bluuebunny/crossref_metadata_2025_split huggingface dataset:
Laboratory Steamfloods in Half of a Five-Spot
Authors: Huygen Hans H. 
Published: December 2007

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

Abstract
Eight crudes were steamflooded at different temperatures and pressures in a 3-dimensional model of a five-spot pattern.
Oil production and steam sweep data are fitted with exponential curves whose parameters are correlated with oil and steam characteristics as are steam sweep and fraction of ultimate recovery occurring at steam breakthrough.
In several correlations, crude viscosity as a correlator is replaced by distillation residue as determined by a simple test. Implications of the correlations are discussed.

Introduction
Enhanced recovery of oil by steam injection is practiced widely by the huff and puff method of stimulation. Several large-scale projects, among them Getty's huge Kern River, are being converted to steamflooding. However, few thermal projects are operated from the start as a projects are operated from the start as a steamflood. This is caused in part by the lack of information on how efficient and economic a continuous steam drive will be in a given field, and in part by the greater payout time that steamflooding part by the greater payout time that steamflooding necessitates. Furthermore, much of the oil needing enhanced recovery schemes falls in the category of heavy oil, and it is thought that oils of several thousand mPa-s (cp) will not allow a satisfactory steam sweep to be made.
To obtain data on the applicability of steamflooding, eight crudes were selected from formations whose pressure was below 6.89 MPa (1000 psia)(at a depth of 2250 ft), thus allowing psia)(at a depth of 2250 ft), thus allowing real-pressure floods to be performed in a 3-dimensional model of half of a 5-spot pattern. To render the problem tractable, influence of gravity segregation is not taken into account, thus excluding modeling of steam override. For the same reason, inhomogeneities due to stratification are not examined, nor are pemeability variations. Moreover, steam injection rate is constant from test to test so as to keep the number of tests manageable. Even so, statistical analysis of the results yields useful correlations.
Chemical Diversion of Heat Will improve Thermal Oil Recovery
Authors: Fitch Jon P. , Minter Rick B. 
Published: December 2007

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

Abstract
Cyclic steam injection has been employed to improve recovery in "heavy oil" (8–16 degrees API) reservoirs for several years. The major factor in maximizing recovery is the ability to ensure uniform distribution of heat across the productive intervals.
A unique chemical process to control steam injection profiles has been developed to divert heat away from depleted, high permeability sands. The product has increased permeability sands. The product has increased injection pressures, has altered downhole survey profiles, and has shown substantial incremental oil when compared to the response of the wells' prior cycles. Treatment costs are minimal in that the diverting agent is carried into the reservoir with injected steam and no special well preparation is necessary. This paper will summarize work accomplished over a two-year period beginning with initial field testing in 1973. The test area is located in Midway Sunset Field, 40 miles west of Bakersfield, California (Figure 1).

Introduction
Poor injection profiles are a major Poor injection profiles are a major detriment to success in waterflooding and most other secondary recovery techniques. Cyclic steam stimulation is no exception and the problem in the subject area is magnified by the massive, unconsolidated Potter sands. These sands, at an average depth of 1400 feet and an average thickness of 400 feet, display permeabilities in excess of three darcies and an average porosity of 35%. The erratic grain size, porosity of 35%. The erratic grain size, varying from fine oil silts to large cobbles, suggests a fluvial fan deposit whose complex intra-stratigraphic framework is the result of interbedded, braided stream systems. The production of low gravity crudes in this area is production of low gravity crudes in this area is influenced by gravity drainage, the dominant reservoir mechanism, and requires gravel packs for sand control. Localized depletion occurs in the upper portions of the major sand bodies which, when coupled with the loss of steam and production control due to gravel packs and production control due to gravel packs and essentially no initial reservoir pressure, compounds steam "thief" problems. These "thiefs" are present at the time the well is completed or they occur through continued steaming.
The Effect Of Void And Filled Perforations On Well Productivity
Authors: Dietrich James K. , Bondor Paul L. 
Published: December 2007

Abstract
Numerical simulation using cylindrical coordinates provides a powerful technique for analyzing the fluid flow behavior in the formation immediately adjacent to production and injection wells. This technique was used to study the effect of both void and filled (gravel- packed) perforations on well productivity. packed) perforations on well productivity. The results indicate that perforating (even without formation damage) causes a more severe level of impairment than heretofore recognized. We found in both the void and filled (gravel-packed) perforation cases that radial flow does not occur as close to the wellbore as previous investigators have assumed. This previous investigators have assumed. This larger than previously expected non-radial flow region will create a skin or damage effect.
In the case of filled perforations, permeability of the gravel pack of perforating permeability of the gravel pack of perforating debris has a very large influence on productivity. Results appearing in the literature concerning productivity through perforated casing (all of productivity through perforated casing (all of which assume the perforation has empty cavity), are unduly optimistic when applied to unconsolidated reservoirs.

Introduction
Details of flow in the vicinity of a cased, perforated well are useful for predicting and evaluating completion methods, impairment, and formation and casing stresses. All previous investigations have assumed that the hole in the formation and the tunnel in the casing formed by the perforating action remain void of any solid material. Thus, in these earlier studies there was no pressure drop between the wellbore and perforation block. Under this assumption, a perforation block. Under this assumption, a perforated wellbore may actually lead to perforated wellbore may actually lead to improved productivity, as compared to the case of an open-hole completion. For example, the results of previous work indicates that a ratio in excess of unity can be achieved when perforating with more than about four 1/2 inch perforations per foot. per foot. In these earlier studies, the fluid was assumed to have a small and constant compressibility and the distance at which azimuthal pressure gradients become insignificant (ro) was pressure gradients become insignificant (ro) was generally specified arbitrarily in the range 18 rw less ro less 30 rw.
A three-dimensional finite difference simulator was used to model the effects of void perforations on the flow of both real gas and a perforations on the flow of both real gas and a fluid of small and constant compressibility. In the case of filled perforations, the effect of pack permeability was examined using constant pack permeability was examined using constant compressibility fluid flow.
The Areal Sweep Efficiency of the In-Situ Recovery of Subbituminous Coal
Authors: Jennings James W. , Gunn Robert D. , Brandenburg Charles F. , Whitman David L. 
Published: December 2007

Jennings, James W., Member SPE-AIME, Texas A and M U. and Laramie Energy Research Center, Gunn, Robert D., U. of Wyoming and Laramie Energy Research Center, Brandenburg, Charles F., Laramie Energy Research Center, and Whitman, David L., U. of Wyoming and Laramie Energy Research Center
American Institute of Mining, Metallurgical, and Petroleum Engineers Inc.

Abstract
This paper presents the results of applying particle tracking techniques to the prediction of areal sweep for the in-situ prediction of areal sweep for the in-situ recovery of subbituminous coal. Comparison of field data with calculated values indicate that these techniques are applicable and support the theory that the in-situ recovery of subbituminous coal as encountered at Hanna, Wyoming, is a permeation process. The model predicts breakthrough of the flame front at the production well and intermediate points with sufficient accuracy for preliminary design purposes.

Introduction
A brief study of the areal sweep efficiency of underground coal gasification (UCG) has been made in connection with the field experimentation being conducted by the Laramie Energy Research Center (LERC), U.S. ERDA, near Hanna, Wyoming. One of the most important questions raised when discussing commercialization of the process is that of resource recovery efficiency and the effect of recovery efficiency on the economics. In addition, with the energy shortage situation of the recent past, more emphasis is being placed on the development of processes which produce a maximum amount of the in place energy. The following discussion describes a simple approach to determining the areal sweep efficiency for UCG and compares the results with field experimental results.

Background
The process being utilized by LERC in the ongoing experimentation near Hanna, Wyoming, is known as the linked vertical well process. This process uses reverse combustion to modify the natural permeability such that gasification in the forward mode can be conducted. This basic process has been described previously.
This study concerns two parts of the LERC program, Phases I and II of the Hanna II experiment. Data from Phase I was presented earlier. The field data reported presented earlier. The field data reported in this paper are from Phase II of the Hanna II experiment which utilized a four well square pattern with 60 feet spacing. The four injection-production wells were drilled into the Hanna #1 coal seam, a subbituminous coal which is 30 feet thick and at a depth of 275 feet at this site.
Dispersion and Tortuosity in Sandstones
Authors: Donaldson Erle C. , Kendall Ronald F. , Manning Francis S. 
Published: December 2007

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

Abstract
Linear dispersion and mass transfer coefficients were measured for Bandera, Berea, Cottage Grove, Noxie and Torpedo sandstones ranging in permeability from 12 to 420 md. Experimental data were permeability from 12 to 420 md. Experimental data were obtained from analysis of effluent concentration changes resulting from a step increase of the influent tracer concentration. Brine and a tritium-labeled brine solution were used as tracers. Coefficients of dispersion were calculated by comparing the experimental data with solutions of the diffusion equation by three methods:analytical solution of the diffusivity equation,a graphical method, andnumerical, finite difference, solution.
The three methods yielded equivalent results.
Tailing of the effluent response curves was interpreted by introducing two additional parameters to the diffusivity equation: (1) the immobile parameters to the diffusivity equation:the immobile fluid fraction of the porous medium determined independently by capillary pressure measurement anda mass transfer coefficient to account for tracer interaction with the immobile fluid fraction.
The Berea sandstone exhibited the sharpest displacement front and the least amount of tailing, making it the best selection for experiments in which steep displacement fronts are encountered, such as miscible displacement.
Molecular diffusion measurements were used to calculate tortuosity factors for each of the five sandstones using two pairs of gases: hydrogenair and hydrogen-nitrogen. These results are equivalent to tortuosities independently determined by electrical conductivity measurements. The coefficient of dispersion and the tortuosity of sandstones are shown to be excellent parameters for characterization of geologic materials for the study of fluid flow properties.

Introduction
Knowledge of the flow patterns of solutes in flowing streams through porous geologic materials is important in applying the technology for miscible phase displacement for recovery of petroleum and injection of mobility- and wettability-control agents. Kaufman and Orlob also emphasized the use of tracers for analysis of saline water intrusion into fresh water aquifers and evaluation of proposals for the underground storage of radioactive materials.
Field Application of Pressure Buildup Tests, Jay-Little Escambia Creek Fields
Authors: Langston E.P. 
Published: December 2007

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

Abstract
Pressure buildup tests are a valuable reservoir description and well evaluation tool in the Jay-Little Escambia Creek (Jay-LEC) Fields of Alabama and Florida. Four practical applications are demonstrated from the results of forty-three tests conducted to date. A comprehensive coring program coupled with high quality, consistent test data have made such applications possible. Buildup tests have provided the basis for arithmetic averaging of core provided the basis for arithmetic averaging of core data to determine effective reservoir permeability and are a significant guide in the permeability and are a significant guide in the planning and evaluation of workovers. Remedial planning and evaluation of workovers. Remedial action taken as a result of such tests will substantially improve waterflood conformance. These tests have also provided information that are an aid in the solution of reservoir description problems.

Introduction
This paper will briefly describe the test and interpretation procedures used by Exxon in the Jay-LEC Field and will demonstrate practical applications of test results to solve specific reservoir and production engineering problems. These applications were made as the field was developed, unitized, moved into a secondary recovery program, and underwent a major stimulation workover program. Specific demonstrated applications are:Buildup test permeability thickness values, correlated with those from core analysis data, provided the basis for arithmetically averaging core data to determine effective reservoir permeability. Well deliverabilities were predicted, and two reservoir models were constructed utilizing these data.Horizontal barriers to vertical flow were determined to exist in massive Smackoverpay sections. As a result, workover planning and implementation was significantly influenced.Buildup tests were used to determine the need for well stimulation to open total pay section and to evaluate the effectiveness of workovers which were designed to accomplish this objective.Reservoir limits, as defined by geological interpretation, were confirmed by buildup tests.
The Jay Field was discovered in Northwest Florida during June 1970 when the St. Regis No. 1 well penetrated the Smackover Formation. Further drilling expanded field limits into Alabama, and development of this (15,500 feet) deep reservoir proceeded rapidly on 160-acre spacing. The Alabama portion of this common reservoir was designated as the Little Escambia Creek Field. During development, a comprehensive data gathering program was maintained. Each well, in addition to being logged with gamma ray, resistivity and porosity tools, was conventionally cored through the Smackover and Norphlet pay zones with core recovery averaging 82 pay zones with core recovery averaging 82 percent. percent.
On the Mechanism of Foam Formation in Porous Media
Authors: Kanda M. , Schechter R.S. 
Published: December 2007

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

Abstract
Foam can be created within the interstices of a porous medium by displacing a resident surfactant solution with a gas. This process of in-situ foam formation has a number of potential applications. Thus, it is of potential applications. Thus, it is of interest to establish those properties of surfactants which improve the performance of a given process.
Both anionic and nonionic surfactants were studied. Each was characterized by its surface tension, surface viscosity, foaming ability, foam stability, bulk viscosity and wettability.
The effectiveness of a particular surfactant solution was determined by measuring the breakthrough time, displacement efficiency and permeability reduction attending the permeability reduction attending the displacement of the solution from a sand pack by nitrogen. It was found that:the breakthrough time is increased by increasing the surface tension and surface viscosity;the displacement efficiency is increased by increasing the surface viscosity and by decreasing the surface tension; andthe permeability to gas is a sensitive function of the surfactant solution wettability.
The presence of salt in the surfactant solutions did not significantly change the results. For most systems its effect can be neglected. On the other hand, the presence of oil, even in very small amounts, cannot be ignored. Oil can have a very deleterious effect on performance.

Introduction
The presence of foam within the interstices of a porous medium can substantially reduce the permeability to gas while leaving the permeability to liquid essentially unchanged. Various applications which utilize this phenomenon have been proposed. For example, it has been suggested that foams may help reduce the leakage of gas through fractures in reservoir rocks (1), (2), reduce gas coning (3) and be used as an oil displacing agent (3), (4), (5), (6), (7), (8), (9). These processes generally involve the injection of processes generally involve the injection of an aqueous phase containing a surfactant followed by gas, although in some cases it has been suggested that the liquid and the gas be injected simultaneously. In either case the purpose is to create a zone following the purpose is to create a zone following the liquid-gas contact which contains a stable foam.
Application of Risk Management Principles to Pipeline Leak Prevention in the Niger Delta
Authors: Abifarin O. , Mishael S. J. 
Published: December 2007

Abstract
Recent oil spills in the Niger Delta have challenged the industry to reassess and more aggressively pursue spill prevention efforts. Further, many production locations are situated in close proximity to local populations, who are skeptical of the industry's commitment to spill prevention. Responding to these concerns, Chevron Nigeria Limited has implemented a Risk Management based Pipeline Integrity Project to significantly enhance leak prevention efforts. Operations comprise approximately 700 pipelines and flowlines situated in various habitats including environmentally sensitive mangrove swamp, agricultural lands and offshore. The Risk Management process estimates likelihood and consequences of potential leak scenarios, both corrosion and non-corrosion. Leak prevention proposals are then evaluated based on how effective they are at reducing risk. A structured project management process is concurrently used allowing rapid transition of project recommendations to project implementation.
Analytic-Numeric Hybrid Modeling Approach for Interpreting Transient Tests in Horizontal Wells
Authors: Su Ho-Jeen , Kabir C. S. , Dismuke C. T. 
Published: December 2007

Abstract
Uncertainties arise while interpreting transient tests in horizontal wells. This study presents a hybrid approach in that both analytic and numeric models are used to circumvent most of the problems associated with the conventional analytic interpretation.
This novel approach entails multiple steps. Initially, reservoir parameters are estimated by identifying as many flow regimes as possible using the analytic method. Thereafter, a numeric simulation model is built using a coupled wellbore-reservoir simulator. Herein, we seek to match the wellbore flow profile data, collected by production logs (PL), by adjusting local permeability and skin. This PL-matched model then allows rate calculation during the transient-test periods, using measured bottomhole pressure as the inner-boundary condition. Finally, the computed rate is convolved with pressure to interpret the drawdown data for seeking reconciliation with buildup interpretation.
We present two field examples to illustrate the application of the notion presented here. Complications arise while interpreting flow and buildup tests using conventional tools, because of complex well trajectories penetrating this heterogeneous carbonate reservoir. Results show that reservoir anisotropy (kv/kh) is a very sensitive parameter and is therefore well determined. The history-matched model was quite successful in predicting the water cut behavior over 18 months in one of the wells.
Advances in Multilayer Reservoir Testing and Analysis using Numerical Well Testing and Reservoir Simulation
Authors: Jackson R. R. , Banerjee R. 
Published: December 2007

Abstract
This paper presents multilayer testing and analysis techniques to obtain layer permeabilities and skin factors using pressure and flowrate transient data from sequential flow tests acquired with production logging tools. The analysis of these tests by application of numerical well test analysis is highlighted. An integrated workflow is shown and a new analysis technique is presented which incorporates numerical reservoir simulation and an automated history matching procedure. A gradient method has been successfully applied to modify simulation model input parameters to match synthetic and field examples of multilayer transient tests. The study also highlights the potential for the application of this method and for automated history matching techniques to pressure transient and flowrate transient analysis and multilayer test analysis and interpretation.
Vertical Interference Testing Method Using Dual Completions with Downhole Water Sink
Authors: Ramos Luis R. , Shirman Ephim I. , Wojtanowicz Andrew K. 
Published: December 2007

Abstract
Downhole Water Sink (DWS) well completions segregate production in the wellbore by producing water from the water leg in the reservoir and oil from the upper oil bearing portion of the reservoir. A downhole pump drains water from the bottom completion and creates pressure drawdown that inhibits water coning up to the upper producing zone. The pump injects the water to a disposal zone lower in the wellbore.
Successful application of DWS technology in wells with water coning problem requires effective zonal isolation between the top and bottom completions of the well and good knowledge of permeability anisotropy. As these wells are dual completed, they are uniquely configured for vertical interference testing. The problem is that such test involves two fluids, water and oil, and is typically performed in a reservoir rock with no isolating layer between the top and bottom completion.
The paper presents a new mathematical model and analysis method for vertical interference testing using top completion (in the oil leg) for production, and bottom completion (in the water leg) for observation. The model is analytical and accommodates partial penetration and permeability anisotropy. The analysis method employs a family of type curves. Also shown in the paper are examples of possible applications of this new testing method.