bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhanced Oil Recovery and Domestic Oil Reserves 10 Years Later
Authors: Doscher T. M. , Kostura J. A. 
Published: December 2007

Abstract
Domestic crude oil reserves and productive capacity were maintained during the past two decades by a mix of fortuitous events – primarily the discovery of the North Slope. Waterflooding and infill drilling succeeded in boosting national oil supplies in the past, but "new EOR" technology has not similarly succeeded and doesn't promise to do so without new invention. The current engineered fall in prices beclouds the ultimate threat to our nation's competitiveness and survival: that it will not have ready suitable alternate energy supplies when domestic oil production dries up before the turn of the century.
Application of Steam Foam in the Tia Juana Field, Venezuela: Laboratory Tests and Field Results
Authors: Keijzer P. P. M. , Muijs H. M. , Janssen-van R. Rosmalen , Teeuw D. , Pino H. , Avila J. , Rondon L. 
Published: December 2007

Abstract
Laboratory research on the steam-foam process as a means of reducing steam mobility in steam-injection projects indicates that steam-foam formulations, which are effective in pilot tests at low steam temperatures, are not necessarily effective at temperatures over 200°C.
However, long-chain alkylaryl sulphonates exhibit an excellent capability for reducing steam mobility at elevated temperature; furthermore, this class of surfactants is thermally stable. The performance of steam foam with these surfactants has been studied in core-flow experiments at steam-injection temperatures representative of steam operations in the Tia Juana field, Venezuela and as a function of the following parameters: surfactant molecular weight and concentration, the presence of an electrolyte, the addition of small amounts of a non-condensable gas, and steam quality. The surfactant molecular weight and concentration appear to be the main parameters for reducing steam mobility.
The laboratory research was followed by a pilot test, operated by Maraven, in the Tia Juana field, in an attempt to improve the injection profile in steam-soak wells.
The results obtained so far indicate the feasibility of:
reducing the effective steam permeability, • plugging the most depleted layers, diverting the injected steam to non-producing sands, enhancing oil production.
Based on the test results and operational conditions, the possibility of optimising steam-soak operations under Bolivar coast conditions has been established.
Field Evaluation of Interfacial Spreading Agent Using Cyclic Decline Curves
Authors: Blair C. M. 
Published: December 2007

ABSTRACT
A new, organic, interfacial spreading agent was injected during at least one steaming cycle in each of a group of wells producing from Miocene sand. For all treated cycles the average rate of oil produced per unit of thermal energy injected was 67% greater than the rate predicted from cycle-to-cycle decline curves derived from steam-only cycles. In addition, the productivity of all cycles immediately following a treated cycle was 49% greater than predicted from the decline curves.
Application of Darcy's radial flow equation to the field results discloses mean increases in effective permeability to oil of more than 100% in both treated cycles and first posttreatment cycles.
A Laboratory Study of Thermal Oil Recovery Using Horizontal Wells
Authors: Joshi S. D. 
Published: December 2007

ABSTRACT
This paper reports laboratory experimental results of steam-assisted gravity drainage using horizontal wells. The results were obtained for 17°API heavy oil and light refined oil. The oil steam ratios and percentage recovery of original oil in place were measured for two different well configurations, injection well completions, and shale barrier configurations. In addition, the effect of limited steam entry was also studied using a light refined oil.
The experiments were conducted in a box-shaped sand pack with five sides of steel and one side of transparent polycarbonate material to facilitate flow visualization. The results indicate that steam-assisted gravity drainage not only gives a high sweep efficiency but also gives oil steam ratios of about 0.7, indicating a high thermal efficiency for producing heavy oils. Steam-assisted gravity drainage produces heavy oil at a rate approximately three times faster than that obtained with cold oil gravity drainage.
In a uniform permeability pack, initial oil production rates using horizontal injection and production wells are higher than those obtained using a vertical injector and a horizontal producer. For a vertical injector, steam injection near the pack top gave higher and faster oil recovery than steam injection near the sand pack bottom.
In the case of shale barriers, a vertical injection and horizontal production scheme gives faster and higher oil recovery as compared to that obtained using a horizontal injection and production well scheme. A light refined oil was used to obtain limited entry results, where steam injection was confined to 5 to 10% of the length of a horizontal injector. This occurs when a vertically fractured zone intersects a horizontal injection well at 90°. The results indicate that limited entry does not affect total oil recovery. On the contrary, it enhances initial oil production rates.
The above results indicate that steam-assisted gravity drainage is an efficient method for producing heavy oils.
Determination of Minimum Miscibility Pressure Using a High-Pressure Visual Sapphire Cell
Authors: Hagen S. , Kossack C. A. 
Published: December 2007

ABSTRACT
A new high pressure visual cell made of Sapphire has been developed to determine minimum dynamic miscibility pressures (MDMP). The pressure rating of this cell is 50 MPa (7250 psia) at 420 K (300°F). The minimum dynamic miscibility pressure for the system methane-propane-n-decane has been determined using this cell. The MMP is determined by visual observations of droplets of gas passing through the reservoir fluid. By multiple contact between the injected gas and the reservoir fluid the injected gas will dissolve in the reservoir fluid at the MDMP. During the experiment the volumes and compositions of the gas and liquid phases are determined. The duration of such experiment is 2–3 hours. A comparison between the experimental phase behaviour and the calculated results using the Peng-Robinson Equation of State is given. The phase characterization of the Equation of State developed from these experiments is different from the phase match characterization developed from the usual pVT experiments. Simulations of slim tube displacements using the two different characterizations are compared. The simulation of the slim-tube displacements using the phase match based on multiple contact experiments (MDMP's from the Sapphire cell) gives the best overall match of the slim-tube displacements.
The Nature of Polymer Plugging and a Wellbore Treatment To Minimize It
Authors: Treiber L. E. , Yang S. H. 
Published: December 2007

ABSTRACT
This paper presents the results of a study of the factors involved in wellbore plugging by clean polymer solutions. Plugging of injection wells can have a very detrimental effect on the economics of polymer flooding. Polymer plugging was found to be a function of the following four factors: (1) volume injected per cross-sectional area, (2) core permeability, (3) hydrodynamic size of the polymer, and (4) core mineralogy and surface state.
Most polymer flood design testing does not give an indication of plugging behavior. The throughput volumes used are relatively small because the tests are generally not scaled to near wellbore conditions. A system utilizing three-cores of different diameters placed in series was used to simulate the shear conditions at the wellbore and at two locations in the near wellbore vicinity. The results suggest the polymer plugging occurs near the wellbore and that little polymer plugging exists in situ in the reservoir.
Polymer plugging in a core is partly a mechanical filtration process which is governed by the total throughput per cross-sectional area open to flow and by the sizes of the polymer molecules and the pore throats. At the same time, the core composition and the polymer-rock interaction can influence polymer plugging significantly. Selected chemicals which alter the rock surface are effective in the laboratory and are being tested for preventing polymer plugging in the field.
U.S. Drilling: Recent History, Future Expectations
Authors: Dougherty T. 
Published: December 2007

Abstract
Since 1981 domestic drilling activity has declined from nearly 91,500 wells to last year's total of approximately 66,000. Oversupply of natural gas and decline in oil prices, plus political threats and the takeover and restructuring binge engineered in the financial community combined to create a severe downcycle in an industry which has been traditionally cyclical.
The percentage of exploratory success and the overall development of additional supplies of oil and gas has been encouraging. However, since 1984 the U.S. has produced 120 percent of what was found in those years.
The downturn has been accompanied by a reduction in drilling and completion costs so that the ratio between even lower prices than those existing early in 1986 is still favorable on a comparative basis.
Deep drilling has been severely impacted by reduced economics, but the proved existence of opportunity in deep horizons insures that it will increase as economics improve.
Oil prices are not likely to remain below the late-1985 level for any length of time and the rise of demand against the realities of proved reserves insures that a new resurgence fo drilling will appear in the Nineties if not before.
Legal Problems Involved in Deep Drilling: Liability of Nonoperators to Third Parties
Authors: Dancy J. R. , Dancy V. A. , Pearson C. A. 
Published: December 2007

Abstract
Due to falling oil and gas prices and the lack of a market for the natural gas reserves usually discovered in deeper wells, oilfield suppliers are increasingly faced with the situation where they have not been paid for the materials or labor supplied in conjunction with the drilling of a well. In many instances these suppliers are filing oil and gas liens against the well, the leasehold, and the associated equipment of machinery. Where a marginal well or a dry hole has been drilled the proceeds from the foreclosure of the oil and gas lien may not satisfy the supplier's claim, and the supplier may look to the operator or non-operator to satisfy the deficiency.
In many instances, the operator is given control of the developmental activities on the leasehold under the provisions of the Standard Form A.A.P.L. Joint Operating Agreement. The operator is therefore the working interest party which actually negotiates and executes the contracts entered into with the oilfield suppliers. When a supplier's claim has not been satisfied by the operator, and the foreclosure of the oil and gas lien does not yield sufficient funds to satisfy the supplier, the supplier may look to the non-operator for payment. The issue thus presents itself as to whether a non-operator is jointly liable for debts incurred by the operator in the development of the leasehold.
A Microcomputer Approach to Drilling Engineering Problem Solving
Authors: Simpson M. A. 
Published: December 2007

Abstract
A "Drilling Expert System" has been developed for the microcomputer which contains over 100 drilling engineering programs and five drilling engineering "Expert Systems." The system performs many routine drilling calculations which historically have been performed on nomographs, slide rules, hand and programmable calculators and main frame computers. Additionally, seemingly exotic drilling calculations which heretofore were seldom attempted because there was no direct mathematical solution, or calculations consumed far too much time, can now quickly, accurately and unimposingly be executed with this powerful set of drilling programs.
Influence of Reservoir Depth on Enhanced Oil Recovery by CO2 Flooding
Authors: Heller J. P. , Taber J. J. 
Published: December 2007

ABSTRACT
This paper describes a procedure for evaluation of an important aspect of the suitability of a reservoir for CO2 flooding. The concern addressed is whether the attainable injection pressure will be sufficient to compress the CO2 to the density required for efficient carbon dioxide flooding. The relevant factors--the required mimimum miscibility pressure (MMP), and the regional geothermal and fracture gradients--are reviewed briefly. Available data are fit to simple equations, and a formula is given which permits computation of the estimated pressure margin in CO2 floods. This is the excess of the attainable bottomhole injection pressure over the MMP, and it can be used as a figure of merit for this aspect of flood design. A reasonably high value of the pressure margin would need to be combined with other favorable factors to indicate that prospects were good for a successful CO2 flood. Since the fracture pressure increases with depth faster than the required miscibility pressure, the operating pressure margin normally increases with depth. Graphical correlations are presented to permit a quick estimate of the potential for CO2 flooding if only the reservoir depth and API gravity of the oil are known.
Fluid Dynamics of Wellbore Bottomhole Cleaning
Authors: Bizanti M. S. , Blick E. F. 
Published: December 2007

Abstract
Bottom-hole cleaning is a major factor affecting the rate of penetration. At the bit face, fluid flows through the nozzles, across the bottom, and back to the surface through the annulus. The resultant friction and turbulence of mixing causes a great loss of energy. Efficient bottom-hole cleaning must accomplish at least three basic functions: Washing at the mud-rock interfaceControlling "crossflow" and avoiding the regrinding of cuttingsFast-lifting of cuttings around the bit face
The objective of this laboratory student is to investigate the main parameters that control or effect bottom-hole cleaning, which is closely related to the rate of penetration and to point out how each parameter is related to bottom-hole cleaning. In this study the fluid dynamic forces on the cuttings were investigated in the vicinity of the bit.
A better understanding of bottom-hole cleaning should allow an engineer to improve the rate of penetration and minimize drilling costs per foot.
Numerical Simulation of the HASDrive Process
Authors: Hsueh L. 
Published: December 2007

ABSTRACT
HASDrive (Heated Annulus Steam Drive) is an in-situ thermal process for recovering bitumen from tar sands. This paper presents the results of a numerical simulation of the HASDrive process in repeated, elongated well patterns. Results show that the process can effectively recover bitumen from tar sands. In a basic configuration, the cumulative recovery in ten years is predicted to be high, but the rate of production is low during the early steam-injection period. Several well configurations and operating procedures were investigated to accelerate the early year production. The recovery mechanisms and the sensitivity of the process to various parameters are also discussed in this paper.
Reservoir Simulation With Block Gathering
Authors: Heinemann Z. , Munka M. 
Published: December 2007

ABSTRACT
For the history matching of large reservoirs it is necessary to change local parameters after successful global matching. These modifications have to be made only in a relatively small part of the reservoir, but the influence of the whole reservoir has to be taken into account, too.
The new technique "gathering" enables to combine blocks outside the focused area. This not only reduces costs but also increases the chances of success.
Comparative simulations with full and gathered block systems show extensive agreement of the results for the focused area.
A Unique Computer Simulation Model Well Drilling: Part I—The Reza Drilling Model
Authors: Reza M. R. , Alcocer C. F. 
Published: December 2007

ABSTRACT
A new non-linear multidimensional, dimensionless mathematical drilling model for deep well applications, utilizing the Buckingham Pi theorem dimensional analysis technique, has been developed. The parameters included in the three equations of penetration rate, rate of bit dulling and rate of bearing wear are: the weight on bit, the rotary speed, the drilling fluid volumetric flow rate, the bit diameter, the bit nozzle diameter, the bearing diameter, the drilling fluid kinematic viscosity, the differential pressure, the temperature, and the heat transfer coefficient.
The unknown exponents and proportionality constants were determined by using the statistical regressional curve fitting method utilizing actual field data from a 21,000 foot well within the Anadarko Basin located in Caddo County, Oklahoma.
To generalize the model, a parametric study was performed for each of the exponents in each of the drilling equations. Also, a comparison between the derived model and the previously developed model which has been widely used by the industry was done.
It was concluded that the derived model yields more realistic results in terms of factors affecting the deep well drilling process than the model compared in this study. This paper is only concerned with the development of the model and the determination or proportionality constants and unknown exponents. The remaining material will be presented in Part II of this series of two papers.
Temporary Liners - A Method of Excluding Fluid Injectivity or Fluid Production
Authors: Gore George L. 
Published: December 2007

Abstract
A new-type, temporary, down-hole liner is made of heavy-gauge rubber hose of greater diameter than the well casing, or open hole. It is stretched lengthwise on a special setting tool, which reduces the liner diameter sufficiently so that it may be lowered by wire line to the proper depth. There, the liner is released, returns to its normal diameter, the resulting pressure-fit sealing off that particular section of formation so that fluids cannot penetrate from the wellbore. A special hydraulic setting-retrieving tool, for use in conjunction with this liner, is also described.

Introduction
A recent innovation in down-hole equipment is a temporary linear which can be set in casing or open hole, to seal off perforations or permeable zones, and later can be retrieved when no longer needed. This liner is simple in construction, economical in cost and efficient in operation.
Essentially, the temporary liner consists of a length of large diameter rubber hose and operates on the principle that, if such a hose is stretched lengthwise, the cross-sectional diameter is reduced. Likewise, when the tension is released and the hose is allowed to return to its original length, the original diameter is restored also. If the diameter of the hose is greater than the casing in which it is released, a tight-pressure fit is obtained, holding the liner in place and sealing off any fluid flow into the adjacent formation [Fig. 1].

Liner Construction
The liner is constructed of special four-ply, nylon-cord-reinforced rubber hose and is available in two standard diameters - one for 5-in. casing and the other for 7-in. casing [as shown in Fig. 2]. Any desired diameter can be made on special order. The hose diameter is slightly larger than the casing in which it will be used, a 5 3/8-in. OD size being used in 5-in. ID casing. The liner length varies, ranging from 10 to 50 ft, as each liner is prepared to match specific well requirements.
The ends of the liner are tapered down to a smaller diameter, the 5 3/8-in. hose being reduced to 4 9/16-in. at the ends. A short, drillable brass sleeve is riveted into either for gripping and stretching the hose. Fig. 5 is a cross-sectional end view of a liner, showing the nylon ribbing in the hose and the internal brass sleeve.
Experimental and Theoretical Considerations for Diverter Evaluation and Design
Authors: Beck F. E. , Langlinais J. P. , Bourgoyne A. T. 
Published: December 2007

ABSTRACT
Until sufficient casing can be set to allow a well to be shut-in during a threatened blowout, diverter systems are used as a means of well control. Diverters permit flow to be directed away from the rig and rig personnel while minimizing pressures in the well. If the well were to be shut in prior to setting sufficient casing, contained pressures could fracture the formations at the conductor shoe and possibly broach to the surface.
Diverter systems must be designed to provide backpressures which will not result in fracture at the conductor shoe. Current diverter sizing calculations often assume atmospheric pressure at the diverter exit and assume that the component of the pressure gradient due to fluid acceleration effects is negligible. This study has shown experimentally that these assumptions introduce large errors into the calculation of backpressures. Experiments were carried out in model diverter systems for a wide range of critical flow rates for both gases and gas-liquid mixtures. Improved pressure loss calculation procedures were developed which gave acceptable agreement to the experimental results.
Green's Functions for Solving Unsteady Fluid Flow Problems in Naturally Fractured Reservoirs with Arbitrary Fracture Connectivity: Part II—Applications
Authors: Wijesinghe A. M. , Kececioglu I. 
Published: December 2007

ABSTRACT
A general theory of Green's functions for solving unsteady fluid flow problems in naturally fractured reservoirs was presented in Part I of this paper. The governing equations for the fracture and pore system pressures are two linear parabolic partial differential equations which are coupled by a pressure-history dependent interporosity fluid transfer term. This model allows for the connectivity and permeability of both the fracture and pore systems over macroscopic distances and incorporates an improved unsteady interporosity flow model that is valid for general fracture configurations.
In this paper, we present a simple technique for deriving the Green's functions and source solutions required to solve unsteady flow problems by the theory developed in Part I. The technique is based on the solution of the eigenvalue problem for the Laplace operator and can be applied to solve a class of problems in which the boundary conditions for the fracture and pore system pressures are uncoupled and have the same functional form. Tables of Green's functions and source functions are presented for layered and rectangular reservoir configurations in bounded and unbounded domains.
Development Model for Geothermal Reservoirs
Authors: Marcou J. A. , Gudmundsson J. S. 
Published: December 2007

Abstract
The deliverability of liquid-dominated geothermal reservoirs is presented in terms of reservoir performance, inflow performance, and wellbore performance. Water influx modeling is used to match the performance of Wairakei in New Zealand, and Ahuachapan in El Salvador. The inflow performance is given in terms of a linear productivity index for liquid-only flow, and a solution-gas drive relationship for two-phase flow. A 9-5/8 in. production well is assumed, flowing 250°C water from 900 m depth, and with a wellhead pressure of 100 psia. A geothermal development model that couples reservoir deliverability and power plant performance is used to illustrate how the development cost of geothermal electric power projects can be estimated.