bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Successful Caprock Queen Water Flood - New Mexico's First
Authors: Riley E.A. 
Published: December 2007

Abstract
As a result of water flooding, some 30-million bbl of oil should ultimately be recovered from the Caprock Queen pool in southeastern New Mexico. The field is a consolidation of the Caprock Queen and Drickey Queen pools (Fig. 1), two separately discovered fields which were joined by subsequent drilling operations during their late primary lives. Practically the entire field is being flooded under unitized operation utilizing an 80-acre five-spot pattern contrived mainly by converting producers to injection status. Eight units have been formed and are injecting water. Only a few productive tracts are still nonunitized; however, efforts to place them in an offsetting unit are continuing. The advent of waterflood activity in New Mexico has added tremendously to the amount of recoverable oil reserves for the state. Obviously, these added reserves would be unrecoverable by primary production methods. Those units approved and injecting water prior to Nov., 1959, are operating under nonrestricted allowables, whereas those formed after this date are authorized to operate under a rule which carries allowable restrictions.

Introduction
Water injection as a secondary recovery technique has just passed its infancy in New Mexico. Although one earlier effort in the state had been reasonably successful, the two pilot floods initiated by Ambassador Oil Corp. and Graridge Corp. in the northern end of the Caprock field in late 1956 can justifiably lay claim to being the "trigger" of concerted waterflood efforts in the state. These two projects proved conclusively the Queen sand in this field could be successfully flooded. The highly impressive performance of the two pilot floods resulted in their inclusion in unitized operations. Unitization efforts then progressed southward, leading to the formation of eight units-seven consisting of wells mainly drilled during primary development and one, the Pebble Queen Unit, containing wells which resulted from secondary-stage "fringe drilling" along the western edge of Unit No. 2 (Fig. 2). Obviously, other undrilled locations along edges of the field will be developed, particularly along the central sector. Unit Nos. 1, 2 and 3 and the John Trigg project operate under the old allowable rule which permits high injection and production rates. The Drickey Queen was injecting water prior to the Roswell (N. M.) hearing but has chosen to operate under Rule 701. The other units commenced injecting water after Nov., 1959; consequently, they operate under the latter rule.

Location
The Caprock-Drickey pool is located along and adjacent to the boundary line between Lea and Chaves counties, N. M., in Townships 12, 13, 14 and 15 South Range 31 East, and Townships 12 and 13 Range 32 East.
JPT
P. 1195^
Brine Disposal Into a Tight Stress-Sensitive Formation at Fracturing Conditions: Design and Field Experience
Authors: Settari Antonin , Warren G. M. , Jacquemont Jerome , Bieniawski Paul , Dussaud Michel 
Published: December 2007

Summary
This paper describes a study of the potential of a tight reservoir zone for disposal of brine generated in salt cavern leaching operations. The study included field injection testing, numerical analysis using uncoupled and coupled reservoir, geomechanical and fracturing modeling, laboratory work and design of a field injection monitoring program. It was shown that a surprising brine disposal capacity exists in the tight (0.03 md) Oriskany target formation. Initial screening was followed by carefully designed injection testing, laboratory work and subsequent evaluation with the aid of detailed coupled fracture and reservoir numerical models, and numerical well test analysis. Low initial estimates of brine disposal capacity were increased significantly by incorporating more sophisticated, coupled reservoir and geomechanical numerical models. The models, which account for stress dependent porosity and permeability and fracture propagation, were calibrated to laboratory and field test data. Using these models, an excellent match of the injection data was obtained, and predictions of injectivity were made under various project scenarios. The coupled model has been also used to design the monitoring program for the first phase of the injection operations.
Prediction of Permeability from the Skeleton of Three-Dimensional Pore Structure
Authors: Liang Z. R. , Philippi P. C. , Fernandes C. P. , Magnani F. S. 
Published: December 2007

Summary
The main purpose of the present work is to predict the permeability of a porous medium from its three-dimensional (3D) porous structure network. In this work, 3D porous structure is reconstructed by the truncated Gaussian method using Fourier transform and starting from a 2D binary image obtained from a thin section of a porous sample. The skeleton of the 3D porous structure provides a way of visualizing the graph of the pore network. It is determined using a thinning algorithm, which is conceived to preserve topology. It gives both visual and quantitative information about the connectivity of the pore space, the coordination number for every node and local hydraulic radius. Once the network of the pore structure is obtained, the macroscopic transport properties, such as the permeability, can be predicted. The method is applied to a 500 mD Berea sandstone and the predicted permeability is in good agreement with the experimental value and empirical correlations.
Reservoir Characterization as a Risk-Reduction Tool at the Nash Draw Pool
Authors: Martin F. D. , Murphy M. B. , Stubbs B. A. , Uszynski B. J. , Hardage B. A. , Kendall R. P. , Whitney E. M. , Weiss W. W. 
Published: December 2007

SummaryRecently acquired geological, geophysical, and engineering data at the Nash Draw Brushy Canyon Pool revealed that the initial reservoir characterization was too simplistic to capture the critical features of this complex Delaware formation. A new reservoir description provides sufficient detail to indicate that compartmentalization exists in the Brushy Canyon interval. This new reservoir description is being used to identify "sweet spots" for a development drilling program as well as to optimize reservoir management strategies. This paper presents recent results of an integrated reservoir characterization effort that is being used at Nash Draw as a risk reduction tool.
Phenomenological Modeling of Critical Condensate Saturation and Relative Permeabilities in Gas/ Condensate Systems
Authors: Li Kewen , Firoozabadi Abbas 
Published: December 2007

SummaryThe effects of gravity, viscous forces, interfacial tension, and wettability on the critical condensate saturation and relative permeability of gas condensate systems are studied using a phenomenological simple network model. The results from the simple model show that wettability significantly affects both critical condensate saturation and relative permeability. Relative permeability at some saturations may increase significantly as the contact angle is altered from 0° (strongly liquid-wet) to 85° (intermediately gas-wet). The results suggest that gas well deliverability in condensate reservoirs can be enhanced by wettability alteration near the wellbore.
Estimating Mechanical Properties of Shale From Empirical Correlations
Authors: Horsrud Per 
Published: December 2007

Summary
Borehole-stability prediction requires knowledge of the mechanical properties of the formations which is rarely available in shale sections. This paper presents empirical correlations to assist in predicting shale mechanical properties. The correlations are based on extensive laboratory testing of shale cores primarily from the North Sea. The acoustic P-wave velocity is a primary input parameter in several of the correlations; thus, various sources of the P-wave velocity such as sonic wireline, sonic measurement while drilling (MWD), and acoustic measurements on cuttings may be used to obtain somewhat continuous estimates of shale mechanical properties. Borehole-stability evaluations can be made at different stages in the drilling process (planning, while drilling, and post-analysis). Other applications of the correlations where shale mechanical properties are required are evaluation of overburden compaction during depletion and optimization of the drilling process (selection of bit type, bit parameters, etc.).
On-site Fracturing Disposal of Oilfield-Waste Solids in Wilmington Field, California
Authors: Hainey B. W. , Keck R. G. , Smith M. B. , Lynch K. W. , Barth J. W. 
Published: December 2007

Summary
With an active drilling program that was generating over 90,000 barrels of drilling waste each year, the THUMS Long Beach Unit in Wilmington Field, California, was spending over 3.5 million dollars per year to dewater and ship these solid wastes to on-shore landfills for disposal. In 1994, THUMS implemented an environmentally safe and economic program of hydraulic fracturing for the long-term, onsite disposal of drilling mud, drill cuttings, and tank bottoms. By reinjecting the drill cuttings downhole, transportation, the major portion of drilling waste disposal costs, was eliminated. This paper reviews the regulatory permitting process and addresses injection interval assessment, well candidate selection, fracture containment, and offset well seismic monitoring. The equipment, injection history, and economics of disposing over one million barrels of slurry over a 3-yr period are detailed.
Fluid-Leakoff Delineation in High-Permeability Fracturing
Authors: Valko´ P. P. , Economides M. J. 
Published: December 2007

Summary
Starting from the original concept proposed by Carter, Howard and Fast, this paper reviews the description of fracturing fluid leakoff in view of modeling flow in porous media. It is shown how various linear leakoff models have been developed and why a new, radial leakoff concept is necessary for high-permeability fracturing, where the injection time is commensurable to the response time of the reservoir. Using Laplace space methods, the new radial leakoff law is calculated and compared to linear leakoff. For comparison purposes a calibration test executed in high-permeability formation is interpreted using several approaches, namely: linear leakoff+bulk leakoff coefficient; filter-cake resistance+linear flow in the formation and finally, filter-cake resistance+radial flow in the formation.
Novel Oxidizing Breaker for High-Temperature Fracturing
Authors: Terracina J. M. , McCabe M. A. , Shuchart C. E. , Walker M. L. 
Published: December 2007

Summary
A novel oxidizing breaker system has been developed for fracturing fluids at high temperatures. Below 200°F, the system is not active, but above 200° F, the oxidizing system aggressively attacks the polysaccharide backbone of the fracturing fluids, resulting in a complete break of the crosslinked fluids. In the presence of a gel stabilizer, an intermediate, reactive oxidizing species is formed. The result of this formation is a delayed, soluble, high- temperature oxidizing system.
Controlled viscosity reduction at 200 to 300°F in crosslinked gelled fluids with and without a gel stabilizer will be demonstrated. Testing included model 50 viscosity profiles, high- temperature static break tests, and conductivity testing. Results from all testing showed the effect of oxidant concentration in producing a predictable, controlled break of the thermally stabilized crosslinked systems. Data were obtained in low-pH and high-pH Zr-crosslinked fluids as well as in borate-crosslinked fluids. The delayed mechanism of the new breaker system provides fluids with excellent crosslinked viscosity properties at early times with predictable, long-term viscosity reductions. Case histories show that the breaker system can be used throughout the treatment in the pad fluid, proppant-laden fluid, and flush.
This article provides data that allow significant improvements in job design. The operations engineer can obtain predictable, controlled gel degradation by using the data provided for temperature, gel type, gel stabilizers, and breaker concentration. The results are optimized treatment designs with rapid fluid recovery, improved proppant-bed conductivity, and increased well productivity.
Modeling Foams for Acid Diversion
Authors: Rossen W. R. , Wang M. W. 
Published: December 2007

SummarySuccessful foam diversion in matrix acid treatments depends on foam mobility during foam injection and liquid (acid) mobility after foam injection. We present new coreflood data for both flow regimes. During foam injection in one core, for qualities below about 80%, when gas and liquid flow rates were varied separately, pressure gradient was nearly independent of water flow rate, as reported by Osterloh and Jante for foam below a threshold foam quality. Upon liquid injection after foam, pressure gradient falls to a steady-state value that varies little with liquid flow rate. The transition to this steady-state pressure gradient is strongly affected by gas expansion as pressure falls, which makes extrapolation from laboratory coreflood to field application complex. However, although some gas escapes during this transition period, the foam front does not advance; that is, this escaping gas moves as free gas, not foam.A simple new model accounts for many of the trends observed. This model assumes that foam mobility is controlled, not by foam coalescence and capillary pressure as for high-quality foams, but by trapping and mobilization of foam bubbles of fixed size. This model explains how foam mobility can be independent of liquid flow rate; why steady-state pressure gradient falls moderately during liquid injection following foam; and why this pressure gradient is relatively insensitive to liquid flow rate. Implications of the model for design of foam processes are discussed.
Effect of Drillpipe Rotation on Hole Cleaning During Directional-Well Drilling
Authors: Sanchez R. Alfredo , Azar J. J. , Bassal A. A. , Martins A. L. 
Published: December 2007

SummaryThe effect of drillpipe rotation on hole cleaning during directional-well drilling is investigated. An 8 in. diameter well-bore simulator, 100 ft long, with a 412 in. drillpipe was used for the study. The variables considered in this experimental work are: rotary speed, hole inclination, mud rheology, cuttings size, and mud flow rate. Over 600 tests were conducted.The rotary speed was varied from 0 to 175 rpm. High viscosity and low viscosity bentonite muds and polymer muds were used with 14 in. crushed limestone and 110 in. river gravel cuttings. Four hole inclinations were considered: 40°, 65°, 80°, and 90° from vertical.The results show that drillpipe rotation has a significant effect on hole cleaning during directional-well drilling, contrary to what has been published by previous researchers who forced the drill-pipe to rotate about its own axis. The level of enhancement due to pipe rotation is a function of the simultaneous combination of mud rheology, cuttings size, and mud flow rate. Also it was observed that the dynamic behavior of the drillpipe (steady state vibration, unsteady sate vibration, whirling rotation, true axial rotation parallel to hole axis, etc.) plays a major role on the significance in the improvement of hole cleaning.Generally, smaller cuttings are more difficult to transport. However, at high rotary speed and with high viscosity muds, the smaller cuttings seem to become easier to transport. Generally, in inclined wells, low viscosity muds clean better than high viscosity muds, depending on cuttings size, viscosity, and rotary speed level.
Unconventional Miscible Enhanced Oil Recovery Experience at Prudhoe Bay
Authors: McGuire P. L. , Redman R. S. , Mathews W. L. , Carhart S. R. 
Published: December 2007

Summary
This paper summarizes the conceptual development, reservoir simulation, and field testing of an unconventional application of the miscible enhanced oil recovery (EOR) process at Prudhoe Bay. The miscible injectant stimulation treatment (MIST) process involves completing a well at the bottom of a thick, continuous, watered-out interval. A horizontal lateral is drilled along the base of the reservoir, and a large slug of miscible injectant (MI) is injected, followed by a small slug of chase water. The MI sweeps rock not contacted by previous MI injection and drives EOR oil to offset producers. MI is injected sequentially into several intervals along the lateral to mobilize EOR oil from previously unswept areas. The lateral well is then returned to normal production or injection service.
Simulation data indicate that each MIST well could recover up to 1,000 MSTB of incremental oil at initial rates of up to 1,000 STB/D. Field results have been encouraging. Incremental EOR from the three MIST lateral wells is over 2.1 MMSTB, with peak production rates of about 6,000 STB/D.
Effects of Foam Quality and Flow Rate on CO2-Foam Behavior at Reservoir Temperature and Pressure
Authors: Chang Shih-Hsien , Grigg R. B. 
Published: December 2007

SummaryThis paper reports a series of steady-state CO2-foam flow experiments performed at reservoir conditions of 101° F and 2100 psig. Three flow rates (total injection rates), 4.2, 8.4, and 16.8cm3/h, and five foam qualities, 20%, 33.3%, 50%, 66.7%, and 80%, were used to study how flow rate and foam quality affect foam mobility.Results from these experiments show that foam mobility (total mobility of CO2/surfactant solution) increases with increasing flow rate and foam resistance factor decreases with increasing flow rate. Results also show that foam mobility decreases with increasing foam quality. Foam resistance factor increases with increasing foam quality ranging from 33.3% to 80%; there appears to be a minimum foam resistance factor between foam qualities of 20% and 33.3%.
Mechanisms of Shallow Waterflows and Drilling Practices for Intervention
Authors: Alberty M. W. , Hafle M. E. , Mingle J. C. , Byrd T. M. 
Published: December 2007

Summary
Geopressured water sands near the mudline in deep water, greater than 1,000 ft, have been shown to be hazards when these sands are permitted to flow outside structural and 20-in. conductor pipe. Special drilling practices are required to contain the pressure during drilling and casing operations.
Four mechanisms have been identified as causes of shallow waterflows: (1) induced fractures, (2) induced storage, (3) geopressured sands and (4) transmission of geopressure through cement channels. Geoscience techniques have been developed to aid in the detection of the shallow waterflow mechanisms, prior to drilling. These techniques include seismic stratigraphic interpretation of shallow hazard airgun data and specially processed three-dimensional surveys, and special pore pressure and fracture gradient prediction methods.
Drilling and cementing practices have been developed to minimize the risk of inducing flow behind structural and conductor casings. Each of these flow mechanisms require adapted drilling and cementing practices to prevent potentially damaging flow.
This paper presents best practices developed by this operator along with our contractors to detect, drill, case, and cement shallow waterflows in the deepwater Gulf of Mexico. These practices should be transferable to other similar sites around the world.
Rig-Site Monitoring of the Drilling Fluid Solids Content and Solids-Control Equipment Discharge
Authors: Davison J. M. , Daccord Gerard , Prouvost L. P. , Gilmour Alan 
Published: December 2007

Summary
Many of the key properties of a drilling fluid are adversely affected by the solids entrained during the drilling process. To control the impact of the drilled solids on the fluid properties the engineer at the rig site requires an effective monitoring tool. This paper describes the development and implementation of a technique based on X-ray fluorescence (XRF) spectrometry. The results are shown to be more accurate than traditional methods of analysis.
The speed and ease of use of the XRF technique facilitates multiple sampling from various points in the circulating system and effluent discharges. Two case histories are cited which demonstrate the use of the technique for monitoring the deployment of solids control equipment at the rig site and optimizing its configuration. The overall result is to improve well quality, control costs, and limit the environmental impact of the drilling process.
The Role of a Worldwide Drilling Organization and the Road to the Future
Authors: Boykin G. F. 
Published: December 2007

Summary
After struggling for the past few years with the question "How can we get the highest return for our drilling expenditures?," major operators have arrived at very different answers. Some have responded by moving the drilling function to business units, some by retaining a mixture of centralized and decentralized drilling staffs, and some by outsourcing the function almost entirely.
The purpose of this paper is to describe why one major operator has chosen to keep drilling management as one of its core competencies, and how it continues to use a centralized drilling group to meet its exploration and production customers' needs. Also discussed is the deliberate strategy employed by this operator to meet the challenges posed by the changing exploration and development environment. This strategy included elements to manage people, business and technical processes, and to ensure that the drilling organization captured and shared its experience. This paper describes this strategy, the organization's successes and remaining challenges, and how this organization plans to address these challenges.
Influence of Reservoir Stress Path on Deformation and Permeability of Weakly Cemented Sandstone Reservoirs
Authors: Ruistuen H. , Teufel L. W. , Rhett D. 
Published: December 2007

Summary
The influence of production-induced changes in reservoir pore pressure on compressibility and permeability of weakly cemented sandstones has been analyzed. Laboratory experiments simulating reservoir depletion have been conducted over a range of stress paths that a reservoir may follow. The results suggest that compressibility of weakly cemented sandstones is stress path dependent. Compressibility measured under uniaxial strain conditions, or a stress path defined by a lower ratio of the rate at which the effective horizontal to effective vertical stress were increased than the one associated with uniaxial strain, is more than twice the corresponding value found from the hydrostatic loading experiment. In contrast, matrix permeability measured in the maximum stress direction show no significant stress path dependence.
Experimental results suggest that a better understanding of the stress-sensitive behavior of weakly cemented sandstones can only be gained by dealing more directly with the microstructure of the rock. The stress-path-dependent nonlinear behavior of weakly cemented sandstones is related to effects of shear-enhanced compaction. Increasing cementation has been experimentally shown to reduce stress sensitivity. The observed nonlinearity is attributed to dilatancy rather than shear-enhanced compaction, also reflected by permeability measurements made in the maximum stress direction.