bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Case Study on Redevelopment of a Giant Highly Fractured Carbonate Reservoir in Iran Based on Integrated Reservoir Characterization and 3D Modeling Studies
Authors: de Galard J. -H. , Zoormand G. H. , Ghanizadeh M. , Daltaban S. , Camus D. 
Published: December 2007

Abstract
This field is located within the Zagros fold belt in the South West Iran and is producing in highly fractured carbonate Asmari and Bangestan reservoirs.
It's a 70 km long anticline with about 50 billions barrels of initial oil in place and a small initial gas cap; initial oil column is 2000 m of 32 API crude with properties varying with depth. The field was discovered in 1937 and produced by natural depletion until 1977 when gas injection was initiated in the gas cap.
A total of 320 wells were drilled on the structure.
A full field reservoir study was conducted to propose a new Master Development Plan to maximize hydrocarbon recovery.
This paper presents:
The reservoir characterization mainly based on rock typing and its extension to uncored wells, on fracture characterization and modeling study and on the construction of a full field geostatistical fine grid model.
The reservoir simulations including phenomenological studies on sector models to determine the proper PVT model to use in the full field model and to quantify impact of fracture properties, matrix bloc sizes, diffusion, block to block interaction on reservoir performance and a full field simulation model with dual porosity media and improved black oil options.
Combination of drive mechanisms acting in this field such as gas gravity drainage, diffusion and convection were represented.
Various redevelopment options studied indicate that the overall oil recovery can be improved by gas injection pattern improvement and selected infill drilling with proper completion strategy.
Eliminating Multiple Interventions Using a Single Rig-Up Coiled-Tubing Solution
Authors: Kumar P. S. , Gisbergen S. V. , Harris J. , Ferdiansyah E. , Brady M. , Harthy S. A. , Pandey A. 
Published: December 2007

AbstractThis paper describes new methods to economically improve production levels in one of the mature fields of Petroleum Development Oman. This field had been developed by infill drilling programs, which were suspended in early 2001 to review the development strategy. A reservoir management team set a challenge to effectively conduct logging operations and quickly utilize the data collected to identify and avail of optimization opportunities, thus maximizing the production of the wells whilst lowering overall costs. The optimization activity consisted of clean-out, saturation logging, perforation and stimulation. These activities were carried out either with coiled tubing only utilizing conventional practises and e-line coiled tubing, or with the combination of coiled tubing and hoist through multiple well entries. Both of these methods were successfull in that they resulted in incremental net oil production but at relatively high costs.This paper presents a methodology which enables clean-out, logging, stimulation and perforation with one coiled tubing intervention, which includes a plastic coated "e-line" coiled tubing, coiled tubing perforating head and new perforation technology. All systems are in complete compliance with the most stringent safety criteria. The new method has a considerable time and cost savings impact, and this is fully illustrated in this paper with field trial case histories, in which a multi-disciplinary team effectively targeted the most suitable zones for perforation and stimulation using a state of the art self diverting, non damaging, acid system. Technical and economic comparisons are made with conventional practices. The methodology is currently being employed in this field and is potentially applicable to other fields.
Musallim Rim Near Field Exploration: New Concept Yields Big Value in an Old Field
Authors: Lawati M. A. , Harthy M. A. , Shuster M. , Willet A. 
Published: December 2007

Abstract
An exploratory appraisal campaign of the greater Musallim Oil Field area was executed in 2003. The main objective was to test the Shuaiba pancake reservoir and to confirm the presence of reservoir on the flanks, prove calibration of the porosity trends derived from acoustic impedance data, provide structural control and determine oil saturations below crestal oil-down-to (ODT) of 1443 mtvdss.
The appraisal campaign was designed to test the ODT pancake model concept in Musallim. The pancake concept is a model where 2-12m thick good reservoir zone overlies poor quality reservoir. Based mainly on oil saturations logged from vertical wells, this boundary was previously interpreted as an oil water contact. However saturation changes represent an ODT as a function of reservoir quality, and permeability in particular. Prior to this campaign, two existing flank wells, (Musallim Deep-1H1 and Tibr-1H1) targeted deeper reservoirs as their primary objective but found oil saturations up to 50% below the ODT of 1443 mtvdss, then defined as the OWC in the 2002 Musallim field FDP.
The 2003 appraisal campaign by PDO's Near Field Exploration team has proved the viability of the pancake model and significantly increased the reserves of the Musallim Field. It has extended the life of the field and opened up many new development possibilities. Another outcome of the exploratory appraisal campaign was that the eastern flank of the structure came in shallower and was confirmed by Tibr-2 which targeted deeper objectives that resulted in a re-assessment of the velocity model used in depth conversion. Success of the Musallim Rim campaign together with Tibr-2 well shows that these oil rims associated with the Shuaiba pancakes and flank plays are attractive targets.
Environmental Regulatory Framework in Europe: An Update
Authors: Garland E. 
Published: December 2007

Abstract
The legal framework in Europe evolves continuously. Regulations are implemented at national level, but the Europe Commission greatly influences the policy, especially onshore. Offshore, regional conventions, such as OSPAR for the North-East Atlantic still play a leading role.
There is not a single measure which can claim to have dramatically changed the way environmental issues are now regulated in Europe. But the sum of recent measures has substantially modified the still dispersed regulatory framework. And there is no doubt that this ground swell will continue to act in the near future: the Europe Commission already greatly influences most of the onshore policy. Offshore, regional conventions, in particular OSPAR, still play a leading role, but probably for a limited time. The industry has to adapt to that changes which do not relate any more solely to end-of-pipe constraints and techniques, but require a dramatic change in the approach of these issues, to identify and anticipate as early as possible the new technical challenges.
Assessing the Socioeconomic Impacts of Petroleum Exploration and Production Operations on Rural Communities in Southern Trinidad
Authors: Khan F. , Lalla F. , Roopchand J. , Dyal S. , Ramnath K. 
Published: December 2007

Abstract
An integral component of an Environmental Impact Assessment is the Socio-economic Assessment. The purpose of these assessments is to identify and evaluate potential impacts of proposed projects on the socio-economic environment of fenceline communities that would most likely be directly impacted by the project.
With the enactment of the Certificate of Environmental Clearance (CEC) Rules in Trinidad in 2001, Exploration and Production (E&P) companies must now apply to the Environmental Management Authority for an environmental permit for any activity designated under these rules. As a result, oil and gas operators in Trinidad have collected a significant amount of socioeconomic data as part of Environmental Impact Assessments (EIA’s) and Environmental Baseline Surveys for CEC applications.
The state owned oil company, Petrotrin, set the standard for conducting socio-economic assessments for energy development projects in Trinidad and did so on a voluntary basis before the CEC Rules were enacted using guidelines developed by the Regional Association of Oil and Natural Gas Companies in Latin America and the Caribbean (ARPEL).
In conducting socio-economic assessments, surveys were conducted for households, community leaders, business proprietors and focus groups. Generally 25% of the population are interviewed in the process to determine their views and aspirations on potential impacts of oil and gas E&P projects based on their historical experience. If effectively conducted, socio-economic assessments are a valuable tool for determining community needs and ensuring win-win partnerships between oil and gas companies and the communities in which they operate.
This paper describes the process by which Petrotrin has conducted socio-economic assessments for EIA’s and Environmental Baseline Surveys for fenceline communities where E&P development activities are planned. It also seeks to give an historical overview of how E&P operations have impacted fence line communities in southern Trinidad over the 20th century.
Automated Continuous Fluid Level Monitoring
Authors: Lieberman S. 
Published: December 2007

Abstract
Most well controllers require a pumping unit installation and difficult data analysis to determine and regulate for optimum well productivity.Wells with ESP's, PCP's or no pump (such as flowing wells, gas wells, etc.) require complicated and expensive equipment to accomplish the same goal.However, a wellhead-mounted, remote-operated, high-sensitivity acoustic fluid level "gun" has been developed which propels a "pressure wave" into the casing up to 100 times per day and sends the information (including casing pressure and other essential data) to any location (if desired).
Based on the information gathered (and automatically or manually analyzed), the units can be set to: regulate pumping speed; shut a well on and off ("time-clock" a well); trigger pump-off or other alarms; shut in safety valves; regulate chokes.In addition, the instrument's advanced "wave form" generation combined with an ultra-sensitive microphone can accurately detect the fluid level, perforations, holes in casing and tubing, paraffin/scale buildup, as well as down-hole equipment location within 5-10 feet in wells up to 20,000 feet depth.
Unlike most fluid level data, the information can be presented digitally on any computer, and adjusted to any sensitivity to maximize the accuracy of as well as the amount of data that can be gathered and utilized.Third-party analysis and monitoring can be arranged for companies that have minimal or no technical support.Important to note is that this technology is available for approximately the same cost as the well controllers offered by the industry today.Now one truly CAN "stick your head down there" and see just what's going on, as often as desired.
The advantages are obvious:minimize expensive electrical use; maximize life of well equipment; produce everything that enters the well; true determination of well productivity; prevent or quickly identify downhole problems; control wells safely onshore and offshore; identify gas well loading; minimize labor costs and human error.
Steam Injection Casing Design
Authors: Wu J. , Gonzalez M. E. , Hosn N. 
Published: December 2007

Abstract
Steam injection is a successful operation to increase heavy-oil production, but the casing failure rates in steam injection wells are very high. Severe thermal-loading to the casing is resulted from steam injection operations and is attributed to the high casing failure rates. The casing failures can be casing parted due to fatigue and/or tensile load at cooling period, and can also be casing ID restriction due to collapse and/or severe buckling. This paper will briefly review the common casing design practice, and provide mathematical modeling of casing stresses in steam injection wells, and discuss ways of reducing casing failures, including the use of high strength casing (such as P-110 grade) to reduce casing hot-yield in most steam injection wells.
The field data at Cymric 1Y field, Bakersfield, California are also presented to support the use of high strength casing (P-110 grade) in steam injection wells, based on the reduction of casing failures in the past two years.
Verification of an Advanced Analysis Model with Downhole Bending Moment Measurements
Authors: Neubert M. , Heisig G. , Forstner I. , Mounzer F. 
Published: December 2007

Abstract
Increasing BHA and wellbore complexity create a need for case specific engineering modeling software. Hence, mathematical modeling of the mechanical and dynamical behaviour of BHAs under various downhole conditions such as different wellbore curvatures has become routine. This paper discusses an advanced engineering model and the verification of its predictions with downhole measurements.
First the mathematical model and the downhole dynamics measurement sub are introduced. Next, three examples comparing measured and predicted steady state bending loads are presented. While the predicted and measured results match well, detail and accuracy of input parameters such as wellbore curvature are proven essential.
Lateral natural frequencies of the model are compared to the peaks in the measured frequency spectrum. In conclusion, the general validity of the model regarding bending loads and vibrations is evaluated.
Backward whirl dynamics is evaluated by comparing downhole measurements with time domain model simulations. The predictions meet the downhole measurements both in frequency and magnitude.
Quantifying Guar Polymer Recovery Post Hydraulic Fracturing to Determine the Degree of Fracture Cleanup: A Field Study of the Point of Rocks Formation, California
Authors: El Shaari N. , Kedzierski M. , Gorham T. L. 
Published: December 2007

Abstract
A field study was initiated to determine fracture cleanup by examining the carbohydrate content of flowback water production from a series of hydraulic fracture stages in the McKittrick field Point of Rocks formation. The study was an effort to understand hydraulic fracture cleanup of the Point of Rocks formation and obtain an idea on the amount of fracture volume contributing to production to optimize hydraulic fracturing design. The carbohydrate content and concentration measured from the water flowback samples are used as direct estimation to the amount of guar polymer recovered post-fracturing treatments. Carbohydrate estimation via anthrone testing method to quantify load recovery is by far the most accurate water analysis method available to the industry outside of injecting (and recovering) any special chemical markers. By contrast, studying the ionic content of produced waters by itself can be a misleading quantifier to load recovery due to the mixing and dilution of the pumped frac water with produced formation water. However, the accuracy of polymer quantification using the anthrone method is as accurate as the process of sampling, the frequency of sampling, the time from sampling to testing, the sample container, the testing method, and the calculations involved due to sampling frequency. This paper will discuss the anthrone testing method and will share guidelines that will enhance the accuracy of the testing process. The paper will also compare the guar polymer recovered from a number of hydraulic fracture stages in different Point of Rocks sands and compare to the amount of polymer pumped to present "hypothesis" as to the percent of the propped fracture actually contributing to production.
One-Trip Sand Control-Completion Technology That Eliminates Perforation Damage While Reducing Rig Time
Authors: Garfield G. 
Published: December 2007

Abstract
Formation damage caused by the perforating process is often found to be one of the leading contributors to poor productivity. Fractured and compacted zones, perforation gun debris, and broken formation blockages are common types of damage that can occur inside the perforation tunnel.
Reducing or eliminating initial perforation damage can result in a more productive well over its lifetime. This paper examines a completely new technology for perforating wells in unconsolidated formations that eliminates explosive perforation discharges and its associated formation damage risk. This new technology also reduces the cost of well construction by eliminating the need for perforating and by allowing the production liner and primary cementing equipment to be run in a single trip with an effective means of sand control.
The tool system uses telescoping tubes that extend from the liner to the formation by hydraulic pressure and mechanical force. Once the tubes are extended (or telescoped), the liner is cemented in place. The tubes form a conduit from the formation to the casing ID and contain sand-control media. This new completion method eliminates gravel packing and minimizes intervention in completion operations, saving substantial rig time. The system does not require large fluid-pumping treatments with high horsepower requirements, which simplifies operational logistics especially in remote or offshore environments.
Formation damage can also be caused by drilling mud and fluid-loss control measures after completion. This new perforating method eliminates both of these highly damaging mechanisms because the tubes extend out past the damage and into the formation, even in a washed out hole.
This paper describes the new system, cost comparisons with existing methods, and expected economic benefits over the lifetime of wells in typical applications of this new technology.
Potential Radon Emissions due to Biogas Generation at TENORM Land Disposal Sites
Authors: Walter G. R. , Benke R. R. , Pickett D. A. 
Published: December 2007

Abstract
Allowing disposal of technologically enhanced naturally occurring radioactive materials (TENORM) from petroleum exploration and production in non-hazardous waste landfills was proposed in a U.S. Deparment of Energy study. TENORM often contains radium that is a source of radon. Diffusion through soil and other cover materials is commonly regarded as the dominant radon transport process from land disposal units. Biogas generation in landfills may increase radon emissions relative to diffusion-dominated sites.
A numerical gas flow and transport model was used to simulate potential radon emissions from radium-bearing TENORM in solid waste landfills and land disposal sites where TENORM is co-disposed with oily waste. The landfill scenarios considered the effect of landfill gas generation potential and rate, cover construction, TENORM disposal method, and gas control methodology on radon emissions. The co-disposal scenarios investigated the effect of biogas generation rate, organic carbon partitioning, and cover construction on radon emissions. Gas generation was found to significantly increase radon emissions from landfills. Depending on the nature of the gas management system, atmospheric radon concentrations could exceed background level both on-site and off-site. The effect of biogas generation on radon emissions from co-disposal sites was found to be strongly dependent on the hydrocarbon content of the waste.
The results of this investigation provide guidance for selecting appropriate TENORM disposal options and for evaluating the potential environmental liabilities associated with the options.
Modeling Long-Term CO2 Storage in Aquifer with a Black-Oil Reservoir Simulator
Authors: Mo S. , Akervoll I. 
Published: December 2007

Abstract
This paper presents results of modeling long-term CO2 storage in a shallow saline aquifer with a commercial black-oil reservoir simulator. Realistic CO2/water phase behavior (pVT properties) covering all pressure, temperature and compositional conditions accounted for during the simulations have been used. The pressure and temperature in the aquifer is above the CO2 supercritical conditions giving rise to the existence of a two-phase fluid system of CO2 as a supercritical fluid ("gas") and CO2 dissolved in the aqueous phase. The objective was to model scenarios of CO2 storage in aquifer with emphasis on the sensitivity of CO2 distribution in the deposit with respect to critical CO2 saturations during the injection period and to residual CO2 saturation for water reentering CO2 filled volumes (hysteresis in fluid saturations). The re-distribution of water occurs after stop of CO2 injection due to gravity segregation of dense CO2 saturated water and CO2-free water. The impact of various reservoir parameters has been studied, including average permeability, vertical to horizontal permeability ratio (kv/kh), relative permeability, and capillary pressure. For the saturation functions the main focus has been on end points and hysteresis effects. It is observed that storage of CO2 as residual gas is most important for low kv/kh ratios.
Lightweight Cement, Ultrasonic Cement Evaluation, and Cased Hole Dynamics Formation Pressure Tester Combine to Enhance Infill-Drilling Opportunities in Shallow Marine Shelf Deposits, Kern County, California
Authors: Formica J. , Davis B. 
Published: December 2007

Abstract
Developed California oilfields are often under pressured. These low pressures and relatively high permeabilities present challenges in supporting mud and cement columns during well construction.
Accurate formation pressures are critical for petroleum exploitation. They are used for geological correlation, drilling/completion design, surface facilities design, and for reservoir management. Obtaining formation pressures in under pressured or tight reservoirs in open hole can be challenging due to poor hole conditions, thick mud cakes, risks of getting differential cable or tool stuck, and supercharging effects. These conditions can either compromise the formation pressure data quality and or result in formation pressure tool fishing operations.
This paper will show the results of a two well case study where lightweight cements of 9.8 ppg where successful run and evaluated for single stage cement jobs in a stacked reservoir with under pressured and over pressured formations. Then a cased hole formation pressure tool was deployed to get a combined total of twelve reservoir pressures after which the tool restored the casing to a condition that allowed for successful down the casing multi-stage high pressure proppant fracture jobs.
This combination of new technologies for mature reservoirs has given operators more options for well design and formation evaluation. Data quality and the answers uncovered have helped justified the continuation of infill drilling opportunities to increase production and reserves.