bluuebunny/crossref_metadata_2025_split huggingface dataset:
Innovative Knowledge-Driven Approach for Shared Earth Model Building
Authors: Rainaud J.-F. , Perrin M. , Bertrand Y. 
Published: December 2007

Abstract
During the last four years, the Institut Français du Pétrole (IFP) has tried to meet the present-day need for oil companies to produce large amounts of 3D geological models that can be updated, extended, modified or rebuilt by any potential user (Shared Earth Models = SEM) by setting up a co-operation with a few French academic research teams.
This multidisciplinary group comprises geologists, reservoir engineers, computer scientists and mathematicians. The all over goal of the co-operation is promoting innovative solutions for an easier production of 3D hydrocarbon reservoir models and for the sharing of the building process and of the results over the net. The work of the group is based on the belief that this challenge can be faced by substituting to the current data-driven modeling approach a knowledge driven approach [J.F. Rainaud & al; 2004]. This means that the geological surfaces included in a geological model should not be considered as geometrical or graphic items but as true geological objects. The topology of the surface assemblage is then no longer an intrinsic feature of 3D model but it can instead be deduced from geological properties attached to the geological surfaces themselves (nature of the surface: stratigraphic limit / fault, geological position: intersecting / unconformable / on-lap).
The objective of the paper is to present how we use geological knowledge, classical surface representations and well bore information to build, populate, and automatically update complex geological and reservoir models based on common geological constraints. One of the most interesting features of this approach for reservoir engineering is the capacity to embed this automatic consistent modeling of the geological and reservoir grid into a complete loop of history matching. The all over proposed medology is illustrated by examples emphasizing various results already obtained
Efficient Wellbore Cement Sheath Design Using the SRC (System Response Curve) Method
Authors: Fourmaintraux D. , Bois A.-P. , Franco C. , Fraboulet B. , Brossollet P. 
Published: December 2007

Abstract
Inter-zonal flow of fluids behind cemented casings has plagued the EP industry for years. This has led to the development of many models, but there is still a need for a unified and practical method to design cement sheaths.
Three leakage categories can be distinguished depending on the physical state of the cement when leakage occurs, and this paper focuses on modeling cement sheaths while in solid state (CSSS). It shows first that predictive simulations are not very efficient, even if tremendous improvements have been made the past ten years. Then, a new modeling method (inspired from the Convergence-Confinement Method for designing of tunnel supports) is introduced, the SRC (System Response curve) method, that simplifies CSSS modeling. Using a case of history, where SRC method has been used to help in designing a well, the paper highlights the importance of pore pressure and shrinkage in predictive cement-sheath modeling.
Tracer-Test Simulation on Discrete Fracture Network Models for the Characterization of Fractured Reservoirs
Authors: Lange A. , Bouzian J. , Bourbiaux B. 
Published: December 2007

Abstract
The presence of fractures at various scales affects the flow dynamics within a reservoir, thus casting uncertainty on the assessment of the field productivity and reserves. Methodologies and tools are now available (i) to reconstruct geologically-realistic models of the fault/fracture network (ii) to turn these models into simplified conceptual models usable for field-scale simulations of multi-phase production methods. However, a critical intermediate step remains that of validating the geometry of the geological fault/fracture network and characterizing it in terms of flow properties.
An original 3D Discrete Fracture Network simulator enabling one to fulfil this characterization step has already been presented by the authors'. This simulator can compute the single-phase flow response of any type of fractured reservoir, whatever the scale, density and connectivity of fractures. An extension of this simulator to compute tracer tests is presented in this paper. Compared with pressure tests, tracer tests may provide additional information about the reservoir heterogeneity due to the convective nature of these tests.
This simulator is based on the dual-medium concept applied to an explicit representation of the geological model of fault/fracture network and matrix medium. The transport and dispersion of non-reactive tracers are modelled by introducing a convection-dispersion equation into the existing dualporosity flow model. A hybrid scheme discretizes the convective term implicitly within densely fractured regions for stability purposes, and explicitly via a double-upstream scheme everywhere else for reducing spurious numerical dispersion.
After demonstrating the reliability of this tracer model on validation cases, a realistic case that combines diffuse fracturing and major objects such as seismic and sub-seismic faults is studied. Tracer tests are simulated for wells in a five-spot injectionproduction pattern. Effects of a fracture/matrix tracer exchange as well as a Taylor-Aris dispersion on breakthrough curves are analyzed. The potentiality of tracer responses for providing information on the distribution of reservoir heterogeneities is discussed.
Simulation of Prudhoe Bay Field Interference Test
Authors: Myers Gary Allen , Johnston Ron D. , Mainwaring John R. 
Published: December 2007

ABSTRACT
An improved reservoir description of a Prudhoe Bay field water injectivity test site was obtained by simultaneously history-matching interference, pressure buildup and production history data with a black oil simulator. Water is currently being injected in a Sadlerochit reservoir inverted, five-spot pattern on the east side of the field. Pressure data were obtained prior to starting water injection.
Interference testing was conducted by successively shutting in and producing each of the four corner wells, which are field production wells, and observing the pressure response at the water injection well in the center of the pattern. Pressure changes, varying from 2 to 8 psi, were measured with a downhole, high-sensitivity, quartz-crystal pressure transducer. While small, the pressure changes were measurable because two major shale complexes exist between the test interval and the large Prudhoe Bay field gas cap overlying the test area. Well spacing varied from 1600 to 2400 feet. Pressure buildup data were recorded for all five wells.
A consistent reservoir description was developed from geological and engineering data. Interference and production history data were history-matched with an XYZ simulator and pressure buildup data were modeled with an RZ simulator. The upper shale complex is sealing, while the middle shale complex, lying immediately above the observation well perforations, allows some vertical communication. Type-curve matching the interference test gave much greater krokh/μ values for the tested interval than the XYZ history match. This occurred primarily because the interference test actually investigated zones above the tested interval.
Optimization of Reverse Osmosis Treatment of in Situ Wastewaters
Authors: Kasper Dennis R. 
Published: December 2007

ABSTRACT
This paper identifies and discusses optimization of wastewater concentration and disposal alternatives for wastewaters generated by in situ solution leaching. Disposal alternatives considered include: 1) deep well injection; 2) evaporation ponds; 3) reverse osmosis (RO) concentration plus deep well injection, and 4) RO concentration plus evaporation ponds. Factors affecting the RO process and other disposal processes include: flushing volume required for restoration, recovery of RO system, degree of pretreatment and restoration pumping schedule.
Petroleum Geology of Baltimore Canyon Trough
Authors: Mattick Robert E. 
Published: December 2007

Abstract
Exploration activity to date on the U.S. Atlantic Continental Shelf includes 3 oil and gas lease sales and the drilling of 5 deep strati-graphic test wells and 26 wildcat wells. Wildcat drilling in the Baltimore Canyon trough has been concentrated in the vicinity of the Great Stone dome and along the shelf edge. The Great Stone dome, a large domal structure inferred to be associated with an Early Cretaceous mafic intrusion, appeared to be one of the largest and most promising single structures on the shelf on the basis of the interpretation of seismic data. Six wells have been drilled on the structure, but no shows of oil or gas have been reported.
Results of wildcat drilling along the outer edge of the Continental Shelf have been more encouraging. Significant shows of natural gas have been reported from 3 out of 14 completed wildcat wells. The combined initial flow rates were about 2 million m3 per day (68.5 million ft3 per day) from Upper Jurassic sandstone beds at depths of about 4,000 m. An additional test, at one of these wells, flowed 48.4° gravity oil at the rate of 100 m3 per day (630 barrels per day) from a thin bed of Lower Cretaceous sandstone. A commercial size field, however, has not been established.
In the Baltimore Canyon trough, analysis indicates that shelf sediments have a relatively low potential for the generation of liquid hydrocarbons, but indications are favorable that natural gas could have been generated below a depth of 3,000 m. However, sandstone porosities deteriorate below 3,000 m, and at these depths, the Jurassic sandstone beds may lack lateral continuity.
Tracts to be leased in upcoming sales will extend out to water depths of 2,500 m. In the deep-water area beneath the Continental Slope, the interpretation of seismic data suggests that the shelf prograded seaward during Jurassic time. Consequently, Jurassic shelf facies containing potential reservoir rock may interfinger with slope facies that could contain source rock capable of having generated liquid petroleum. In spite of the huge investments of money that will be required for deep-water exploration, the possible presence, under the slope, of complex extensional-fault patterns, reef complexes, and salt diapirs will probably encourage interest in upcoming sales.
Eastern Tight Sands, A Stimulation Assessment
Authors: McKetta Steven F. , Koziar Gregory , Cook Louis S. 
Published: December 2007

ABSTRACT
This paper is an evaluation of massive hydraulic fracturing and dendritic fracturing applied to four tight gas sands of the Eastern United States. A total of ten fracturing treatments were performed in the Berea, Benson, Clinton and Medina formations. The objective of this program was to determine whether a meaningful productivity increase could result from the application of new fracturing techniques over that of conventional hydraulic fracturing and/or explosive shooting. The small number of test wells, coupled with a wide range of test results and other geological factors make it difficult to draw definitive conclusions.
Financing the Appalachian Oil and Gas Industry
Authors: Riley Thomas E. 
Published: December 2007

Abstract
In recent years, the Appalachian area has experienced a resurgence of oil and gas drilling and development. Increases in prices and the outlook for continued growth in the value of oil and gas has generated this growth in activity. Most of this growth has come from the smaller, independent, operator and contractor. It is these companies who must rely on additional outside capital to achieve their growth. This capital can be generated either from new investors or from debt. This paper will deal with the various methods of securing and structuring debt for these different facets of the oil and gas business in the Appalachian area.
For the small, independent oil and gas or contracting companies, which comprise the majority of the business in the Appalachian area, the only available major debt structure is secured lending. Secured lending means that banks will loan money to a company using a part or all of a company's assets as collateral. For a contractor, this collateral is his equipment; for a pipeline owner, it is his pipeline and sales and purchase contracts; and for the producer it is his oil and gas reserves. It is the bank's role, then, to determine (1) the value of this collateral and whether it will generate sufficient cash flow to pay interest and retire debt, as well as (2) the borrower's financial responsibility, character, integrity, business stability and potential, and business relationship to the bank. This latter determination can be established with financial statements, earnings reports, business references, and credit reports. Determining the value of collateral presents a more difficult problem. For equipment, this can be done through an appraisal; in the case of oil and gas reserves, this requires a property evaluation by the bank's oil department or an outside consultant.
Capital requirements for drilling and service companies are usually for new or additional equipment. This equipment, then, is the collateral available for financing. Banks traditionally loan on the order of 80% of the purchase price of the equipment. The term of the loan is usually three to seven years depending upon the physical life of the machinery, area of activity, and company/bank relationship.
Development Planning for a Group of Oil Fields
Authors: Sullivan Jan 
Published: December 2007

ABSTRACT
The use of an integrated model for planning the development of a group of onshore oil fields is reviewed. The planning problem is identified as one of finding a minimum cost strategy for developing and maintaining capacity to meet specified production goals over the lifetime of the reserves. The strategy identifies a schedule of production and injection for each reservoir, together with an installation schedule for any necessary additional equipment.
The planning model uses optimisation techniques to select the development strategy. This enables a wide range of strategies to be compared in an efficient and consistent manner. By specifying a suitable objective to the model, the economic life of the reserves for a particular target production and crude price profile can be found. This analyses may be used to estimate the minimum crude price required to make a given production profile economically viable.
The application of the planning model in the planning process is discussed in relation to the use of simulation techniques. The two methods are complementary. The results of the integrated model identify the most appropriate production strategy for each reservoir within the context of the complete system. This can then be validated through individual studies of the reservoirs and of the surface facilities.
Geological Interpretation of Oil Entrapment in the Zubair Formation, Raudhatain Field
Authors: Al-Rawi Munim M. 
Published: December 2007

ABSTRACT
The purpose of this paper is to interpret geologically the oil entrapment in the Zubair Formation at the Raudhatain Field which is essentially barren at the neighbouring Sabriya Field although it is structurally high in the latter.
The Zubair Formation is of Early Cretaceous age and consists of sands and sandstone intercalated with siltstones, shales and few thin limestone beds. The average total thickness of the formation is 420 m (1380 ft).
The available data showed that the formation contains three potentially productive zones with many sand pools separated by shales. Analysis of the data showed that at the end of Zubair time, the upper reservoir was structurally higher at Raudhatain than Sabriya by about 16.5 m (54.4 ft), taking into account constant compaction. However, the present structural relief of the upper reservoir at Sabriya is about 29.4 m (98 ft). This gives a structural growth at Sabriya of about 46 m (152 ft).
Petrographic study of the sandstones showed drastic differences in porosity. The reservoir sands are very clean quartzite with average porosity of 20%. The aquifer sandstones however, show a reduction in porosity to about 7%.
It is interpreted that oil accumulation in the Zubair Formation at Raudhatain represent a case history of a "paleotrap". Oil migration occurred early before sands diagenesis. Oil entrapment was sealed off and with subsequent structural growth the oil frozen-in and did not migrate to Sabriya structural high and retained in situ. Secondary migration from the Zubair reservoir to higher horizons was postulated through growth faults at the Raudhatain. It is suggested that the relation between structural growth and reservoir characteristics should be investigated in the Arabian region to outline paleostructures which are open and presently unprospective, while they may contain important frozen-in accumulation.
Sedimentary Response to Tectonic and Eustatic Changes: an Example From the Mid-Cretaceous Wasia Formation, Saudi Arabia
Authors: Entsminger Lee D. 
Published: December 2007

ABSTRACT
Deposition of the dominantly siliciclastic Cretaceous Wasia Formation (Albian through Turonian) in Saudi Arabia was initiated when tectonic movement uplifted a portion of the Arabian Shield. The magnitude of this uplift was greatest to the north as evidenced by the Pre-Wasla Unconformity, The Wasia, which is normally conformable to the Aptlan Shu'alba Formation, overlaps increasingly older formations from the Cretaceous Biyadh in the south to the Lower Devonian carbonates in the north. The primary sources of the Wasia sediments are the older formations eroded when the Pre-Wasla Unconformity was active. Feldspar, heavy mineral and quartz type distributions within the Wasia members suggest that the Arabian Shield was not a major contributor of sediments for the Wasia until the Wara member was deposited in late Albian Time.
The depositional sequence of the Wasia is reconstructed from evidence derived from outcrop, cores, and various subsurface maps. Eustatic cycles documented worldwide are correlated with the Wasia members, with limestone units representing Mid-Cretaceous transgressions.
Proper Fluid Pretreatment to Minimize Hydrogen Sulfide Dangers
Authors: Samuels Alvin , Wendt Richard P. 
Published: December 2007

ABSTRACT
The potential hazards in the drilling, completion and/or servicing of wells containing hydrogen sulfide are described. A new generalized mud theory is used to calculate the level of corrosive or poisonous gas contamination due to varying amounts of hydrogen sulfide and carbon dioxide entering a mud stream as dependent on the mud's buffering capacity and alkalinity. It is demonstrated that an intrusion of gas containing as little as 0.5 mole percent hydrogen sulfide can create hazardous conditions. Even highly alkaline muds are predicted to have severely limited ability to neutralize acid gas intrusions and cannot be relied on for safety.
The important need for pretreatment of the muds to remove the hydrogen sulfide rather than merely neutralize it is described. Published laboratory kick simulation experiments and documented field results show that proper scavenger pretreatment and monitoring of the mud can protect against a well kick producing 10 million cubic feet (2.83 × l05m3) per day of sweet gas and 500,000 cubic feet (1.42 × 104m3) per day of hydrogen sulfide.
Productivity Testing Using Production Logging Techniques
Authors: Weiss Ernst N. , Taylor James G. , Toronyi Robert M. 
Published: December 2007

ABSTRACT
A method of individual zone productivity and inflow performance relationship testing has been employed in two prolific offshore oil fields.
The procedures involving downhole measure ment of flow and pressure data using production logging combination tools are explained.
This testing approach conveniently obtains individual zone productivity inform at ion as well as general PI data, and is therefore useful for delineating important reservoir characteristics. Field results from carbonate and sandstone reservoirs are presented and discussed.
Carbon/Oxygen Or Resistivity/Pulsed Neutron Logging - A Case Study
Authors: Kerr Michael E. 
Published: December 2007

ABSTRACT
The carbon/oxygen log is evaluated for measuring water saturation in observation wells containing a mixture of low salinity injected water and saline formation water. Good results are obtained when the reservoir nears depletion, but the tool is adversely affected by a mud filtrate annulus when an oil column remains in the reservoir. Combining resistivity and pulsed neutron logs gives a more accurate picture of reservoir behavior under these conditions.
Telemetered Surveillance and Control of an Onshore Gas Field
Authors: Handyside Christopher B. 
Published: December 2007

ABSTRACT
A Supervisory Control and Data Acquisition (SCADA) system has been installed in Bahrain's Khuff gas field to carry out surveillance and control of the remote dehydration and transmission facilities. The system has proven to be a valuable operating tool in an operation where heavy load swings and a small system gas capacity are operating realities.
Performance of Powered Water Injectors in Arab ‘D’ Reservoir of UMM Shaif Field Offshore Abu Dhabi
Authors: El-Hadidi S. M. , Al-Rubaie J. S. , Allam M. , Fadak A. 
Published: December 2007

ABSTRACT
Power water injection started in Umm Shaif Arab D reservoirs as early as January 1976. Presently, there are more than 15 wells converted from dumpflood to power injection using treated seawater from the Gulf. Water quality specifications in ADMA-OPCO are in line with water quality specifications of other operating companies in the region. A comparison is presented.
Daily injection rates and corresponding wellhead injection pressures are recorded daily using telemetry. Injectivity indices versus time for each power injector were calculated using well performance data and pressure fall-off tests. A deterioration of injectivity indices with time was observed. Reasons for injectivity indices deterioration were investigated and recommended action(s) are presented. One of the wells was backflowed and an assessment of the backflow exercise is presented.
Principles and Applications of a New In-Situ Method for Inspection of Well Casing
Authors: Smith Glenn S. 
Published: December 2007

ABSTRACT
The ETT-C is a recently developed corrosion tool for the in-situ inspection of well casing. Electromagnetic techniques are used to measure casing wall thickness, apparent magnetic permeability, and inside diameter. Previous tools of this type made a single measurement which was dependent on both wall thickness and magnetic permeability. The single measurement technique did not allow the log analyst to differentiate between thickness changes and magnetic permeability variations. The ETT-C system monitors magnetic permeability to obtain an independent wall thickness measurement. A sensitive, non-contact internal diameter measurement has also been added.
A system description explains the ETT-C measurement principles, significance, and processing interaction. Tool applications and interpretation are also discussed. The utility of the additional information provided by the ETT-C is demonstrated with log examples.
Effect of Formation Heterogeneity and Temperature on Alkaline Waterflooding Performance
Authors: Dokla Mahmoud E. 
Published: December 2007

ABSTRACT
The effect of permeability variation on recovery from unconsolidated sand-packs when flooded with alkaline water was studied. The effect of temperature on the process was also considered. Floods were carried out on stratified and heterogeneous sand-packs with permeability ratios up to 7.
Alkaline water results in higher oil recovery from stratified and heterogeneous systems than ordinary water. Maximum recovery occurs when the pH of displacing water is around 10. It is believed that alkaline water results in contact angle values around 90°, which is better for oil movement. Water-oil permeability ratio is affected by type of displacing water and by temperature. Increasing the temperature has the effect of smoothing the differences in oil recovery caused by permeability variation.