bluuebunny/crossref_metadata_2025 huggingface dataset:
Improved Techniques in Laying Underwater Pipelines
Authors: Bauman J.E.
Published: December 2007

This paper presents a brief review of Creole's Pipe Laying experience in Lake Maracaibo prior to 1958 along with a review of the formulation of basic design data, operational procedure and evaluation of two new pipe layer barges which were delivered in 1958.

The New Barges incorporate a number of improvements in equipment design and handling procedures. Some of the more important improvements covered in the paper are listed below:Increase in hull width and depth to improve stability and provide more storage space for pipe.Provision for two welding stations so that two welds can be made simultaneously.Installation of a stiff leg to move pipe from "dumb" barges to the pipe layer barge storage rack.Installation of mechanical handling facilities consisting of air actuated rams, transfer arms, and air powered motors.Provision for two 150 KW diesel electrics sets which furnish power for electric motors used to drive equipment.Addition of neoprene covering on storage and feeder rack areas and pipe handling facilities to reduce the amount of damage caused by storing and handling coated and wrapped pipe.Installation of facilities to improve efficiency of operating personnel.

A brief review is made of the performance of the new pipe layer barges with special emphasis given to increased laying rate, reduction in personnel requirements, and reduction of pipe coating damage resulting from design improvements.
Advances in Drilling Technology (1981-1986) and Where Drilling Technology Is Heading
Authors: Millheim K. K.
Published: December 2007

Major advances in drilling technology development and utilization have occurred over the past five years. This paper presents an overview of the new drilling technology and how it is being applied in field operations. The major technology development topics that will be discussed are: (1) development of computer tools such as new drilling algorithms; (2) real time drilling and communications; (3) advanced designs in bit technology and mud motors; (4) advances in mud and solids control technology; (5) advances in measurement while drilling (MWD) and other drilling technology.

The future of drilling that is presented in this paper is even more exciting. Centralized control of drilling operations will rapidly expand. Closed mud systems and treatment plants along with new super muds will evolve. New smaller automated drilling rigs will be developed. Directional drilling will be used more and more in the development of both land and offshore fields with much longer horizontal departures. New high speed bits and mud motors will compete with rotary drilling. All this new technology will open up new vistas for exploration drilling, deep drilling, and offshore development.
Current State of the Art of MWD and Its Application in Exploration and Development Drilling
Authors: Gearhart M. , Moseley L. M. , Foster M.
Published: December 2007

Today, Measurements While Drilling (MWD) is a widely available and accepted service industry in the international marketplace. As it has matured, the focus has shifted from the novelty of telemetry to the measurements themselves; what can be measured, and how can that information be of value?

The most widely used and best understood service is the directional survey. The promptness and accuracy of MWD surveys has proven to be of real value in the control of difficult directional wells. The MWD service of formation measurements is growing. It is being used, not only for marker selection, but as the sole logging service for some footage. In exploratory wells, the immediate nature of the logs takes some of the guesswork out of the real-time decisions and the quality of measurements made in an undamaged borehole improves interpretation. Evaluation also continues on a host of MWD sensors that bear on the efficiency, safety and control of drilling.
Latest Developments in Tanker-Based FPSO Systems
Authors: d'Hautefeuille B. , Remery G.
Published: December 2007

Nine floating production, storage and offloading (FPSO) systems utilizing tankers (or barges) anchored by single point moorings have been installed or are under construction.

Since the first FPSO system began operation in 1976 a total of almost 40 system-years operational experience has been accumulated. As a result of this experience, component design reflects the particular FPSO environment and reliability has been much improved while system downtime has been reduced.

After broadly describing the nine FPSO facilities, the operational experience of the most essential components and subsystems are detailed. The key elements include: the mooring system, the fluid transfer system, the processing equipment and the cargo offloading system.

Emphasis is put on the fluid transfer system which includes high pressure flexible risers and high pressure swivels accommodating independent paths for crude, gas and water. The principal results are given for a research program investigating high pressure seals for large diameter swivels.

The paper concludes with a near-future forecast of FPSO applications.
The Bluewater Tower Wishbone Mooring System
Authors: van Heijst W. J.
Published: December 2007

The "TOWER WISHBONE MOORING SYSTEM" – a Bluewater concept, is particularly suited to marginal oil field developments in areas with moderate seas and shallow to medium water depths, or where exceptional conditions call for disconnection of the tanker at short notice. Such areas could be those where typhoons occur, or where icebergs or irregular ice coverage may endanger the tanker.

Application of a Tower Wishbone Mooring as a single point mooring for a storage or floating production system eliminates many of the drawbacks of previous SPMs. Those systems usually incorporated a CALM or SALM buoy with the tanker moored via a rigid arm. Elasticity was provided by the buoy's anchoring with the accompanying inconvenience of underwater articulations and/or flexible flowlines.

The Bluewater system is based on the principle of the tanker being moored to a rigid jacket via flexible yokes. Gravity weights incorporated in the yokes are suspended from the jacket via tension members attached to a turntable, thereby allowing the moored tanker to weathervane.
Computerized Field System for Real-Time Monitoring and Analysis of Hydraulic Fracturing Operations
Authors: Cleary M. P. , Buharali A. M. , Crockett A. R. , Salehi I. A.
Published: December 2007

A new calibre of systems, generically denoted as RT-MACS, has been designed and developed for the monitoring, analysis and potential control of hydraulic fracturing treatments in real-time during the field operation. A number of prototypes have been built, based on state-of-the-art computer hardware, ranging from super minicomputers to entirely portable systems. They perform the complete spectrum of functions: data-acquisition from calibrated sensors, data-processing and storage in the central facility, display of processed data on scrolling windows, simulation of the overall process, using realistic engineering models for analysis, and display of overall status, including model results. The models used are unique in many respects: they use real-time data as input; they employ a novel history-matching scheme to determine elusive reservoir and fluid parameters in real-time; and they use the most advanced threedimensional analysis to make calculations for pressures, height, width and length of fractures. Both trailer-transported and portable system prototypes have been suc-cessfully implemented in a number of commercial field operations, running without disruption in standard jobs on cooperative wells provided by interested producing com-panies; their presence had sufficient practical impact that the portable systems are now being offered on a broader scale throughout the industry.
High-Strength Microsphere Additive Improves Cement Performance in Gulf of Bohai
Authors: Wu C. , Onan D. D.
Published: December 2007

Operators in the Gulf of Bohai have practically eliminated remedial squeeze cementing requirements by using encapsulated air as a lightweight cement additive. Air entrapped in hollow beads composed mostly of silicon and aluminum is added to the slurry to allow for mixtures lighter than water, but with necessary strength to provide good primary cement jobs.

Cementing in the Gulf of Bohai is made difficult by bottom-hole static temperatures (BHST) of 275–320°F (135–160°C). Specific gravity of the mud is 1.1 to 1.3. Most wells have three to eight productive zones, making good isolation between zones critical to drillstem testing and future production work. Use of high-strength microspheres (HSMS) as a cement additive has improved primary casing and liner cementing to the point that remedial squeeze cementing in the Gulf of Bohai is now a rarity.
An Overview and Evaluation of the North Burbank Unit Block A Polymer Flood Project, Osage County, Oklahoma
Authors: Zornes D. R. , Cornelius A. J. , Long H. Q.
Published: December 2007

The North Burbank Unit Block A polymerflood project was initiated in September 1980, with the injection of a fresh water preflush into 36 wells within the 1,440-acre [582.7 ha] project area. An economic production response has occurred from the use of the Phillips in-depth polymer-aluminum citrate-polymer process in this naturally fractured sandstone reservoir. The oil production rate now averages over 30,000 BOPM [4,769 m3/M] (mid-1985) from a pre-project rate of less than 15,000 BOPM [2,385 m3/M] and the producing water-oil-ratio (WOR) has been reduced from over 100 to less than 50. Total cumulative oil recovery is projected at over 4.4MM STB [0.67MM m3], near 85% of the pre-project projection, assuming an economic limit of 2 BOPD [0.31 m3/D] per well.

The chemical injection sequence has included 500 ppm active polymer augmented by 500 ppm aluminum citrate crosslinking agent, 250 ppm polymer, 50 ppm polymer, a fresh water postflush, and finally produced brine injection. A total of 4.17 MM pounds [1.89MM kg] of polyacrylamide was injected into 36 wells. Fresh water and polymer production were monitored at 84 producing wells in an attempt to correlate with oil production response.

This paper summarizes the design, operation, monitoring, response, and cost of the polymerflood project. Economical and technical factors to be considered in an expansion project in the North Burbank Unit or in application of the Phillips polymer process in other reservoirs are addressed.
Polyacrylamide Vertical Conformance Process Improved Sweep Efficiency and Oil Recovery in the OK Field
Authors: Surkalo H. , Pitts M. J. , Sloat B. , Larsen D.
Published: December 2007

The OK field is located in Campbell County, Wyoming, USA. The field produces from approximately 8050 ft. (2454 m) and is operated by Universal Resources. The reservoir exhibits a high Dykstra-Parsons variation factor of 0.85 and a mobility ratio of 2.5. The reservoir was produced on primary for approximately 2 years and produced 3.8% OOIP (0.03 PV). Ultimate primary oil recovery was estimated to be 11.8% OOIP (0.09 PV). A waterflood was initiated in a single well and water was injected for 3 months. At that time, the well was treated to improve vertical conformance with a cationic and anionic polyacrylamide and aluminum process. Two production wells were later converted to injection with chemical treatment coincident with water injection. Total recovery of oil as a result of primary recovery and polymer augmented waterflooding was 41.9% OOIP (0.31 PV) as of June 1985. An estimate of 671,035 bbls of incremental oil was produced as a result of the chemical process.

Laboratory radial corefloods designed to evaluate additional chemical oil recovery processes indicate that the potential for additional recovery exists. Mobility control polymer and alkaline-polymer injection into adjacent fields' core and fluid systems recover 0.10 PV and 0.15 PV, respectively, additional oil beyond the waterflood. Surfactant systems (micellar-polymer and low concentration surfactant-polymer) recover an additional 0.31 PV beyond the waterflood in an OK field fluid system.
Evaluation of Gravel Blending and Pumping Techniques for Accurate Control and Protection of the Gravel During the Gravel Packing Operation
Authors: Solum J. R.
Published: December 2007

Due to the high cost of accurately screened gravel and the importance of not breaking or crushing it; the treatment and placement of gravel with surface equipment is a primary factor in proper sand control. Over a period of years various tests have been performed on the placement of gravel. Tables will show the results of the various methods of metering gravel into the completion fluid stream and the results of the efficiency of the gravel pack versus the metering systems. Flow diagrams of the surface gravel placement system and pumping systems will be shown together with photographs of the test operations, both laboratory and field.

Special laboratory equipment was manufactured to accurately inject gravel into the fluid stream. The various progression of this equipment and the field tests of accurate gravel control in the fluid stream will be shown. Test data, together with field data will show the various displacement rates and fluid gravel ratios. Tests are shown of methods to inject gravel into the fluid stream after the pump, to prevent breakage of the gravel during the pumping of the gravel through the pump valves. Results and tables will show the high variance in fluid gravel ratios under the various systems that gravel is now being pumped into the well.

This paper will summarize the methods and equipment being used to pump gravel in the well, together with lab test results and field results. It shows the importance of proper gravel control and treatment of the gravel during the gravel packing operation.
Scale Control During Waterflooding Operations: A Field Appraisal of Inhibitor Requirements and Performance
Authors: Tanner R. N. , Wittingham K. P.
Published: December 2007

To achieve effective scale control when implementing a sea water flooding operation, several facets of the operation must be addressed. The characteristics and potential for scale damage associated with sea water injection, from the injection wells through to the production wells and production facilities following subsequent sea water breakthrough, must be carefully considered. Problems vary in magnitude, for example from increased maintenance costs to at worst malfunction of safety equipment or lost production. Additionally, the scales can be radioactive and consequently require careful handling if they are not to pose hazards to operating personnel.

There is a considerable incentive to implement effective control measures. This paper outlines the experiences of scaling associated with the operation of the Forties Field in the UKCS. It describes the methods used to identify the extent of scaling problems encountered during field operations. It also describes the chemical inhibitor deployment procedures used and discusses the Field techinques employed to monitor the performance of inhibitors.

The principles behind the evaluation could be applied to many operating oilfields with potential scaling problems.
On-Site Testing of Oilfield Waters
Authors: Robinson K.
Published: December 2007

The correct on-site testing of oilfield waters is important for minimising waterflood operating costs and maximising oil recovery. Recent advances in test methods involving core studies, corrosion inhibition and biocides are discussed, in addition to observations on the limitations of certain conventional on-site analytical techniques.
The Role of Reservoir Simulation in Optimal Reservoir Management
Authors: Thomas G. W.
Published: December 2007

This paper discusses the role reservoir simulators play in formulating initial development plans, history matching and optimising future production and in planning and designing enhanced oil recovery projects. The Hibernia Field in Canada and the Hassi R'Mel in Algeria illustrate how simulation can be used to assist in initial reservoir development. The Lookout Butte Rundle (Alberta) and others are cited to exemplify optimisation of future production plans with the aid of simulation. Finally, applications to several reported EOR projects are briefly discussed with major emphasis concentrating on the Bati Raman Field in Turkey.
Evaluation of Long-Term Proppant Stability
Authors: Cobb S. L. , Farrell J. J.
Published: December 2007

This paper presents initial results of a new testing program initiated to determine the performance of natural and man-made ceramic proppants over extended periods of time (months). The mechanisms involved in proppant performance are related to chemical and crystallographic makeup, as well as to processes used in their manufacture. Definition of the mechanisms controlling proppant behavior will allow future product development work to be concentrated on improving performance characteristics.

Data from standarized API permeability/ conductivity testing are presented with a summary of previous long term testing. Results are coupled with new long term permeability data and acid reactivity data. Chemical and crystal structure phase analyses are also reviewed. The various tests were performed on a variety of oxide ceramics (intermediate and high strength proppants) as well as quartz sand.

The long term data show that, after an initial period of consolidation, reductions in permeability over time are very slight for the commercial ceramic proppants tested at conditions of 69 MPa stress, 93°C, flowing a 2% KCl brine. Efforts made to correlate long term performance to short term acid reactivity have not been successful. It is unlikely that the long term performance of different classes of proppant can be compared by analyzing standard acid reactivity data.
Artificial Lift by Hydraulic Turbine-Driven Downhole Pumps: Its Development, Application, and Selection
Authors: Manson D. M.
Published: December 2007

With the increased use of Secondary Oil Recovery Techniques and in particular of pumped artificial lift systems, there was a requirement for a more reliable, flexible and robust form of downhole pump. To this end the author's company has developed the Hydraulic Turbine Drive Downhole Pump. This paper examines the background to and the development of the unit together with a detailed step by step description as to the methods and procedures used when selecting a suitable downhole pump/turbine configuration, for either an oil or water lift application.
Technical Aspects of a Joint China/Canada Mobile Offshore Production System
Authors: Cao J. Z. , Chen K. W. , Gibb P. R. , Gu M. X.
Published: December 2007

Two new mooring system designs suitable for mobile offshore production system have been developed. Both designs are based on field-proven principles and possess excellent dynamic characteristics. The two systems can be completely and easily relocated and their quick disconnect/reconnect feature allows the vessel to quickly depart in case of typhoons.
Elements Affecting Thickening Time of a Cement Blend
Authors: Cobb J. A. , Pace R. S.
Published: December 2007

This paper is a continued study of the work presented in SPE 13041, "Improved Bulk Blending Techniques for Accurate and Uniform Cement Blends." Further investigation was conducted to better understand the factors which affect the physical performance of a cement blend, specifically the thickening time. The variability of neat cement was found to be one of the main elements affecting the thickening time. Cement samples from one load of cement and samples from many different loads were seen to differ significantly in thickening time. It was determined that standard thickening time tests do not necessarily indicate the true responsiveness of a cement. Effects of sampling procedures on thickening times and additive distributi on were investigated. Placement of sample valves was found to be an important factor affecting the sampling. Using proper sampling procedures and by conducting pilot tests with the same cement used to blend a job, thickening times can be correlated between the laboratory and the field. The effects of offshore transportation and transfer of cement blends to the rig were also examined. The uniformity of the cement did not change with the transfer from the boat to the rig with hematite or retarding additives.
A Simple Implicit Model for Thermal Cracking of Crude Oils
Authors: Millour J. P. , Moore R. G. , Bennion D. W. , Ursenbach M. G. , Gie D. N.
Published: December 2007

Thermal cracking product distributions are presented for three oils (8°API, 13°API and 24°API). Tests were performed on oxidized and unoxidized samples (water and rock matrix present) at temperatures of 360°C, 397°C and 420°C for periods of time up to 48 hours. Product yields are reported as weight percent coke, asphaltenes, maltenes and non-condensible gas. Seven sets of experimental data are reported.

Previous thermal cracking kinetic models have been unable to reproduce the following product distribution: The initial time delay in coke production.The early time transfer between maltenes and asphaltenes content.

A simple implicit model which requires a small number of parameters has been developed. It gives a good match of all the experimental sets. The model consists of coke formation versus temperature relationship which contains two parameters; a temperature independent relationship between coke and maltenes; a temperature independent relationship relating coke and maltenes to asphaltenes; and a mass balance to calculate the amount of non-condensible gas.

The model is simple to use and provides an excellent check for the consistency of experimental data. It can very easily be implemented into a numerical simulator.
Laboratory Studies and Field Evaluation of a New Gelant for High-Temperature Profile Modification
Authors: Chang P. W. , Goldman I. M. , Stingley K. J.
Published: December 2007

This paper reports the laboratory development and initial field testing of FLOPERM™ 325, a novel gelant for high temperature profile modification.

The new gelant is a synthetic, thermosetting material which can be used at concentrations of about 1-2% in injection brines. Its gelation rate can be controlled over the range of several hours to about 10 days at temperatures of up to 221°F (105°C), permitting emplacement at varying distances from the injector wellbore. In sandpack testing to simulate gelant performance under reservoir conditions, the new system reduced permeability to brine by more than 90% while retaining most of the original permeability to oil. Moreover, in parallel sandpack tests the gelant selectively reduced permeability in the zone with higher initial permeability. Emplaced gels have retained functional stability in sandpacks for more than ten months at 197°F (92°C).

An injector well test of the gelant was performed at ARCO's Nelson Minnelusa Unit ((197°F (92°C), in Campbell County, Wyoming)) in March, 1984. A 2000-bbl solution was emplaced in the formation over a two-and-one-half day period. Injection profiles showed diversion of injection brines from a water channel to the oil payzone. Enhanced oil recovery and decreased water cut were observed within several months of the treatment and are continuing.
Steam Soak Predictive Model
Authors: Gros R. P. , Pope G. A. , Lake L. W.
Published: December 2007

This paper presents the results of a predictive model (SSPM) to assess the feasibility of steam soaks in various prospective reservoirs at low computational cost. SSPM requires only a small fraction of the computing time needed by numerical simulators, yet is capable of producing quantitatively good results. Run times are on the order of one second or less; hence, economic analysis is both feasible and inexpensive for multiple runs.

The model uses an energy balance which is a refined and extended version of that presented by Boberg and Lantz. SSPM uses time-dependent average saturations calculated from a simple material balance, and temperature-dependent relative permeability relationships to calculate the flow rates of the reservoir fluids. The pressure and temperature behavior of both formation and fluids is used to calculate the average reservoir pressure as a function of time. This pressure and temperature is used in a productivity model to calculate oil and water production rates. The model is capable of predicting the performance of a multi-layer reservoir for one or several cycles. Extension to any number of productive layers and shales of different properties is only one of several significant improvements over previous models of this type.

The paper presents the theoretical work leading to the model, its validation on a field case, and a brief sensitivity study.
Field Measurements of Downhole Drillstring Vibrations
Authors: Wolf S. F. , Zacksenhouse M. , Arian A.
Published: December 2007

NL's Wire Telemetry System was used in the field to provide high-data-rate measurements of downhole forces, accelerations, pressures and formation properties. This paper describes, and briefly discusses, downhole longitudinal and lateral vibrations and their correlation with formation characteristics.

Whi1e drilling through hard formations with a tricone bit, smooth drilling was achieved after increasing the rotary speed above the longitudinal resonant condition. The system resonant frequency was significantly lower than the natural frequency of the drillstring.

Downhole bending moments up to 25Kft-1b were measured while drilling in a straight hole. Fluctuations in the bending moments, about the two lateral axes of the drillstring, were at frequencies 3.5 to 5.5 times that of the rotary speed.
Supplemental Anode System for Offshore Structures
Authors: Plugge J. R. , Deacon-Davis N. A. , Koehler W. M.
Published: December 2007

A supplemental anode system was developed for the Hondo A platform which introduced two new techniques for installing galvanic anodes on deepwater offshore structures. The system includes: 1) the installation of tubular strings or anode piles lowered through the jacket structure and electrically connected at the lower deck elevation by welding, and 2) the installation of discrete structural units or anode pods set on the seafloor and electrically connected to the platform with cables.
A Discriminant Analysis of Acquired and Acquiring Companies in the Oil Industry
Authors: Noble J. E.
Published: December 2007

The purpose of this study was to determine if there were financial and industrial characteristics of acquired and acquiring oil companies that would distinguish the companies in each group. A multivariate statistical technique, multiple discriminant analysis (MDA), was used to evaluate 24 financial and industrial variables and to develop a discriminant model that best discriminated between 14 acquired and acquiring companies.

Using the MDA technique, eight variables: sales/total assets, earnings/share growth, finding cost/barrel, times interest earned, PE ratio, the ratio of discounted future net cash flows/share to the average price/share of common, the ratio of commom equity to total capitalization, and inventory turnover were identified as those that would best distinquish the two groups. A discriminant function was derived using these variables.

Acquiring companies were characterized as having higher asset utilization, greater earnings-per-share growth, a higher percentage of commom in total capitalization, and greater inventory turnover. Acquired companies were characterized as having lower perbarrel finding costs and greater future net cash flow potential relative to their average cost/share of commom stock.

The study's findings generally support the opinion that the reorganization of the oil industry through mergers and acquisitions reflects a beneficial reallocation of the industry's assets to companies that place a higher value on their use and will, consequently, utilize those assets more efficiently.
Case History: Successful Drilling in the Altamont and Bluebell Fields of Utah's Uintah Basin
Authors: Trichel D. K. , McKinney W. E. , Bryant G. A.
Published: December 2007

Some of the most challenging drilling encountered in the Uintah Basin of northeastern Utah occurs in the Altamont and Bluebell Fields (see Figure 4). Drilling costs in the area have been historically high due to such problems as surface water flows, lost circulation, abnormal pressure, hard and abrasive formations, and flows of crude oil with high concentrations of paraffin.1

Through implementation and improvement upon a carefully planned and executed drilling program, drilling costs in the area were reduced by 48%. All wells used in this study were drilled using a fully company owned and operated drilling rig. This paper details the improvements made in drilling fluids systems, hydraulics, bit selection, solids control, cementing practices, and other drilling related parameters pertinent to our drilling success.
Use of Expanding Cement Improves Bonding and Aids in Eliminating Annular Gas Migration in Hobbs Grayburg-San Andres Wells
Authors: Seidel F. A. , Greene T. G.
Published: December 2007

Annular gas migration and poor cement bonding throughout much of the wellbore have been continual problems in the primary cementing of Hobbs Grayburg-San Andres Wells. This paper discusses the formulation of an expanding cement system and the implementation of good primary cementing techniques to improve cement bonding and to eliminate annular gas flow after cementing. The work is based on a review of previously unsuccessful attempts to control annular gas flow by conventional gas control methods typically used by the industry.

Case histories, cement bond logs, previous primary cement slurries, and procedures used in the field are presented with possible explanations of why they failed to control the problem. The formulation of the primary cement system is outlined in detail including refinements made to the system during the 1984-85 drilling program.
Evaluating Sour Gas Exploratory and Development Ventures
Authors: Honeycutt B. D. , Price B. C. , Gater J. E.
Published: December 2007

An assessment of potential profitability of an exploratory venture in a sour gas play should include the large effect gas composition can have on plant cost. Based on expected composition, processing plant costs can vary six-fold, ranging from simple sweetening and dehydration units to those including sulfur recovery and tail gas units. Examination of basin trends may provide reasonable guidelines on expected variation in gas composition, hence the expected variation in both cost and profit. Data from three formations illustrate gas compositional variation. If gas composition varies widely in a play, expected plant cost can be calculated by weighing plant cost with chance of compositional occurrence.
Innovation Technology in Producing Operations
Authors: Neely A. B. , Etchison T. A. , Larbi K. , Holcombe H. W. , Jaccuzzo R. J. , Neuroth D. H. , Christ F. , Petrie H. , Haynes C. D. , Charles J. G. , Rau J. , Venkatesh E. S. , Arketa P. M. , Hudgins T.
Published: December 2007

The Production Operations Forum is designed to allow the discussion of and dissemination of information about technical innovations and solutions in production engineering that are of immediate practical use but do not warrant a full-scale paper. Each subject is presented in a five to eight minute period with a discussion period of seven to ten minutes. A wide range of subjects is encompassed in the session. Abstracts of the presentations follow.

"Electric Motor Selection and Sizing on Beam Pumping Wells to Minimize Energy Costs"

A.B. Neely, Shell Western E&P Inc.

The relative efficiency of very high slip and NEMA "D" electric motors has been widely debated. A test was carried out using both types on an instrumented well. When properly sized, the test showed that power consumption increased slightly and rod loading decreased slightly (up to ± 5%) with large increases in speed variation during the stroke. However, the most important finding was that power consumption could increase by a factor of two to three when the motor is significantly oversized. Details of the test will be presented.
The Politics of Energy Policy: A Congressional Perspective
Authors: Barrett M. F.
Published: December 2007

Diamonds, it is said, are created under great pressure. In the 1.26 decades since the oil embargo of 1973 and the beginning of the energy crisis, Congress has endured enough pressure to have created a great number of diamonds.

Some of the pressures came from advocates of increasing the supply of fossil fuels. An equal counterforce was exerted by conservationists who advocated restraints on demand. Congress chose a mixture of both: improving supply through supply incentives including the easing of environmental restrictions and dampening demand through the regulation of consumption and offering of conservation incentives.

I was present at the creation -- and frequently participated in the creation -- of the legislation which, in the latter half of the 1970s, came to be known as "national energy policy." That policy has been articulated in an alphabetic concatenation of legislative solutions -- EPCA, ECPA, EECA, NECPA, NEES, PMPA, PIFUA, ESECA, ESA, FERC, DOE, CAFE and more. Somewhere in there, there is concealed more than one jewel. Some of them, however, may require a considerable degree of polishing. Together they constitute a national energy policy crafted with great political acumen, in a reasonable bipartisan fashion and they work fairly well.
Effective Well Stimulations with Gelled Methanol/Carbon Dioxide Fracturing Fluids
Authors: Fairless C. M. , Joseph W.
Published: December 2007

CO2 foam fracturing fluids with gelled methanol as the external phase have been developed. These CO2 foams are generated on the surface by a patented CO2 heating process. Field applications of these fluids demonstrate that they are effective well stimulation fluids for hydrocarbon bearing formations that exhibit low permeability, low reservoir pressure or water sensitivity.

With this system water can be completely eliminated from the treatment fluid while the CO2 provides a gas drive to assist in returning load fluid to the wellbore. Since the density of these fluids is near that of water, they can be utilized to fracture stimulate deep formations without experiencing excessive wellhead pressures. Some CO2 dissolves in the methanol to yield a non-damaging low "pH" methanol fluid system that exhibits extremely low surface tensions which also assists in load fluid recovery. Additionally, these fluids exhibit near perfect proppant support and very high fluid effeciencies.

A comparison of these surface generated methanol/CO2 foam fracture treatments with other stimulation methods in the Morrow formation in the Texas Panhandle and Western Oklahoma and in several other formations in Texas, Oklahoma and Colorado illustrates their success.
The Gas Research Institute's Tight Gas Sands Program in East Texas
Authors: Hathaway S. C. , Salehi I.
Published: December 2007

For the past two years an extensive field-based research and development program has been ongoing in East Texas; if the results generated are to have the maximum impact on industry then the end user of these developments must be "in touch" with the program. To be exact, the Travis Peak/Hosston Formation of East Texas is being used as a laboratory for tight gas sand technology development. The Gas Research Institute's (GRI) Tight Gas Sands Program is able to bring such a diverse, but complimentary range of research to the field thanks to the cooperation of numerous East Texas operators. The objective is to develop the information, tools and diagnostic capability needed to increase the recovery effectiveness and reduce the costs of gas from tight sand reservoirs. This paper will serve as an introduction to GRI and to the East Texas-based field activities of the Tight Gas Sands Program, as well as extending an invitation to East Texas operators and service companies to take advantage of the research activities through direct participation.
Productive and Economic Potential of Tight Gas from the Travis Peak Formation in East Texas
Authors: Haas M. R. , Stone A.
Published: December 2007

Increasing operator activity and a pending FERC tight formation designation for the Travis Peak formation in East Texas indicate its large potential. The overall potential reserve additions from applying improved reservoir evaluation and stimulation techniques, however, has not been clear in the currently changing environments of technology, prices, and taxes and regulation.

This paper fully analyzes the conjoint effects of current geological understanding, engineering and financial costs, and production technologies on Travis Peak potential. Cores and logs, well tests, and production data from current (tight) Travis Peak wells provide a detailed geological basis for the analysis. The combined effects of geology, technology, costing, and resource development are analyzed in a comprehensive study of individual or overall benefits in the Travis Peak of specified technology or production practice improvements. The knowledge gained from this analysis is useful to direct R&D efforts toward those technologies that most increase reserves in specific locations.

Analysis results show the Travis Peak has economic tight gas potential (per section of productive area) greater than that estimated for the better known Cotton Valley, but varying substantially by location. For a 6700 mi2 Study Area in East Texas, over 3.8 Tcf in potential reserves are available at current prices and technology. Sensitivity analyses of alternative reservoir evaluation and stimulation technologies are individually described in terms of their effects on reserves, production, and economics, potentially adding more than 50% in reserves at current prices.
The SPE Microcomputer Users Group and its Activities
Authors: Eckles W. W.
Published: December 2007

Microcomputer technology has begun to revolutionize petroleum engineering. Petroleum engineers' use of relatively inexpensive personal computers (PC's) is likely to continue expanding rapidly. Since 1982 SPE's Microcomputer Applications Committee has developed a Society-wide users group, a bi-monthly newsletter (MICROCOMP NEWS), a SPE Continuing Education Short Course, a Petroleum Industry Applications of Microcomputers Symposium, a hardware and software distribution program, and a world wide electronic network (SPE NET).

The purpose of this paper is to share SPE's experience in creating a dynamic program for meeting the individual member's need in the application of microcomputers to petroleum engineering. My hope is that this will encourage other engineering and scientific organizations to provide similar programs for their members.
Cracking Nonmagnetic Drill Collars Prompts Analysis and Corrosion Specification
Authors: Zylstra L. P. , Richert J. P.
Published: December 2007

Thums Long Beach Company had experienced a 400%increase in stainless steel drill collar failures in a three month period. By means of failure analysis and field evaluations, the failure mechanism was identified as intergranular stress corrosion cracking. With proper drill collar specifications and alloy selections the failures and related costs were eliminated.
Advanced Techniques for Laboratory Full-Scale Drilling Tests
Authors: Cooper G. A. , Peltier B.
Published: December 2007

The SCR Drilling Test Station allows drilling with bits up to 12 1/4″ diameter into a rock sample held under conditions found in boreholes as deep as 5,000 m.

The control system permits rock conditions and drilling parameters to be altered interactively in real time to mimic field conditions more exactly.
Aluminum Drillpipe for Directional Drilling
Authors: Glagola M. A. , Wong L. F.
Published: December 2007

The purpose of this paper is to discuss some key properties and design criteria of aluminum drill pipe leading to its substantial advantage over conventional steel drill pipe in doglegs or directional drilling.

Fatigue data from full section fatigue endurance tests comparing aluminum and steel drill pipe will be presented. The effect of well shape on drill string loads and torque is discussed by comparing steel and aluminum drill strings in build and hold and "S" shaped wells.

Additionally, a short section on corrosion resistance is also presented.

The results show the advantages of aluminum drill pipe over steel in directional drilling — better fatigue life, maximum permissible dogleg severity, reducing drill string drag and torque, reducing wear on tool joints, pipe body and casing, better resistance to stress corrosion and corrosion fatigue.
Standard Buggy Rack Inspection with Continuous Cross-Sectional Area Measurement
Authors: Curtis W. W.
Published: December 2007

With used drill pipe it is important to know the minimum cross-sectional area (CSA) of the tube and the remaining wall in areas of pitting. Until now there has been no effective way to measure cross-sectional area or to evaluate remaining wall, over the full length, while rapidly scanning drill pipe with a standard buggy rack inspection. A buggy rack inspection tool has been developed which measures and displays the cross-sectional area over the full length of the tube, and provides a means to evaluate pitting based on average remaining wall.

This paper describes the device, test results, and the unique advantages of this addition to a standard buggy rack inspection.
Treatment Reclamation and Disposal Options for Drilling Muds and Cuttings
Authors: Hinds A. A. , Donovan D. M. , Lowell J. L. , Liao A.
Published: December 2007

Concerns about the environmental impact of offshore drilling discharges have resulted in increasingly stringent conditions being imposed in general NPDES permits for the OCS areas. Similarly there is increasing concern for the potential adverse impact of drilling mud on ground water. Impending prohibitions (EPA) on the discharge of muds or cuttings contaminated with diesel oil or containing "high trace metal" barites underscore the degree of concern. As a consequence, increasingly large volumes of mud and cuttings are being transported to shore for treatment and disposal.

The principal methods of mud and cuttings disposal are reviewed and the potential environmental impact assessed.

A novel approach to the reclamation and disposal of drilling muds is presented. The treatment process developed employs mechanical solids – liquid separation; chemical stabilization and fixation of solids; and chemical coagulation/flocculation of the effluent to meet water quality discharge criteria or for re-use in mud formulation. The process can accommodate water-base and oil-base muds (OBM) and cuttings. Oil from OBM is recycled and used for mud formulation.

Factors influencing the effectiveness of polymers in removing dispersed solids and heavy metals were investigated and comparative cost data for different treatment regimes employing polymers and/or polyvalent metal salts developed.
Permeability Impairment Due to Fines Migration in Sandstones
Authors: Sharma M. M. , Yortsos Y. C.
Published: December 2007

In a previous publication1 critera were derived for predicting the onset of fines release in sandstones. The present paper describes quantitatively the behavior of the sandstone after the fines have been released. The entrapment of fines at pore throats is modelled using a statistical approach and general population balance equations are written for the various species of interest. The equations are solved for the open pore densities and size distributions, for some special cases. The Effective Medium Theory is used to calculate the permeability once these are specified. The model therefore provides permeability as a function of time and position i.e. the extent and depth of damage. Such information will be valuable in not just predicting formation damage but also in designing appropriate stimulation jobs once the damage has occured.
Acidization of Dirty Sandstones with Buffered HF Acid Systems
Authors: Smith M. J. , Clark G. J. , Hendrickson A. R. , Egbogah E. O.
Published: December 2007

Previous studies have shown that acidization of sandstone with 12% HCl/3% HF acid systems can lead to secondary precipitation of many different compounds. Formation of these precipitate often have been found to be pH dependent. If the pH of spent HF formulations can be kept low, the likelihood of secondary precipitation may be reduced. This paper presents the results of a study showing the effect of acidizing a Berea Sandstone (76 × 5 cm), containing 9% carbonate, with a buffered HF acid system (12% H3PO4/3% HF). These results are then compared to results with 12% HCl/3%HF.

Treatment with one pore volume of the buffered acid system was found to increase the native permeability of the Berea sandstone core to a depth of 60 cm. No evidence of damaging precipitation or unconsolidation was found in any section of the core. The pH of the reacted acid was found to be low (2.0 – 2.5).

Fourteen pore volumes of HCl/HF increased the permeability only to depth of 25 cm and caused unconsolidation of the first 10 cm and 0.5 pore volume of HCl/HF caused formation of damaging precipitates.

The absence of secondary precipitation with 12% H3PO4/3% HF is most likely due to two factors: the buffering ability of the phosphoric acid kept the pH low and hence prevented precipitation of silicon or aluminium complexes, and the unique surface reactions between calcite and 12% H3PO4/3% HF prevent large amounts of calcium ions from being brought into solution from reaction with the carbonate content of the sandstone. These two factors were confirmed by reacting 12% H3PO4/3% HF with synthetic sandstone like mineral blends.
Solids-Free Brines: Efficient Displacement Techniques can Save You Money
Authors: Krause D. C.
Published: December 2007

Effective removal of drilling muds and related solids from well bores has been a topic of major concern for several decades. Displacement of incompatible fluids such as drilling mud with solids free brine is a critical point during well operations. A clean efficient displacement is mandatory to maintain the brine and mud integrity, reduce filtration costs, reduce rig time and provide a solids free environment in the well. The net result – downhole operations become easier, faster, and more effective in clean fluids.

The displacement process is divided into two components: Predisplacement – the mechanical and chemical conditioning of the mud before it is actually displaced.Displacement – the actual removal of the mud from the well using appropriate spacers, chemical washes and technique.

Methods to analyze and compare displacements are proposed.
The Management of Renqiu Oilfield During its Medium-Late Development Stage
Authors: Liu Renda
Published: December 2007

The production performance of Renqiu oilfield, which is a fractured massive carbonate reservoir with bottom water has indicated the remarkable blocking characteristic controlled mainly by inner faulted structures and karst formation.

Based on a comprehensive study on the data of the faulted structures, Karst formations and reservoir performance, the oilfield has been divided into eight development a blocks falling respectively into one of the three types: dolomite with well-developed high angled fractures, dolomite with fairly homogeneously developed fractures and cavities and intercalated dolomites with extremely heterogeneously developed crevices and fractures.

In view of the geological and development a characteristics of each type, proper technologies have been employed in the management of the oilfield. This has been done with fairly good results. Production decline rate has been controlled, production of a single well increased, interference from water producing zones in the open holes reduced, production potential in the formations with poorly developed fractures tapped, and recovery of the sections below interfaces raised. All of these will greatly improve the development of the oilfield in its medium-late stage.