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Copyright 2012, SPE/APPEA International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Production This paper was prepared for presentation at the SPE/APPEA International Conference on Health, Safety, and Environment in Oil and Gas Exploration and Prod uction held in Perth, Australia, 11-13 September 2012. This paper was selected for presentation by an SPE/APPEA program committee following review of information contained in an abstract submitted by the author(s). Contents of the paper have not been reviewed by the Society of Petroleum Engineers or the Australian Petroleum Production & Exploration Association Limited and are subject to correction by the author(s). The material does not necessarily reflect any position of the Society of Petroleum Engineers or the Australian Petroleum Production & Explorati on Association Limited, its officers, or members. Electronic reproduction, distribution, or storage of any part of this paper without the written consent of the Society of Petroleum Engineers or the Australian Petroleum Production & Exploration Association Limited is prohibited. Permission to reproduce in print is restricted to an abstract of not more than 300 words; illustrations may not be copied. The abstract must contain conspicuous acknowledgment of SPE copyright.
- Oceania > Australia > Western Australia > North West Shelf (0.29)
- Oceania > Australia > Western Australia > Perth (0.24)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Barrow Basin > Greater Gorgon Field > Barrow Island Field (0.94)
- North America > United States > Utah > Island Field (0.94)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > WA-253-P Permit > Block WA-253-P > Wheatstone Field > Mungaroo Formation (0.89)
- (12 more...)
1. INTRODUCTION Consideration of the 3D anisotropy of rocks has become a more common oilfield reservoir characterization practice today, particularly in unconventional shale reservoirs. In the past, rocks were commonly described with isotropic properties, simplifying the second order stiffness tensor into two dynamic properties (DTc and DTs) and the compliance rock tensor into two independent elastic properties such as Youngโs modulus and Poissonโs ratio. Sometimes the isotropy assumption was considered, even though a great difference between vertical and horizontal rock stiffness was obvious from acoustic logs or ultrasonic core measurements. Sedimentary rocks frequently are anisotropic by nature due to lamination, bedding and in some cases due to micro-cracks or natural fractures. Shales, in particular, are strongly anisotropic, not only transversely between vertical and horizontal elastic properties but azimuthally when they contain aligned micro-cracks or macroscopic natural fractures. Therefore, accurate in-situ horizontal stress profiles in shales require a full orthotropic anisotropic model. This paper provides an analytical solution for the two horizontal stresses as a function of the stiffness tensor components and the relationship between the orthotropic elastic pro stiffness tensor. Currently, cross-dipole multi-array acoustic logs are available to measure shear wave anisotropy in rocks from vertical wells. The azimuthally polarized vertical shear wave anisotropy can be estimated from cross-dipule full-wave forms while the transverse shear wave anisotropy can be derived from Stoneley wave monopole processing. However, these two acoustic anisotropies still provide insufficient information to fully describe orthotropic rocks. Consequently, additional acoustic measurements performed on core samples complement the information and enable full characterization of the stiffness tensor. A vertically transverse isotropic rock requires five independent elastic measurements while an orthotropic rock needs nine elastic constants. Sensitivity analyses are presented to demonstrate the influence of rock anisotropy in deriving horizontal stresses for three cases: isotropic, transverse isotropic and fully orthotropic.
- North America > United States > Texas (0.93)
- Asia (0.68)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (0.95)
- Geology > Petroleum Play Type > Unconventional Play > Shale Play (0.68)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Seismic Modeling > Velocity Modeling (0.68)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Sabinas - Rio Grande Basin > Eagle Ford Shale Formation (0.99)
- North America > United States > Texas > Maverick Basin > Eagle Ford Shale Formation (0.99)
- (6 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization > Reservoir geomechanics (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (1.00)
Offshore ESP Selection Criteria: An Industry Study
Romer, Michael C. (ExxonMobil Production Company) | Johnson, Mark E. (ExxonMobil Production Company) | Underwood, Pat C. (ExxonMobil Production Company) | Albers, Amanda L. (ExxonMobil Production Company) | Bacon, Russ M. (R.M. Bacon Engineering Ltd)
Abstract Most offshore wells that require artificial lift are gas lifted, as gas typically is readily available and compared to other lift systems, gas lifting is relatively inexpensive and low maintenance. However, electric submersible pumps (ESPs) can efficiently and economically increase oil production and reserves recovery under the appropriate operating conditions. This may translate to a lower abandonment pressure in the long termโpossibly reducing the total number of wells required to deplete an asset. Since few ESPs currently are installed in offshore wells, an ESP screening "Rules of Thumb" was created as a simple guide for prioritizing offshore ESP candidates. The selection criteria focus on feasibility of installation, operability conditions and operating practices to maximize run life, and economic considerations. ExxonMobilโ and industry experience from North America, South America, West Africa, Asia, Australia, the Middle East, and the North Sea provided the basis for the study.
- Asia > Middle East > Qatar (0.68)
- North America > United States > Texas (0.49)
- Europe > United Kingdom > North Sea (0.48)
- North America > United States > California (0.46)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BM-C-7 > Peregrino Heavy Field (0.99)
- South America > Brazil > Rio de Janeiro > South Atlantic Ocean > Campos Basin > Block BM-C-47 > Peregrino Heavy Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > WA-191-P > Block WA-27-L > Mutineer-Exeter Field > Exeter Field > Angel Formation (0.99)
- (10 more...)
Recent Progress of High-Pressure Air Injection (HPAI) Process in Light Oil Reservoir: Laboratory Investigation and Field Application
Jia, Hu (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China) | Yuan, Cheng-Dong (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China) | Zhang, Yu-Chuan (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China) | Peng, Huan (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China) | Zhong, Dong (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China) | Zhao, Jin-Zhou (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, China)
Abstract High-Pressure Air Injection (HPAI) in light oil reservoirs has been proven to be a valuable IOR (Improved Oil Recovery) process and caused more attention worldwide. In this paper, we give an overview of the recent progress of HPAI technique, based on a review of some representative HPAI projects including completed and ongoing projects. Some most important aspects for HPAI field application are discussed in depth, including reservoir screening criterion, recognition of recovery mechanism, laboratory study, numerical simulation, gas breakthrough control, tubing corrosion consideration and safety monitoring. With the successful HPAI application in Zhong Yuan Oil Field in China, it is estimated that foam or polymer gel assisted air injection should continue to grow in the next decade as a derived technology of HPAI for application in high-temperature high-heterogeneity reservoirs. The purpose of this paper is to investigate the ranges of some key parameters, new understanding based on laboratory test and successful field application, thus to provide lessons learnt and best practices for the guideline to achieve high-performance HPAI project.
- North America > United States > Texas (1.00)
- Europe (1.00)
- Oceania > Australia > Western Australia (0.93)
- (2 more...)
- Research Report (0.46)
- Overview (0.34)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (0.73)
- Geology > Mineral > Silicate > Phyllosilicate (0.49)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.46)
- Oceania > Australia > Western Australia > Carnarvon Basin (0.99)
- Oceania > Australia > South Australia > Cooper Eromanga Basin (0.99)
- Oceania > Australia > Queensland > Surat-Bowen Basin (0.99)
- (34 more...)
Sorption of CO2 in Shales Using the Manometric Set-up
Khosrokhavar, Roozbeh (Delft Uiniversity of Technology) | Schoemaker, Christiaan (Delft Uiniversity of Technology) | Battistutta, Elisa (Delft Uiniversity of Technology) | Wolf, Karl-Heinz (Delft Uiniversity of Technology) | Bruining, Hans (Delft Uiniversity of Technology)
Abstract In a transition period from a fossil fuel based society to a sustainable energy society it is expected that CO2 capture and subsequent sequestration (CCS) in geological formations will play a major role in reducing greenhouse gas emissions. Possibilities of sequestration include storage in aquifers and depleted gas reservoir. The storage capacity of gas reservoirs for CO2 depends also on the sorption in the omnipresent minerals and shales. It is important to investigate whether adsorption on shales gives an important contribution to the storage capacity. It is also important to relate the adsorption to the carbon content in the shale. Only a few measurements have been reported in the literature for high-pressure gas sorption on shales, and interest is largely focused on shales occurring outside Europe. We present results using a high pressure manometric setup on a dried black shale sample from Belgium. It consists of more than 57% of clay minerals and 6.58% organic matter. The excess sorption isotherm shows an initial increase to a maximum value of 0.19 mmol/gram and then starts to decrease until it becomes zero at 82 bar and subsequently the excess sorption becomes negative. Similar behavior was also observed for other shales and coal reported in the literature. We derive the equation for excess sorption in the manometric set-up allowing for a changing void volume. This equation is based on the finite density of the adsorbed phase. However, this is not the only mechanism causing a maximum in the sorption curve. Other reasons for void volume change are swelling of the shale and volume changes due to chemical reactions excluding sorption. Further research is necessary to investigate reasons for void volume changes in shales.
- Europe (1.00)
- North America > Canada > Alberta (0.28)
- North America > United States > Kentucky > Big Sandy Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Muderong Shale Formation (0.98)
- North America > Canada > British Columbia > Western Canada Sedimentary Basin > Horn River Basin > Muskwa Field > Muskwa Formation (0.94)
- (2 more...)
- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs (1.00)
- Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
- Health, Safety, Environment & Sustainability > Sustainability/Social Responsibility > Sustainable development (1.00)
- (2 more...)
Abstract Today the development of subsea fields or satellites and the remoteness of thelocation not only require subsea processing but have also has implications forthe provision of power. The norm for offshore power generation is the use offossil fuel. However, the uncertainty surrounding a global climate policy at atime when the projection is for an exponential increase in offshore powerdemand is a cause for pause to look at renewable power solutions. Types ofrenewable power solutions that have application to the offshore oil and gasindustry include: solar, wind, and ocean energy (various). This paper provides a rank/value for offshore power generated with bothrenewable- and conventional- energy sources relative to four (4) projectscenarios: Status Quo, Supply-to-the-Rescue, The Green Agenda, and DoubleJeopardy. The work to select a power solution began by identifying a key focusquestion about the future that the scenarios would address: How will the demandfor offshore (subsea) power and the potential externalities that may resultshape the power generation options over the next decade? The paper also pointsto resources that can shed light on the latest technological advances andfuture trends for renewable energy sources. The hope of the author is that thepaper will prove to be a useful reference for R&D specialists and projectengineers who are often asked to respond to the question: Renewables - Ready orNot? Introduction The project goal was to identify the best fit power delivery solution forhydrocarbon assets located remotely and/or in deepwater. For the purpose ofthis paper we would consider the power delivery implications for hydrocarbonassets located offshore North West Australia. The search for a feasible powerdelivery concept must be wide and deep enough to neither overlook promisingdevelopments in the Renewable Energy Market nor misjudge the overall impact ofproject externalities. The high-level workflow to arrive at a comprehensive solution is illustrated inFigure 1. Typical for the oil and gas space is a staged gate approach to arriveat a chosen system concept. These stages can be generically labeled as Phase 1,2, 3, etc. or given qualifying names like Identify, Assess, Select, Define, etc. The tasks attached to each stage as illustrated in figure 1 isself-explanatory. What is needed is greater clarity on terminology that may notbe broadly applied in the industry:" Givens" are facts, assumptions, and decisions already made and taken as agiven for this project. A " solution space" is a matrix showing all possible combination of theproject scenarios and system concepts. A subset of these will constitute thefeasible configurations for in-depth system modeling and analysis.
- North America > United States (1.00)
- Oceania > Australia > Western Australia (0.67)
- Asia > Middle East > Israel > Mediterranean Sea (0.24)
- Oceania > Australia > Western Australia > Carnarvon Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Rankin Platform > North West Shelf (0.89)
- North America > United States > Wyoming > Great Basin (0.89)
- (7 more...)
Abstract Faced with increasing field maturity and production decline from conventional gas reservoirs, oil companies are shifting their focus and pursuing new alternatives; one of them being the development of shale and gas plays. To be economically viable, these low-permeability formations require fracture stimulation. Interval selection within shale reservoirs for hydraulic fracturing or horizontal laterals are based on several variables: sufficient organic matter or total organic carbon (TOC) and favorable hydraulic fracturing stimulation. The presence and extent of the natural fracture system can also influence the performance of a shale reservoir; therefore, natural fractures should be characterized within the shale formation not only from wireline or LWD borehole images logs but also from cross-dipole deep shear wave imaging which can illuminate fractures up to 60 ft away that do not intersect the well. To assess these aspects, a mineralogical, structural, and geomechanical characterization of the shale formation should be conducted. The mineralogical characterization and TOC quantifications mainly rely on a pulsed neutron spectroscopy and nuclear magnetic resonance (NMR) logs. The processing of capture and inelastic gamma ray spectra obtained from the pulsed neutron tool quantifies the formation's basic elemental composition, including silicon, calcium, aluminum, iron, sulfur, magnesium, and carbon. Geomechanical characterization is based on acoustic and density log responses. Variation in the reservoir mineralogy and TOC content affect the rock mechanics properties. Stress vs. strain curves can be derived from a micro-mechanical model of the rock which enable correlations between dynamic (obtained from acoustic logs) and static elastic properties (obtained from triaxial compression testing on core samples). Additionally, the azimuthal and transverse shear wave anisotropies are processed from cross-dipole acoustic logs to characterize the vertical and horizontal rock stiffness. This anisotropic characterization of the rock enables the evaluation of the fracture gradient and stress contrast between the target formation and the overlying and underlying formations. The paper focuses on the interaction between mineralogy, organic content and geomechanical analyses in shale gas reservoir evaluation.
- North America > United States > Texas (1.00)
- Europe (1.00)
- Asia (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geomechanics (1.00)
- Geophysics > Borehole Geophysics (1.00)
- Geophysics > Seismic Surveying > Borehole Seismic Surveying (0.67)
- North America > United States > West Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Virginia > Appalachian Basin > Marcellus Shale Formation (0.99)
- North America > United States > Texas > West Gulf Coast Tertiary Basin > Eagle Ford Shale Formation (0.99)
- (13 more...)
There is plenty to be optimistic about in the upstream oil and gas oil sector. In this article, the Energy Industries Council (EIC) focuses on offshore opportunities globally, and identifies the hot spots of activity. It will also examine some of the key issues facing the sector and the energy supply chain today, such as the need to maximize oil and gas recovery from challenging environments and new offshore fields, and the need to reduce costs and innovate.
- Asia (1.00)
- Europe > United Kingdom (0.96)
- North America (0.73)
- Oceania > Australia > Western Australia > North West Shelf (0.70)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-268-P > Greater Gorgon Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-267-P > Greater Gorgon Field (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > Rankin Platform > Greater Gorgon Development Area > Block WA-25-P > Greater Gorgon Field (0.99)
- (27 more...)
Summary The selection criteria for multiphase boosting options remain somewhat subjective and are frequently influenced by the vendors? data, which may mask potential limitations of this emerging technology. Existing literature on multiphase pumping tends to focus on a certain pump type for a specific field application, but does not provide more-generalized criteria for the selection of multiphase boosting solutions from among those available in the market. A comprehensive literature review into the working principles of the major pump types identified the intrinsic advantages and limitations of each technology for subsea and downhole applications. The survey showed that, for subsea application, both the twin-screw pump (TSP) and the helicoaxial pump (HAP) can handle high suction gas volume fraction (GVF) with a fluid recycling system, or flow mixer. Thus, GVF is not a discriminating factor. The positive-displacement principle allows TSPs to work with very low suction pressure, but limits their operating range because of the dependency of flow rate on their relatively low speed. However, these pumps can handle highly viscous fluid. The rotodynamic concept enables the differential pressure of HAPs to self-adjust to any instantaneous change in suction GVF, and to achieve higher flow rate if sufficient suction pressure is maintained. Because HAPs usually run at higher speed, they offer a wider operating range. For subsea application, HAPs appear to be a better option than TSPs because they offer higher operation flexibility and have a better installation track record. For downhole applications, the electrical submersible pump (ESP) and the progressing-cavity pump (PCP) are the outstanding favorites, with the latter being preferred for lifting streams that are viscous or with high sand content. For GVF up to 70%, the rotodynamic pump (RDP) is becoming a popular solution. Although it is claimed that the downhole TSP (DTSP) can handle up to 98% GVF, it is not yet widely accepted in the field.
- North America > United States (1.00)
- Europe (1.00)
- Africa (1.00)
- Asia > Middle East (0.68)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Carnarvon Basin > Dampier Basin > WA-191-P > Block WA-27-L > Mutineer-Exeter Field > Exeter Field > Angel Formation (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Beagle Basin > Dampier Basin > WA-191-P > Block WA-27-L > Mutineer-Exeter Field > Exeter Field > Angel Formation (0.99)
- North America > United States > Gulf of Mexico > Central GOM > East Gulf Coast Tertiary Basin > Mississippi Canyon > Block 764 > King Field (0.99)
- Europe > United Kingdom > North Sea > Northern North Sea > East Shetland Basin > Block 3/02 > Lyell Field (0.99)
Abstract Several wells have been drilled in the south eastern side of Tunisia but only two wells are producing. However, to better understand the petroleum system mechanism of the area, a geochemical study was performed including oil-oil and oil-source rock correlation that was proved to be an essential tool for assessing oils occurrence, source rocks characteristics, their depositional environments and their distributions. The geochemical study was followed by 1D basin modeling to better understand the petroleum system functioning of the area. The geochemical survey is based on the analysis of a total of 214 cutting samples and 6 crude oil samples. In a first part, potential Silurian and Ordovician source rocks were analyzed by Rock Eval to characterize their petroleum potential. In the second part, DST oil samples are correlated to Silurian and Ordovician source rocks using biomarkers and light hydrocarbon fraction. Migration distances calculation was based on carbozoles and benzocarbozoles. Rock Eval results show that Silurian Hot shales exhibit good petroleum potential with mature type II oil prone kerogen, while Ordovician Shales show poor to fair petroleum potential and contain bad preserved type II kerogen. Geochemical correlations study proved that the Silurian Hot shales are the main source rock in the basin and excluded any contribution from the Ordovician shales. Carbozoles and benzocarbozoles concentrations in the oils of the northern part of the area suggest close proximity to the source kitchen while oils from the southern part seem to be sourced by a kitchen located in Ghadames basin. The 1D modeling indicates that oil and gas generation from the Silurian hot shales began in the Carboniferous at about 360 Ma and reaches the maximum generation phase in the Upper Jurassic at about 160 Ma. The Hercynian unconformity surface was the main drain of secondary migration in the basin.
- Phanerozoic > Paleozoic > Silurian (1.00)
- Phanerozoic > Paleozoic > Ordovician (1.00)
- Phanerozoic > Mesozoic > Jurassic > Upper Jurassic (0.34)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock > Shale (1.00)
- Geology > Geological Subdiscipline > Geochemistry (1.00)
- Geology > Geological Subdiscipline > Economic Geology > Petroleum Geology (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.48)
- South America > Brazil > Brazil > South Atlantic Ocean > Santos Basin (0.99)
- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin > Dampier Basin > WA-209-P > Oryx Field > Oryx 1 Well (0.99)
- North America > United States > California > San Joaquin Basin (0.99)
- (11 more...)