bluuebunny/crossref_metadata_2025_split huggingface dataset:
Influence of Permeability Anisotropy and Reservoir Heterogeneity on Optimization of Infill Drilling in Naturally Fractured Tight-Gas Mesaverde Sandstone Reservoirs, San Juan Basin
Authors: Al-Hadrami H. K. , Teufel L. W. 
Published: December 2007

Abstract
Production of Mesaverde tight-gas reservoirs is highly dependent on natural fractures. Fractures not only enhance the overall permeability, they also create significant permeability anisotropy that causes the drainage area of the wells to be elliptical. Elongated drainage areas creates production interference and drainage overlap between adjacent wells that are aligned in the maximum horizontal permeability direction, and increases the potential for leaving large sections of the reservoirs undrained. In addition, the Mesaverde sandstone reservoirs are locally heterogeneous, because of their fluvial depositional environment. Reservoir characterization and simulation models have been conducted in two pilot areas to predict reservoir quality, permeability anisotropy, well productivity for infill wells drilled on 80 acre spacing. Simulation results are compared to well performance of these infill wells and demonstrate the value of reservoir simulation in determining effective drainage areas, optimum location, and additional recovery of infill wells.
Predicting Natural Fracture Distribution in Reservoirs From 3D Seismic Estimates of Structural Curvature
Authors: Belfield William C. 
Published: December 2007

Abstract
Natural fracturing is a manifestation of brittle strain imparted to the rock mechanical units during deformation. It seems logical that attempts to predict distribution of fractures in reservoirs should then use strain-based measures as a guide. One way of estimating relative strain is with structural curvature. The approach taken here is to examine curvature as a function of scale. The reason for the scaling approach is to examine folds of different wavelengths for fracture potential. With this technique, principal curvature magnitude and direction can be determined at any point on the seismic grid and at any scale. From the principal curvatures an estimate of preferred fracture orientation can be made. Comparison of preferred orientation estimates made by this technique with borehole measurements of preferred orientation using imaging tools show very good correlation. The correlation holds even when fracture orientations are oblique to the maximum in-situ stress. When relative strain measures derived from the principal curvatures are compared to well-productivity indices, a positive correlation is found. This suggests that the technique is able to both identify areas of increased fracture potential and determine preferred orientation prior to drilling.
Case History: Observations From Diagnostic Injection Tests in Multiple Pay Sands of the Mamm Creek Field, Piceance Basin, Colorado
Authors: Craig David P. , Odegard Chad E. , Pearson Walter C. , Schroeder James E. 
Published: December 2007

Abstract
The objective of diagnostic fracture injection tests is to optimize multi-sand completions by estimating pore pressure and permeability in each lenticular sand. Since December 1998, over 200 diagnostic fracture injection tests have been pumped into isolated Piceance Basin Mesaverde sands in an effort to optimize well completions. The diagnostic injection tests were implemented to qualitatively identify the presence of fractures/fissures, to provide estimates of pore pressure and permeability, and to optimize the perforation scheme for effective limited entry fracture treatment diversion. This paper describes the diagnostic fracture injection test methodology, summarizes the results, and provides illustrative examples of typical Mesaverde sandstone pressure falloff response.
The results from 201 diagnostic fracture injection tests show extreme differences in reservoir quality between sands with very similar openhole log signatures.
While approximately half of the injection tests indicate open fractures/fissures through pressure-dependent leakoff, it is quite common to observe relatively high-permeability (kg &gt; 0.050-md) without indications of open fractures/fissures. Permeability estimates between pay sands separated by less than 50-ft have been observed from kg &lt; 0.001-md to kg &gt; 0.100-md. Several examples of sands damaged by drilling mud invasion (fracturing) have also been verified with the diagnostic injection test analysis, which can differentiate between reservoir fluid permeability and fracture face damage. Since the differences in reservoir quality are identified with a pre-frac diagnostic injection test, the final perforation scheme can also be adjusted to ensure a limited entry fracture treatment will divert to the "best" reservoir rock.
Although the results presented are specific to the Piceance Basin, the methodology and analytical techniques are valid in all basins.
In-Situ Determination of Residual Gas Saturation by Injection and Production of Brine
Authors: Bragg J.R. , Shallenberger L.K. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
A new in-situ procedure has been developed for measuring the residual gas saturation in watered-out zones of gas reservoirs. Gas-free formation brine is injected into a well penetrating the water-invaded zone to dissolve the penetrating the water-invaded zone to dissolve the residual gas from a region around the wellbore. The brine is then produced from the well. The volume of brine containing no dissolved gas is then determined by sampling the brine and analyzing for gas content. The original residual gas saturation can be calculated from these data.
The procedure has been confirmed by computer simulation and by laboratory tests on a long glass-bead pack. Two full-scale field tests have also been conducted; the interpretation of one of these tests is discussed in detail.

Introduction
Water invasion is a significant drive mechanism in many natural gas reservoirs. The residual gas saturation left behind the water front is an important parameter required for accurate prediction of recoverable reserves, frontal advance velocity, and optimal production scheduling.
The traditional method for determining residual gas saturation is laboratory waterflooding of core plugs. With that method there is usually some uncertainty as to whether the core samples used are truly representative of the entire reservoir zone, or whether the displacement process is representative of that within the reservoir. Pressure coring has been used successfully to measure residual gas saturations, but it is a very expensive procedure which requires that a new well be drilled in an already-depleted portion of the reservoir. In theory, neutron logging methods could be used in existing water-invaded wells to measure the residual saturation. However, cased-hole logging tools sample a relatively small volume of reservoir, and local wellbore effects might produce results that are not typical of general produce results that are not typical of general reservoir conditions.
In the new method described here, a relatively large volume of reservoir around a well is observed. Brine containing no gas is injected into the well, dissolving the residual gas within a circular zone around the wellbore. Brine is then produced from the well, and the concentration of dissolved gas in the brine is measured during production. The original residual gas saturation in the zone can be calculated from the amount of brine produced before dissolved gas appears.
This paper describes the theory of the method, results from laboratory and field tests, and results from test simulations using mathematical models. The test accuracy and range of applicability determined from field experience are reported.
Field Results Verify Afterflow Analysis From D.S.T. and Short Time Production Test
Authors: Milner E.E. , Warren D.A. , Claiborne P.M. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
The actual production performance of a number of wells have been compared to predictions made by the McKinley afterflow analysis of drill stem test and short time production test data on these wells.
Many formations are tested for short time periods that do not give sufficient or periods that do not give sufficient or conclusive data for reservoir analysis by conventional methods thereby necessitating use of an afterflow method.
The example wells in this study show low permeability, wellbore damage, two zones permeability, wellbore damage, two zones with a large contrast in permeability, artificial stimulation and naturally occurring fracture systems with a tight matrix.
Example plotted curve shapes of the above conditions are illustrated along with a discussion of how to recognize and use each. Limitations as well as the applications of the McKinley afterflow method are discussed.
The most important use of the McKinley After-flow Method is the ability to predict the tight matrix production rate of a well after a stimulated wellbore area has been depleted. Comparison of drill stem test analysis before completion with production test analysis after completion on the same well give comparable answers.
Data on a group of wells selected from South Texas, the Permian Basin and Rocky Mountain areas have been furnished by the industry and the results are shown in Table 3. Illustrations of D.S.T. charts, Horner plots, McKinley plots and production decline curves are shown plots and production decline curves are shown for most examples.
The conclusions reached from this study show the McKinley afterflow method gives reliable predictions of reservoir performance when predictions of reservoir performance when conventional analysis methods cannot be used.
Seafloor Wells and TFL A Review of Nine Operating Years
Authors: Keprta Donald F. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Atlantic Richfield has completed eight sea-floor wells in the Eugene Island Block 175 Field, offshore Louisiana. Initial installation was in 1966. These wells are remotely operated and serviced from a central platform through flowlines of lengths up to 6,175 feet. Operation of the wellheads and a variety of through-flowline (TFL) procedures have been performed repeatedly since installation. performed repeatedly since installation. Although equipment failures have occurred, control of the wells has always been maintained.
This paper describes the surface, seafloor and downhole equipment installed, TFL operations and significant problems encountered.

Introduction
The Eugene Island Block 175 Field is 70 miles southwest of Morgan City, Louisiana. Water depth is 85 feet. It is a piercement salt dome, multi-reservoir field, with productive intervals between 7,000 and 12,000 feet. Original oil production was established in 1957 with wells drilled from a platform ("A") located on the southern portion of the block. Another platform ("B") was set in the center of the block in 1958. Platform "A" was destroyed during Hurricane "Hilda" in October, 1964. Consequently all wells from that platform were reentered and plugged. This loss platform were reentered and plugged. This loss resulted in the decision to utilize seafloor completions to minimize the chance of losing wells to hurricanes and to expedite reestablishment of oil production.
Two wells were initially drilled and made seafloor completions to exploit the reserves from the Platform "A" area. The wells were connected by flowlines to the "B" platform. Production from these wells was initiated in Production from these wells was initiated in September, 1966. Exploratory drilling in the northeast quarter of the block resulted in discovery of a major field extension. Again, early exploitation was afforded by drilling and completion with a mobile rig and flowline tie-ins to "B" platform. Five seafloor wells were completed on the east flank under that program. The final seafloor well was program. The final seafloor well was completed in the "A" platform area in August, 1969.
Subsequent to the completion of the eight seafloor wells, an 18-slot platform was installed and field development was completed by drilling directional wells. Economic comparison of seafloor wells to platform wells is not attempted in this appraisal.
An Overview of the Global Health, Safety, and Environmental Program for Advanced Well-Construction Systems
Authors: Coats E. Alan , Preston David , Figenschou Anne Nilsen 
Published: December 2007

AbstractThis case-history paper presents details for a health, safety, and environmental (HSE) program, jointly developed by a service company and an oil company as part of an advanced, software-controlled, composite coiled-tubing, offshore drilling system. This drilling system can enable oil companies to economically harvest known hydrocarbon zones that were previously bypassed and to find and exploit new reserves.From the feasibility study forward, the latest HSE standards were incorporated into all phases of the project. The resultant Global HSE Program allowed access to the knowledge and experience of professionals from all parts of both organizations. This paper provides a detailed description of the national, cultural, engineering, and logistical challenges overcome during the development of the HSE Program.The paper also illustrates how teams from design, manufacturing, operations, maintenance, technical safety, HSE, quality verification, and management were unified for delivering a safe product. Included is an overview of the specific requirements necessary to fully define the unit for deployment in the Norwegian sector.
Repair of Buried Submarine Pipelines in the Long Beach Unit
Authors: Ellison W.F. , Robuck R.D. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
This report covers the planning, acquisition of equipment and materials, and organizational staffing employed by THUMS Long Beach Co. to accomplish in-place repairs of buried submarine pipelines.
This paper includes a description of (1) methods and procedures developed to satisfy demands of the work environment, and (2) those actions taken for the protection and preservation of the marine environment. preservation of the marine environment

Introduction
THUMS Long Beach Co., acting in the capacity of agent for the field contractor, Texaco, Humble (now Exxon), union, Mobil, and Shell, furnishes the operating services for the City of Long Beach, unit operator for the Long Beach Unit, in the East Wilmington field. The 400,000 bbl (approximate) of gross fluids produced offshore each day are collected through produced offshore each day are collected through a submarine pipeline system linking the four man-made islands, in the San Pedro Bay less than 1 mile offshore from the City of Long Beach, Calif., with onshore treating facilities. The buried pipeline system consists of 30 miles of 6-, 8-, 12-, and 14-in. pipe buried 7 to 15 ft beneath the bottom of the bay in 30 to 40 ft of water. All lines are externally somastic coated for corrosion protection. The larger lines are weighted with 1 1/2 to 2 in. of reinforced concrete coating. Installation of the pipelines was made by the lay-barge method in 1966 and 1967. Each joint was metallurgically inspected, 100 percent of the welds were x-ray inspected, and the lines were hydrostatically tested after placement.
The entire pipeline network is externally protected with an impressed current cathodic protected with an impressed current cathodic system. Additionally, pipeline scraper facilities were installed to facilitate weekly scraping of the lines.
From the beginning, field operations were developed with great concern for protection of the environment and, in particular, prevention of an oil spill immediately offshore and adjacent to one of the nation's most attractive recreational beach areas.
As soon as equipment became available and techniques were perfected to make internal pipe evaluations of the integrity of the pipelines, surveys were initiated and have been run at intervals of approximately 6 months.
The Effect of Poisson's Ratio on Rock Properties
Authors: Kumar J. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
This paper presents various relationships between Poisson's ratio and other rock properties such as overburden pressure, bulk properties such as overburden pressure, bulk compressibility, Young's modulus, modulus of rigidity, compressive and tensile strength, porosity, density, wave velocities, modulus of porosity, density, wave velocities, modulus of resilience, modulus of rupture, fractures, drillability, and hardness. Thus, it points out the importance of Poisson's ratio in the understanding of some of the questions in rock mechanics.

Introduction
Though the change in Poisson's ratio for various types of rocks is small in general, sometimes this change can be significant. Assumption of a constant value of Poisson's ratio in some cases may result in serious errors. Unfortunately, the importance of Poisson's ratio in the understanding of other rock properties is not fully realized and very little work, both theoretical and practical, has been done on this subject. This paper presents various relationships between Poisson's ratio and other rock properties such as overburden pressure, bulk properties such as overburden pressure, bulk compressibility, Young's modulus, modulus of rigidity, compressive and tensile strength, porosity, density, wave velocities, modulus of porosity, density, wave velocities, modulus of resilience, modulus of rupture, fractures, drillability, and hardness. Thus, it points out the importance of Poisson's ratio in the understanding of some of the questions in rock mechanics.
POISSON'S RATIO POISSON'S RATIOWhen a force is applied to a body, at right angles to the force, a certain amount of lateral (transverse) expansion or contraction takes place. This phenomenon is shown in Fig. 1. In place. This phenomenon is shown in Fig. 1. In other words, it can be said that, if a solid body is subjected to an axial tension, it contracts laterally; on the other hand, if it is compressed, the material expands sidewise.
So the definition of Poisson's ratio can be stated as the ratio of transverse strain to axial strain induced by unconfined axial deformation. Poisson's ratio can be expressed as(1)
where the strains are caused by uniaxial strain only.
Generally, values of Poisson's ratio vary between 0.25 and 0.35.
Why HSE MS/Cases for External Environmental Certification in an Operating Company
Authors: Amadi Amadi , Sunmonu Mutiu , Benebo Tari 
Published: December 2007

Abstract
The SPDC Alakiri experience has demonstrated that the preferred route to external environmental certification is the implementation of an HSE management system aligned to ISO 14001 standard.
This approach is consistent with Shell HSE MS requirements and guarantees staff and contractor buy-in, promotes ownership and accountability and yields result faster. There is the added merit of very little additional cost required to align the HSE MS elements with ISO 14001 elements, mainly from consultancy and verification/certification fees.
Also, adopting an integrated (HSE MS) approach to risk management enables the component risks in the business to be weighed from the perspectives of their Health, Safety and Environmental impact, and how any failure in the ineffective administration of one would interrelate and/or impact on another.
However, in using HSE MS as a vehicle for external environmental certification in an operating company, it is essential to distinguish between HSE MS ‘Risk’ as described using the Risk Assessment Matrix (RAM) and ‘significant environmental aspect’ as used under the ISO 14001 regime. More parameters are considered in determining environmental significance. Once an ‘E’ aspect is adjudged as significant, the onus is on the asset custodian to show that there are operational controls in place to mitigate against the release of the hazard(s) as well as ensure the reduction of residual risks/impact to as low as reasonably practicable (ALARP).
Other benefits of an HSE MS approach include (i) HSE competence development for staff and contractor personnel HSE competencies all at once, sufficient to address gaps in technical operations and contractor activities. (ii) Focus on operational control to manage inherent risk. (iii) Significant cost savings from material and energy consumption. (iv) Reduction in HSE incidents, not just environmental incidents and (v) Co-operative and harmonious relationship with stakeholders, especially host communities. A positive relationship with host communities results in less production deferment and better public image. Overall, our experience with the pilot project has demonstrated that with management commitment and motivation to change attitude, external environmental certification is achievable in a complex operating company.
Developments in the understanding of working on extended nights offshore
Authors: Miles Robert W 
Published: December 2007

Abstract
This paper explains the UK HSE regulatory position with regard to shiftwork and the need for shiftwork to become part of the risk management process. Advances in research understanding are reviewed and the growing evidence for the adjustment of offshore workers to continuous night shifts is discussed. Data is presented to demonstrate the significant effects of shiftwork and fatigue on accident rate. The problem of preferred vs. safest shift patterns is discussed and suggestions made as to how this problem may be addressed.
Systematic Assessment of Human Error Potential in Operations
Authors: Thomas Jeffrey J. , Noerager Jere A. , Danz-Reece Mary E. , Pennycook Wayne A. 
Published: December 2007

Abstract
HFAST (Human Factors Analysis Software Tool) is a self-help software tool used by operating sites to identify the potential for human error in the design, operation, and maintenance of site systems. Reduced error potential results in fewer errors in daily operations, leading to improved safety and more efficient operations. Through a process of consensus, the team rates diagnostic statements about the conditions at their site in as many as 14 general categories for improvement (e.g., field workplace design, procedures, training, communication structure). Based on these responses, the program produces a report that provides guiding principles for improving the design of systems and work processes to reduce the potential for human error. This paper describes the genesis and development of the tool, how the tool would be used by an operating site, and provides examples of site benefits from applying the tool.