bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Method for Determination of Reservoir Pressure
Authors: Kuchuk Fikri J. 
Published: December 2007

Abstract
This paper presents a simple and practical technique for determination of reservoir pressure from pressure buildup tests. The technique is based on the wellbore pressure solutions to an instantaneous source, including wellbore storage (afterflow) effects. The new technique is applicable to different flow regimes, such as cylindrically and spherically radial. The technique is sufficiently general that it may be applied to a wide variety of well/test configurations such as DST and wireline formation tester as well as vertical and horizontal wells.
The new technique is compared with the well-known Horner method. If the flow rate is well stabilized and the producing time is sufficiently long before the buildup test, the technique gives the same results as the Horner method. However, the new technique works better than the Horner method if the producing time is short, the flow rate is unstable and/or flow regimes are not fully developed.
Well tests in low-permeability (tight) or low-pressure reservoirs are well suited for this new technique because frequently they do not flow to the surface or sustain the flow rate long enough so that the conventional interpretation methods can be used. The technique can also be applied readily to wells in unconsolidated formations that produce sand, which usually plugs the wellbore during flow periods. For these cases, the technique will provide good estimates for permeability, skin, and reservoir pressure. A few buildup test examples are presented for the application of the technique.
High-Speed Downhole Memory Recorder and Software Used to Design and Confirm Perforating/Propellant Behavior and Formation Fracturing
Authors: Schatz J. F. , Haney B. L. , Ager S. A. 
Published: December 2007

Abstract
Propellants, now sometimes combined with perforating guns, have the potential to clean up damaged perfs, penetrate near-wellbore damage, and create formation fracturing. Although some of these dynamic techniques have been available for years, the lack of a standard measurement and analysis method has restricted their widespread use. Now, improved ultra high-speed downhole memory data recorders and computer software fully incorporating well, perforation, and tool details address this issue. Hardware and software are described. Several demonstration cases show the use of this technology in the field for vertical and deviated cased and open hole wells. Dynamic pressure data are compared with calculations and the realism of the results is shown, as well as how to make procedural and design improvements. The combination of the new recorder and software for the design and evaluation of dynamic well treatments allows the optimization of job design, and the evaluation of post-job results to understand tool performance and improve future tools and applications.
An Analysis Technique for Optimising Reliability in System Design
Authors: Hother John A 
Published: December 2007

Abstract
This paper describes an analysis technique, developed for improving systems reliability in the aerospace and defence industry, that can be used in the oil & gas industry for engineering projects demanding high reliability, such as subsea production systems and deepwater remotely operated vehicles (ROVs).
The method, called Reversionary Mode Analysis, is based on the same principles as the well-known Failure Modes Effects & Criticality Analysis (FMECA). It is used to determine the effects, on the operational performance of the system, of failures in the constituent parts and thence to optimise the system's resilience to failures. Its output is similar to that of FMECA in essence, but it does not depend on statistical data, and so can be used in circumstances where FMECA is not appropriate in its traditional form, such as when quantitative, statistical input data is not available.
Reversionary Mode Analysis has delivered important benefits in, for example, air defence systems - Highlighting areas of the system design that need priority attention to improve fault-tolerance;Confirming that design changes really do improve the fault-tolerance;Reassuring the customer that the proposed system will deliver the desired degree of fault-tolerance.
The paper explains how the technique was developed to meet customer demand for demonstrable fault tolerance in new systems at the design stage. The technique is then described in the form of six steps. The issues of who is best equipped to use the method, and when is the best time to apply it, are explored. Finally, the paper recommends how the technique can be applied to oil & gas projects, to deliver the benefits.
Field Investigation of the Effects of Stick-Slip, Lateral, and Whirl Vibrations on Roller Cone Bit Performance
Authors: Chen S. L. , Blackwood K. , Lamine E. 
Published: December 2007

Abstract
The effects of downhole vibrations on polycrystalline diamond compact (PDC) bit performance have been well discussed in recent years. However, most research on the downhole dynamics of roller cone bits has focused on axial vibration and its effects on bit performance. The questions which remain to be answered are: What kind of vibrations does a roller cone bit experience, and what are the effects of these vibrations on roller cone bit performance?
To investigate these questions, a series of field tests was conducted in a full scale drilling research rig, with downhole vibration data recorded by an advanced instrumented sub. Soft to medium hard formations were drilled using four 8½-in. roller cone bits (IADC Code 517. Three kinds of harmful vibrations were observed, and their effects on bit performance in terms of rate of penetration (ROP), insert breakage, and bearing/seal and bit life are discussed.
Rock Strength Measurements on Cuttings as Input Data for Optimizing Drill Bit Selection
Authors: Uboldi V. , Civolani L. , Zausa F. 
Published: December 2007

Abstract
Selecting the most appropriate bit for any hole section is a key-feature in achieving superior drilling performance. The aim, to maximize hours on bottom and rate of penetration without jeopardizing safety and bit integrity, in order to improve and optimize performance. These factors have an enormous influence on the drilling and ultimately well economics.
The most important factor to correctly select, or even design "ex novo", a bit, is to understand how the bit cutting structure effects the rocks to be drilled. These interactions depend on formation physical characteristics, mainly rock structure and nature, compressive strength, abrasiveness, wettability, under-overbalance etc. The conventional approach in bit selection is to derive actual expected performances on reference data such as previous runs or information from offset bit records. In this way, the achievement of improved performances and optimization may require a long time and much expense.
Analyzing the formation characteristics while drilling directly on cuttings, we may obtain substantial information that lead to define the most suitable cutting structure for any specific hole section, leading to identification of the most suitable bit and saving valuable time and money.
In order to reach this goal, a methodology has been developed, based on micro indentation tests on cuttings, to mechanically characterize formations. The compressive strength index values obtained by micro-indentation are then used by a Drill Bit Optimization System to aid Operators with the bit selection decision.
This system uses lithological data and compressive strength values as input and provides bit class indication, together with bit hydraulic configurations and gage protection as output.
After an introduction devoted to illustrate the indentation tests, focus will be given to the actual results of field tests. We will detail the methodology and the verification process as performed during the field tests, carried out in a very demanding environment in central-southern Italy, and will point out how it can be easily implemented at the rig site, practically at no extra cost.
Furthermore, discussion will cover how the planning of new drilling activities may benefit from the results derived by the Drill Bit Optimization System, supplied with data from the micro indentation test eventually validated by E-logs, in order to maximize penetration rate and drilling efficiency.
Dielectric-Independent 2-MHz Propagation Resistivities
Authors: Wu Peter T. , Lovell John R. , Clark Brian , Bonner Stephen D. , Tabanou Jacques R. 
Published: December 2007

Abstract
All commercial 2-MHz and 400-kHz propagation resistivity logging-while-drilling (LWD) tools use an assumed value or relationship for dielectric permittivity to derive independent resistivities from phase shift and attenuation measurements. This methodology has been used for over ten years. For resistivities below 100 Ω-m, the phase shift resistivity is not strongly affected by the assumed value of dielectric constant. In contrast, the attenuation resistivity is sensitive to the assumed dielectric constant above 10 Ω-m, and extremely sensitive above 50 Ω-m. A new empirical relationship between relative dielectric constant and resistivity is proposed to improve the phase shift and attenuation resistivities above 100 Ω-m. However, in high resistivity formations, and in unusual lithologies with exceptionally large dielectric permittivities, it is better to invert the measured phase shifts and attenuations together to obtain an apparent resistivity that is independent of the dielectric constant. This "dielectric-independent" resistivity will be free of possible errors caused by assuming a wrong value for dielectric permittivity. Even though phase shift and attenuation resistivities exhibit different vertical and radial response characteristics, simulations show that bed boundaries and moderate invasion do not adversely affect the computation of the dielectric-independent resistivity. In oil based mud, it is possible to read resistivities above 1000 Ω-m. This provides the ability to differentiate among high resistivity formations, but not necessarily the ability to measure a quantitative value. Three field examples illustrate the strengths and limitations of the dielectric-independent resistivity.
How to Measure Exploration-Production Efficiency
Authors: Komlosi Zs. 
Published: December 2007

Abstract
A complete proper economic analysis of a known property yields different investment indices. The bests of them must satisfy the 3H rule, i.e., they must answer all three questions: How much return may be expected? How much capital is required? How long does the E&P process last? Several yardsticks had been analyzed. There was established that Growth Rate of Return ("GRR") and Internal Rate of Return ("IRR") are the only yardsticks fulfilling the 3H rule completely. Comparison of the investment rank of properties is suggested by GRR. Application of Monte Carlo simulation allows estimating, besides the most probable value, the quantity of risk taken with property.
In case of an unknown property (i.e., exploration) the stochastic evaluation using Monte Carlo simulation gives the most sophisticated solution calculating probability distribution of any yardsticks. During the evaluation, probability distributions of the unrisked input parameters (such as e.g., reserve, production forecast, future expenses and prices) of cash flow model of complete E&P process are to be estimated. When limited information or time available input parameter-values for a few outcomes (e.g., high, low and most probable) and relevant probabilities are required. Then, Monte Carlo simulation of cash flow model with input parameters yields probability distribution of results (e.g., net present value and expected return/risk). Ranking or comparison properties done by expected values, first.
The economic value and the risk associated with a company's exploration portfolio can be calculated with Monte Carlo simulation from probability distributions of the net present values that derived from each property to be explored. The expected value of the portfolio can be compared to the property's values of "normal" risk, such as reserve acquisition and production. Judging a new exploration venture requires analysis of how the new property it affects on the value and the risk of company's exploration portfolio.
Overcoming Slugging Problems in a Long-Distance Multiphase Crude Pipeline
Authors: Al-Kandari Ali Hussain , Koleshwar Vilas S. 
Published: December 2007

Abstract
The paper discusses the wide range of issues arising out of the slugging problems experienced in a 36 km. long, 36" multiphase pipeline gathering well fluids from several ESP fitted oil wells of a distant oil field in Kuwait and processing it in a gathering center. Over a time frame of 3 to 4 years, the slug characteristics of this line showed substantial increase on account of gradual increase in flow, GOR and water cuts of the flowing well fluids.
The higher liquid content slugs at the current production level began to give severe operational difficulties in the separators at the gathering center. These slugs further resulted into HSE related issues like severe pipeline vibrations, weakening of pipe supports, corrosion and excessive smoke flaring.
The paper will discuss some of the quick fix actions taken to eliminate the above mentioned slugging problems and bring back the operations to normal. Such quick fix actions were taken without shutting down the facility and without any major modifications. As is sometimes the case, operational compulsions demand the ability to utilize what is available to ensure that production losses are minimized.
The paper also provides the back-up calculations to show how the flow regime changed to undesired condition over a period and how the same was favorably changed to a more manageable flow regime.
Based on the lessons learnt from the above-mentioned case, the paper identifies and recommends variety of techniques to enable operations to maximize efficiency of their multiphase flowlines.
Experimental Study of Low Liquid Loading Gas-Liquid Flow in Near-Horizontal Pipes
Authors: Meng Weihong , Chen Xuanzheng T. , Kouba Gene E. , Sarica Cem , Brill James P. 
Published: December 2007

Abstract
Low liquid loading flow in wet gas pipelines is a common occurrence in the transport of unprocessed raw gas. The most important parameters governing the flow behavior are pipe geometry (inclination angle and diameter), operating conditions (flow rate, pressure, and temperature), and physical properties of the gas and liquid (density, viscosity, and surface tension). In this study, extensive experiments were conducted using a test loop made of 50.1-mm diameter acrylic pipe with inclination angles from the horizontal of -2°, −1°, 0°, 1°, and 2°. Gas and liquid superficial velocities ranged from 5 to 25 m/s and from 0.001 to 0.053 m/s, respectively. In-situ liquid loading ranged from 150 to 1800 m3/MMm3. Flow patterns studied were stratified (smooth and wavy) and annular. Measured parameters included gas and liquid volumetric flow rates, liquid film flow rate, pressure drop, temperature, liquid holdup and droplet deposition rate.
The experimental results show that, at low liquid loading, there is a broad transition range from stratified wavy flow to intermittent flow. Entrainment can occur in the gas core at relatively low gas velocities, and droplet deposition occurs simultaneously with entrainment. An increase in gas velocity did not increase liquid entrainment fraction over a relatively broad range of gas velocities. However, an increase in liquid flow rate did increase the liquid entrainment fraction. Surprisingly, in the annular flow region, a new phenomenon was observed at certain superficial gas velocities: an increase in liquid flow rate decreased the liquid film flow rate and liquid holdup, and increased the entrainment flow rate. This phenomenon may have significant impact on operations to sweep liquids from wet gas pipelines. Seven correlations of liquid entrainment onset point and entrainment fraction in the gas core are evaluated and modified to better fit the data. A new interfacial friction factor closure relationship is proposed. Based on this new information, a procedure is proposed for calculating low liquid loading in wet gas pipelines. The data obtained, the interfacial correlation developed and the proposed procedure to estimate liquid loading can be used in designing wet gas pipelines, determining pigging frequency, and predicting hydrate formation in deep water wet gas pipelines.
A Review of Field Performance of New Propellant/Perforating Technologies
Authors: Gilliat Jim , Snider Phillip M. , Haney Robert 
Published: December 2007

Abstract
The use of propellants as a production enhancement tool is not new in the petroleum industry. However, the concept of combining the propellant into a sleeve form with the perforating gun is unique. This technology has recently been introduced to the oilfield and shows promise of solving many of the inherent preforating problems for which solutions have been needed.
This paper will review the development of the combined propellant and perforating technique and will use case histories that focus upon tubing-conveyed applications to document the positive effects gained by combining these technologies. The case histories will present some of the operational successes as well as some of the failures experienced to date.
The propellent/perforating technique has been applied in both extreme over- as well as underbalanced well conditions in approximately 1,000 wells. It has proven that it can offer a cost-effective, safe method when used as a near wellbore clean up tool and for prefrac preparation. Additionally, its usage can eliminate other service needs that often occur subsequent to perforating. These facts will be evidenced by the case history experiences disclosed in this paper.
Foam for Gas Mobility Control in the Snorre Field: The FAWAG Project
Authors: Blaker T. , Celius H. K. , Lie T. , Martinsen H. A. , Rasmussen L. , Vassenden F. 
Published: December 2007

Abstract
The FAWAG Project (Foam Assisted WAG) is a full-scale demonstration by Saga Petroleum of the use of foam for gas mobility control. The injection of foam started in the Central Fault Block at the Snorre Field in August 1998, after a two-year planning period and many years of active research. The first phase of the project, Surfactant-Alternating-Gas (SAG) injection was completed late 1998, and the co-injection phase is expected to be completed by Summer 1999. Approximately 2000 tons of commercial grade surfactant will be injected in the project. The project is partly sponsored by the European Commission's Thermie program.
The paper presents the basic concept behind the method, the selection of chemicals, the logistics for handling of the chemicals and the technical modifications needed on the offshore facility to perform the injection. Preliminary results, particularly the response from the injector, is presented for the first phase of the project.
Environmental Impact Assessment for the Salalah Gas Pipeline
Authors: Simons David J. , Adams Marcus B. 
Published: December 2007

Abstract
The planned route of the proposed Salalah Gas Pipeline will traverse 700 kilometres of desert and ecologically sensitive mountainous terrain from the centre of the Sultanate of Oman to the southern coast at Salalah. Petroleum Development Oman LLC (PDO) has commissioned extensive environmental studies during the definition phase of the pipeline design resulting in an Environmental Impact Assessment (EIA), and in the production of Environmental Management and Construction Specifications. Detailed analysis of the environmental baseline, together with in-depth sociological studies and a commercial crop inventory, have allowed a highly project-specific EIA to develop. Extensive and innovative mitigation measures have been identified to alleviate the impact of routing the pipeline through the unique and internationally recognised ecosystem of Jebel Qara and through the sociologically sensitive Salalah Plain. PDO's internal environmental engineering guidelines have been updated to reflect a growing awareness of the advantages of such prescient environmental studies. This paper describes the joint Company and Consultant approach to the studies, the findings, and the recommendations for impact mitigation in a unique and fragile environment.
The Answer to Increasing Environmental Compliance Costs: Regulatory Reform or Technological Advance?
Authors: Godec Michael L. , Petrusak Robin L. 
Published: December 2007

Abstract
Environmental compliance requirements on the U.S. E&P (E&P) industry continue to rapidly evolve and become more stringent. Controlling the costs of environmental compliance, without sacrificing industry's and governments' commitment to environmental quality, will continue to be a priority, especially in a world of sustained low prices.
This paper examines a number of potential legislative and regulatory initiatives that could affect environmental requirements on the U.S. oil and gas E&P industry. The paper provides a quantitative assessment of these initiatives on oil and gas supplies, government revenues, and industry activity (e.g. drilling, E&P expenditures, etc.). The paper also examines some of the major emerging technological developments that could reduce the E&P industry's future expenditures for environmental compliance. These technological developments include the use of synthetic drilling fluids in offshore operations, evolving technology for downhole separation of produced water and oil, and improved technology and industry practices to reduce emissions of toxic air pollutants and potential greenhouse gases. The paper will compare and contrast the potential benefits associated with the two alternative approaches to reducing compliance costs – regulatory relief and technological advance – and provides some thoughts on the relative benefits and potential liabilities associated with each approach.
This study concludes that for the period 2000 to 2010, a stringent regulatory compliance scenario could result in $11.7 billion more expenditures by industry for environmental compliance, relative to a less stringent, risk-based regulation scenario. Potential compliance requirements related to drilling and drilling waste management are estimated to account for about one third of the potential environmental compliance expenditures, and potential requirements related to stringent regulation of hydraulic fracturing are estimated to account for almost half the potential compliance expenditures. In contrast, aggressive development and implementation of environmental compliance technology results in approximately $1.8 billion in savings in overall industry expenditures for environmental compliance during the same period. An estimated 90 percent of this potential savings is associated with downhole water separation. In the regulatory case comparison, where the risk-based case is considered the baseline, the more stringent regulatory scenario results in a 38 million barrels per year drop in oil production by 2010. Similarly, the more stringent regulatory scenario results in a 90 Bcf per year drop in gas production by 2010. In the technology case comparison, where the risk-based regulation case is considered the baseline, the aggressive environmental technology case results in a 37 million barrels per year increase in oil production by 2010. Similarly, the environmental technology scenario results in a 40 Bcf per year increase in gas production by 2010.