bluuebunny/crossref_metadata_2025_split huggingface dataset:
Deep Hydraulic Pumping-Reno Field
Authors: Hollis R.G. 
Published: December 2007

Abstract
Hydraulic pumps set deeper than all other pumps in the world are producing at rates up to 3,400 BOPD in the Reno field, Wyo. The magnitude of producing rates, operating pressures and well depths provides interesting production engineering problems. This report is concerned with equipment design and layout for surface and bottom-hole pumping systems, and includes recommendations for optimum surface pumping equipment for future batteries. Operating problems associated with high-volume pumping from 15,000 ft are discussed, and plans are outlined for increasing production rates to more than 4,300 BOPD/well.

Introduction
Wells in the Reno field, located near Buffalo, Wyo., are particularly suited for casing-free hydraulic pumping because of their depth, high productivity and low GOR. Production problems have generally been handled by increasing the capacity of the production equipment and decreasing pressure drops in the system. The cost of hydraulic pumping equipment has been on the order of $100,000/ well for tae four completed wells. A study made in an attempt to reduce the cost of production equipment for future wells revealed the capital cost could not be significantly reduced for these 1,200+ B/D wells, but fewer, larger power oil pumps and. engines were recommended for future batteries to reduce operating costs, especially where fuel must be purchased. Since safety of the surface high-pressure oil-pumping system is important, the layout and design of the power oil system were carefully planned.

Initial Development
Recovery of 5,750 ft of oil during drill-stem test No.1 from Government Well 41X-24 in Jan" 1965, signaled the discovery of the Reno field. In Feb., 1966, the four completed wells in the Reno field produced an average of 8,465 BOPD from 15,000 ft. Casing-free hydraulic pumps are used for artificial lift. Development of the field is progressing with six rigs drilling in the area.
Fig. 1 is a schematic drawing of a typical well completed in the Minnelusa (Tensleep) formation. Two of the zones are very fine to fine grain sandstone with dolomitic cement, and the third zone is micro-crystalline dolomite with porosity due to vugs. Table 1 shows reservoir and PVT data of interest. The reservoir originally had a static BHP of 6,600 psi and a low 450 psi bubble point. The crude bad a 34.9° API gravity and a GOR of less than 100 at a 30 psig separation pressure.
The discovery well, perforated in only the two sandstone zones, bad an initial flowing rate of 800 BOPD, but then declined to a rate of approximately 530 BOPD (no water) with a 30 psig tubing pressure. Based on gradient curves, the flowing BHP was estimated to be 5,000 psi, indicating a PI of 0.3. Due to the low GOR, the well could not flow at rates much above 500 BOPD; therefore, artificial lift was installed to maximize production and aggressively determine the well's inflow performance relationships.
Micro-PVT Apparatus Without Mercury
Authors: Laugier Serge , Richon Dominique 
Published: December 2007

Summary
A new type of PVT apparatus is presented that avoids use of mercury and works with small sample quantities up to 10,500 psia [72 000 kPa] and 392°F [200°C]. The equipment is fully automated and the PVT cell is light enough to be weighed with an analytical balance within 10−5 lbm [0.5 × 10−5 kg]. Efficient stirring inside the PVT cell is achieved by use of a magnet rotating in a magnetic field. Internal capacity of the PVT cell is varied by movement of a piston, the displacement of which is measured within 1 μm to perform very accurate volume determinations.
A New Organic Fluid-Loss-Control Additive for Oilwell Cements
Authors: Stout C.M. , Wahl W.W. 
Published: December 2007

Abstract
A new organic fluid-loss additive for neat and gel cement slurries has been developed for use in squeeze operations to provide controlled dehydration of the slurry and, thus, fewer job failures. In addition, this additive provides greater fill-up behind pipe, even in highly porous formations. This material is compatible with bentonite materials and all portland cements, and it does not retard cement setting times of Class A cements or adversely affect the physical characteristics of the set cement. It acts as a thinner for high-gel cements, facilitating their application. It is effective over a wide range of well conditions and should provide improved control of cementing treatments. It is believed that this additive may permit the adaptation of neat portland slurries and permanent completion techniques to conventional squeeze-cementing operations.

Introduction
During the past 15 years, many advances have been made in oilwell cement formulations and application techniques. Recent cement technology has been directed toward "tailor-made" cement systems that achieve low slurry weight, minimize mud contamination, improve pumpability and provide other properties which help overcome the multitude of problems involved in current cementing operations.
One property of conventional neat portland or retarded cement slurries which has merited considerable study has been filtration control. Particular emphasis has been placed on developing adequate testing equipment and procedures which will simulate temperature and pressure conditions encountered during a well cementing operation. Various additives or admixes, developed to impart low filtration characteristics to cement slurries, have lost favor since development of more rigorous but realistic testing procedures. Good agreement now exists between the many different research organizations, so that the current tests developed by API Committee constitute a realistic yardstick by which newly developed additives can be evaluated properly. Also, cement systems employing these additives can be used in actual field operations with a greater certainty of success than ever before.
Analysis of the Flow of Gas Through Low-Permeability Porous Media
Authors: Newberg Mary Aylward , Arastoopour Hamid 
Published: December 2007

Summary
A computer program based on the continuity and momentum equations for prediction of the flow of gas through low-permeability porous media was developed. This program uses the FORSIM code, which is based on the method of lines and several integration algorithms. Transient gas flow rates predicted with the computer program were compared with Inst. of Gas Technology's (IGT's) data for both partially water-saturated and dry tight-sand core samples.
Calculation of Vertical Fracture Containment in Layered Formations
Authors: Fung R. L. , Vijayakumar S. , Cormack Donald E. 
Published: December 2007

Summary
An analytic procedure for calculating vertical fracture extent in symmetrical trilayered formations was extended to multilayered, asymmetrical formations using a semianalytic technique. The fracture extents computed by this method were compared with those calculated with the finite-element method. It was found that even for modulus variations between layers as large as a factor of 5, the semianalytic procedure gave exactly the same results as the finite-element solution in a fraction of the computation time and with significantly less manual data manipulation. It is recommended that the analytic and numerical procedures be used in a complementary manner to calculate fracture-width profiles in layered formations.
DeMoss Flood Handles Early Water-Breakthrough Problem
Authors: Riley E.A. , Williams B.G. 
Published: December 2007

Introduction
The DeMoss field located in Archer County, Tex., 7 miles southeast of Archer City, is being water flooded under a unitized program (Fig. 1). The correct name for the unit is "Strawn (Basal) Sand Reservoir Unit"; however, for brevity and convenience it will be called the DeMoss flood in this paper. The purpose of this report is twofoldit is a case history of waterflood operation, andit shows how the profit and ultimate oil recovery were increased by the use of equipment designed to handle large volumes of fluid.
Two features,very high vertical permeability andhigh horizontal-permeability variation in portions of the pay zone, are believed largely responsible for early and excessive water breakthrough during waterflood operations.
The possibility that this solution to the problem of excessive water production in water floods could be instrumental in the development and production of waterflood reserves, which otherwise may be uneconomical, has been an added stimulus in the preparation of the paper.

Primary Development and Production History
The discovery well, A.J. DeMoss No. 1 (Unit Well No. 3–1) was completed in Nov., 1949, in open hole from 3,598 to 3,608 ft, flowing 302 BOPD and no water. Rapid development on 10-acre spacing followed, resulting in 27 producers by June, 1950 (Fig 2). General completion practice was to drill a few feet into the pay section with rotary tools, run electric logs, set and cement either 5 - or 7 in. production casing in a lime cap over-laying the pay zone. The wells were then swabbed-in on a flowing status. Very few of the wells had the entire pay zone penetrated by the wellbore. Production by solution-gas drive first began to decline in Nov., 1950; consequently, small hydraulic-fracture treatments were applied to a majority of the wells during Jan., 1951. Primary production peaked at 35,674 bbl of oil in April, 1951, as a result of the frac jobs; then, it declined to a low of 3,150 bbl of oil by Jan., 1957 (Fig. 3). Primary recovery to Jan. 1957, was 1,101,039 STB. An investigation of records revealed that the A.J. DeMoss No. 14 (Unit Well No. 3–14) probably produced 35 per cent of the accumulated, total primary recovery. This high one-well recovery figure is a result of a mildly active water-intrusion in this area acting on this well only. During the primary life of the field, the water encroached updip toward this well, thus sweeping a reservoir area greater than the normal well location. This will logically explain the very high recovery figure for the well.
Gas Invasion and Migration in Cemented Annuli: Causes and Cures
Authors: Stewart R. B. , Schouten F. C. 
Published: December 2007

Summary
A laboratory study has been conducted to identify the various mechanisms involved in the invasion and migration of formation gas in cemented annuli and to develop procedures to stop this process. Mechanisms operate differently in different circumstances, and it is important for the zonal-isolation characteristics of the cement that the preventive procedures used are the appropriate ones.
Dynamic Pore Pressure Ahead of the Bit
Authors: Peltier Bertrand , Atkinson Colin 
Published: December 2007

Summary
An analytic approach is presented in an attempt to improve the understanding of the mechanism of pore-pressure invasion ahead of the bit during drilling. An axisymmetric model accounts for a zone of damaged permeability (skin) on the work front. The effect of rate of penetration (ROP) and rotation speed on the pore pressure at the depth of cut is significant in the lower range of permeabilities, while for the high permeabilities, the skin has an overwhelming control on the pressure invasion.
Simultaneous Underground Gas Storage and Secondary Oil Recovery
Authors: Burke William F. 
Published: December 2007

Abstract
The Ambassador and New York City fields in Clay County, Tex., both of which produced from the Mississippian lime, are two depleted oil fields now being used for the underground storage of natural gas. Both of these fields are recovering substantial quantities of crude oil as a result of the high-pressure gas injection under the gas storage operation. The histories of these fields prior to the storage operations, the reasons for their selection as underground storage reservoirs and their performance both as storage fields and secondary recovery projects are reviewed.

Introduction
The basic function of a gas transmission company is to provide adequate service to its customers under any given load condition. This requires that the gas company contract for sufficient supplies of gas to meet its maximum demand under peal load conditions and provide adequate facilities to move such gas to its markets in the required quantities. Sufficient underground storage will allow the purchase and storage of gas in low-demand periods and the delivery of such gas to markets in the required volumes in periods of high demand. The high-pressure gas transmission lines of today are expensive, and it is extremely important that underground storage fields be geographically situated so that gas can be moved closer to markets in these low-demand periods through existing pipeline facilities. If underground storage can be combined with secondary oil and/or condensate recovery, liquid hydrocarbon recoveries can greatly reduce the over-all cost of underground storage.
Considering the fact that, in the period from 1942 through 1950, our annual system gas purchases had grown from 67,415 MMcf to 150,821 MMcf and anticipating continued rapid growth of the system (particularly the principal market, the Dallas-Fort Worth area); it became apparent that costly additional pipeline facilities to adequately service such growth would soon be necessary.
Rheological Properties of Daqing Crude Oil and Their Application in Pipeline Transportation
Authors: Yan Dafan , Luo Zheming 
Published: December 2007

Summary
The variation of the rheological properties of Daqing waxy crudes with their thermal history and their time effect are discussed. Rheological properties of Daqing crude were determined in the laboratory with rotational viscometers and U-tube devices. The feasibility of using the proper heat treatment to improve the low-temperature flow property of Daqing crude was studied. Field tests on three long-distance heated-crude pipelines showed good agreement with laboratory measurement. A mathematical model for determination of the optimum operation parameters of pipeline transportation is also given.
Interpreting an RFT-Measured Pulse Test with a Three-Dimensional Simulator
Authors: Lasseter T. , Karakas M. , Schweltzer J. 
Published: December 2007

Summary
An interpretation procedure has been developed to analyze repeat formation tester (RFT™) pressure surveys quantitatively during well-to-well interference tests with a three-dimensional (3D) simulator in which only the pressure equation is solved, while retaining saturation effects on fluid viscosity and relative permeability. This approach accurately and efficiently determines location and transmissibility of faults, horizontal permeability of production zones, and vertical permeability of barriers over length scales comparable to reservoir dimensions.
Physics of Blob Displacement in a Two-Dimensional Porous Medium
Authors: Lenormand Roland , Zacone Cesar 
Published: December 2007

Summary
The evolution of the geometry of blobs is observed during displacements in a two-dimensional (2D) transparent micromodel, and such macroscopic parameters as pressure drop and recovery are monitored simultaneously. The results are in good agreement with experiments performed in real media and with theoretical calculations of the conditions required for blob mobilization when the presence of loops in the structure is taken into account.
Detecting Fluid Movement and Isolation in Reservoir Core With Medical NMR Imaging Techniques
Authors: Baldwin B. A. , Yamanashi W. S. 
Published: December 2007

Summary
A medical nuclear magnetic resonance (NMR) imaging instrument has been modified to image water and oil in reservoir rocks by the construction of a new receiving coil. Both oil and water inside the core produced readily detectable hydrogen proton NMR signals, while the rock matrix produced no signal. Because of similar NMR half-lives, the water was doped with a paramagnetic ion, Mn+2, to reduce its relaxation time. This procedure enhanced the separation between the oil and water phases in the resulting images. Sequential measurements, as water imbibed into one end and oil was expelled from the other end of a core plug, produced a series of images that showed the location of the fluids as a function of flow time. For water-wet Berea sandstone, a flood front was readily observed, but some of the oil apparently was left behind in small, isolated pockets that were larger than individual pores. After several additional PV's of water flowed through the plug, the NMR image indicated a homogeneous distribution of oil. The amount of residual oil determined from the ratio of NMR intensities closely approximated the residual oil saturation of fully flooded Berea samples measured by the Dean-Stark method. A Berea sandstone core treated to make it partially oil-wet did not show a definitive flood front but appeared to channel the water around the perimeter of the core plug. The relative ease with which these images were made indicates that NMR imaging can be a useful technique to follow the flow of oil and water through a core plug for a variety of production processes.
Evaluation and Comparison of Residual Oil Saturation Determination Techniques
Authors: Chang M. M. , Maerefat N. L. , Tomutsa L. , Honarpour M. M. 
Published: December 2007

SummaryThe amount and distribution of residual oil saturation (ROS) are critical parameters for determining whether to apply an EOR process to a reservoir. A brief review of available ROS techniques is presented, indicating advantages, limitations, problems, and possible improvements of each technique. Advantages and disadvantages of each ROS-determination technique are summarized. Screening criteria for determining the best ROS technique under certain wellbore or reservoir conditions are presented.This paper also presents results from comparisons of ROS measurements obtained from the literature as calculated from resistivity logs, pulsed neutron capture (PNC) logs, pressure coring, single-well tracer tests, nuclear magnetism logs (NML), carbon/oxygen (C/O) logs, and electromagnetic propagation tool (EPT) measurements. In this study, the ROS measured by each method is compared with that determined by other methods conducted in the same well. The comparison shows that average values of ROS determined by C/O log, PNC-LIL (log-inject-log), and single-well tracer test do not differ statistically when compared with other methods. The resistivity log tends to give higher than average [2 saturation units (s.u.)] ROS measurements, while pressure coring tends to give lower than average (4 s.u.) ROS values. EPT and NML show deviations of about 8 s.u. of ROS values from other methods, which indicates a statistically significant difference.ROS vertical profiles obtained by two different methods from the same well were compared to eliminate the ROS variation resulting from formation depth. The vertical profiles based on ROS zoning and foot-by-foot measurements were studied to provide more "resolution" for comparisons. The results show that discrepancies in measurement methods are more pronounced when vertical profiles are divided into different zones. This could mean that the discrepancies are much greater for some zones than for others. This approach offers the possibility of studying ROS-method discrepancies as a function of different ROS values.
Effectiveness of Screening Tests as Predictive Models for Steamflood Additives
Authors: Strycker Arden R. , Madden Michael P. , Sarathi Partha 
Published: December 2007

SummaryThe control of fluid mobility has become increasingly important to steamflood applications for oil recovery. Most of the EOR projects in the U.S. use steamflooding techniques. The efficiency of these projects is often reduced because such effects as gravity override result in poor volumetric sweep through the reservoir. Additives can improve the efficiency of steamflooding, but screening tests must be performed for selection of the most effective additive for individual applications. As potential additives, nine commercially available sulfonate surfactants were tested with the high-temperature/high-pressure foamability (HTHPF) test procedure, and eight of these were tested with the mobility control (MC) procedure. These surfactants were evaluated at 250 and 425°F [121 and 218°C] in deionized water and in 1% added NaCl. A correlation trend was also found between foam stability measured by the HTHPF test and mobility reduction measured by the MC test. This trend was evident for more than one type of sulfonate at both temperatures; an increase in temperature corresponded to a decrease in foam stability and mobility reduction. The dependence of foam stability on the presence of added NaCl varied from surfactant to surfactant.
Phase-Behavior Correlation for High-Salinity Surfactant Formulations
Authors: Chou S. I. , Bae J. H. 
Published: December 2007

Summary
Many reservoirs targeted for surfactant flooding contain high-salinity brine. When preflushing such reservoirs proves unsatisfactory or uneconomical, it is essential to have surfactant formulations optimized for the reservoir brine. To minimize experimental effort in formulation design, we developed a theoretical model that can quantitatively predict the phase behavior of surfactant formulations mixed with oil. The model considers the effect of salinity, surfactant, alcohol, and oil on the geometry of the interfacial surfactant layer in microemulsions. The phase behaviors of five salt-tolerant surfactants — ethoxylated sulfate, two ethoxylated sulfonates, ethoxylated carboxymethylate, and alpha-olefin sulfonate — with a series of n-alkane oils (C6 through C16) and short-chain alcohols (C4 through C6), were studied and used to evaluate the theory. The optimal salinities of the systems studied ranged from 1 to 22% NaCl.
Model calculations of optimal salinity and solubilization capacity at optimal salinity show excellent agreement with experimental data. The well-known curves of solubilization vs. salinity, which cross over at the optimal salinity, are quantitatively produced for the systems investigated. In addition, the model correctly predicts the transition from lower- to middle- to upper-phase microemulsions as salinity is increased. Hence, it can be used as the basis of a compositional model in surfactant flooding.
Xanthan Stability at Elevated Temperatures
Authors: Seright R. S. , Henrlcl B. J. 
Published: December 2007

SummaryXanthan stability is examined to define more clearly the polymer's temperature limitations as a mobility-control agent. Experiments were performed to probe the relative importance of hydrolysis, oxidation, and helix-coil transitions in xanthan degradation. In the absence of oxidizing agents (i.e., dissolved oxygen), results indicate that free-radical, oxidation/reduction reactions are not the dominant mechanism for xanthan degradation. Depending on the pH, acid-catalyzed hydrolysis and base-catalyzed fragmentation reactions may play important roles. With Arrhenius calculations, it was estimated that under ideal conditions (no dissolved oxygen, pH 7 to 8, and moderate to high salinities), a xanthan solution could maintain at least half of its original viscosity for a period of 5 years if the temperature does not exceed 75 to 80°C [167 to 176°F], New polymers will be needed for chemical floods where xanthan does not have sufficient stability.