bluuebunny/crossref_metadata_2025 huggingface dataset:
Reduced Maintenance Costs For Rotating Equipment Through Monitoring: A Rationale Based On North Sea Experience
Authors: Miles A.P. , McGregor I.G. , Melling T.H.
Published: December 2007

The use of electronic aids in monitoring the performance and condition of rotating machinery has performance and condition of rotating machinery has in the past decade taken a considerable upward trend. Widespread use is being made of vibration measuring systems coupled with the monitoring of temperature, pressure, load and speed, all of which are indicative pressure, load and speed, all of which are indicative of the system performance. Other methods such as magnetic chip debris collection and spectrographic oil analysis procedures (SOAP) are being increasingly employed outside of the aerospace industry in which they were conceived. The upward trend in offshore rotating machinery monitoring appears to result from the present high cost of frequent and often unnecessary routine overhauls. Improved techniques in machinery monitoring have in may cases enabled operators to reduce shutdown frequency and operate on a planned for basis rather than a pull it to pieces and lets see approach. Unfortunately, the unsurge of interest in this field has inevitably led to jumping on the bandwagon and a wide range of equipment claimed to give early indication of damage over a wide range of machinery components is now being promoted. This paper seeks to briefly outline the inherent difficulties of relating machinery damage to vibration presents hands on experience from several major presents hands on experience from several major northern North Sea developments and brings to light why many of the available systems are entirely unsuitable as general purpose indicators of damage. Concluding remarks include a section on future trends and developments toward truly universal system.
What Motivates Engineers From A Major Company's Point Of View
Authors: Juge Peter E.
Published: December 2007

JUGE, PETER E. NO COMPANY

Good afternoon. It is a pleasure to be here this afternoon to participate in this session of your Fall meeting, which focuses on the topic "Engineering People-Motivation, Productivity, Profits". My talk is entitled "What Motivates Engineers from a Major Company's Point of View"

I plan to include some discussion on the retention or engineers in my remarks as well, because I believe the two are closely related. Also I reel it is important first or all to begin by giving you some brief general information about Engineers in Mobil, and how they are recruited, as background for the rest or the discussion.

Out of a workforce of some 10,000 employees in Mobil's Exploration and Producing Division worldwide, engineers number just under 1150. Roughly Producing Division worldwide, engineers number just under 1150. Roughly half of these engineers are located at Mobil units in the United States. The other half are located abroad. Many or the latter are nationals or the countries where we operate. The approximate number or American engineers working abroad for Mobil is 230.

About 30% or Mobil's engineers are in managerial and supervisory positions. The other 70% are in professional ladder positions. I'll have more to say about this later.

Like most of the majors, we "grow our own" engineers. Most are recruited directly out of college. During the past three years we have recruited over 200 engineers from schools in the U. S.

Mobil's record in recruiting on campus is good. We hired 33 out of the total of 360 B.S. PEs and 42 MS PEs who graduated last year or about 8%. Our overall college recruiting acceptance ratio is on the order or 50% as compared with an industry average of 35%. We have a program for just- graduated, young engineers who join the Company to assure proper orientation and training in various engineering fields of specialization. The program is not a formal training program as such but more a series or work assignments within the Company and at outside schools, with tracking to help make certain all bases are covered. The main reason given by young engineers who join us from the college campuses for their decision to choose Mobil is the quality or the engineers and other professionals they meet during the recruiting process. The negative reason most often given by those who turn us down is location. But there doesn't appear to be any real pattern here. Some don't want to work in a city like Houston or New Orleans. While others don't want to go to such garden spots as Freer Texas or Morgan City.

Most of the engineers we recruit from college stay with us, pursuing a wide variety of engineering careers possible within Mobil. Our current turnover rate for engineers is 4%. This I believe is better than the average rate for majors and reflects a downward trend in Mobil over the past few years.
Control of Gas Cap Encroachment in a Thin High Permeability Reservoir
Authors: Al-Emadi Ismail A. Abdulla , McCoy Michael W. , Thomasen Jakob B.
Published: December 2007

The Nahr Umr sandstone reservoir in the Al Shaheen field offshore Qatar is a thin high permeability oil bearing reservoir with a primary gas cap. Effectively producing the oil reserves has been challenging due to the flat reservoir structure that promotes gas channelling from the gas cap to oil producers. Horizontal water injectors placed at the edge of the gas cap have been used to shield the oil producing regions from the ingress of gas. Water injectors have also been incorporated into radial patterns away from the gas cap to provide pressure support and efficiently sweep the oil bearing areas. Development to date comprises 15 horizontal production and injection wells drilled from three surface locations.

This paper discusses the completion techniques used for injectors and producers, along with the water flood monitoring programme and the interim results of the water flood compared to reservoir simulation predictions. Four years of performance data are presented.
Optimisation of Carbon Steels for Sour Service
Authors: Emenike Cornelius O. , Borouky Fikry F.
Published: December 2007

Failures in sour environments are a major concern to oil producing companies because these failures do not usually involve material loss (wall thinning). These time – dependent failures can release toxic gas (hydrogen sulphide) to the environment. Of major concern is the exposure of facilities designed for sweet service to wet hydrogen. Hence, this paper reviews the theory of HIC. For new production facilities such as Pipelines, free-water knock out ( FWKO) drum and flare stack, material selection using the well-known immersion test NACE TM0177/ NACE TM02 84 is highlighted.

Structure – property relationship is of paramount importance in design, hence regression equations were used to establish the effect of chemistry and microstructure on mechanical properties.

Recommendations were made for repair of equipment / facilities that failed during the transition from sweet to sour services. Eventually, a rule based form of expert (knowledge based) system was used to formalize a number of relationships. These rules are in the form of IF -THEN relationships. A brief explanation of the expert system is given as the basis of rule format.
Use of Sludge for Removal of Heavy Metals from Wastewater
Authors: El-Mahadi Hayat , Chaalal Omar , Zekri Abdulrazag Y.
Published: December 2007

In this paper sludge biomass is used for removal of heavy metals such as Cu, Cd, Pb, and Zn from wastewater and this was introduced in order to develop a comprehensive technique that remove or reduce heavy metal concentration to an acceptable level. Also SEM was used to explore the surface of the sludge and ensure the availability of microorganisms or pores, which may add additional advantages for retention of heavy metals.
New Technique Estimates Drilling Filtrate Invasion
Authors: Hassen Barry R.
Published: December 2007

A technique has been developed which calculates filtration of drilling fluids under actual well conditions. Theoretical and empirical equations were derived from the findings of an extensive literature search. These relationships enable comprehension of the many intricacies of downhole filtration far beyond that enabled by the primitive static fluid loss test. With this understanding, it is possible to modify drilling fluids and drilling practices such that invasion of drilling fluid filtrate is minimized.

The model accuracy was verified through comparison with well log results on 21 Canadian wells. Filtration volumes into a particular zone can now be estimated through use of a programmable calculator under conditions where well log data fails to do the job.

This paper outlines the types of filtration relationships derived, examples of the model results and the potential applications of the system. Armed with the capabilities of this system, it becomes possible to reap the benefits of reduced filtrate invasion.
Bridging Particle Size Distribution: A Key Factor in the Designing of Non-Damaging Completion Fluids
Authors: Mahajan Naresh C. , Barron Bruce M.
Published: December 2007

Great care must be exercised in the formulation and use of completion and workover fluids; otherwise extreme damage can be done by "non-damaging" fluids. Excessive loss of brines, polymers, or bridging solids to a producing strata can result in irreversible formation damage. Rapid formation of an effective filter cake on the formation face with the resultant low filtration rate and minimum solids penetration can significantly reduce the potential for formation damage.

Laboratory data indicates that low filtration rates achieved with the formation of a thin, competent filter film composed of properly sized bridging particles and hydrocolloid polymers will most effectively prevent formation damage. The deposited filter film acts as a downhole filter, screening out unwanted solids from the small volume of filtrate actually entering the formation.
A Practical Analytical Model for Geothermal Reservoirs Simulation
Authors: Castanier Louis M. , Sanyal Subir K. , Brigham William E.
Published: December 2007

This paper describes the theory and algorithm for a practical, analytical model for simulation of geothermal reservoirs. The model can be applied to any type of geothermal reservoir: all liquid, all steam, or two-phase. The model assumes radial geometry with three distinct zones: (1) an innermost, circular production zone; (2) an intermediate, concentric zone subjected to fluid flow and heat transfer but no production or injection; and (3) an outermost, radially infinite (or finite) aquifer zone. The reservoir is assumed to be producing from the innermost zone, as dictated by the capacity of a power plant. The innermost zone is treated as a tank from the viewpoint of mass and energy production, using a lumped-parameter model, but one in which the pressure distribution is calculated by an analytical formulation of pressure behavior of off-centered wells enclosed in a constant pressure boundary circle. The surrounding intermediate zone from which fluids migrate into the production zone is assumed to have a radial temperature profile, T(r), depending upon the reservoir. This profile can be either continuous or a step profile. The injection occurs in the outermost zone and induces a flow of fluid from the outermost zone through the middle zone into the central tank. There is no constraint on the relative size of various zones. Injection in the central production zone (such as in a five-spot development) is possible. If there is no injection, natural transient water influx from the aquifer is considered.

For a given step of depletion in the tank model, mass and energy produced are calculated and the pressure distribution in the central part of the reservoir is computed. The mass of fluid injected and/or natural water influx from the aquifer zone is estimated, and corresponding fluid flow from the intermediate zone into the central zone is calculated. The new temperature profile in the intermediate zone is then computed, and the average enthalpy of the influx water into the central zone is then estimated. The average temperature and pressure in the central zone are then calculated and a new step of depletion is initiated using the lumped-parameter model. If either constant enthalpy or constant available work is the specified constraint on production, an iterative approach is used to assure satisfaction of the constraint. This process is continued until the abandonment temperature or pressure is reached.

Application of this model to the East-Mesa reservoir shows a reasonable agreement with the more complex simulations done with an Intercomp model by Republic Geothermal, Inc. A sensitivity study of this reservoir has been made.
Construction of Grounded Ice Island for Drilling in Beaufort Sea, Alaska
Authors: Brinker Tyler
Published: December 2007

An exploratory well was drilled by Union Oil Company of California from a grounded ice island constructed in the Beaufort Sea. The ice island was 60 km west of Prudhoe Bay, Alaska, 3 km offshore, in 3 m of water.

Operations commenced in November, 1976, and terminated in April 1977. Project cost was $8 000 000. The ice island melted by mid July, 1977.

Grounded ice islands can be used in arctic areas of shallow water and little pack ice movement. They are environmentally acceptable and economically feasible.
A Laboratory Investigation of Enhanced Recovery of Methane from Coal by Carbon Dioxide Injection
Authors: Fulton Paul F. , Parente Carol A. , Rogers Bruce A. , Shah Nitin , Reznik A. A.
Published: December 2007

An experimental procedure for determining the effectiveness of CO2 injection into methane-containing coal samples for the purpose of enhancing methane production is described. Experimental results on both dry and water saturated samples reveal that CO2 injection greatly enhances both production rate and recovery efficiency. Most effective is a cyclic CO2 injection-gas production technique which recovered essentially all of the adsorbed methane in the 3½″ core samples used in the experiments.
A Wireline Hydraulic Fracturing Tool for the Determination of in Situ Stress Contrasts
Authors: Voegele Michael D. , Jones Arfon H.
Published: December 2007

A significant amount of research has been devoted in the past few years to the study of fracture containment in stimulation of low permeability gas reservoirs. One finding of this research is that vertical fracture growth is controlled by contrasts in the in situ stress state. A knowledge of the variation of horizontal stress with depth would aid in the design of well stimulation.

The only method available today for determining in situ stress at depths greater than about 200 meters is a small scale hydraulic fracturing technique; stress calculations are based upon several relatively simple measurements; however, at present the economics of sending the tool downhole on a tubing string are unfavorable. To overcome this problem the design of a self contained tool which operates on a standard seven conductor wireline cable has been undertaken by Terra Tek, Inc.; funding is being provided by the U. S. Department of Energy, Morgantown Energy Technology Center. A major goal of the design effort is to build the tool primarily with commercially available components. The basic tool consists of a downhole hydraulic power supply control unit, straddle packers and pressure transducer; it has been designed to function in cased or open holes. Additionally, the tool design incorporates a fracture detection device so that orientation can be determined.

In conjunction with the tool design a laboratory investigation utilizing 1 meter cubic samples is being pursued to study the mechanics of stress determination in cased boreholes. Since there is very little published literature on the determination of in situ stresses through perforated casing, it is hoped that the laboratory investigations will allow stress determinations in cased wells with the same degree of reliability that now exists for stress determinations in open holes.
Second Generation Technology for the Production of Pipeline Quality Gas from Sanitary Landfills
Authors: Rice Frederick C.
Published: December 2007

With the advent of replacement energy cost pricing for natural gas, the recovery and treatment of methane generated by sanitary landfills has become a commercial reality. The first landfill methane recovery plant, owned and operated by Getty Synthetic Fuels, Inc., has been in operation at Palos Verdes, California since 1975. Getty has built a second plant, which has been in operation in the city of Monterey Park, California since August 15, 1979. These two facilities are the only plants in the United States which produce pipeline quality gas from landfills.

Although similar to the Palos Verdes facility in some respects, the Monterey Park methane recovery facility is four times as large, and represents a significant advance in the State of the Art of landfill methane recovery and purification. This paper will discuss the similarities between these two operations, but, more importantly, will point out the significant technological advances made over the past four years, which have advanced landfill methane recovery from the demonstration project phase to the large scale, economically viable operation that it is today.
Completion Techniques and Production Data from Vertical Methane Drainage Boreholes, Jawbone Coalbed, Dickenson County, Virginia
Authors: Steidl Peter F. , Trevits Michael A. , Diamond William P.
Published: December 2007

Five vertical methane drainage boreholes have been completed in the Jawbone coalbed at the Clinch-field Coal Co. McClure No. 1 mine in Dickenson County, Va. Foam stimulation treatments were used to increase gas production from the boreholes. After 15 months the cumulative gas production from the first hole was 310,000 cu m (11 MMcf) with production averaging 700 cu m/d (25.000 cu ft/d).
Advance Methane Control and its Impact on Gas Emissions in the Pocahontas #3 Coal Seam
Authors: von Schonfeldt Hilmar A. , Pothini B. R. , Aul George N.
Published: December 2007

Methane emissions into underground coal mines in certain areas of the United States represent a serious hazard and contribute to lowering mining productivity. In order to reduce methane emissions into some of the deep south west Virginia Coal Mines an advance methane drainage program was developed. This paper gives a state of the art account of drilling long in-seam and slant holes into virgin areas of the Pocahontas #3 and #4 coalbeds. Directional drilling techniques are discussed. Methods to evaluate the drainage effectiveness of this program on the emissions in an operating mine are also covered. It is concluded that an effective methane drainage program can reduce methane emissions significantly thereby improving safety conditions in the mine. It also has the potential for increasing mining productivity. The recovered gas could also lead to a better utilization of our available energy resources.
Analysis of the Coalbed Degasification Process at a Seventeen Well Pattern in the Warrior Basin of Alabama
Authors: Ancell K. L. , Lambert S. , Johnson F. S.
Published: December 2007

This paper presents an analysis of the coalbed degasification process. The theoretical and experimental basis of the degasification process are discussed and a simulation model which incorporates all aspects of this process is described. The simulator is demonstrated using actual field data developed by a joint industry/government demonstration project funded by the DOE and U. S. Steel. The basic reservoir description is discussed in detail, including variations of important description parameters with location.

Initial and boundary conditions are demonstrated and analyzed. Initially, the coalbed was saturated with water. With water production, reservoir pressure is lowered, causing gas to desorb from the coal creating a mobile gas saturation. Subsequently, interwell interference effects are demonstrated and the need for such effects explained.

Finally, the long term gas deliverability of the pattern is forecast. This forecast shows that about 45% of the gas within the pattern can be removed if the pattern is in operation six years ahead of mining.
Seismic Velocity Analysis to Locate Shale Gas Wells
Authors: Boyer John St. A. , Anstey Nigel A.
Published: December 2007

It is known that economic production of shale gas is currently possible only where shale is naturally fractured. The exploration problem is therefore to locate zones of fracture. In principle, extenstive zones of natural fracture in a thick shale can be identified by the measurement of seismic velocity from the surface. The technique of reflection velocity analysis uses differential reflection time of reflections observed at the surface (with various source-geophone distances) to infer the extent of the gas saturated fracture zones. This technique has been applied along an available seismic line in Southeastern Ohio. A continuous velocity analysis of the shale interval along this line was prepared, and areas of depressed velocity have been identified. These results, and the results of drilling in the first area of low velocity will be discussed.
Recent Results On The Use Of Polymers In Tertiary Oil Recovery In Brines Of High Salinity
Authors: Lange Werner , Rehage Gunther
Published: December 2007

By means of viscosity measurements at low shear rates (0.1 to 10 s−1) a great number of commercial polymer samples were tested. We succeeded in finding a few polymers which have a viscosity high enough for polymer flooding (>20 mPa⋅s) at a polymer concentration of 800 ppm, even in a brine of high salinity (salt content 200 g/l). In additional filtration tests some of the selected products with sufficient viscosity values showed good results. Measurements of elastic and viscous properties indicated that some of the promising polymer solutions have pronounced elastic properties even at relatively low concentrations. As the elastic properties reduce the mobility ratio of the system oil-polymer solution, there should be an increase of oil recovery as the elastic properties of the polymer solution increase.
The Effect Of Alcohol On Surfactant Mass Transfer Across The Oil/Brine Interface And Related Phenomena
Authors: Chiang Michael Y. , Shah Dinesh O.
Published: December 2007

The effect of alcohol on surfactant mass transfer from bulk solution to the oil/dilute tnicellar solution interface was studied. Various interfacial properties of the surfactant solutions and their ability for displacing oil were determined. For the surfactant-oil-brine systems studied, the interfacial tension (IFT) and surfactant partition coefficient did not change when isobutanol was added to the following systems: 0.1% TRS 10–410 in 1.5% NaCl vs n-dodecane and 0.05% TRS 10–80 in 1.0% NaCl vs n-octane. On the other hand, the interfacial viscosity, oil drop flattening time (i.e. the time required for an oil droplet to flatten out after being deposited on the underside of a polished quartz plate submerged in the micellar solution) and oil displacement efficiency were influenced markedly by the addition of alcohol.

In the presence of isobutanol, the oil/dilute micellar solution interface became more fluid and the flattening time decreased from 90 seconds to less than a second or 420 seconds to less than a second, and the final oil saturation decreased from 30% to 5.36% and 11.73% to 1.28% respectively for the two systems mentioned above. Furthermore, it was observed that after the arrival of the oil bank, the ΔP leveled off for the isobutanol containing systems, whereas it continuously increased for the systems without isobutanol. This observation is consistent with the proposed role of alcohol in lowering the interfacial viscosity and promoting coalescence of oil ganglia in porous media.

The flattening time was strikingly lower for the surfactant + alcohol system as compared to the flattening times in the presence of the surfactant or alcohol alone in the brine, suggesting that the rate of achieving ultra low IFT at the oil/micellar solution interface is strikingly enhanced by the presence of isobutanol resulting in greater oil recovery.

In order to delineate the effect of surfactant mass transfer on in situ behavior of oil ganglia, we carried out several oil displacement experiments using equilibrated and nonequilibrated oil/micellar solution systems. For equilibrated systems, the oil displacement efficiency showed an excellent correlation with IFT and capillary number. However, for unequilibrated systems, the oil displacement efficiency depended on salinity. Below optimal salinity, the oil displacement efficiency almost remained the same for both equilibrated and nonequilibrated systems, whereas at and above optimal salinity the oil displacement efficiency was higher for non-equilibrated systems as compared to equilibrated systems. This was attributed to mass transfer rate effects in these systems. Both sand packs-and Berea cores gave similar results. The results of this study demonstrate the importance of transient phenomena at oil/dilute micellar solution interface for oil displacement process with emphasis on the effect of alcohol and salinity.
Produced Fluid Changes During A Fireflood
Authors: Fulford Richard S.
Published: December 2007

The Cities Service-U.S. DOE Bodcau In-Situ Combustion Project in Bellevue Field, Bossier Parish, Louisiana, has been in progress since 1976. During this fireflood, oil, gas and water produced at 37 wells were analyzed five times to measure changes in the fluids resulting from the fireflood. One analysis was done during the dry burn phase of the project and four were done during the simultaneous water-air injection phase. Temperatures as high as 800°C are reached in the dry burn phase and as high as 550°C in the wet combustion phase. Burning of coke and oil at these high temperatures results in complicated chemical and physical changes of the fluids.

Hydrothermolysis of the crude oil by the fireflood resulted in a lower sulfur content, a shift in the distillation curve toward increased amounts of lighter components and a slight increase in the API gravity and a decrease in viscosity.

The methane concentration in the produced gas increased during the fireflood. Evidence indicates that this methane increase was produced by coke gasification reactions rather than thermal degradation of the crude oil.
Oxidized Petroleum Fractions As Co-Surfactants And As Feedstocks For The Manufacture Of Sulfonates For The Tertiary Recovery Of Oil
Authors: Klaus E. E. , Jones J. H. , Nagarajan R. , Ertekin T. , Fan J. J. , Lin C. M. , Yarzumbek A. J. , King G.
Published: December 2007

Pure paraffinic hydrocarbons and petroleum fractions (which may be aromatic-free) on vapor phase oxidation give an oxidized product useful as a co-surfactant and as a feedstock for the synthesis of sulfonates. The oxidations may be carried out in a simple tubular reactor using oxygen or air as the oxidant and nitrogen or steam as the reactor diluent and reaction-heat absorber. The reaction is non-catalytic and occurs readily at atmospheric pressure at temperatures ranging from 300 to 400°C.

The major products of the oxidations are cyclic ethers mixed with varying proportions of olefins and carbonyls. Mild conditions (low temperatures and the use of diluents) favor the formation of the cyclic ethers and other oxygenated compounds over olefins. The cyclic ethers are largely composed of 5- and 4- membered rings containing carbon and a single oxygen atom. Such products are useful as co-surfactants and as starting material for the manufacture of sulfonates.

The oxidized products which are rich in cyclic ethers react readily with sulfur trioxide or oleum to give sulfonates as the principal products. Such sulfonates are effective surfactants in tertiary oil recovery.

Low concentration slugs formulated from the above surfactants have performed well in core tests. Highest oil recoveries have been achieved by matching the ηmin of the slug with the EACN of the oil in place. Such matched properties always give slugs having low interfacial tensions with the oil to be recovered. The sulfonates in low concentration slugs without co-surfactants or viscosity control in the slug have produced oil in core tests at high efficiency levels.
Another Significant Step in the Evolution of Stimulation Treatments in the Muddy J Sand – Wattenburg Field
Authors: Harp Laddie J.
Published: December 2007

Stimulation technology in the tight Muddy "J" Sand formation of the Wattenburg field has passed through another phase of development. This phase has centered in the changing of fluid type, fluid volume, proppant size and techniques of proppant scheduling with the result of much improved productivity in every case.

This paper presents a brief history of stimulation treatment development over the life of the field, the sequence of evaluation of treatment variables, and some of the thought behind the alterations that have been made.

The author was involved in seven of the treatment designs for the experimental wells included in the development of the improved treatment and procedure. The paper includes general treatment data and comparisons in productivity on three of the test cases which represent the pivotal steps in the ultimate evolution of the new treating approach.

All data, wells and results pertain to properties owned and operated by Amoco Production Company.
Formation Evaluation Utilizing Gamma Ray Spectral Analysis
Authors: Heflin Jearald D. , Nettleton Ken A.
Published: December 2007

Since currently producing hydrocarbon reservoirs can no longer supply the world's energy needs, the search for new sources has led to another look at formations that have posed difficult evaluation problems.

Several formations encountered in the Rocky Mountain region are in this category. In the past, drilling or evaluation techniques could not accurately indicate productive and nonproductive zones. Three of the stratigraphic units which have proven difficult to evaluate with conventional surveys are the Niobrara, Mawry and Phosphoria.

Problems in evaluating these formations can result from several factors. Mast can be related to determining the true clay content for accurate lithology and resultant porosity determinations, the location of fractured or fracturable zones, and evaluating formations that contain a low or unknown salinity formation water.

Recent developments in wireline logging instruments provide measurements which enable these and other sequences with similar problems to be correctly evaluated.

These methods rely on the spectral analysis of natural and induced gamma rays. Two commercially available instruments that provide these measurements are the Spectralog and Continuous Carbon/Oxygen log.

This paper will present the theory of operation and parameters measured with these instruments. Applications of these measurements will be discussed, with field examples showing how these measurements provide an improved evaluation of these formations.
Texas Railroad Commission Drilling and Completion Filing
Authors: Richter Thomas H.
Published: December 2007

The drilling and completing of gas wells in the State of Texas has long been of interest to the Railroad Commission of Texas. The Oil and Gas Division is charged with the responsibility of regulation of the oil and gas industry for the purpose, of conserving petroleum and preventing its waste, providing for equity among owners, protection of usable quality waters from pollution above and below the ground surface, and safety of the public. All the forms which are required by the Commission for drilling, completing and producing a well are designed to satisfy the aforementioned responsibility. Through proper planning, a gas well can be drilled, completed and put on pipe line with an allowable with a minimum amount of paperwork or time lost (which is money). Erroneous form filing or delinquent form filing will only cost the operator of the well time and production, and can cause other operators in a competitive field the loss of usable allowable, and consequently, production.

This paper will cover all forms that are required to drill, complete and obtain an allowable in the State of Texas. Common problem areas on each form will be examined, along with several definitions. Commission notification requirements will be reviewed. Gas well testing procedures and required form submission in regard to timely filing will also be reviewed. Special problems associated with Cotton Valley completions will be discussed.
Unique Transformer Design for the Special Requirements of Electric Submersible Pumps
Authors: Owen Donald W.
Published: December 2007

Electric submersible pumps require nonstandard voltage levels. A conflict between voltage versatility and power efficiency exists in many multiple voltage transformer designs. This conflict was resolved by a unique transformer design. A review of the fundamental considerations in power transformation and equipment protection is induced by the importance, cost and vulnerability of electric submersible pumping equipment.
The Analysis of Spherical Flow with Wellbore Storage
Authors: Brigharn William E. , Peden James M. , Ng Kitson F. , O’Neill Neil
Published: December 2007

The theory describing the flow of fluid in a spherical system affected by wellbore storage has been derived. Type curves have subsequently been developed based upon this derived theory which facilitate the analysis of spherical flow behaviour dominated by wellbore storage at short times. The analysis of long time pressure transients when wellbore storage becomes less important is also discussed with reference to a cartesian plotting technique.

Finally the analysis of data from interference tests for isotropic and anisotropic systems is also discussed.
Definition and Development of the Mackerel Field, Gippsland Basin
Authors: Limbert Alan R. , Maughan David M. , Mebberson A. John
Published: December 2007

The Esso-Hematite Mackerel oilfield is located approximately 70 kilometres offshore in the Gippsland Basin, south-eastern Australia. It is one of a number of fields in this basin in which the reservoir occurs beneath an unconformity at the top of the Latrobe Group which is of Paleocene-Eocene age. The trap has been formed within a topographic erosional feature, sealed by calcareous shales and mudstones of the Oligocene Lakes Entrance Formation.

This paper covers two topics. The first is the history of, and problems related to, the definition of the irregularly eroded Latrobe surface. In particular, the use of migrated seismic data to define the Top of Latrobe is discussed.

The second topic of the paper is the use of seismic stratigraphy to help plan the development of the field. Progradational seismic character in the Latrobe reservoir section is observed on the seismic data at Mackerel. Seismic stratigraphic work was integrated with the results from the four exploration wells to build a model of the reservoir section prior to field development. This model was then used to help plan the development well program.

Finally, the results of development drilling to date are discussed and an evaluation made of the pre-development geophysical and geological interpretation.
Oil Base Foam Fracturing Applied to the Niobrara Shale Formation
Authors: Driscoll Patrick L. , Bowen James G. , Roberts Mark A.
Published: December 2007

The Niobrara Shale wells in the Overland Dome field of Wyoming have undergone a variety of well completion procedures. Stimulation treatments have utilized gelled oil, gelled water, water base foams, and co-mingled CO2 and oil. These systems have not been completely successful. In the authors’ opinion, these systems have not satisfied the fluid loss and fluid compatibility requirements necessary to successfully fracture the Niobrara Shale formation. The oil foam system described in this paper has excellent fluid loss properties, is an efficient proppant carrier, and is compatible with the formation. The use of this fluid appears to offer the most promising technique thus far used to stimulate the Niobrara Shale. The process appears economical. The largest treatment performed to date has been 100,000 pounds of sand with 100,000 gallons of foamed oil, utilizing less than 400 hydraulic horsepower.

Use of the oil base foam fracturing procedure has successfully led to the reactivation of the field. It has also been applied to the shaley, silty Frontier Formation in this same field. The most successful previous treatment had a sustained maximum production of 8-10 BOPD. Utilization of improved completion procedures and the oil foam fracturing process has resulted in stabilized increased production from old, existing wells. On new wells the production has ranged to BOPD. For better application of the fracturing fluid to the most potential zones, natural fractures were identified and these zones were perforated on a limited entry basis.

The previously commercially unproductive Frontier Formation in this field has been treated with the same technique and has resulted in economical wells.

This paper will describe the geology, completion techniques, and the fluid and procedures used to stimulate the Niobrara Shale formation.
Reserve Recognition Accounting – An Engineering Viewpoint
Authors: Pielsticker John R. , Steiger Natalie M.
Published: December 2007

Presents the approach of Cities Service Company in preparing the "Summary of oil and gas producing activities on the basis of Reserve Recognition Accounting" for the year ended December 31, 1979 as published in the Company's SEC Form 10-K. Discusses the problems encountered in attempting to comply with the Security and Exchange Commission's rules and regulations in a timely manner, such as, the determination of product prices, estimating future investment, the deferral of investment costs and others. Discusses future problem areas such as the decontrol of domestic oil prices, the windfall profits tax, and the reporting of RRA data in the annual report to stockholders as well as the Form 10-K.
Applied Technology Meets Trinidad Sand Control Challenge
Authors: Mower L. N. , Soverall David G.
Published: December 2007

In 1975, Holman1 and Likwartz2 described the challenge to sand control technology presented by the extremely fine grained unconsolidated producing formations in the Teak Field, offshore Trinidad. Results of a research study and operating experience were incorporated in field completion techniques which reduced sand production to trace quantities while producing at rates exceeding 5000 BOPD/well.

As a more mature phase of the Teak Field production was reached, substantial changes in sand control techniques were mandated. Initiation of the MM-0/1 sand waterflood and associated workovers of wells with a prior history of trace quantity sand production presented yet another challenge in design and implementation of gravel packs. Gravel pack design and procedures which had been effective during the early producing life of the field were no longer successful.

Findings of the original research effort were reexamined and post appraisals were made of significant completions. As the result of these studies, improved and radically different sand control technology was applied. Major changes implemented were the use of finer grained, high quality gravel pack sand together with two stage packing of "old wells".

An overview of field sand production as reflected by separator cleanout frequency demonstrates that improved techniques can effectively control sand with no loss of productivity. A very significant relationship has been established between increased use of smaller gravel pack sand and a decrease in the volume of produced sand.
The Ideal Role for the Petroleum Engineer
Authors: Whiting Robert L.
Published: December 2007

The purpose of this paper is to describe the ideal role for a petroleum engineer. In an effort to accomplish this, the history of the engineering profession is traced from 3iblical times to the present. The evolution of engineering curricula from its founding in the U.S. at the U.S. Military Academy in 1812 is reviewed. The growth of the petroleum industry and the background and responsibilities of the technical personnel who developed the U.S. petroleum reserves and productivity is summarized. The evolution of petroleum engineering curricula from its origin at the university of Pittsburg in 1910 is traced to the present.

This historical information permits one to understand – at least in part – the reasons for the composition of modern petroleum engineering curricula and the modern concept of a petroleum engineer. ECPD and SPE minimum curricula requirements for petroleum engineering and petroleum technology programs are presented. The SPE technical areas for petroleum engineeringnence petroleum engineers-are cited.

The role of the individual who is seeking to become a petroleum engineer is traced from the time of entrance into College until he becomes a petroleum engineer. For convenience, his progress is traced through phases called academic, planning, learning, practica and management. The role of the individual in each phase is generalized and the methods for maximizing his productivity are discussed.

It is concluded that there are many ideal roles for a petroleum engineer and that they exist in all types of petroleum industrial organizations and branches of the petroleum industry.
Worldwide Exploration Areas
Authors: Birks Jack
Published: December 2007

Declining future oil production prospects and higher prices have stimulated exploration efforts worldwide. The prospects of finding giant oil reserves are declining and explorers have to be satisfied with smaller, deeper and more expensive fields. Much exploration is offshore in increasingly hostile environments. The paper reviews worldwide activities and considers the prospects for future oil and gas production and discusses the conditions needed to stimulate oil and gas exploration.
The Role of Diagenesis in Successful Formation Interpretation, Well Production, Stimulation, and Enhanced Recovery
Authors: Davies David K. , Almon William R.
Published: December 2007

Post depositional modifications (diagenesis) of sandstones play an important role in controlling hydrocarbon discovery and production. Diagenesis can effect the ways in which geologists and engineers interpret, evaluate and develop sandstone reservoirs. In particular, diagenesis has a significant effect on several topics of importance to the oil industry including: 1) Petrophysics, 2) Fluid System Compositions, 3) Drill Stem Testing, 4) Well Production, and 5) Enhanced Recovery.
Application of Areal Seismics to Mapping Sandstone Channels
Authors: Dobecki Thomas L.
Published: December 2007

The seismic formation mapping project is a two-part program whose prime objective is the evaluation of state-of-the-art seismic reflection methods as a means of mapping the subsurface configuration of low permeability sandstone channels - potential gas reservoirs typical of Tertiary and Cretaceous formations of the Western United States. The initial part of the program involved performing a computer model study to predict the effectiveness of seismic techniques applied to such targets and to develop criteria for interpreting real data. The second part consisted of a seismic field experiment designed to test and evalute the ability to map known lenses. The field program utilized areal (d-D) acquisition methods at a site underlain by known, shallow Mesa Verde channels.

Through the lessons learned by seismic modeling, we have been able to interpret field seismic data in terms of channeling and thereby predict the orientation of channels in the subsurface. Projecting these channels out of the area of seismic coverage in order to predict their outcrop position, we have located existing channels which agree quite well with the seismic description and projection. It is felt that this exercise has satisfied the program objectives, and that seismic methods may be successfully applied to the description of channel sandstone reservoirs. The next test of this will be in the upcoming DOE-sponsored multi-well experiment.
Remote Characterization of Tight Gas Formations with a New NMR Logging Tool
Authors: Jackson Jasper A. , Brown Joseph A. , Crawford Theodore R.
Published: December 2007

A new Nuclear Magnetic Resonance logging technique under development at Los Alamos National Laboratory has characteristics which afford several operating and measurement advantages in tight western gas sand formations over existing nuclear magnetic logging tools. Among these are 1) elimination of the need to condition borehole fluids prior to logging a hole, 2) higher sensitivity per unit sample volume, 3) shorter instrumental dead time, and 4) potential for greater formation penetration. The new technique has been laboratory tested in tool geometry. A prototype tool utilizing permanent magnets is under construction and design has started on advanced tools using superconducting magnets.
NMR Measurements on Western Gas Sands Core
Authors: Brown J. A. , Brown Lee F. , Jackson Jasper A.
Published: December 2007

Proton longitudinal relaxation (T1) measurements have been made on several Western Gas Sands core samples. These water-saturated specimens show a distributed relaxation time reflecting the distribution of pore sizes in the sandstone matrix. Mercury porosimeter determinations of the pore-size distributions correlate well with the Nuclear Magnetic Resonance (NMR) measurements, and in addition show a correlation between bulk porosity and pore size. The NMR signal strength is shown to be related to porosity and water saturation, in all but one case.
Phase Separation of Two-Phase Fluid in an Injection Wellbore
Authors: Elson T. D.
Published: December 2007

Flow of a two-phase, gas-liquid fluid in a model wellbore has been studied. Observations using an air-water system are related to in-wellbore phase separation of two-phase steam typical of that being injected into multiple perforations or zones. The air-water system has a phase density difference similar to steam vapor and liquid. Results show that when such a two-phase fluid exits the injection tubing in the model wellbore, separation of the phases occurs. This may translate into nonuniform steam quality distribution at various points in an interval undergoing steam injection. Phase separation in the wellbore is of concern because it may affect steam drive or stimulation efficiency. Parameters that affect in-wellbore vapor-liquid distribution include completion geometry, total injection flow rate, and downhole quality.
Gas Lift Design and Performance
Authors: Pittman Robert Wayne
Published: December 2007

The optimum design of a continuous flow gas lift installation is dependent upon the critical combination of a number of pertinent variables, including well performance index, gas in solution, static reservoir pressure, tubing size and injection gas pressure. The economic performance of the optimum design is dependent upon maintaining a minimum injection gas to produced liquid ratio that relates to minimum adiabatic power associated with recycle gas compression. Examples illustrate this to be accomplished by designing for and maintaining injection gas pressures such that a maximum injection valve depth for the design production rate can be utilized.
Designing for Corrosion Control in Surface Production Facilities
Authors: Watts R. K.
Published: December 2007

In order to design surface production facilities to have the most cost effective service life and meet safety objectives, it is essential to predetermine all aspects of the environment to which the various segments of the system are to be exposed. The design must provide corrosion protection, either by material selection, chemical inhibition, protective coatings and/or impressed electrical currents. In addition, monitoring devices are needed to provide base corrosion rates and to monitor the effectiveness of corrosion inhibition programs.

In order to evaluate the environment, the data must include chemical composition, pressures, temperatures, phase, velocities and percent undissolved solids. Chemicals for inhibition must be evaluated in an environment designed, as far as possible, to simulate the actual process conditions.

The paper discusses the corrosive environment normally encountered in oil field production operations, and practical approaches to evaluation, monitoring, and control methods.