperature is 210ยฐF. In this study, a thermodynamic reservoir simulation has been adopted to investigate the competence of Steamflooding to improve oil recovery. The objective of this work was to examine the feasibility of steam-injection processes, so a thermodynamical reservoir model (CMG-STARS) has been applied to demonstrate the effect of using steam injection as a heating agent to increase the sweep efficiency in this heterogeneous formation. The twenty injection wells have been converted to steam injection for twelve future prediction years. The process has demonstrated a considerable increase of the cumulative oil production. This result has been compared with the base scenario of water injection at the same injection rates of 10,000 STB/DAY per well. The water injection scenario has been done by CMG-IMEX. This incremental has been proved over most of the production wells that have distributed among the reservoir by showing a significant difference between the two cases.
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.72)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Zubair Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Shuaiba Formation (0.99)
- Asia > Middle East > Iraq > Basra Governorate > Arabian Basin > Widyan Basin > Mesopotamian Basin > Rumaila Field > Nahr Umr Formation (0.99)
- (4 more...)
Abstract The use of pressure transient data in the field of Formation Testing in efforts to describe productivity and permeability of reservoirs is considered mature technology, particularly when applied to data collected through production testing. The extension of this technique to data obtained using Wireline Formation Testers, where either a single probe or a straddle packer is used to propagate a pressure pulse into a reservoir, has been gaining momentum in the industry over the past decade, however the integration of these outputs with other measurements of rock and fluid data is not always straight forward. This paper presents different methods of using pressure transient data from Wireline Formation Testers such as quantitative permeability determination, identification of permeability discrepancies in homogenous clastic formations, upscaling of permeability in a complex stacked reservoir and comparison of Wireline Formation Tester and conventional well test derived permeabilities. Additionally, this paper highlights the challenges one faces while planning, acquiring and interpreting pressure transient data from Wireline Formation Testers, as well as the importance of real-time monitoring and control of data.
- Asia (1.00)
- North America > United States > Texas (0.28)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Formation test analysis (e.g., wireline, LWD) (1.00)
Abstract Unlike the petroleum which has been awaking the attention of the Romanian scientists since the end of the XIX-th century (Pilide, C.L.-1877, Cobalcescu, G.-1887) and the beginning of the XX-th century (Poni, P.-1900-1901 Edeleanu, L.-1907), geochemistry have been developing since `80 years and especially after 1990, when theoretical considerations joined modern technologies for oil and rock analyses. Today we are at the same level like similar laboratories in the world because of the results obtained with the new generation tools. There are relatively little geochemical information published in the last years on the characteristics of oils and their potential source rocks from Romania. This paper presents the first detailed data for oils from the western part of Romanian Getic Depression. It used gas-chromatography-mass spectrometry to obtain various biomarker ratios and isotopic analysis. The Getic Depression constitutes the Tertiary foredeep developed in front of the Southern Carpathians and it lies from Dambovita Valley (in the east) to the Danube River (in the west), whereas in the south, down to the Pericarpathian Fault which delimits it from the Moesian Platform. For this work we selected the western part of Getic Depression between Jiu River (West) and Cerna River (East). 57 oils were analyzed after the fractionation into saturated hydrocarbons, aromatic hydrocarbons and nitrogen, sulfur and oxygen (NSO) compound fractions, in order to get the distribution of the biomarkers. The results of these investigations were been evaluated and interpreted using the new PC Soft: IGI. We characterized the various oil families in more detail, observing a special and interesting case of one of the analyzed fields (Ticleni) and we say now, that we better understand the petroleum system in the studied area.
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.72)
Establishing Higher Oil Production Capabilities: Engineered Approach Achieves Longest Lateral Hole Section in Kuwait
Al-Ajmi, Hadi (Kuwait Oil Company) | Al-Barazi, Nasser (Kuwait Oil Company) | Al-Rushoud, Abdul-Aziz (Kuwait Oil Company) | Trivedi, Ranjan (Kuwait Oil Company) | Maliekkal, Harish (Smith Bits, a Schlumberger Company) | Ghoneim, Osama (Smith Bits, a Schlumberger Company) | Saleh, Mustafa (Smith Bits, a Schlumberger Company) | Nair, Prakash (Smith Bits, a Schlumberger Company)
Abstract Kuwait Oil Company (KOC) is analyzing the feasibility of utilizing extended reach drilling to achieve a long lateral section to increase oil production in northern Kuwait. Several attempts were made to accomplish the objective with roller cone and PDC bits on various directional tools with limited success. The major problem was short bit life/cutting structure durability and steerability issues in the difficult Mauddud carbonate reservoir. A drilling optimization initiative would benefit the entire northern Arabian basin because Mauddud is an important oil reservoir with uniform thickness and extensive regional distribution. Offset analysis showed three to four TCI bits were required to drill 3000 ft of lateral hole section. PDC bits display increased durability making up to 2500 ft of hole but were pulled for low ROP and unacceptable drilling inefficiency before reaching TD. A second PDC was required to finish the lateral and gain sufficient access to the reservoir. Before the optimization project, the longest single run with PDC was 2935 ft. The average footage drilled by roller cone TCI is approximately 1500 ft with average PDC footage around 2500 ft. To improve PDC bit performance, a rock strength program was run to identify the unconfined compressive strength (UCS) of Mauddud for use in an FEA-based modeling system. The software pegged the formation's UCS range between 9-15 kpsi with peaks up to 24 kpsi. Analogous rock sample files were selected and laboratory tests were performed to duplicate fundamental shearing action under the appropriate confining pressures. The resulting data was entered into the modeling system and simulations were performed with a baseline PDC to identify how lithology influences the bit/BHA and to investigate was to mitigate destructive drillstring dynamics. The engineering study produced a six-bladed PDC that drilled the longest lateral interval (5250 ft) in Kuwait through Mauddud. The bit ed excellent steerability and completed the hole section without losing ROP. This resulted in 100% footage improvement against offset PDC runs and is more than 150% better than the best TCI performance. The completed well has provided a 200% increase in production capabilities making up to 4500 bbls/day.
- North America > United States > Texas (1.00)
- Asia > Middle East > Kuwait (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.48)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock > Limestone (0.33)
- North America > United States > Texas > East Texas Salt Basin (0.99)
- North America > United States > Louisiana > East Texas Salt Basin (0.99)
- Asia > Middle East > Qatar > Arabian Gulf > Rub' al Khali Basin > North Field > Laffan Formation (0.99)
- (15 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Drilling > Drill Bits > Bit design (1.00)
Abstract A review of the available data of the Obaiyed field was carried out by Bapetco as part of the 2002 FDP update and the last review of Oct.2004. The Obaiyed field is a complex field, characterized by large uncertainties in permeability distribution and accordingly connected GIIP. The objective was to produce an integrated diagenetic and sedimentological model that can be utilized in 3D reservoir modelling. The study has resulted in a comprehensive 3D model of an estuarine, incised valley depositional system. Geological, Petrographical, sedimentological and Reservoir Engineering data have been integrated to create model realizations reflecting extreme scenarios of the permeability distribution within the field in an attempt to define their connectivity. The majority of the sandstone were deposited as bars within the estuary. The occasional higher permeability layers correspond to petrographic differences in the sandstones that relate to depositional sub-environment. Rock samples have been taken from the Paleozoic/Mesozoic in order to assess the diagenetic history, its impact on reservoir quality, and potential petrographic criteria by using the following analyses: Rock composition, Thin section petrography, SEM-analysis, XRD; Clay Mineralogy and Illite crystalinity; Age dating and Age of diagenesis: K/Ar-dating of Illite/Kaolinite concentrates. The permeability and saturation distribution are a function of the diagenetic history of the field, causing the Paleozoic sandstones, which underlie the Mesozoic Lower Safa, to have a markedly lower permeability and generally lower saturation. The Obaiyed gas/condensate field presents the challenging combination of a complex subsurface and a short timeframe to fully develop the field and to deliver committed daily quantities. The field was discovered in 1992, subsequently 4 appraisal wells were drilled between 1994 and 1996. After issuing the initial FDP in 1996 a development campaign was started in 1997, first gas was produced in 1999. After drilling 28 wells in the area subsurface uncertainties have been reduced significantly, the current updated FDP focuses on the development of reserves locked in the tight parts of the field as a means to maximize profitability of the field. Currently over 50% of the in-place gas is locked in tight gas sandstones in the Obaiyed field. In order to rule out other causes of poor productivity, the formation damage is the mechanism responsible for poor productivity. As this can only be done by ensuring no damage during drilling Over the next two years, drilling activity in Bapetco will be increased, mainly because of the upcoming drilling campaign to develop the NEAG field In Abu El Gharadig Area and Obaiyed Area. Initial development plan will comprise drilling of 8-10 development wells in both Areas. The majority of the sandstone was deposited as bars within the estuary. The occasional higher permeability layers correspond to petrographic differences in the sandstones that relate to depositional sub-environment. Rock samples have been taken from the Paleozoic/Mesozoic in order to assess the diagenetic history, its impact on reservoir quality, and potential petrographic criteria by using the following analyses: Rock composition, Thin section petrography, SEM-analysis, XRD; Clay Mineralogy and Illite crystalinity; Age dating and Age of diagenesis: K/Ar-dating of Illite/Kaolinite concentrates. The permeability and saturation distribution are a function of the diagenetic history of the field, causing the Paleozoic sandstones, which underlie the Mesozoic Lower Safa, to have a markedly lower permeability and generally lower saturation. A comprehensive data gathering and interpretation campaign has been progressed, including more cores, image logs, nuclear magnetic resonance tools, age dating, palynological and Paleomagnetic analysis to improve understanding of the reservoir permeability distribution. The Illite distribution is the most important control on the permeability values (quantitative and/or qualitative). Over the next two years, drilling activity in Bapetco will be increased, mainly because of the upcoming drilling campaign to develop and sustain the deliverability of the Obaiyed field. Initial Obaiyed development comprised drilling of 18 development wells between Nov.1997 and end of 2000, and the upcoming campaign (6-8 wells) between 2002 and 2004. The main objectives of these wells are to ensure availability of at least 40 MMscf/d (after fraccing) per each well to allow the DCQ of 300 MMscf/d to be safely delivered. During the past two years Bapetco has carried out field reviews and updating the development plans for Obaiyed fields, with the aim to re-assess the optimum life cycle development of these resources. As part of these reviews, 3-D reservoir modelling and full field simulation studies were carried out using tools such as Geocap, Logic, MoReS and Pegasus. The studies have resulted in comprehensive 3-D models of the coastal plain and shallow marine reservoir sequences in these fields. Geological, petrographical, petrophysical and reservoir engineering data have been integrated to create model realisations reflecting uncertainties in a range of parameters such as reservoir architecture, petrographic and diagenetic process, structure and fluid contents in an attempt to define the range in the hydrocarbons initially in place (HCIIP) and static connectivity. 3-D permeability and porosity models have been generated for all reservoirs and were subsequently used in MoReS reservoir simulation studies. These models are being used actively for development planning purposes. To date, some 18 well proposals have been matured on the basis of these studies, of which 17 have been drilled. This paper summarizes the results of these wells and presents the main learning points gathered over the past years. Although most wells were successful, there were also disappointments. Following the update of the models with the results of these wells, scope for horizontal well is opened. At the same time however, additional gas volumes were identified to the north and possibly further appraisal well have consequently been raised. 3D static and dynamic reservoir modelling have now become part of Bapetco's day to day activities. Generally, use of these tools has facilitated the preparation of proposals and has shortened the approval cycle due to the increased technical standards of the proposals. This has allowed us to successfully progress the intensive activity program of the last few years. Over the next two years, drilling activity in Bapetco will be increased during the drilling campaign to develop the Obaiyed field, Egypt's most prestigious gas development. Initial Obaiyed development comprised drilling of 18 development wells between 1997 and 2000 and construction of surface facilities. Obaiyed is a complex field, characterized by large uncertainties in GIIP and permeability distribution. Rapid interactive feedback between actual and predicted well results is being applied to allow proper management of the next development campaign.
- Phanerozoic > Paleozoic (1.00)
- Phanerozoic > Mesozoic (1.00)
- Geology > Sedimentary Geology (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (1.00)
- Geology > Mineral > Silicate > Phyllosilicate (1.00)
- Geology > Geological Subdiscipline > Petrology > Petrography (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying (0.88)
- Africa > Middle East > Egypt > Western Desert > Shushan Basin (0.99)
- Africa > Middle East > Egypt > Western Desert > Obaiyed Field (0.99)
- Africa > Middle East > Egypt > Western Desert > Khatatba Formation (0.99)
High Resolution Saturation Analysis in Nile Delta Turbiditic Sands from Imaging Tool Resistivity and NMR in Oil-Based Mud
Salah, A.. (Belayim Petroleum Company) | Sabra, M.. (Belayim Petroleum Company) | Said, M.. (Belayim Petroleum Company) | Van Steenes, M.. (Schlumberger) | Haddad, E.. (Schlumberger)
Abstract Porosity, water saturation, and net-to-gross evaluation can be challenging in thinly bedded sands. The use of standard induction resistivity for formation evaluation can lead to the overestimation of water saturation. This work explores the following options to improve formation evaluation in these conditions: the use of high resolution density and nuclear magnetic resonance (NMR) data to improve porosity vertical resolution; the use of high-resolution resistivity from an oil-based-mud microresistivity imaging tool in improving the saturation computation (Sw); and the comparison of imaging tool resistivity-based sand count and NMR-based thin-bed fraction. Using high-resolution porosity inputs from density and NMR provided a porosity curve with a better vertical resolution to match the high resolution resistivity from the imaging tool. It also identified additional productive thin beds compared to the standard resolution outputs and allowed computation of a high-resolution irreducible water saturation. The induction-based Sw is strongly affected by shoulder bed effect and overestimates Sw by approximately 10 to 15%. The high-resolution curve from the imaging tool was used as an input into the Sw computation, which was made possible by shallow oil-based mud (OBM) invasion. This approach gave good results in beds thicker than 6 in., where Sw from the imaging tool matches the irreducible water saturation computed from NMR, giving 20 to 30% Sw. A thin-bed fraction curve was computed from the NMR data. It shows a good match with the image-based high resolution- sand count and the image features, demonstrating that NMR and the imaging tool are equally able to identify and quantify thin beds, even though they have different vertical resolutions. This study showed that the microresistivity imaging tool and NMR are essential tools to characterize thinly bedded reservoirs.
- North America > United States > Texas (0.47)
- Africa > Middle East > Egypt > Nile Delta (0.41)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Sandstone (0.71)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.33)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.47)
Abstract Production logging measures downhole flow properties under dynamic conditions with an objective to gain insight into the downhole flow dynamics and quantify zonal flow contributions. Production logs are acquired during "stabilized flowing and shut-in conditions?? and the observed flow behavior is assumed to be representative of the reservoir flow behavior. In a homogenous reservoir this assumption may not be far from reality. Heterogeneous reservoirs, however, pose another challenge. Flow dynamics observed in heterogeneous reservoirs can be time dependent; therefore the time frame of data acquisition is critical to the conclusions that can be drawn from the interpretation. Presented herein is a case study of production logs acquired in a seemingly homogenous reservoir, the interesting dynamics observed from the data, and the methodology used to unravel the reservoir behavior. The production logs acquired during shut-in conditions revealed downhole cross flow between the reservoir layers. However a change in the direction of cross-flow between two shut-in acquisitions, acquired within 10hours of each other, revealed a much more complex reservoir than originally anticipated. Further analysis of the data and integration with other reservoir evaluation techniques revealed the heterogeneity of the reservoir with the existence of three radial compartments exhibiting different reservoir pressures, mobility and productivity index. The flow behavior observed from the production logs is unique and provides an insight to downhole flow dynamics in heterogeneous reservoirs. The methodology used in unraveling the reservoir behavior, and the integration of the production logs with other reservoir evaluation techniques, aided in improving reservoir characterization and ultimately reservoir management. Introduction Production logs provide measurements of downhole flow properties to promote an understanding of the downhole flow repartition of several zones, which then provides more information on the contribution the different reservoir layers make to the total production. In a homogenous reservoir, with constant properties, the reservoir response does not change with time and the flow behavior recorded at any time can be assumed to be representative of the reservoir behavior. However, in a heterogeneous reservoir, the nature of the reservoir may cause its flow behavior to change with time. A typical example will be a dual porosity reservoir system: in a dual porosity system, the reservoir is described to be composed of two systems - a block system and a matrix system. The matrix system has high permeability but low storativity, meaning that the fluid will flow faster through the matrix but it does not have enough volume to support the production (Fig 1). The block system on the other hand has high storativity but low permeability, meaning that fluid cannot flow directly from the block system into the wellbore. The fluid will flow from the block system into the matrix and then into the wellbore (Fig 2). When this type of reservoir is put on production, the initial flow will be from the matrix and the time it will take for the pressure to equalize between the matrix and the block will depend on the storability and permeability of the reservoir system. When production logs are acquired, the well is put on production and the production is allowed to stabilize before the well is logged. Without sufficient knowledge on the reservoir system or understanding of the heterogeneity inherent in the reservoir, if production logs are run in this type of system, it is possible to acquire the logs during the matrix flow period. Any inference made from this analysis will not be representative of normal flowing conditions, i.e. when the well has had sufficient time for pressure equalization between the block and matrix system. Therefore the time frame during which production logging data is acquired becomes critical in understanding the behavior of the reservoir.
Abstract El-Morgan Field was discovered in 1965 and is located offshore in the Gulf of Suez (GoS) approximately 160 miles south of Suez, Egypt. Peak Production was approximately 300,000 BOPD within only three years. El- Morgan is considered one of the giant fields since its STOOIP is estimated to be approximately 2.689 billion BO with an ultimate recoverable reserve around 1.439 billion BO. Over its history, more than 250 wells were drilled. Currently, 179 wells are operating (125 producers & 54 Injectors). El-Morgan is considered highly sophisticated field due to reservoir heterogeneity (Kareem reservoir), moderate stratification, limited aquifer support, high bubble-point pressure, low-permeability layers and its friable sand. Due to the high bubble-point pressure and high initial-rate (Pi=2,990psi & PB=2,269psi), the bubble-point pressure was encountered early in the field resulted in using peripheral injection to support reservoir pressure. In addition the reservoir heterogeneity while injecting peripherally, it is believed that significant oil reserves were being bypassed and were potentially unrecoverable. This paper presents an integrated approach to optimize the development for a complex field from both subsurface and operations views. It also shows studies conducted to maximize the asset value, explains how the development strategy have been revised over time, to augment oil ended by using an EOR method nowadays (BrightWater). All of these studies are coupled to the economical calculations. Managing giant fields with a significant potential is very important since each incremental 1% in RF will increase the ultimate recovery by tens of millions oil barrels. Also through this paper you will assure importance of certain reservoir evaluation tools and how you can optimize them to increase ultimate recovery factor. Paper is an excellent example for reservoir management that resulted in more than 52% primary RF.
- Africa > Middle East > Egypt > Gulf of Suez (0.95)
- Africa > Middle East > Egypt > Suez Governorate > Suez (0.24)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Morgan Field (0.99)
- South America > Falkland Islands > South Atlantic Ocean > South Falkland Basin > Darwin Formation (0.97)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Kareem Formation > Shagar Member (0.97)
- Africa > Middle East > Egypt > Gulf of Suez > Gulf of Suez Basin > Belayim Formation (0.89)
A New Strategy to Explore Tight Oil/Gas Reservoirs "Fit for Purpose Acid Fracturing"
Hegazy, G. M. (American University in Cairo (AUC), and Suez University, Egypt) | Salem, Adel M. (American University in Cairo (AUC), and Suez University, Egypt) | Shedid, Shedid A. (British University in Egypt (BUE), Egypt) | Shalaby, Shouhdi E. (Suez University, Egypt) | Abbott, J.. (Schlumberger, Abu Dhabi, UAE)
Abstract Oil 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.
- Africa (0.69)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.16)
- Research Report > New Finding (0.46)
- Research Report > Experimental Study (0.46)
- Geology > Rock Type > Sedimentary Rock (0.93)
- Geology > Geological Subdiscipline > Geomechanics (0.93)
- Asia > Middle East > UAE > Abu Dhabi > Arabian Gulf > Rub' al Khali Basin > Zakum Concession > Zakum Field > Upper Zakum Field > Thamama Group Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Tengiz Formation (0.99)
- Asia > Kazakhstan > Mangystau Oblast > Precaspian Basin > Tengiz Field > Korolev Formation (0.99)
- (3 more...)
- Well Drilling > Drilling Operations > Directional drilling (1.00)
- Well Completion > Hydraulic Fracturing (1.00)
- Well Completion > Acidizing (1.00)
- (6 more...)