bluuebunny/crossref_metadata_2025_split huggingface dataset:
Advancements in Drill Stem Testing Through the Use of Annular Pressure Responsive Equipment and Improvements in Open Hole Testing Through Inflatable Packer Systems
Authors: Hortman Norman G. , Callis Cliff G. 
Published: December 2007

ABSTRACT
Many advancements have been forthcoming over the past decade in relation to new techniques in testing of oil and gas reservoirs. Perhaps the most significant advancement over the past decade has been the use of annulus pressure responsive testing tools. We will endeavor in this paper to present a state of the art on all of the various tools including valves, sampling equipment, etc. used in an annulus pressure operated string.
We will give a general run down on the success and failure of these tools which have been used extensively in North Sea and Far East operations. Additionally, we will present conclusive arguments to prove the need for the use of annular pressure responsive tools both on land and in shallow water operations.
The advantage of APR® tools is that they allow opening and closing of the tool to the samples or other operations without rotation or reciprocation of the testing string. This, of course, allows for a much safer operation on non-rigid drilling platforms. The enhanced safety from such an operation also makes this system applicable on land and jack-ups in relatively shallow water where high pressure or H2S environments create unusual safety problems.
Additionally, a general run down on the state of the art will be given in reference to a new inflatable testing packer which has found widespread use. The obvious advantage of an inflation packer is that they require no weight to expand and are more functional in larger washed out holes than conventional weight operated packers. Their use in drill stem testing requires the application of a down hole pump since surface pump pressure cannot be utilized with an empty or partially empty drill pipe.
A new inflation type testing packer system has recently been introduced with excellent success and customer acceptance. We will describe the developmental efforts and more specifically the field experience gained since introducing the system.
Waterflooding Performance and Pressure Analysis of Heterogeneous Reservoirs
Authors: Osman Mohammed E. , Tiab Djebbar 
Published: December 2007

ABSTRACT
This paper presents a study of fluid flow in heterogeneous porous media. The major part presents a modification to the Dykstra-Parsons method to predict waterflooding performance of multi-layered composite reservoirs. The modification takes into account the variations in reservoir properties and dimensions both vertically and horizontally. Two important cases, constant injection rate and constant injection pressure drop, are considered. It was found that waterflooding performance in multi-layered composite linear reservoirs is mainly controlled by the mobility ratio.
The rest of the paper discusses the pressure behavior of a well located in the center of the multi-layered composite reservoir. It was found that changes in fractional flow rates from each layer and pressure behavior are mainly controlled by transmissibility variations from layer to layer and from region to region.
A Practical Approach in Developing a Stabilizing Assembly for Deep Hole Drilling
Authors: Melton Horace B. 
Published: December 2007

ABSTRACT
The deeper a hole is drilled the more important it becomes to control hole changes and maintain hole straightness. Stabilizing assemblies have been accepted as the best method for accomplishing this. Designing an assembly by evaluating formation conditions proves to be a practical method for stabilizer selection and assembly design.
The Role of Seismic Data in Planning Drilling Programs for Ultra Deep Geopressured Tests in the Gulf Coast
Authors: Kozik Harry G. 
Published: December 2007

ABSTRACT
The success of drilling to deep objectives in the Gulf Coast will depend upon the ability to predict accurately pore fluid pressures and formation fracture gradients for each geological formation before it is penetrated.
With proper processing, seismic can provide the driller reasonable data on the aforementioned critical parameters whereby he can set up his casing and drilling programs to reach his objective safely with minimum cost.
Ixtoc No. 1, Blowout and Control Operation
Authors: Lugo Oscar Luis Ulloa , De Leon Ignacio Osorio 
Published: December 2007

ABSTRACT
The Well IXTOC No. 1 was located 94 km Northwest of Ciudad del Carmen, Campeche in the Gulf of Mexico. The drilling objective was to determine the existence of hydrocarbons in carbonate rocks of the paleocene, cretaceous and jurassic formations; the drilling operation was initiated on December 1st, 1978. On June the 3rd at 2:45 hrs., the Well started to flow out of control. This was the beginning of the IXTOC No. 1 blowout which lasted nine months and twenty-two days.
The purpose of this paper is to describe in a summarized form, the well control activities, including: the operations to reduce the flow of the well, the drilling of the directional control wells Ixtoc 1-A and Ixtoc 1-B, the installations used to assist in the operation and the pumping of fluids from the directional Wells to achieve the dynamic control on the Ixtoc No. 1 Well, that brought about the final plug operation.
Pressure Gradient Determination from the Fluid Density Log
Authors: Sarabian A. R. 
Published: December 2007

Abstract
Pressure gradient determination in production and injection wells is essential to obtain information concerning the effects of flow-rate, pipe size, and pressure on each other. This factor is also used to estimate the power and gas injection-rate requirements for lifting the oil in the case of gas-lift operations.
Although the theory and methods for predicting the pressure gradient in the vertical pipe in which gas, oil, and water are flowing have been developed, the majority of techniques require graphical procedures to calculate the pressure gradients which result in the between 10% to 20% errors.
The present method utilizes the fluid density tool to estimate the density of the fluid in the vertical pipe for determining the pressure gradients when two or three phases are encountered. This technique is much shorter than those given in the literature, and does not include any graphical procedure. Furthermore, the pressure profile can be predicted with higher accuracy than those other methods.
Economic Field Development Planning
Authors: Bennett Paul M. 
Published: December 2007

ABSTRACT
Once a field has been discovered and a general method of reservoir exploitation selected, there are many ways to attain the reservoir management goal, but some ways may cost twice as much as others. The purpose of this paper is to discuss the importance of in-depth, overview development planning and to suggest the timing of such reviews. In general, such planning should consider all field development options rather than concentrate on certain phases while ignoring others that may be equally important. The pertinent development options are listed then discussed with examples.
Early Implementation of A Full-Scale Waterflood in The Abo Reef, Terry Co., Tx. - A Case History
Authors: Benton Jerry P. , Maslanka Paul M. , Smith Robert L. 
Published: December 2007

ABSTRACT
The kingdom Abo Reef Field, located in the northwestern portion of Terry County, Texas is a relatively recent discovery along a linear organic bank trend which is intermittently productive from Eddy County, New Mexico to Hockley County, Texas (Fig. 1). Gulf Oil Corporation operates a major portion of the Kingdom Abo Reef Field, thus enabling Gulf to rapidly apply the technology that is highlighted in this paper.
The first part of this paper deals with the history and initial development of the field with the objective of providing a basis for a waterflood project. The emphasis is placed not on the development of new technology, but rather the application of existing technology in characterizing the reservoir to assist in the early recognition of a low primary recovery factor. An analysis of basic data taken during development and early production operations led to the conclusion that primary operations would result in a low primary recovery, which provides the setting for the waterflood feasibility study. The description of the waterflood feasibility study emphasizes the specific methodology employed to predict the waterflood performance. The physical development of the waterflood is discussed which emphasizes both the infill expansion project and the water-injection systems. The paper concludes with a discussion of the present operations and a review of the flood's performance.
Interest in Abo carbonate reservoirs began with the discovery of the Lovington Abo Field in Lea County, New Mexico in 1951. Subsequent discoveries were made in the Empire Abo Field in 1957 and Vacuum Abo Field in 1960 along what is today called the Abo Reef Trend. It is along this geologic trend in Terry County, Texas that the Kingdom Abo Reef Field is located.
Carbon Dioxide Foam Rheology in Porous Media: a CT Scan Study
Authors: Du D. , Zitha P. L. J. , Uijttenhout M. G. H. 
Published: December 2007

Abstract
Carbon Dioxide (CO2) foam has been widely studied in connection with its application in EOR. This paper reports an experimental study concerning CO2 foam propagation in a surfactant saturated Bentheim sandstone core and the subsequent liquid injection with the aid of X-ray Computed Tomography (CT). The experiments were carried out under various system backpressures. It is found that CO2 foam flows in a characteristic front-like manner in the transient stage and the water saturation keeps at relatively high level at the outlet of the porous media due to CO2 solubility and capillary end effect. The subsequent surfactant solution injection shows a significant fingering behavior, accompanied by a low flow resistance over the core. It is also found that CO2 foam flow shows higher liquid saturation near the outlet and lower pressure drops under higher system backpressures. This can be attributed to the solubility of CO2 in the liquid phase. The results indicate the advantage of using foam in EOR process such as water alternating foam (WAF), where foam flow has higher sweep efficiency and stronger mobility control ability compared for instance to WAG. Nevertheless, care should be taken during water injection stage in order not to favour the fingering.
Multiple Application of Image Log Data to EOR Operations in the Cooper Basin, Australia
Authors: Mildren S. , Burgess J. , Meyer J. 
Published: December 2007

Abstract
Reservoir geometry, natural fracture networks and in situ stress directly impact on the planning and implementation of flooding operations. Image logs were acquired from two wells in Field A, the Cooper Basin, with three main objectives in mind: increase confidence on the distribution of oil reservoir sand prior to in-fill drilling; quantify natural fracture populations and assess their possible contribution to production from a tight reservoir, and; quantify the contemporary stress regime and consider its bearing on idealised flow direction.
Tectonic tilt and palaeocurrent indicators were identified in conjunction with natural fractures and in situ stress features from both wells. Palaeocurrent flow directions confirmed a dominant transport direction to the south. However, sediment transport within the Tirrawarra Sandstone reservoir is clearly to the northeast parallel to the strike of the Field A structure. This implies enhanced permeability parallel to this direction due to grain stacking.
Natural fracture density is more enhanced at the crest of the structure than the flanks and the dominant 065°N natural fracture trend is predicted to have greater hydraulic conductivity with respect to the in situ stress field.
The in situ stress field was determined to be strike-slip with σHmax oriented approximately 117°N defining a third permeability enhacement associated with Field A. Without further knowledge of the relative magnitudes of each of these permeability enhancements, it is recognized that EOR patterns planned in an east-west orientation will maximize flooding and sweep efficiency within the Tirrawarra Sandstone oil reservoir.
Utilization of Composition Observation Wells in a West Texas CO2 Pilot Flood
Authors: Henry R. L. , Feather G. L. , Smith L. R. , Fussell D. D. 
Published: December 2007

Abstract
Two composition observation wells were drilled in a tertiary CO2 pilot in the Levelland Field, Hockley County, Texas. The purposes of these wells were to 1) confirm the laboratory determined mechanism of oil displacement from the composition analysis of mobilized fluids; 2) obtain mixing zone length and growth information to improve estimates of CO2 requirements for fieldwide floods; 3) determine relative mobilities of the various banks, and 4) obtain information on CO2-reservoir rock interactions.
Composition observation wells were drilled 15.2m and 44.2m from an injection well and inline with a central producing well. The composition wells were completed in a 10.7m interval of the total 54.9m pay section. Representative reservoir fluid samples were obtained periodically (usually once a week) from these wells through the use of a bottom-hole sampler, and the volumes of the various fluids (gas, oil, and water) collected were measured. The composition of the hydrocarbons was determined by chromatography techniques. This permitted a composition profile of the oil moving zone (CO2-oil mixing zone) to be determined for each of the wells. The ionic concentration in the water was determined by standard mineral analyses.
Composition data confirmed miscible tertiary oil displacement. A small CO2-free oil bank was detected followed by a relatively large oil moving zone which grew with distance traveled from the injection well. The initial analysis of the oil moving zone growth was consistent with a laboratory determined correlation based on first contact miscible fluids. Volumetric data, which are the changes in bottom-hole water-oil ratio with time, indicated more than one zone was swept by the carbon dioxide. Logging observation well data confirmed this conclusion. Bottom-hole pressure data recorded in the composition observation wells showed a cyclic trend with higher pressures occurring during the CO2 injection cycle and lower pressures occurring during the water injection cycle. Preliminary calculations of the total mobility of fluids flowing between the observation wells suggested an in-depth mobility reduction during the CO2 slug process as compared to the pre-CO2 waterflood. Analyses of the water obtained in the sampler indicated CO2 displaces connate water and slowly reacts with the reservoir rock.
Manvel Enhanced Recovery Pilot - Performance Evaluation
Authors: Widmyer Richard H. , Pindell Robert G. 
Published: December 2007

Abstract
A surfactant-polymer pilot flood was conducted in the Manvel Field, Brazoria County, Texas. The chemical system, reservoir matrix and fluid parameters, pilot design and implementation equipment and procedures were described in a previous paper.1 The purpose of this report is to present the test results and conclusions based upon an interpretation of the performance response.
The objectives were to test the effectiveness of a brine-tolerant chemical system in the presence of a high salinity, active water drive where formation preconditioning was not applicable. The relatively high temperature of the 6 m thick, 1646 m deep sandstone reservoir was 75°C. A number of similar reservoirs exist on the Gulf Coast.
As shown in Figure 1, the well array consisted of 2 injection and 3 production wells in a line drive configuration, with 142 m between adjacent wells. The pilot was located in a fault block and aligned with a water drive source from the southwest across the non-sealing Natali Fault. Injection and production rates were optimized at 159 m3/day/injection well and 175 m3/day/production well.1 The total production rate exceeded the injection rates to maximize capture and confinement.
A Computer Model for Comparative Economic Analysis of Enhanced Oil Recovery Projects
Authors: Cronquist Chapman , Secrest E. Leigh , Jones Jack W. 
Published: December 2007

ABSTRACT
A computer model has been developed for comparative analysis of EOR project economics which affords the versatility to analyze economic sensitivities for most injection sequences and economic aspects of several different types of enhanced oil recovery processes.
Input of economic parameters is in terms of constant value dollars for investments and operating costs. Input of project performance is by specifying cumulative fractional oil recovery versus cumulative pore volumes of material injected. Risk can be appraised by input of three such relations, i.e., "expected", "good", and "poor" performance, each of which can be probability-weighted. Conversion to time-rate of recovery is done internally, either through input transmissibility data or user specified pore volume injection rate for each injection stage.
Economic sensitivities to various input parameters are in terms of a new economic parameter, "present value cost per present value barrel", which was developed in the course of this work.
Project performance and economic data from Maraflood projects in Pennsylvania and Illinois were utilized to demonstrate model capability. Economic sensitivities are presented for variation in: barrels per acre-foot recovered, time rate of recovery, cost of chemical slug, cost of polymer, initial investment, and direct operating cost.
The model is intended primarily for investigation of economic sensitivities to parameters like: oil in place at project initiation, recovery efficiency, transmissibility, and material-investment-operating costs. It is not intended for a stand alone evaluation of the feasibility of undertaking a specific project, although it can be used in support of programs designed to do so.
A Type Curve Approach to Reserves for the Big Piney Gas Field
Authors: Hale Brent W. 
Published: December 2007

ABSTRACT
Various methods have been used to define the reserves for the Frontier/Muddy formations of the Big Piney Gas Field. This paper reports the results of a study based on production histories interpreted with constant pressure type curves. Over 80 wells were studied in detail with resulting data used to develop relationships between rate, permeability, and net pay. Using these empirical relationships, reserves for the field were determined. Gas-in-place was calculated for each well as well as effective drainage area and recovery efficiency. Individual well deliverabilities were calculated. A relationship between effective well spacing and recovery was developed.
The results of the study generally agree with previous work. The type curve approach should prove useful in providing details about effective gas-in-place and drainage area. This is not easily obtained from conventional testing. It also provides a link to analyzing newer tight gas wells by showing that type curve solutions are valid over the life of a well.
Greater Green River Basin Stratigraphy as IT Relates to Natural Gas Potential
Authors: Newman Harry E. 
Published: December 2007

ABSTRACT
Major reserves of natural gas remain to be discovered in the Greater Green River Basin of southwestern Wyoming and northwestern Colorado. This basin, occupying approximately 21,000 square miles, includes four sub-basins. These are the Green River Basin proper, west of the Rock Springs Uplift, and the Red Desert, Washakie, and Sand Wash Basins, on the east side of the uplift. Thick sections of Tertiary and Upper Cretaceous rocks exist throughout most parts of the Greater Green River Basin. Drilling depths to penetrate these sections range from relatively shallow depths on the flanks of the individual basins to depths greater than 20,000 ft in certain areas of the Green River Basin proper. The Mesaverde Group, Lewis, Lance and Lower Tertiary Fort Union and Wasatch Formations have significant thick intervals of tight and near tight sandstones containing natural gas. Most of the new discoveries will probably come from stratigraphic traps. Although many of these reservoirs are currently non-commercial, there is a tremendous future potential with improvements in drilling and completion practices. With increased gas prices, new interests in deep drilling have been created.
Five generalized lithofacies maps of the environments of the Upper Cretaceous section of the Greater Green River Basin of Wyoming were constructed to provide information on the productive areas of the stratigraphic section. These maps also indicate the extent of these intervals in the basin, those areas in the basin with the thickest section and some key strand plain trends. This report and the lithofacies maps should provide a good overview of the geology of the Upper Cretaceous and Lower Tertiary stratigraphic section in the Greater Green River Basin of Wyoming and help determine where the most future potential exists for natural gas.
Mobility Control, A New Tool Engineering
Authors: Schurz George F. 
Published: December 2007

Abstract
A new tool has become available to the water flood engineer as a result of recent discoveries in polymer chemistry. It is now possible to treat injection brines with appropriate polymeric materials to reduce the mobility of the brine solution in the formation. This permits the adjustment of the water oil mobility ratio to the most advantageous point for efficient oil recovery.
Standard calculation procedures of reservoir engineering can be applied to estimate maximum recovery improvement through the use of polymer solutions, however, the economic optimum point is not calculable by prior techniques. The ability to predict recovery improvement, however, makes it possible to eliminate fields where mobility control is not required and also to decide on an appropriate value of mobility ratio to use on the field in question.
The equipment used for a mobility-controlled flood is primarily standard oil field equipment. Capital expenditures for such equipment are negligible. The polymers used present no special problems of toxicity or corrosiveness.

INTRODUCTION
Recently announced discoveries in water flooding have yielded new techniques of potentially great benefit to the petroleum industry. It has been shown that certain water soluble polymeric materials may be dissolved in water flood brine to give a flooding medium whose mobility in porous media is greatly reduced. The extent of the mobility reduction may be varied at will over a considerable range depending On the field conditions. Practical reductions of mobility up to twenty fold have been disclosed.
This reduction in mobility 1s important because by properly controlling the mobility ratio between the oil and the displacing phase important improvements in recovery can be achieved thus potentially improving the economics and hence extending the useful range of the water flooding process. The present paper discusses the techniques and apparatus necessary in the field use of such solutions.
Stochastic Model of Fracture Propagation: Initial Results
Authors: Palmer Ian D. , Carroll Herbert B. 
Published: December 2007

ABSTRACT
A model of hydraulic fracture propagation through a medium which contains variations of in-situ stress has been developed. An expanding fracture is divided into a number of sectors, and a stress intensity factor Ki is calculated at each sector tip. Sector expansion is proportional to Ki and radial fluid flow equations are applied to each sector. Although non-rigorous, the model allows estimates of the likely effects that stress variations have on fracture length and bottomhole pressure. Initial results are presented to illustrate such effects: (1) payzone bounded by uniform higher stress zones, (2) payzone bounded by higher stress zones within which are superimposed random stresses (giving the probability of breakout), (3) alternating sandstone/shale layers with fixed shale stress but random sandstone layer stresses (giving the probability of a fracture reaching a desired length). The results are preliminary and refinements to the model will be made.