Injector Placement Research Articles

NUMERICAL AND EXPERIMENTAL RESEARCH ON THE DI-CI ENGINE PERFORMANCE CHARACTERISTICS UNDER LPG - DIESEL DUAL FUEL COMBUSTION MODE

Properties of Liquefied Petroleum Gas (LPG) are suitable as an alternative fuel for internal combustion engines. This work aims to combine both numerical optimization analysis of LPG injector placement angle and subsequent experiment with selected mounting injector angle to investigate the effects of using LPG as a parallel-partial substitute fuel with diesel fuel under dual-fuel combustion mode. An electronic injection fuel control system was applied to the modified intake manifold to generate the appropriate LPG injection. Three mounting angle injector positions including 450, 900 and 1350 in the upstream direction of intake air have been defined by Ansys Fluent to take into account efficient LPG-air mixing. Then, the experiment was conducted with LPG-diesel dual-fuel combustion mode (DFC mode) and compared to entirely diesel combustion mode as baseline data. Different load conditions ranging from idle to 4.0 kW were imposed at a constant engine speed of 1700rpm. The obtained results revealed that the injector’s mounting angle position by 45 opposite to the intake air flow showed the correlation with the calculated LPG-air ratio in dual fuel combustion reaction. In DFC mode, the brake thermal efficiency (BTE) decreased on average by 4.6% and the LPG substitution rate gradually decreased while brake-specific fuel consumption (BSFC) increased for all engine loads. The exhaust temperature in the dual-fuel combustion mode was found to be higher than that of full diesel fuel mode at low loads (less than 2.5 kW) and began to decrease at higher loads.

Mechanisms of Waterflood Inefficiency: Analysis of Geological, Petrophysical and Reservoir History, a Field Case Study of FWU (East Section)

The petroleum reservoir represents a complex heterogeneous system that requires thorough characterization prior to the implementation of any incremental recovery technique. One of the most commonly utilized and successful secondary recovery techniques is waterflooding. However, a lack of sufficient investigation into the inherent behavior and characteristics of the reservoir formation in situ can result in failure or suboptimal performance of waterflood operations. Therefore, a comprehensive understanding of the geological history, static and dynamic reservoir characteristics, and petrophysical data is essential for analyzing the mechanisms and causes of waterflood inefficiency and failure. In this study, waterflood inefficiency was observed in the Morrow B reservoir located in the Farnsworth Unit, situated in the northwestern shelf of the Anadarko Basin, Texas. To assess the potential mechanisms behind the inefficiency of waterflooding in the east half, geological, petrophysical, and reservoir engineering data, along with historical information, were integrated, reviewed, and analyzed. The integration and analysis of these datasets revealed that several factors contributed to the waterflood inefficiency. Firstly, the presence of abundant dispersed authigenic clays within the reservoir, worsened by low reservoir quality and high heterogeneity, led to unfavorable conditions for waterflood operations. The use of freshwater for flooding exacerbated the adverse effects of sensitive and migratory clays, further hampering the effectiveness of the waterflood. In addition to these factors, several reservoir engineering issues played a significant role in the inefficiency of waterflooding. These issues included inadequate perforation strategies due to the absence of detailed hydraulic flow units (HFUs) and rock typing, random placement of injectors, and uncontrolled injected fresh water. These external controlling parameters further contributed to the overall inefficiencies observed during waterflood operations in the east half of the reservoir. A detailed understanding of the mechanistic factors of inefficient waterflood operation will provide adequate insights into the development of the improved recovery technique for the field.

Effect of well configuration, well placement and reservoir characteristics on the performance of marine gas hydrate reservoir

Reservoir simulations are used to forecast the long-term gas production from gas hydrate reservoirs. In the present work, we explore different well placements and well configurations to analyze the gas production strategy for an oceanic, unconfined, class-2, gas hydrate reservoir using an in-house three-dimensional finite volume simulator. In the past, for depressurization in an unconfined class-2 reservoirs, isolation of the aquifer zone by well placement is suggested. We show that for high pressure conditions in marine gas hydrate reservoirs, depressurization is ineffective even with horizontal producer placed far away from the aquifer. Therefore, Warm water injection is necessary along with depressurization. We demonstrate that, the injector placement and configuration determines the gas production behavior and producer conditions do not significantly impact the production potential. We also find that the unconfined aquifer below the hydrate zone helps in the warm water convection and proximity of the injector to the aquifer improves gas production behavior. However, for unconfined class-2 gas hydrate reservoirs with low initial pressure, depressurization is effective and leads to a very high recovery (80%) of the gas. The reservoir porosity governs the warm water injection which affects the available dissociation energy to the gas hydrates and hence the gas recovery. In a layered reservoir, the porosity of the hydrate layer adjacent to the overburden has significant impact on the gas production due to the available dissociation energy from the overburden.

Impact of CO2 mixing with trapped hydrocarbons on CO2 storage capacity and security: A case study from the Captain aquifer (North Sea)

Gas mixing in the subsurface could have crucial implications on CO2 storage capacity and security. This study illustrates the impact of gas mixing in the “Captain X” CO2 storage site, an open saline aquifer and subset of the greater Captain aquifer, located in the Moray Firth, North Sea. The storage site hosts several abandoned hydrocarbon fields where injected CO2 could interact and mix with any remaining hydrocarbon gas left in the depleted structures. For this study, compositional simulation of CO2 injection into the Captain X storage site reservoir model was conducted to quantify the impact of mixing. Results show mixing of CO2 with the remaining trapped hydrocarbon gas makes the plume considerably less dense and more mobile. This increases the buoyancy forces acting on the plume, causing it to migrate faster towards the shallower storage boundaries and therefore, reduces the storage capacity of the site. Mixing also compromises the storage security as it mobilises the structurally trapped hydrocarbon gas from within the abandoned fields. Informed injector placement helps to manage and reduce the impact of mixing. Correct assessment of mixing is also considerably dependent on the volume and property of the trapped hydrocarbon gas. To provide a correct long term understanding of storage capacity and security, the impact of mixing, therefore, needs to be correctly considered in all large-scale CO2 storage operations.

DETERMINATION OF TECHNOLOGICAL PARAMETERS OF THE AEROSOL TYPE RAIL LUBRICATORS

The article presents the results of experimental studies of technological parameters of a pilot sample of aerosol type lubricant. As a lubricant, the industrial I-12A oil was added with the addition of graphite powder to it, which provides the implementation of a two-layered coating of the working surface of the rail. The test piece is a closed type oiling unit, which feeds on compressed air and allows the regulation of air and oil supply to the working nozzle. For drawing of a lubricant on a working surface the coaxial nozzle with the external formation of an aerosol - a mixture of oils and air is used.Studies were conducted in laboratory conditions. At the first stage, the geometric dimensions of the stain of the oil applied to the vertical surface were measured, depending on the distance between the nozzle and the surface. Such data makes it possible to adjust the settings of the injector placement relative to the rail, taking into account the permissible dimension of the approach, which is essential for the introduction of rail pads under operating conditions. Subsequently, depending on the width of the stain of the oil and the thickness of the lubricating layer from the supply of oil and air, were installed. Also, the dependencies of the cutting time of oil and air are set. The obtained data are necessary for determining the oil consumption in the operation of similar rail lubricants in real conditions. In addition, these data allow you to adjust the control system of the rail lubricant by the criterion of the limit time of cutting the oil and minimizing the cost of lubricant.According to the results of laboratory studies, an estimation of the effectiveness of the aerosol type air-lubricant was performed on the criterion of the total consumption of the lubricant for the predicted resource of the rails in the curved sections of the track. It was obtained the dependence of the number of inclusions of the lubricant and the lubricant flow rate on the number of load cycles for the rails for the projected resource. For one load cycle, a single passage of the wheelset of rolling stock along the rail was taken.

The injector location impact on the fuel combustion process in a direct gasoline injection system

The article contains an analysis of the fuel dose combustion phenomena and exhaust emissions in a direct injection system of an SI engine for variable injector location in the combustion chamber. The research performed is a continuation of the research presented in the article CE-2018-104. The tests were performed using the AVL Fire 2017 simulation environment. 27 injector placement combinations in three planes were analyzed: axial distance from the cylinder axis, injector depth relative to the head and angular position relative to the cylinder axis. An optimal solution was chosen, taking into account the significance of individual indicators. It was shown that the greatest impact in terms of the most advantageous combustion process indicators is the injector setting depth in the combustion chamber cavity, while the distance from the cylinder axis is of secondary importance. The smallest changes in the combustion and emission factors values are seen with the change of the injector placement angle (in the value range used in this study).

The impact of injector placement on the dose preparation conditions in a gasoline direct injection system

Direct fuel injection requires appropriate conditions for proper ignition of the formed mixture. The proper combustion process is shaped by the direct fuel injection, whose parameters vary. Preparation of the dose requires proper injector placement in the combustion chamber. This article focuses on the issue of the injector specific spatial and angular position in order to implement the injection and atomization of the fuel. The injectors pseudo-optimal location has been presented along with several changed positions. The research was conducted as a simulation experiment using AVL FIRE 2017 software. The best position of the injector was selected based on the fuel spraying and injection process indicators. It has been shown that the spatial position has the most impact and the injector placement angle is of secondary importance.

Estimating the Leakage along Wells during Geologic CO2 Storage: Application of the Well Leakage Assessment Tool to a Hypothetical Storage Scenario in Natrona County, Wyoming

Depleted oil and gas reservoirs have the potential to store an estimated 675 to 900 gigatones of carbon dioxide (CO2). Such reservoirs represent a significant resource for long-term geologic CO2 storage (GCS), which is a key mitigation strategy to reduce atmospheric CO2 (Metz et al., 2005). However, the relatively high density of wells drilled into oil and gas reservoirs means that there exists significant potential pathways for unwanted fluid migration into overlying receptors in a GCS scenario. Wells, especially in fields that span many decades of exploration and production, are often known to have issues with their integrity. The reasons for loss of well integrity comprise a wide range of technological, operational, and environmental causes. In GCS, the buoyant CO2 plume and region of elevated pressure expand from the injectors and contact a large number of the existing and potentially leaky wells. This contact can occur both during injection and for significant time during the post-injection site care. Understanding the long-term potential of these wells to serve as unwanted fluid migration pathways is, therefore, critical to ensuring the viability of these resources as storage reservoirs. The National Risk Assessment Partnership (NRAP), a United States Department of Energy led initiative, is developing a set of tools and methodologies that use a science-based understanding to characterize risks associated with GCS. One such product is the Well Leakage Analysis Tool (WLAT), which is a tool that estimates well leakage in the form of a response to different scenarios representing initial well states and configurations. This tool contains a set of reduced-complexity models (e.g., reduced-order models and reduced-physics models) that give a rapid assessment of leakage for several different scenarios and well conditions.In this study, the WLAT is used to estimate CO2 and brine leakage along existing wells in a hypothetical storage scenario in Natrona County, Wyoming. We identified several key parameters that in comparison with others can significantly affect the amount of CO2 and brine leaked. Among those parameters are distance from injection site, well age, leak path length and permeability. Using the WLAT, the wells with the highest likelihood of excessive leakage were estimated, and the rate of CO2 and brine flux quantified.A workflow is outlined in which candidate fields for GCS can be assessed to identify wells that represent the greatest impact of leakage. Additionally, the proposed approach can be used to test possible linking relationships (e.g., if leak-path permeability is correlated with well age or a documented history of well integrity issues) and their impact on the leak behaviour. This information can then be used to rank wells with the highest priority for recompletion before CO2 injection is initiated. Additionally, predicting the potential breakthrough time and flow rates of fluids from the existing wells provides valuable information to help estimate where and when monitoring will be most effective and aids in decision making about injector placement at a storage site. Operators can then make decisions regarding the location of the injection site based on proximity to the wells with the longest breakthrough time and minimum flow rate. The ability of the WLAT to predict potential leakage before any CO2 injection occurs will ultimately reduce the resources (time and money) spent on injection into sites ill-suited for long-term geologic CO2 storage.

Analytical Approach for Modeling of Multi Well CO2 Injection

Disposal of carbon dioxide (CO2) into underground geological formations is considered a viable strategy for the mitigation of global warming. It aims to reduce greenhouse gases emitted from point sources such as power plants. In order to select and evaluate a potential storage formation, many reservoir properties such as porosity, permeability, lateral and vertical extents, and a variety of residual fluid properties are considered. Injection design, which includes the placement of injectors and their flow rates, should be chosen to optimize injection capacity. One of the most important considerations to be addressed during design stage of sequestration is evaluation of pressure behaviour inside the reservoir during and after injection as the sequestered CO2 increases the pressure within the formation. In order to maintain the integrity of the reservoir the pressure needs to be maintained below the fracture pressure, typically at least 10% below. Thus evaluation of reservoir pressure is essential to ensure the reservoir remains under the maximum allowable pressure while sequestering the maximum amount of CO2 for long term storage in the reservoir. The optimal injection rates within a multi well injection site occur when the bottom-hole pressure at each injection site is at the maximum allowable pressure. In this study we present an analytical approach for modeling the pressure evolution during multi well CO2 injection into saline aquifers and using the model modify the injection rates to optimize injection capacity within a formation. We show that this optimization procedure significantly increases the capacity of formation as opposed to using the same injection rate at each wellbore.

Thrust Control by Fluidic Injection in Solid Rocket Motors

Cold-flow tests, thermal tests, and numerical simulation were performed to study the thrust-adjustment characteristics, and the thrust-vector-control characteristics, of a fluidic nozzle throat combined with the method of shock vector control. The effective throat-area ratio, thrust-adjustment ratio of the fluidic nozzle throat, and the effect of gas and liquid medium on thrust-vector-control characteristics were investigated. The feasibility of a fluidic nozzle throat being applied to solid rocket motor was verified. Finally, the relationship between the effective throat-area ratio, the thrust-adjustment ratio, and the modified mass-flow-rate ratio has been obtained to provide accessibility for fluidic-nozzle-throat design. The combination of fluidic nozzle throat and shock vector control has been studied with a view to increasing the thrust-control effect. Results show that the effective throat-area ratio, thrust-vector angle, and adjustment ratio are associated with the injection angle, injector placement, and distribution of secondary flow, and increase with the modified mass-flow-rate ratio. By proper placement of secondary-flow injectors, the flow-interface loss can be effectively decreased to retain acceptable thrust-vector-control performance by the combination of fluidic nozzle throat and shock vector control.

Time-Lapse Seismic for Reservoir Management: Case Studies From Offshore Niger Delta, Nigeria

Summary This paper presents case studies focused on the interpretation and integration of seismic reservoir monitoring from several fields in conventional offshore and deepwater Niger Delta. The fields are characterized by different geological settings and development-maturity stages. We show different applications varying from qualitative to quantitative use of time-lapse (4D) seismic information. In the first case study, which is in shallow water, the field has specific reservoir-development challenges, simple geology, and is in phased development. On this field, 4D seismic, which was acquired several years ago, is characterized by poor seismic repeatability. Nevertheless, we show that because of improvements from seismic reprocessing, 4D seismic makes qualitative contributions to the ongoing field development. In the second case study, the field is characterized by complex geological settings. The 4D seismic is affected by overburden with strong lateral variations in velocity and steeply dipping structure (up to 40°). Prestack-depth-imaging (PSDM) 4D seismic is used in a more-qualitative manner to monitor gas injection, validate the geologic/reservoir models, optimize infill injector placement, and consequently, enhance field-development economics. The third case study presents a deep offshore field characterized by a complex depositional system for some reservoirs. In this example, good 4D-seismic repeatability (sum of source- and receiver-placement differences between surveys, dS+dR) is achieved, leading to an increased quantitative use of 4D monitoring for the assessment of sand/sand communication, mapping of oil/water (OWC) front, pressure evolution, and dynamic calibration of petro-elastic model (PEM), and also as a seismic-based production-logging tool. In addition, 4D seismic is used to update seismic interpretation, provide a better understanding of internal architecture of the reservoirs units, and, thereby, yield a more-robust reservoir model. The 4D seismic in this field is a key tool for field-development optimization and reservoir management. The last case study illustrates the need for seismic-feasibility studies to detect 4D responses related to production. In addition to assessing the impact of the field environment on the 4D- seismic signal, these studies also help in choosing the optimum seismic-survey type, design, and acquisition parameters. These studies would possibly lead to the adoption of new technologies such as broad-band streamer or nodes acquisition in the near future.

Characterizing fracture networks: an effective approach using seismic anisotropy attributes

The development of naturally fractured reservoirs is significantly influenced by the characteristics of the fracture network since these control the volume and flow direction of the fluid through the reservoir rocks. The presence of fractures can be very beneficial since knowledge of their characteristics allows the design of well paths that intersect a larger number of permeable fractures, thus increasing production. It also enables optimized placement of injectors for improved sweep efficiency and better control of the reservoir pressure. However, fractures can also be damaging for the economic potential of a field. They can create preferential flow paths which may lead to premature water breakthroughs or, conversely, act as barriers to impede production. A good understanding of the fracture network in terms of intensity, orientation, and spatial distribution is therefore essential for improved reservoir development. Some fracture information is available from core observations and image log interpretation, but these data are only valid in the vicinity of the borehole, and when extrapolated beyond this, can lead to erroneous prediction of the overall reservoir dynamics. Even though geostatistical methods can help to reduce the uncertainty associated with spatial predictions by taking into account the geological heterogeneities, a true 3D attribute is necessary in order to accurately characterize a fractured reservoir. Following the observations of Crampin (1985a, 1985b), Crampin et al. (1986), Thomsen (1988), and others, it is now widely recognized that fracture systems are often found to be aligned in a preferential direction. This induces a directional (or azimuthal) dependence of seismic properties such as traveltime, velocities and reflection amplitudes. This directional dependence, also referred to as anisotropy, can cause seismic shear waves to split in preferential directions related to the alignment of the fractures: the fast shear waves being polarized parallel to the fractures and the slow shear waves polarized perpendicular to the fractures. It can also affect the amplitude of compressional waves depending on the azimuthal direction of propagation. An analysis of the anisotropy effects observed in 3D seismic data can therefore provide insight into the fracture characteristics (Thomsen, 1995; Lynn et al., 1995, 1996). Methods based on shear-wave splitting analysis are well established (Crampin, 2000), but unfortunately shear wave data are relatively expensive to acquire and process. As a result, in the last few years there has been a growing interest in P-wave azimuthal amplitude variation. Rüger and Tsvanskin (1997) demonstrated that reliable estimates of the anisotropy parameters could be obtained from the P-wave amplitude. Later, the approximations of the P-wave reflection coefficient presented by Rüger (1998) were extended into a linearized form by Jenner (2002) and used by many authors for inferring fracture properties. Angerer et al. (2003a) then went on to propose an integrated workflow for seismic fracture characterization from wide-azimuth large offset P-wave and PS data. This approach (Figure 1) includes a state-ofthe- art geostatistical decomposition technique combined with azimuthal anisotropy analysis and yields quantitative estimates of fracture intensity and direction. It can be applied either to horizon-based attributes, such as interval velocity maps and RMS amplitude maps, or to 3D attribute volumes such as seismic amplitude and AVO attributes. Here we present the results of a recent fracture characterization study based on P-wave azimuthal anisotropy from a wide-azimuth 3D land dataset. The goal of the study was to characterize the fracture distribution in a carbonate reservoir using several attributes such as interval velocities, RMS amplitude and seismic amplitude. In addition, to confirm the validity of the estimated anisotropy attributes, this study also included an analysis of the fractures using FMI/FMS log data from six wells. Several comparisons of anisotropic and conventional processing illustrate the benefits of our approach at different stages of the processing. Finally, we review the accuracy and efficiency of each seismic attributes in terms of characterizing the fractures orientation, magnitude and distribution.

Approach to in situ analysis of scramjet combustor behavior

Procedures used to assess combustion behavior of scramjet engines in the 1960s were not published at that time, but may be relevant to current scramjet research. This article describes hydrogen-fueled scramjet investigations performed at the General Applied Science Laboratories during the 1966-1970 time period. The analysis procedure, involving fuel-injection tailoring, aided in locating injection sites in the scramjet combustor and in predicting the pressure rises induced by combustion at selected points in the combustor. The method was applied to two geometrically dissimilar engines whose performance levels were measured in similar freejet facilities. One of these engines incorporated a combustor entrance (gap) height of approximately 2.9 in. and an overall combustor/nozzle length of 10 gap heights. The injector placement resulting from this development approach did not induce pressure distributions that one would associate with the higher-process-efficiency, minimumentropy solution. Nevertheless, approximately 80% of the target thrust levels were attained in these engines at fuel-air equivalence ratios of one, without the benefit of isolators and without deleterious combustor-inlet interactions. Agreement between predicted and measured combustion pressure rises was generally good and satisfactory agreement exists between the pressure rise measured and that calculated using a current cycle analysis.

Chemigation Pipeline Transport Model for Nonsoluble Pesticide II. Numerical and Field Validation

A computer model describing the injection and transport of a nonsoluble pesticide in a linear move irrigation lateral is developed and validated. Inputs to the model are both intensive and extensive properties of irrigation water and pesticide, and the model outputs chemical concentration in water for each sprinkler along the linear move irrigation lateral. Numerical studies are performed that compare Eulerian and Lagrangian methods and provide the transition between the two methods. The transport model and a model for evaluating drop diameter are used to calculate sprinkler discharge concentration as a function of distance along the pipeline, and the model is compared with field data for a single port injector. The model is also evaluated for multiorifice and multiport injection systems. A technique for optimizing placement of injectors for the multiport system is described and evaluated.

Involvement of Neurons Sensitive to Angiotensin II in the Median Preoptic Nucleus in the Drinking Response Induced by Angiotensin II Activation of the Subfornical Organ in Rats

The involvement of neurons sensitive to angiotensin II (ANG II) in the median preoptic nucleus (MnPO) in mediating the drinking response caused by administration of ANG II either directly into the subfornical organ (SFO) or intravenously was examined in the conscious rat. In all rats ( n = 16) having correct injector placement in both of these brain sites, injections of ANG II (10 -12 M) into the SFO elicited drinking. Previous injections of saralasin (10 -10 M), a specific ANG II antagonist, but not saline vehicle, into the MnPO significantly attenuated the drinking response to ANG II administration directly into the SFO. Intravenous infusions of ANG II (75 ng/kg) produced a drinking response in 12 of the 16 rats, and the response was significantly reduced by pretreatment with saralasin (10 -10 M), but not by saline, in the SFO. These results show the importance of MnPO neurons responsible for ANG II in mediating the dipsogenic response to ANG II acting at the SFO and suggest that the response may be implicated in angiotensinergic neural circuits from the SFO to the MnPO.

Use of Well Test Results in Oilfield Development Planning in the Timor Sea

Summary The analysis of several transient-pressure surveys employing both analytical and numerical simulation techniques is presented. Case histories include examples of the following: partial penetration and spherical flow; flow influenced by various boundary conditions and geometries, including linear flow; variations in transmissibility; and effects from ocean tides. It is shown how these well-test results can be integrated with the geological framework, and their overall impact on oilfield development planning is discussed. Introduction The success of defining an optimum hydrocarbon-field development plan is crucially dependent on the early knowledge of the reservoir drive mechanisms and heterogeneities that may affect fluid flow in the reservoir. For offshore field developments, decisions related to the possible placement of injectors are of particular concern. As shown in the documented case histories, a greater effort to obtain quality data from extensive well testing may be warranted in such situations to confirm the geological model derived from seismic. petrophysical, and geological considerations. In any development, but particularly of significance in offshore (platform) situations, the three largest reservoir uncertainties commonly found are related to aquifer strength, sealing capacity of faults, and the extent of sand development. This is also true of the situations described here that use floating production facilities kept on location by a single-point mooring system, accommodating a small number of wells. In these more marginal field situations. there is not only a need for technically creative and novel engineering solutions that are robust and cost-effective, but also a need for a more detailed definition of future production and injection expectations and strategies. Well Testing In Timor Sea Oil Fields One new frontier in oilfield development is the Timor Sea. This offshore area, bordering the northwestern coast of Australia (see Fig. 1), has been explored to a relatively small extent, and to date only two commercial fields have been delineated: the Jabiru and Challis fields, contained in Permit AC/P4. In the Jabiru field, further described in later sections, it could be ascertained from well-test analysis that the large degree of reservoir faulting would not impede the initially indicated high production rates. A second vital piece of information obtained from well tests in this field relates to the anticipated aquifer response. In this respect, an effective vertical-to-horizontal-permeability ratio could be deduced from partial penetration and hemispherical flow. Although the well tests conducted were not strictly limit tests, they nevertheless indicated the accessibility of large reservoir volumes and the likelihood of a strong bottomwater drive. In contrast to the Jabiru field, which shows a sand development of considerable thickness, the Challis field comprises relatively thin oil-bearing sands. This field, also further described in the following sections, presented a particular challenge for well-test analysis. Because of the limited sand thickness, the impact of faults led to varied pressure-transient characteristics arising from different flow and boundary conditions. Furthermore, because appraisal wells in this field are to contribute directly to future production (subsea wells), the determination of "connected oil" is of great importance, particularly because completion costs, including costly flowlines, exceed the original drilling cost. The confirmation of reasonably sized fault compartments is also a prerequisite for the successful placement of water injectors. In the Timor Sea fields discovered so far, permeabilities are in the darcy range, requiring certain precautions to be taken during testing i.e., the use of high-accuracy gauges and tide corrections. As previously observed in Australian offshore sedimentary basins, corrections for ocean tide effects are particularly necessary, because these perturbations can be easily misinterpreted as boundary effects when superimposed on a relatively flat pressure-buildup response.