bluuebunny/crossref_metadata_2025 huggingface dataset:
Demonstrating Adequate Management of Risks: The Move from Quantitative to Qualitative Risk Assessments
Authors: Bower-White Graham
Published: June 2014

This paper will demonstrate that the use of quantitative risk analysis (QRA) has limitations and does not, in isolation, demonstrate adequate management of risks. The only way to demonstrate that risks are being appropriately managed is to identify all hazards; understand the level of risk; identify all prevention, control and mitigation barriers; and then demonstrate that those barriers are adequate and effective in managing that risk to a level that is as low as reasonably practicable.

This paper is applicable to all process industries and, in particular, those industries operating under a legislated safety case regime. Under these safety regulations we have a legal obligation to demonstrate that we are managing risk to levels that are demonstrably ALARP.

In summary this paper will show that QRA has its place in demonstrating adequate management of risks; however, it should not be used in isolation. Having a QRA conducted can sometimes provide a false sense of security that risk is being managed. The UKOOA Risk-based Decision Making Framework is a useful tool in demonstrating the small part that QRA plays in managing risk. The answer to managing risk effectively lies in demonstrating that adequate and effective controls are in place. Not only do we need to identify the controls that are required to manage risk effectively, we also need to demonstrate that those controls are actually in place, are performing as they should and that competent people have confirmed that this is the case.

In the process industry, post-Macondo & Montara, it is essential that operators move away from just demonstrating that they understand the level of risk that personnel and the environment are exposed to. We all need to move towards demonstrating that we have adequate and effective barriers and controls in place to manage that risk effectively.
Defensive Driver Training (Does e-learning have a Roll to Play)
Authors: Fee Wayne , Morrison Gareth , Berg Brodie Von
Published: June 2014

Land transportation-related accidents continue to be the highest cause of fatalities within the oil and gas industry, as shown in the International Association of Oil & Gas Producers (OGP) 2011 performance indicators. Despite widespread efforts, performance improvements have been slow to realize.

This presentation discusses the effectiveness of Instructor Led Defensive Driver Training (ILDDT) in reducing the number of Land Transport Fatalities whilst exploring the impact of supplementing current training methodologies with e-learning. The presentation will discuss the traditional and e-learning models covering, what is currently available, the pros and cons of both options and how the two methods can be used together to increase awareness and improve behavior. Currently OGP 365 Land Transport Safety Recommended Practices recommend initial theoretical training followed by refresher training based on risk exposure and drivers’ performance with a refresher at least every 3 years. This paper challenges the recommended frequency given the significance & implications of transport related incidents whilst providing affordable options to regularly provide supplementary training at frequent intervals. Additionally the presentation will highlight some perceived gaps in ILDDT and provide recommendation on how e-learning can potentially address those gaps in terms of its ability to continually and regularly keep driving relevant and ‘top of mind’, its flexibility in being able to deliver specific and individualized content, its alignment with best practices in adult learning and its ease of deployment. Finally the presentation will explain the role e-learning can potentially play in areas such as corporate liability & social responsibility as well as explaining its effectiveness as a stand alone application in other verticals and how this effectiveness can be translated to the Oil & Gas sector.
Management Systems Approach to Managing Human Rights Issues
Authors: Nguyen Tam , Fokkema Bert , Vallat Julie , Cleland Roper
Published: June 2014

Recently there has been a proliferation of external guidance and guidelines for managing human rights issues. While these are useful tools to inform the management of potential risk, at best they may offer abstract concepts or normative aspirations of performance. There are a range of external expectations for companies to demonstrate how they respect human rights, including having business processes in place to prevent or mitigate potential human rights issues that may be caused by the company’s projects or operations. The paper describes how IPIECA, the global oil and gas industry association for environmental and social issues, has responded to the emergence of external guidelines in connection to implementing human rights due diligence by improving existing management systems and processes.
Updated Requirements to Area Based Cooperation in Emergency Response Reflecting 10 Years of Norwegian Success
Authors: Vinnem Jan Erik
Published: June 2014

Requirements to area based emergency response arrangements were published in 2000. An updating of the Guidelines for area based emergency response arrangements (OLF?) has been carried out in the period 2010–2012, with the main emphasis on review of experience and the need for revised requirements. The requirements address water and air born resources within established areas for cooperation, and do not address the requirements to each installation’s resources. Experience with the existing requirements has been collected from operators of offshore installations, work force representatives, authorities plus a large number of experts and personnel with essential emergency response qualifications and roles. An extensive supporting documentation has been prepared, based on analyses, discussions and evaluations. A revised Guideline has been issued with response and capacity requirements. During the process, the need for one additional emergency response scenario to be standardized in the offshore industry was found, and new requirements have been formulated for the emergency response relating to helicopter crash on the installation. The experience with these emergency response arrangements is clearly very positive, and includes a number of lives that have been saved each year. The requirements are regarded by the authorities as the best practice in relation to emergency response arrangements, and increase in the area of application is one of the vital evaluations for the future. The paper will describe and discuss the requirements and report on the experience gained through more than ten years of operation, as well as identify and discuss future challenges which may lead to future revisions.
Modelling the Options for Managing Drill Cuttings Piles on Decommissioning
Authors: Hayes Sean , Galley Liz
Published: June 2014

This paper describes advanced modelling that has been applied to the decommissioning of a major North Sea drill cuttings pile to support the decommissioning programme. The environmental impacts associated with North Sea drill cuttings piles were examined in the 1990s and 2000s with agreement to manage cuttings piles based on simple estimated oil loss and footprints. Options for managing the piles must be considered on decommissioning, and piles may be disturbed during removal operations and from the ultimate collapse of any remaining structures.

Advances in modelling techniques now allow us to predict long-term trends in cuttings pile characteristics and environmental risks quantitatively, providing firm direction in mitigating risks. This is key in determining appropriate decommissioning options for the piles and nearby structures. Modelling involving fluid dynamics, soil mechanics, scientifically verified 3D dispersion modelling, contaminant degradation and seabed recovery was used in several scenarios: the extant pile; moving the pile across the seabed using suction pumps; backflush discharges relating to retrieving the pile; and disturbance from remaining jacket footings ultimately falling into the pile after several hundred years.

The existing 15.3 metre high pile was re-created in the model domain with a good correlation using the original drilling discharge data from 54 wells and recent survey data. Long term characteristics and risk aspects were then modelled twenty years into the future, and extrapolated several hundred years to calculate persistence footprints, oil loss, and the contributing elements to environmental risk, such as toxicity, grain size change and dexoxygenation. This approach identified key risk factors and enabled quantitative option comparison. Water column impacts were also calculated.

The process generated valuable lessons regarding using survey data, generating input data, managing uncertainties and combining different modelling types. To date, there have been limited opportunities to evaluate cuttings pile impacts at the point of decommissioning and this will assist others and advance understanding and reasoning in this field.
Exemplary Environmental Impact Assessments as Tools to Optimize Operations and Assure Approvability - Experiences With Projects Around Germany's Largest Oilfield in a National Park and UNESCO World Heritage Site
Authors: Reichenbach Marc , Mattfeld Heiner
Published: June 2014

Exploration and production of oil or gas in protected nature areas require a comprehensive and flexible approach in order to adapt the project to the specificity of the respective conservation objectives. Approvability can only be achieved if all reasonable technical and logistic alternatives, which are able to minimize the environmental impact, are exhausted. These principles are illustrated by experiences from 10 years of handling different projects within Germany’s largest oil field located within a Wadden sea national park: the laying of two pipelines and two sea power cables, the establishment of extensive scour protection and the preparatory planning for four exploration wells.

All projects had to be assessed against the conservation objectives of different regimes: national park, biosphere reserve, nationally protected habitat, European Habitat Directive, European Bird Directive, special species protection and – since 2009 – UNESCO world heritage site. The examples illustrate in which way the technical and logistic concepts were – sometimes radically – changed and adapted to the conservation needs of the area. The main topics to be addressed were:

Strict avoidance of any contamination of the environment (zero discharge principle)

Avoidance of sensitive periods,

Avoidance of raising soil temperature more than two Kelvin,

Minimization of area use

Extensive monitoring

Implementation of compensation measures (revitalization of salt marshes)

These examples of good practice show how an environmental optimization of projects can lead to successful application procedures (even confirmed in court cases). Thus it can enable the exploration and production of oil or gas in protected and environmentally highly sensitive areas. In this way environmental impact assessments should not be seen as static evaluations but rather as a process during which a project is adapted and optimized towards approvability.
A Plant Simulator to Enhance the Process Safety of Industrial Operators
Authors: Manca Davide , Colombo Simone , Nazir Salman
Published: June 2014

The significant impact of human errors on the operation of industrial processes calls for improved methodologies and tools to train both control-room and field operators. Common Operator Training Simulators (OTSs) meet almost exclusively the needs for the formation of Control-Room Operators (CROPs). On the Field Operators (FOPs) side, few contributes have been carried out to improve their training level. The paper presents and discusses a solution for immersive training of industrial operators that allows experiencing the multifaceted scenarios of (real) plant operations. This tool comprises two dynamic simulators that interlink the simulation of the operations underwent in the plant with the replication of abnormal situations, near-misses, and eventually possible accidents. The two-way interaction between a dynamic process simulator and a dynamic accident simulator, when performed in real-time, allows reproducing the experiences lived by industrial operators. These dynamic simulators are the engines that work behind the curtains of an Immersive Virtual Environment (IVE) and make possible the realism (and the associated interest, involvement and enjoyment) of the simulated operations of the plant. The immersive environment is based on Immersive Virtual Reality (IVR), commonly referred to as 3D, where a stereoscopic reproduction of the whole plant, coupled to spatial sounds, increases the situation awareness of the field operators who interact with control-room operators by means of push-to-talk devices.

The paper discusses some applications of the Plant Simulator in the Oil & Gas and the polymerization industries that allow reproducing not only specific training case-studies but also real accidents.
Virtual Reality as Effective Tool for Training and Decision-Making: Preliminary Results of Experiments Performed with a Plant Simulator
Authors: Colombo S.. , Nazir S.. , Manca D..
Published: June 2014

The use of Immersive Virtual Reality (IVR) for training is an idea that is around since long time; the real, unclarified doubt about its use is whether it does really increase performance with respect to traditional methods such as classroom and on-the-job training. The most critical point of traditional training methods is the difficulty to train operators about system’s deviations from nominal conditions. But even the more advanced simulation-supported training approach, commercially represented by the Operator Training Simulator (OTS), is not immune from flaws as it is affected both by the subjectivity of the assessment (making useless the operators’ benchmarking) and by the impossibility of training simultaneously the Field Operator (FOP) with the Control Room Operator (CROP), i.e. team training. The advent of the Plant Simulator (PS) enabled to overcome the inherent limitations of the training methods. But the efficacy of using Immersive Virtual Environments (IVE) was, and to some extent still is, to prove. This paper goes exactly in that direction by explaining the preliminary results of an experiment campaign performed in a PS, which demonstrates the clear benefit of using IVR for training (field) operators. The paper even highlights that, if a PS is used, the benefits are not just limited to the training but can also be extended to operations management.
Perforating High-Temperature Wells
Authors: Bell W.T. , Auberlinder G.A.
Published: June 2014

The recent achievement of new records in well depths has presented a new set of problems to the perforating industry. Resulting extremes in pressures and temperatures have pointed up the limitations of existing tools and explosives, thereby imposing new challenges for equipment and techniques.

This paper describes some of the major problems stemming from deep-well mud pressures and temperatures. Proper techniques for measuring bottom-hole temperatures are discussed. Thermal limitations of currently used wire-line explosive tools and components are emphasized along with recommended ratings and specialized operating techniques. Misconceived notions relating to the capabilities of conventional explosives are treated.

An answer to the trend to deeper wells with higher pressures and temperatures is introduced in the form of a newly developed, high-temperature explosive package for the steel retrievable shaped-charge gun.

Introduction

The extreme bottom-hole temperatures and mud pressures of today's deeper wells present new problems for the perforating industry. As deep tests continue to explore the earth, constant development of equipment and refinement of techniques are required to keep abreast of steadily mounting pressure-temperature conditions.

Deep-well drilling surged upward during the early 1950's. In 1952 less than 10 wells were producing from deeper than 15,000 ft. In 1959 alone, 63 new producers were completed below that depth. Drilling and producing depth records have shown a steady trend upward, resulting in a maximum drilling depth of 25,340 ft, with the deepest successful completion recorded at 20,745 ft.

Should this general trend be maintained, the wireline service industry will, within a few short years, be faced with high pressure and temperature completion problems taxing the capability of existing tools and lab-test facilities.
Optimization of Drainage-Area Configurations To Maximize Recovery From SAGD Operations
Authors: Manchuk Johnathan G. , Deutsch Clayton V.
Published: June 2014

Placement of steam-assisted-gravity-drainage (SAGD) surface production pads and subsurface drainage areas in the McMurray formation to maximize the economic potential of an area is a challenging problem. The location of surface pads (SPs) and drainage areas has a large impact on their production performance because of several factors, including variation of bitumen in place, variation of the reservoir base surface, vertical conformance, areal conformance, interaction between different drainage areas and pads, and surface hazards. An optimization algorithm is presented to determine the positions and orientations of SPs and drainage areas over a reservoir area; therefore, the potential for economically recoverable bitumen is maximized. The optimization considers either a deterministic model of the relevant properties or multiple realizations to account for uncertainty. Optimization considers all drainage areas simultaneously to ensure joint optimality of an entire set. The algorithm is demonstrated using two realistic examples that show a significant improvement in potential recovery. The algorithm executes in a reasonable amount of computation time, considering the complexity of the problem.
Quantifying Heat Requirements for SAGD Startup Phase: Steam Injection, Electrical Heating
Authors: Moini Behdad , Edmunds Neil
Published: June 2014

A proper and effective startup of the steam-assisted-gravity-drainage (SAGD) well pairs, where both horizontal wells inject steam, is a key parameter to SAGD performance. In the past, a number of investigations have been conducted on the optimum startup strategy and operational procedures; however, fewer studies have modelled the heat requirements of the process. This study proposes an effective practical method that correlates the heat flux inside the horizontal wellbore with the temperature outside the wellbore wall. A transient conductive-heat-transfer equation in a cylindrical coordinate system is adopted for two different startup strategies: (a) variable heat flux (steam circulation in the well pair) to maintain a constant desired temperature at the wellbore wall and (b) constant heat flux (electrical heating of the well pair) to gradually increase temperature and finally reach a desired temperature on the wellbore wall. A novel and simple mathematical technique is presented for each startup approach to evaluate the instantaneous and cumulative heat requirements to keep the wellbore hot. Excellent agreements between the results of the proposed techniques and outputs of a commercial reservoir simulator are demonstrated. Accurate quantitative evaluation of heat requirements for the startup phase of SAGD enables optimum planning for steam requirements and practical design of any other heat sources employed in the process.
Straightline Analysis of Flow Rate vs. Cumulative-Production Data for the Explicit Determination of Gas Reserves
Authors: Ye Peng , Ayala Luis
Published: June 2014

Production forecasting and prediction of original fluids in place are important gas-well-performance evaluations which are routinely conducted using rate/time decline-curve analysis. Currently, rate/time decline-curve analysis of natural-gas reservoirs relies heavily on the use of empirical curve fitting of boundary-dominated rate/time production data using type curves or the Arps hyperbolic decline model. In this study, we show that original fluids-in-place prediction and gas-well-performance evaluations can be conducted simply by straightline analysis of boundary-dominated data in flow-rate vs. cumulative-production plots. We first analytically demonstrate that the hyperbolic decline exponent describing the depletion of single-phase volumetric gas reservoirs is not subject to empirical determination from rate/time data. Decline behaviour of gas wells producing at less than full potential is also shown to exhibit a hybrid decline character: hyperbolic during early boundary-dominated flow and exponential at later times. In both cases, explicit calculations of hyperbolic decline coefficients are possible, thus enabling the explicit calculation of gas reserves using flow-rate vs. cumulative-production straightline plots. Numerical and field case studies are presented to demonstrate the applicability and generality of the proposed reserves determination methodology.
Operations Research, A New Discipline of Interest to the Petroleum Engineer
Authors: Allen Fraser H. , Jones Kevin R.
Published: June 2014

Introduction

A new field of applied science known in this country as "operations research" is making rapid gains as a means of determining the optimum course of action in complex situations. In Great Britain this type of activity is referred to as "operational research". The term "operations analysis" and the abbreviations "OpSearch" and "OR" are in relatively common usage both in this country and abroad. The Germans employ the name "Wirtschaftsforschung" (economic, or management, research) and the Russians, who are now becoming much more active in this type of work, seem to use various terms, one of the more common ones being "operations investigation".

Within this new discipline are a number of techniques especially designed to handle problems involving risk and uncertainty. Probably no industry is so vitally concerned with risk as is the petroleum industry and no professional man is forced continually to deal with such uncertain basic physical data as is the petroleum engineer. The growing interest in operations research in the SPE membership is not surprising.

The Mathematical Model

The first step in formulating the solution to a problem through operations research is to state the problem precisely in mathematical language. It is then necessary to set up what is termed a "mathematical model" of the situation. The development of a mathematical model need not be difficult. In fact almost any engineering calculation, such as a simple pore-volume estimate of reserves, is essentially the same type of thing except that most individuals approach these calculations as a stepwise series of arithmetical calculations. They stop frequently with partial or intermediate answers, weigh the feasibility of the sub-answers, and then proceed. The more sophisticated mathematical-model approach simply demands that the whole series of these steps be set up ahead of time in the form of equations and statements of inequality. The various factors included in these mathematical statements of equality and inequality, as well as the answers themselves, can be restricted within pre-defined limits. This avoids the necessity of pondering the logic of the sub-answers before proceeding.
In-Situ Poisson's Ratio Determination from Interference Transient Well Test
Authors: Shahri Mojtaba P. , Miska Stefan Z.
Published: June 2014

Poisson's ratio is usually determined using well-logging, fracturing data and core samples. However, these methods provide us with a Poisson's ratio which is representative of only near-wellbore regions. In this paper, a technique is proposed by extending currently used pressure-transient testing concepts to include reservoir stresses. More specifically, the interference well test is generalized to find not only conventional flow parameters such as reservoir transmissivity and storage capacity, but also the average dynamic in-situ Poisson's ratio. This is accomplished by using the generalized diffusivity equation, which takes into account flow-induced stress changes.

Firstly, a generalized diffusivity equation is formulated by considering a deformable porous medium. The main goal of the generalized diffusivity equation is to extend current well testing methods to include both fluid flow and rock mechanics issues, and to present a way to determine the rock mechanics-related property, Poisson's ratio, from interference well testing. The line source solution to the diffusivity equation is used to modify the current interference well testing technique. Field data is utilized to show the main steps of the proposed transient well testing analysis technique.

An average in-situ value can be put in practice in different applications requiring accurate value of Poisson's ratio. Some examples of these include in-situ stress field determination, stress distribution and rock mass deformation, next generation of coupled fluid flow-geomechanical simulators, hydraulic fracturing design, wellbore stability analysis and sand production design. Using dynamic Poisson's ratio that could capture the flow-induced stress changes, we would be able to find the stress distribution due to production/injection within the reservoir more precisely. Accurate determination of stress distribution has a significant impact on wellbore stability issues in challenging wells, such as depleted and deep water reservoirs.
A Novel Approach for Efficiently Evaluating Extended Intervals in Coalbed Methane Reservoirs
Authors: Harfoushian Jack H. , Pourabed HamidReza , Moh Hsiao Wun , Torlov Vladislav , Cheong Boon
Published: June 2014

Over the past few years, there has been a surge of interest in using Australia's coalbed methane (CBM) resources to produce liquefied natural gas (LNG) for export, taking advantage of increasing prices and growing global demand for gas. Principally in Queensland, the second largest state, situated in the northeast of the country, there has been significant investment by a number of companies to secure footholds in this resource play. By December 2008, seven proposals for LNG plants had been announced, most involving partnerships between Queensland companies with coal seam gas resources and international petroleum companies.

Most exploration and appraisal CBM wells are tested to determine pressures and coal seam deliverability. As the majority of wells cannot flow to surface naturally, closed chamber tests are conducted, most often in open hole. An alternative testing method employed by a number of operators in Australia over the past 2 years has been the dual packer module of wireline formation testers. Although wireline packers provide a cost-effective and an efficient way of obtaining high-quality pressure transient data sets, they are limited to relatively small test intervals. A new, innovative approach enables testing coal seams of up to 15 m in thickness using wireline formation testers. The new wireline formation testing configuration offers several benefits over conventional drillstem tests (DST) for this application, including rig-time savings. Another benefit of the new technique is the broad range of drawdown and inflow rates, extending coverage from very low- to high-permeability coals. Additional applications used in the field include step-rate tests, the results of which have been applied to assess and rank different coal seams across a number of fields and coal types.
An Innovative Attribute for Enhancing Faults Lineaments and Sedimentary Features During 2G&R Interpretation
Authors: Massala Antoine , Keskes Noomane , Goncalves-Ferreira Liliana , Onu Cajetan , Cordier Philippe
Published: June 2014

Abstract

Exploration and Development teams are challenged to find and develop fields with increasing complexity. At different stages of seismic interpretation, the introduction and combination of seismic attributes are key to better understand structural and sedimentary features.

The geology derived from seismic attributes must be accurate and of high definition during the exploration, appraisal and production phases of the field. Uncertainties related to fault networks, geobodies mapping and their interfaces may have significant impact on prospect definition as well as on field development plans. In order to reduce these uncertainties, a new attribute Gradient-Coherency Cube (GCC™) has been implemented in Sismage®, a Total In-house software, with a new insight in seismic interpretation.

This attribute highlights both structural and sedimentary features through the seismic volume. The algorithm integrates a 3D (multi-azimuthal) gradient with a maximum correlation search (coherency) which allows detecting subtle lineaments that are not seen, or that are difficult to detect with conventional attribute maps. By enhancing subtle event detection, this new approach helps to:

- improve fault network and geobodies definition

- identify flow barriers encountered by DSTs

- identify relay zones

- reduce uncertainties on fault sealing capacity and communication between panels

- optimize field development plan, well design and geosteering.

Within Sismage®, Gradient coherency cube can be combined with conventional attributes to provide benefits to the overall 2G&R interpretation workflow. By facilitating seismic interpretation, this approach combines the efficiency of seismic attributes with respect to geology and reservoir engineering by delivering optimal well placement and optimizing the field development plan.
Theory and Application of Pressure and Rate Transient Analysis in Unconventional Reservoirs
Authors: Torcuk Mehmet A. , Kurtoglu Basak , Fakcharoenphol Perapon , Kazemi Hossein
Published: June 2014

Pressure and rate transient analyses are reliable methods to estimate effective formation permeability of unconventional reservoirs. The results of such analyses are used to validate or fine-tune the numerical simulation models both for the primary and enhanced oil and gas recovery methods.

Pressure-rate transient test applications in unconventional reservoirs are somewhat different from similar tests in conventional reservoirs because of the extremely tight nature of target formations and the use of horizontal wells as an integral part of well completion and reservoir stimulation. Accordingly, this paper presents theory, mathematical formulation, and application of the numerical and analytical well testing solutions to characterize unconventional reservoirs. The mathematical models pertain to the single-porosity and dual-porosity concepts. In the latter we focused on the issues surrounding the unsteady state (USS) and pseudo steady state (PSS) flow. The models studied in this paper were a 1-D analytical model and a hybrid 3-D numerical model that combines the USS and PSS dual-porosity formulations; a trilinear analytical model and a MINC (Multiple Interacting Continua) numerical model. The 3-D numerical model was compared with the trilinear analytical and MINC numerical models.

In unconventional reservoirs the dual-porosity environment emanates from the auxiliary effect of multi-stage hydraulic fracturing for which the unsteady-state mathematical solutions are more appropriate. The benefits of such solutions are supported by field results, which we will present and discuss. Furthermore, the results of pressure-transient and rate-transient analyses of two oil wells in an unconventional reservoir were presented.
Diagnosing Pressure-Dependent-Permeability in Long-Term Shale Gas Pressure and Production Transient Analysis
Authors: Vera Fabián , Ehlig-Economides Christine
Published: June 2014

The current state of shale gas reservoir dynamics demands understanding long-term production, and existing models that address important parameters like fracture half-length, permeability, and stimulated shale volume (SSV) assume constant permeability. However, observed steeply declining rates may involve pressure-dependent permeability (PDP).

This study accounts for PDP in two potential media: the shale formation and the created hydraulic fractures. Sensitivity studies comparing expected long-term rate and pressure production behavior show that PDP in the shale formation is distinct from PDP in created hydraulic fractures, and both are distinct from behavior without PDP. Successive buildups spaced apart in time reveal PDP behavior, but they do not necessarily indicate whether the permeability changes are in the shale formation or in the hydraulic fractures. The combined buildup and rate-normalized pressure data presentation displays both short-term and long-term transient trends that distinguish the source of the PDP behavior.

Pressure and rate field data demonstrate evidence of PDP in Horn River and Haynesville shale, but not in Fayetteville shale. Successive buildup transients in Horn River shale show evidence of permeability increase while in Haynesville shale they show significant permeability loss. In the Haynesville shale case, the impact of PDP is effectively reduced recovery from the stimulated shale volume defined by productive fracture half-lengths.
Identifying and Addressing Drilling Dysfunctions in Long Horizontal Wells
Authors: Lund H. , Martel K.
Published: June 2014

Horizontal Montney wells in the Albright field of Western Canada drilled by all operators are riddled with motor failures. In 2012, ConocoPhillips drilled two wells in the field that gave us significant insight into the drilling mechanics of slim hole horizontal wells. After 6 consecutive motor failures in the lateral of the first well in 2012, the decision was made to take steps to understand what was happening down hole. The paper will cover the findings as they relate to understanding and mitigating some of the common drilling dysfunctions in the field including vibration, buckling, and loss of WOB while rotating.

This paper will provide some tools and ideas to identify and mitigate some drilling dysfunctions that cause drilling inefficiencies in fields all around the world.

During the planning phase it was determined that the field had a history of drilling dysfunctions. Of these dysfunctions, buckling was identified and addressed in the planning phase. Vibration problems were confirmed while drilling, and steps were taken to mitigate the vibrations. Significant loss of WOB (over 20klbs) while rotating without buckling was observed, and steps were taken to compensate for this loss. Data will be presented to dispute the industry assumption that a well is axially "frictionless" while rotating; significant drag can in some cases exist in a well even while in rotary drilling mode. An alternate theory to relate axial friction to RPM will be presented.

Various drilling dysfunctions are often common in the field, and often viewed as acceptable since the industry is still able to drill the wells. Dealing with the downhole dysfunctions our industry face will likely improve our drilling performance. The current theory on axial friction of rotating drill pipe is proven incorrect, which means a new mathematical model is needed for the torque and drag computer models. A practical method for measuring and dealing with the drag while rotating without the need for expensive BHA components will be presented.
Downhole Steering Automation and New Survey Measurement Method Significantly Improves High-Dogleg Rotary Steerable System Performance
Authors: Sugiura Junichi , Bowler Adam , Hawkins Richard , Jones Steve , Hornblower Peter
Published: June 2014

The first commercial high-dogleg rotary-steerable systems (RSSs) were introduced in 2011. These systems were specially designed to drill vertical, kick off, build at planned 8° to 12°/100 ft (or even higher), and drill the lateral to lengths of up to 6,000 ft in unconventional reservoirs (such as shale gas applications) in North America. Because of the improved economics and other benefits for efficient drilling a high-build-rate curve and lateral in single run, high-dogleg RSS technology has rapidly gained acceptance for drilling shale wells.

The performance of the high-dogleg RSS is greatly enhanced with automated steering mode in vertical and lateral sections by reducing a human–machine interaction and minimizing wellbore tortuosity in these sections. Downhole trajectory-control algorithms make small, but frequent, adjustments to RSS steering parameters, comparing the near-bit continuous survey data against a planned well trajectory. Downhole steering automation is an integral part of the overall drilling system automation that the drilling industry is pushing forward.

A new static and continuous (dynamic) survey method has been used in the near-bit sensors of a specific high-dogleg-severity (DLS) RSS. The new survey method significantly improved the inclination and azimuth measurement in near-vertical angles; thus, it not only enhanced the automated vertical drilling feature but also provided more accurate kickoff from a near-vertical position using the RSS near-bit static and continuous survey. In addition, improved continuous measurements around magnetic north and south allowed the closed-loop trajectory-following algorithm of the RSS to drill lateral sections more precisely in these directions.

The software simulation and field trials were conducted to test a new survey measurement method implemented in a high-dogleg RSS, along with automatic trajectory-following algorithms. In one of the field trials, the RSS drilled more than 10,750 ft (vertical, high-dogleg curve, and lateral) in one run, including 5,000 ft of vertical and 4,500 ft of lateral sections in automated steering mode, saving 4 days (about 30%) compared with the previous non-high-dogleg RSS runs. A unique combination of the new technologies has enabled increased well construction efficiency in shale plays by providing a step change in steering technology, trajectory-following algorithms, and downhole survey method.
Record Success in a Frontline Pilot Deployment of Intelligent Well Completion with Multiple Technology Applications
Authors: Okpokpor Obaro Amos , Azoom Iorkam , Alabi Isaac Babatunde , Nnanna Erasmus John , Oguntimehin Adegbenro B. , Mbanefo Edith Ifeyinwa , Erumwunse Courage Osasuyi
Published: June 2014

Abstract

Shell Companies in Nigeria have engaged aggressively in searching for means of optimally draining the predominantly stacked reservoirs of the Niger Delta operating region. This quest, in 2002, led to the identification/adoption of intelligent well completion (IWC) technology as an acceptable means of connecting the multiple/stacked productive reservoirs to a single production well conduit (Single String Multiple - SSM).

This paper serves to describe how a dedicated deployment team analyzed various proven intelligent completions architectures and ultimately settled for the ‘direct hydraulic' system as the pilot trial IWC solution for SPDC's Well Victor-2, a 3-Zone intelligent well

The design comprises of interval/zonal isolation packers, Interval Control Valves (ICV), tubing and annulus Permanent Downhole Gauges (PDHG) for each zone and a low powered single well Surface Hydraulic System (SHS) with downhole data acquisition capability. The system is to be remotely monitored and operated by means of a field management supervisory application, named SmartWell Master™ (SWM), with some customization to accommodate the remote power and identified communication infrastructure constraint. The design offers easy operation and integration with the field control operational requirements and communication infrastructure.

In recognition of the regional security challenges, the SHS and associated communication components were designed to be protected by an external enclosure which should allow front access for maintenance purposes - this is in addition to the customized platform design. Within the same protective platform enclosure, a Thermoelectric Generation unit (TEG) is installed to provide the SHS with necessary electrical power.

A major configuration design challenge was that of ensuring efficient deployment of three hydraulic packers intandem noting that several deployment challenges had previously been recorded for single hydraulic packers' installations. Also, there were fears of inability to adequately confirm proper installation/sealing of a combination of external swell packers (integral with lower completion string) and internal hydraulic packers (integral with upper completion string).

This paper further outlines how cementation, dimensional accuracies, proper integration of lower and upper completions compatibility, assurance of proper platform design, surface equipment communication, definition and management of the interfaces between all vendors involved in the pilot deployment project, proper stakeholders engagement, among others were considered and treated as key success factors to the pilot installation.
Thermally Stable Explosive System for Ultra-High-Temperature Perforating
Authors: Barker James M.
Published: June 2014

As oil and gas companies continue to expand drilling and completion operations into increasingly demanding environments, perforating systems must be developed for these extreme conditions. Several upcoming oil and gas frontiers are being developed by operators that will have downhole temperatures exceeding 450°F (230°C); this means perforating operations at these temperatures will push, or even exceed, the limit of traditional explosive systems using HMX and HNS. The thermal deficiency of these explosives will be magnified further whenever the perforating guns are conveyed by tubing rather than wireline because the operational times will be significantly increased.

This paper describes a perforating system based on the thermally-stable explosive PYX, which overcomes the temperature/time limits of traditional explosives. Desirable characteristics of the bulk PYX explosive are discussed, along with design considerations for the major components that comprise the system: percussion detonator, detonating cord, detonation transfer elements, and shaped charges. The role of specialty booster explosives that complement PYX performance, such as NONA and BRX, is also discussed. The testing infrastructure and methodology undertaken to validate thermal performance at both the component and system levels are described, along with results of test programs that demonstrate successful performance to levels up to 480°F (250°C) for 100 hr.

Additionally, steps that promote operational success in the field, such as gun-preparation and loading techniques, are also presented.
Performance and Analysis of a Borehole Gravity Log in an Alaska North Slope Grind-and-Inject Well
Authors: Brady Jerry L. , Bill Michael L. , Nind Chris , Pfutzner Harold , Legendre Fabienne , Doshier Ronald R. , MacQueen Jeffrey D. , Beyer Larry A.
Published: June 2014

A new-generation borehole gravity meter (BHGM) and sonde have been developed and successfully operated under the rigors of a pressurized wireline logging operation in an Alaska North Slope solids injection well. The new BHGM addresses shortcomings of earlier technology, such as sonde diameter, maximum well deviation, depth correlation, reliability, and availability.

Borehole gravity logging provides a large depth-of-investigation alternative to the very shallow formation bulk density measurement obtained with conventional nuclear density logging tools, and the measurement accuracy is close to that of a nuclear density log. Therefore, it is a candidate for density measurements in wells with large near-borehole effects such as invasion, mudcake, rugosity, and completion hardware that are detrimental to nuclear density logs. A BHGM is also well suited for reservoir injection applications, such as the present case study, where changes in the pore fluid, and therefore bulk density, are expected at large distances from the borehole (many tens of feet) and long times (months or years).

We present the results of BHGM measurements made in a disposal well that has been receiving injected slurry of ground-up drilling cuttings and water for 12 years. Descriptions of the well injection history and BHGM log are presented along with performance data from the gravity and depth measurements. The BHGM density log showed agreement above the injection zone with a pre-injection openhole nuclear density log, but showed a large increase in density at the injection region.

Software for 3D gravity forward modelling, constrained by the known total mass of injected material and known porosity, provided a reasonable spatial model of the injected material in the formation consistent with the gravity measurements. This type of analysis, coupled with time-lapse BHGM measurements, can also be used in reservoir monitoring applications to visualize movement of waterflood fronts or gas expansion zones before they reach producing wells.
Radio Frequency Identification (RFID) Leads the Way in the Quest for Intervention Free Upper Completion Installation
Authors: Adan Iain
Published: June 2014

Traditional methods of running the upper completion system in a well typically include several interventions in order to complete the installation. Such activities require skilled resources and consume significant amounts of rig time. In addition, activities such as wireline, electric line and even coiled tubing intervention carry with them the possibility of operational problems leading to non-productive time (NPT). Elimination of such NPT and associated intervention costs has always been an industry goal, but while options exist for such operations as packer setting and tubing isolation, to date no approach has been available which can enable the operator to take full remote control of the installation.

As modern technology evolves so old technologies can be re-evaluated. One such technology is radio frequency identification (RFID) which offers the user flexibility in controlling downhole operations without intervention. RFID uses close proximity sensing to communicate by simply passing a coded tag through an antenna equipped downhole tool to actuate it. These tools also have a secondary means of communication by pressure pulse signature, or timer, if circulation of a coded tag is not feasible. Using this technology an upper completion system comprising packer, circulation sleeve and downhole barrier valve has been developed which is controlled by a single RFID module, thus providing a means to remotely control the installation, reducing running costs and the elimination of NPT.

In this paper the authors will review current upper completion operations and describe in detail the development and operation of an RFID enabled completion. A case study of the industry's first truly remote controlled upper completion, successfully installed in the Middle East will be presented.