Borehole Stability Research Articles

Coupled Geomechanics Reservoir Simulation of UTF Phase A Project Using a Full Permeability Tensor

Abstract In this research study, we conducted a coupled thermal-stress-fluid flow numerical model on the UTF Phase A SAGD project in order to investigate the fundamental geomechanical behaviour involved in the SAGD process, and to gain insight into the reservoir response to temperature and pore pressure changes. The numerical simulation is carried out by using a self-developed coupled finite element model which incorporates our proposed strain-induced permeability model. The obtained simulation results were compared with the measured data. Introduction Thermal recovery processes involve coupling between heat transfer, multiphase flow and stress/deformation, which has become an increasingly important subject in the petroleum field(1). Particularly, the coupling is crucial in problems such as borehole stability, hydraulic fracturing and injection/production induced deformation of the ground surface during the thermal recovery process in heavy oil or oil sand reservoirs. Numerical modelling of the coupled processes is historically carried out in the areas of geomechanics modelling and reservoir simulation. The former is to compute the stress-strain behaviour; therefore, the deformation. The latter is to essentially model the multiphase flow and heat transfer in porous media. Each of these disciplines simplifies the part of the problem that is not of primary interest. These approaches are unacceptable in situations where the coupling is strong and the changes of porosity and permeability cannot be accounted for by rock compressibility alone. Gutierrez and Lewis(2) extend Biot's theory to multiphase fluid flow in deformable porous media. Based on their formulation, they conclude that the coupling between the geomechanics and the multiphase flow occurs simultaneously. Thus, fully coupled system equations of deformations, multiphase flow and heat transfer should be solved simultaneously. Development of such kinds of fully coupled geomechanics-multiphase flow-heat transfer simulators needs tremendous effort, since the existing FEM geomechanics codes and FDM reservoir simulators cannot be used. Settari and Mourits(3) present an approach to couple the stress-strain behaviour to multiphase flow-heat transfer using porosity as a coupling parameter. The geomechanics module and the thermal reservoir simulator are used in a staggered manner. Pore pressure and temperature changes are calculated from the thermal reservoir simulator and transferred to the geomechanics module. The stress and the displacement changes are then calculated in the geomechanics simulation. An iterative algorithm is used to ensure that the porosity calculated from the geomechanics module is the same as that from the thermal reservoir simulator. The staggered technique employed to solve the coupled system equations allows for the use of the existing geomechanics codes in conjunction with a standard reservoir simulator. Currently, most of the commercial coupled geomechanics-multiphase flow-heat transfer simulators are developed in this way. The disadvantage of these kinds of coupled simulators is that the thermal reservoir module, usually developed using the finite difference method (FDM), cannot accommodate the full permeability tensor, since they adopt the standard discretization scheme, such as 5-spot for 2D problems and 7-spot for 3D problems. In this paper, the development of a coupled geomechanics-multiphase flow-heat transfer simulator using the finite element method (FEM) is described with the use of Galerkin's least squares (GLS) technique(4) to stabilize the saturation equation.

A new well path optimization model for increased mechanical borehole stability

Borehole collapse is the commonly encountered wellbore stability problem during drilling. The precursor of such borehole failure can be often eliminated by a proper determination of the critical mud pressure. Recently, Al-Ajmi and Zimmerman developed a new 3D analytical model to estimate the mud pressure required to avoid shear failure (i.e., borehole collapse) at the wall of an arbitrarily oriented borehole. This was achieved by using linear elasticity theory to calculate the stresses around the borehole, in conjunction with the fully-polyaxial Mogi–Coulomb criterion to predict failure. This model was used to study the behaviour of the collapse pressure under different in situ stress regimes. We found that the optimal drilling trajectory is directly related to the principal in situ stresses. Accordingly, we now develop a new analytical solution to optimize well path. The stability model has been applied to several field cases, from the North Sea, Indonesia and the Arabian Gulf, and the new model in each case is consistent with the field experience. We conclude that the optimal wellbore profile can be ensured by employing this new analytical stability model.

Rate dependence of the flexural tensile strength of Laurentian granite

Shale gas is becoming a new energy development focus worldwide with advances in horizontal wells and hydraulic fracturing, and spontaneous water-based working fluid imbibition is one of the strongest phenomena that can impact borehole stability and the gas extraction rate. Our present experimental work was carried out on shale Brazilian discs with 5 different bedding orientations (0°, 30°, 45°, 60° and 90°) after air-drying and spontaneous water imbibition using a split Hopkinson pressure bar. The results illustrate that under the same loading rate (100–900 GPa/s), spontaneous water imbibition obviously weakens the dynamic tensile strength of shale discs, except for shale discs with a bedding orientation of 90° when the loading rate exceeds 400 GPa/s, and does not change the anisotropic dynamic tensile strength variation trend versus bedding orientations. Models that can well fit test data and reveal the coupling effects of bedding orientation and loading rate on the dynamic tensile strength of shale after air-drying and spontaneous water imbibition are proposed. The rate-dependent failure mode only appears among shale discs with bedding orientations of 30°, 45° and 60°, and this phenomenon is exacerbated and more complex after spontaneous water imbibition. Bedding planes of shale discs after air-drying and spontaneous water imbibition both play three different roles in affecting the failure crack propagation, i.e., intersecting propagation, promoting propagation and promoting turning. Finally, the dynamic tensile strength responses of shale after spontaneous water imbibition are analyzed and discussed, and potential field applications in borehole stability, perforation design and hydraulic fracturing are suggested.

Determination of magnitude and orientation of the in-situ stress from borehole breakout and effect of pore pressure on borehole stability — Case study in Cheshmeh Khush oil field of Iran

The detailed profile of the orientations of borehole breakouts as a function of depth were investigated in wells CK-8 and CK-9 in the Cheshmeh Khush oilfield in south-west of Iran. Borehole breakouts without tensile induced fractures were detected from UBI logs. By analyzing statistically of borehole breakout orientation in two wells, it was found that while a mean azimuth of maximum horizontal stress in CK-8 is N–S (s.d = 0.4°); the azimuth of breakout in CK-9 varies as a function of depth with a mean azimuth 345° + 26°; which since no 3D seismic survey has been run upon the field, assumed to be caused by active tectonic state. By utilizing presence and absence of borehole breakout and tensile induced fracture, as well as density, rock strength, pore and mud pressure in deviated borehole, in situ stresses magnitude in CK-8 were constrained. The experiment showed that the state of stress is normal faulting regime and maximum horizontal stress magnitude is closer to SV comparing with S hmin. Pore pressure was predicted by deploying Eaton's method on observed sonic data deviation from normal compaction trend. Considering the behavior of breakout and pore pressure in CK-8 in accordance with rock strength changes, demonstrated that the borehole gets more stable as pore pressure increases.

Critical condition study of borehole stability during air drilling

The purpose of this paper is to establish the existence of the critical condition of borehole stability during air drilling. Rock Failure Process Analysis Code2D was used to set up a damage model of the borehole excavated in strain-softening rock. Damage evolution around the borehole was studied by tracking acoustic emission. The study indicates that excavation damaged zone (EDZ) is formed around borehole because of stress concentration after the borehole is excavated. There is a critical condition for borehole stability; the borehole will collapse when the critical damage condition is reached. The critical condition of underground excavation exists not only in elastic and ideal plastic material but in strain-softening material as well. The research is helpful to developing an evaluation method of borehole stability during air drilling.

Compaction bands induced by borehole drilling

Drilling experiments in rock blocks subjected to pre-existing true triaxial far-field stresses simulating real in situ conditions often result in localized failure around the created borehole, which brings about the formation of borehole breakouts. In weakly bonded quartz-rich porous sandstones breakouts take the form of narrow tabular (slot-like) openings extending along a plane perpendicular to the maximum applied-stress direction. Scanning electron microscopes images of failed boreholes strongly suggest that these breakouts are compaction bands that have been emptied to different extents. The bands form as a result of the stress concentration accompanying the creation of the borehole. The evacuation of the compaction bands is brought about by the circulating drilling fluid flushing out debonded and often fragmented grains from within these bands (Haimson and co-workers, 2003–2007). The objective of this paper is to predict the conditions under which compaction bands are formed around boreholes. To this end, a new analytical model is formulated that enables prediction of the stress field around emptied and filled compaction bands, the various factors affecting the breakouts lengths, and their final length. Good agreement of the developed analytical model with experimental results obtained by Haimson and co-workers (Haimson and Klaetsch in Rock physics and geomechanics in the study of reservoirs and repositories, vol 284, pp 89–105, 2007; Haimson and Kovachich in Eng Geol 69:219–231, 2003; Klaetsch and Haimson in Mining and tunneling innovation and opportunity, University of Toronto press, pp 1365–1371, 2002; Sheets and Haimson in Proceedings, paper ARMA/NARMS 04-484, 2004) is demonstrated. The presented study is of practical relevance: boreholes are often drilled deep into weak porous sandstone formations for the purpose of extracting oil and gas, and the question of borehole stability is crucial. In addition, borehole breakouts are often used to estimate the state of stress in the Earth’s crust, and our new formulation will help improve these estimates.

Compaction bands simulated in Discrete Element Models

Compaction bands, i.e. tabular zones that accommodate compaction but no shear, have recently been observed in high-porosity sandstone, where the dominant micromechanism is grain breakage and crushing. Such bands are extremely important for hydrocarbon extraction, forming barriers that might inhibit the flow. They have further been associated with borehole stability problems. However, compaction band initiation and propagation remain poorly understood, while the necessary material conditions for their formation require further investigation. Three-dimensional Discrete Element Method simulations of the stressing of a sandstone sample were conducted. These successfully reproduced a discrete compaction band; its initiation and propagation are shown. An investigation into the effects of the cementation bond strength and the post-fragmentation behaviour of the grains on the observed behaviour is also presented. Well-localised discrete bands were observed when both the bond strengths were high and the grains lost their load-bearing capacity after being broken. On the contrary, an advancing crushing front resembling a diffuse compaction band was observed in simulations where the broken grain could still carry force. The data presented here provide the micromechanical insight necessary for a better understanding of conditions leading to compaction band initiation and propagation, which might facilitate identification of rocks that might form them.

Finite element formulation for poroelastic problem with zero effective stress boundary condition

AbstractZero effective stress boundary condition along with constant fluid flux is commonly encountered in geotechnical applications such as uncased borehole stability, fluid injection and production at an uncased borehole, hydraulic fracturing and sand production. This complex boundary condition introduces high nonlinearity in the numerical simulation. Conventional iterative methods such as Newton–Raphson method are required to solve this nonlinear problem iteratively, which involve huge computing time and also pose numerical difficulties on the convergence. To overcome this numerical difficulty and hence reduce the computing time, a novel numerical technique is proposed in this paper. Its performance is evaluated using a numerical example simulating fluid injection around an uncased borehole. Copyright © 2009 John Wiley & Sons, Ltd.

A prediction method of borehole stability based on seismic attribute technology

Borehole instability in drilling engineering can bring about serious problems of drilling quality and safety. Based on the close relationships between seismic and well log information, the prediction method of borehole stability is presented to effectively control borehole instability. Conventional and nonlinear seismic attributes are extracted from borehole-side seismic traces of impending drilling well and drilled offset well respectively. Then the optimal attributes combinations sensitive to log properties are selected by using genetic algorithm and wavelet neural network technology together. A series of mapping models which reflect the nonlinear relationships between seismic attributes and acoustic and density log data of various formation intervals in drilled well are constructed through neural network modeling. With analysis of cutting logging data, seismic attributes of the formation under bit and corresponding mapping model can be used to predict acoustic and density log curves of this formation. Based on the predicted log data, log interpretation method, analysis technology of in-situ stress and mechanics model of borehole stability are employed to calculate in-situ stress, pore pressure, collapse pressure and fracture pressure, thus the safe drilling fluid density window which can keep borehole stable is determined. Prediction precision and real-time operation ability of the proposed method are satisfying, which have been proved in practical application in TR oil field.

State and origin of present-day stress fields in sedimentary basins

The present-day stress field provides fundamental insight into the forces driving plate tectonics and intra-plate deformation. Furthermore, Knowledge of the present-day stress field is essential in petroleum, geothermal and mining geomechanics applications such as the stability of boreholes and tunnels, and improving production through natural and induced fractures. The World Stress Map (WSM) Project has, for over 20 years, compiled a public global database of present-day tectonic stress information to determine and understand the state of stress in the Earth?s lithosphere. The WSM database has revealed that plate-scale stress fields are controlled by forces exerted at plate boundaries (e.g. mid-ocean ridges, continental collision zones), commonly resulting in regional stress orientations sub-parallel to plate motion. However, the state and origin of present-day stress fields at smaller scales, such as within sedimentary basins, remains poorly understood in comparison. Detailed analysis of present-day stresses from within 70 sedimentary basins commonly reveals significant and complex variations in the present-day stress orientation, both across basins and within fields. For example, borehole breakouts in the North German Basin, Nile Delta and the Baram Delta province of northwest Borneo indicate broad regional rotations in the horizontal stress orientation. The present-day maximum horizontal stress orientations in the Gulf of Thailand are approximately north-south at the basin-scale (perpendicular to plate motion) and are perturbed locally to be sub-parallel to fault strike. The North Sea and Permian Basin of Texas display widely varying stress orientations between fields, with some neighbouring fields exhibiting perpendicular stress orientations. Basin- and field-scale stress fields result from the complex combination of numerous factors acting at different scales, including far-field forces (e.g. plate boundary forces), basin geometry (e.g. the shape of deltaic wedges), geological structures (e.g. diapirs, faults), mechanical contrasts (e.g. evaporites, overpressured shales, detachment zones), topography and deglaciation.

Stressed-Shale Drilling Strategy—Water-Activity Design Improves Drilling Performance

Summary Nonaqueous drilling fluids are often chosen to drill troublesome shale formations in an effort to minimize wellbore-instability problems. However, experience in the Gulf of Mexico (GOM) indicates that when drilling in highly faulted areas, oil- and synthetic-based fluids do not always prevent wellbore destabilization. This is evidenced by wellbore collapse, and the resulting difficulty with hole cleaning, tripping, logging, and casing running. It is known that the chemical, physical, and mechanical effects resulting from the interaction between the drilling fluid and the formation may degrade the stability of the borehole in the already weakened and stressed fault interval. Commonly, the practice has been to increase the drilling fluid's salt content to enhance the borehole stability. The perception that low drilling-fluid water activity is beneficial to wellbore stability needs to be revised. A detailed laboratory investigation using preserved-shale core and drilling information has confirmed that the water activity of drilling fluids is often much lower than necessary. This study has shown that when drilling faulted or fractured shale, the correct, not higher, salt content in drilling fluids will reduce wellbore-collapse problems and improve drilling performance. A laboratory method, which allows the quantitative measurement of water and ion movement during shale/mud interactions, combined with geological information optimizes the salinity design of drilling fluid, which controls water and ion movement. Laboratory data and field cases from GOM drilling support the concept of optimum salinity to enhance borehole stability in naturally fractured formations as part of the stressed-shale-drilling strategy to improve drilling performance.

Techbits: LWD Sonic Technology Focus of Emerging Technology Workshop

Techbits A technology designed to help drillers make improved real-time decisions in uncertain environments was the focus of an Emerging Technology Workshop (ETW), held 12–13 May in San Antonio, Texas. Seventy workshop participants representing drillers, petrophysicists, geophysicists, geologists, and tool/service providers discussed the current value and future potential of logging-while-drilling (LWD) sonic technologies to increase the quality and speed of downhole data measurement. LWD sonic technologies use a wave propagator or signal source to send a sonic signal from the wellbore out into the formation, and receivers to pick up the return signals which are stored in memory. Derived formation-sonic-travel time measurements are sent through a telemetry mud pulse system to the surface in real time. LWD offers several benefits that enable nearly instantaneous data collection to improve the safety of drilling operations and create a more efficient business process by improving the speed and quality of geological interpretations and operational decisions, as Gopal Amruthapuri, Operations Geologist for Chevron and Chairperson of the ETW, explained. "Drilling without any LWD tools on the bottomhole assembly is like walking in a dark tunnel, and as seismic resolutions are poor under salt, we need a flash light to better understand these complex structures," he said. "Drilling activities continue to move into deeper waters and high-pressure/high-temperature (HP/HT) reservoirs… there are many uncertainties that cannot be determined with predrill seismic studies. "A LWD sonic tool enables us to drill safely and efficiently in subsalt sections," Amruthapuri continued, "and the velocity measurements let you predict bore-hole stability, understand rock mechanical properties and time-to-depth seismic correlation while drilling, measure petrophysical properties like porosity determination, and even identify cement top. This allows us to prepare for or circumvent potential problems." Yet given this level of potential, there is still hesitation within the industry to more fully adopt the technology. A major aim of the ETW was to bring together the industry's experts to openly discuss why this hesitation persists, and to address the technology gaps that must be filled before more widespread industry acceptance is possible. Keynote Address Frames Potential The keynote address was delivered by Brian Hornby, Geophysical Adviser for BP. "My aim in the keynote was to focus on what LWD sonic technology could realistically deliver. In my view, new technologies normally generate a lot of enthusiasm on introduction and this can lead to failure because of unrealistic expectations that are not fulfilled. A conservative approach where one focuses on initially achieving basic, robust deliverables followed by introduction of more exotic developments is recommended." Hornby started with the basic question of why a company would want to run LWD sonic in the first place. "The main pull for this technology is compressional-wave (P-wave) logging, so the key to introducing this technology to more of the industry is to focus on delivering a reliable P-wave logging service. On the business side, decision makers may ask if LWD sonic adds something in combination with a wireline tool, or if it can replace wireline outright.

State-of-the-Art in Coalbed Methane Drilling Fluids

Summary The production of methane from wet coalbeds is often associated with the production of significant amounts of water. While producing water is necessary to desorb the methane from the coal, the damage from the drilling fluids used is difficult to assess, because the gas production follows weeks to months after the well is drilled. Commonly asked questions include the following: What are the important parameters for drilling an organic reservoir rock that is both the source and the trap for the methane? Has the drilling fluid affected the gas production? Are the cleats plugged? Does the "filtercake" have an impact on the flow of water and gas? Are stimulation techniques compatible with the drilling fluids used? This paper describes the development of a unique drilling fluid to drill coalbed methane wells with a special emphasis on horizontal applications. The fluid design incorporates products to match the delicate surface chemistry on the coal, a matting system to provide both borehole stability and minimize fluid losses to the cleats, and a breaker method of removing the matting system once drilling is completed. This paper also discusses how coal geology impacts drilling planning, drilling practices, the choice of drilling fluid, and completion/stimulation techniques for Upper Cretaceous Mannville-type coals drilled within the Western Canadian Sedimentary Basin. A focus on horizontal coalbed methane (CBM) wells is presented. Field results from three horizontal wells are discussed, two of which were drilled with the new drilling fluid system. The wells demonstrated exceptional stability in coal for lengths to 1000 m, controlled drilling rates and ease of running slotted liners. Methods for, and results of, placing the breaker in the horizontal wells are covered in depth.

Borehole stability in naturally fractured reservoirs during production tests

Based on the plane of weakness theory, a model for predicting borehole stability in fractured reservoirs under different stress states was estiblisted and the equations for solving borehole stability were developed. The minimum downhole pressures required to maintain borehole stability under different natural fracture occurrences were calculated by using the data from a well in the Tazhong (central Tarim) area, Tarim Basin, west China. Several conclusions were drawn for naturally fractured reservoirs with a dip angle from less than 10 ° to greater than 30 °. Application in three wells in the Tazhong area indicates that this model is practically useful.

Optimization of Required Volumetric Flow Rates for Aerated Mud Underbalanced Drilling

In the aerated mud underbalanced drilling, the bottomhole pressure is intentionally reduced by reducing the hydrostatic mud column due to the two-phase flow occurrence in the annulus. However, in the field, it is incorrectly assumed that the aerated mud can be treated as a homogenous mixture of liquid and gas, neglecting the slippage between the two phases and, thus, the flow pattern and its effect on pressure drop calculation. Accurate prediction of bottomhole pressures and optimal flow rates requires the modeling of the complex flow mechanisms involved in aerated mud flow, which includes flow pattern prediction and slip liquid hold-up. The objective of this study is to develop a simulation tool to optimize the gas and liquid volumetric flow rates using bottomhole pressure and borehole stability as the selecting criterion. The investigation of the drill pipe size effect on the optimal gas and liquid flow rates was also part of this study. A vertical, two-phase, flow comprehensive mechanistic model is modified and incorporated in the simulator to predict the pressure drop in the annulus according to the existing flow pattern. The modified model predicts the annulus bottomhole pressure and the corresponding optimal gas and liquid flow rates for various drill pipe diameters. The simulator was validated using field data, and the results show a fairly accurate match. In conclusion, the optimization of required flow rates for aerated mud drilling was achieved by the developed simulator, which considers flow pattern occurrence in the pressure drop calculation. Furthermore, the drill pipe size was found to be an influential parameter for flow rate optimization.

Borehole stability analysis considering spatial variability and poroelastoplasticity

Typically, stability analysis of oil-producing wells is carried out considering that both the hydraulic and mechanical parameters of the rock mass are deterministic. When analyzing borehole stability, two failure mechanisms are generally considered, namely, failure due to either tensile or compressive (shear) stresses. These mechanisms are produced, respectively, by either too high or too low drilling fluid pressure. Mechanical and hydraulic properties of rock masses, and in particular sedimentary rock masses, may show a considerable degree of spatial variability. This paper focuses on the evaluation of the limits for the internal pressure associated with a target probability of failure, taking into account both the spatial variability of hydraulic and mechanical properties, and the simple variability of the initial pore pressure and in-situ stresses. The analysis is performed with a finite element program that incorporates coupled fluid-mechanical effects and elastoplastic behavior of the rock. In this way, the proposed borehole stability analysis can be set into a reliability-based framework described in the paper. Examples are shown, using stochastic data from the literature, and conclusions are drawn regarding the effect of spatial variability on the borehole stability.

Challenges for Coring Deep Permafrost on Earth and Mars

A scientific drilling expedition to the High Lake region of Nunavut, Canada, was recently completed with the goals of collecting samples and delineating gradients in salinity, gas composition, pH, pe, and microbial abundance in a 400 m thick permafrost zone and accessing the underlying pristine subpermafrost brine. With a triple-barrel wireline tool and the use of stringent quality assurance and quality control (QA/QC) protocols, 200 m of frozen, Archean, mafic volcanic rock was collected from the lower boundary that separates the permafrost layer and subpermafrost saline water. Hot water was used to remove cuttings and prevent the drill rods from freezing in place. No cryopegs were detected during penetration through the permafrost. Coring stopped at the 535 m depth, and the drill water was bailed from the hole while saline water replaced it. Within 24 hours, the borehole iced closed at 125 m depth due to vapor condensation from atmospheric moisture and, initially, warm water leaking through the casing, which blocked further access. Preliminary data suggest that the recovered cores contain viable anaerobic microorganisms that are not contaminants even though isotopic analyses of the saline borehole water suggests that it is a residue of the drilling brine used to remove the ice from the upper, older portion of the borehole. Any proposed coring mission to Mars that seeks to access subpermafrost brine will not only require borehole stability but also a means by which to generate substantial heating along the borehole string to prevent closure of the borehole from condensation of water vapor generated by drilling.

Scientific results from Gulf of Mexico Gas Hydrates Joint Industry Project Leg 1 drilling: Introduction and overview

The Gulf of Mexico Gas Hydrates Joint Industry Project (JIP) is a consortium of production and service companies and some government agencies formed to address the challenges that gas hydrates pose for deepwater exploration and production. In partnership with the U.S. Department of Energy and with scientific assistance from the U.S. Geological Survey and academic partners, the JIP has focused on studies to assess hazards associated with drilling the fine-grained, hydrate-bearing sediments that dominate much of the shallow subseafloor in the deepwater (>500 m) Gulf of Mexico. In preparation for an initial drilling, logging, and coring program, the JIP sponsored a multi-year research effort that included: (a) the development of borehole stability models for hydrate-bearing sediments; (b) exhaustive laboratory measurements of the physical properties of hydrate-bearing sediments; (c) refinement of new techniques for processing industry-standard 3-D seismic data to constrain gas hydrate saturations; and (d) construction of instrumentation to measure the physical properties of sediment cores that had never been removed from in situ hydrostatic pressure conditions. Following review of potential drilling sites, the JIP launched a 35-day expedition in Spring 2005 to acquire well logs and sediment cores at sites in Atwater Valley lease blocks 13/14 and Keathley Canyon lease block 151 in the northern Gulf of Mexico minibasin province. The Keathley Canyon site has a bottom simulating reflection at ∼392 m below the seafloor, while the Atwater Valley location is characterized by seafloor mounds with an underlying upwarped seismic reflection consistent with upward fluid migration and possible shoaling of the base of the gas hydrate stability (BGHS). No gas hydrate was recovered at the drill sites, but logging data, and to some extent cores, suggest the occurrence of gas hydrate in inferred coarser-grained beds and fractures, particularly between 220 and 330 m below the seafloor at the Keathley Canyon site. This paper provides an overview of the results of the initial phases of the JIP work and introduces the 15 papers that make up this special volume on the scientific results related to the 2005 logging and drilling expedition.

Real-time prediction method of borehole stability

Abstract Based on the close relationship between seismic and logging information, a real-time prediction model of borehole stability is established using seismic, logging, and geological data to control borehole wall sloughing instability. First, seismic attributes are extracted from borehole-side seismic traces of target wells and drilled offset wells. The mapping models of relationships between seismic attributes and logging data of various formation intervals in drilled wells are then constructed using wavelet neural network. Using the seismic attributes of formation under bit and the corresponding mapping model, the acoustic and density logging data of the current undrilled formation can be predicted. On the basis of the prediction results, the mechanical model of borehole stability is employed to calculate pore pressure, collapse pressure, and fracture pressure, thus predicting the safe drilling fluid density range. Practical application in Tarim Oilfield shows that real-time operation performance of the model is excellent and the prediction accuracy of parameters is satisfactory.

Deformation mechanisms and safe drilling fluids density in extremely thick salt formations

Hydrocarbons are very often associated with salt structures. The oil and gas industry is often required to drill along and through long salt sections to reach and recover hydrocarbons. The unique physical properties of salt require special techniques to ensure borehole stability and adequate casing design. This paper assumed that the mechanical behavior of salt is regulated by the magnitude of mean stress and octahedral shear stress and under the influence of different stress conditions, the deformation of rock salt can be represented by three domains, i.e. compression domain, volume unchanged domain, and dilatancy domain, which are separated by a stress dependent boundary. In the compression domain, the volume of salt decreases until all microcracks are closed, with only elastic deformation and pure creep; in the volume unchanged domain the deformation is considered steady incompressible flow controlled by pure creep; and in the dilatancy domain the volume of salt increases during deformation due to micro-cracking, causing damage and accelerating “creep” until failure. This paper presents a hypothesis that the borehole is stable only when the magnitude of octahedral shear stress is below the dilatancy boundary. It gives the design method for determining drilling fluids density, and calculates the closure rate of borehole with the recommended drilling fluids density. If the closure rate of the borehole is less than 0.1%, the drilling fluids density window can be used during drilling through extremely thick salt formations.