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The automation system was designed to provide accurate measurement and control of the CO2 injection process and to provide communications between the wells and a central terminal unit. The central terminal unit was to make automatic scans of the field and generate alarm/alert reports in the event of a malfunction at a well. In addition, the central terminal unit would provide historical
reports of injection volumes, rates and pressures from all wells. The planned injection pressure was between 1600 and 1700 psig and the expected temperature was between 40 and 70 degrees F.

Safety around Pumping Units is a basic overview of safety policies and procedures used by oilfield service companies to comply with federal regulations as well as requirements set forth by oil companies in order to achieve the overall goal of zero incidents and zero injuries.

With the extensive search for energy materials, more wells are being drilled into zones that are capable of producing hydrocarbons containing hydrogen sulfide. This paper will deal with training and preplanning to handle the special problems associated with the drilling of sour gas wells.

Being associated with an electrical utility company where safety is as much a part of doing the job as the job itself, it is a privilege to have the opportunity to point out to you some things that might help in the safe operations of electrical leases.

We in the electric utility business are always interested in safety, particularly that which applies to electricity. As so many people are uninformed about electricity, we are always eager to talk about electrical safety to industrial or public group. Some people are of the opinion that electricity is not dangerous to a person unless he is standing in water. Other people have remarked that an electric circuit is not harmful if the person concerned is touching only one wire. There's concepts are, of course, false and are the type of thing with which we concerned and wish to correct.

Older wells become marginal due to a variety of production problems. AMOCO's Carthage team looked into a revolutionary new method to increase production in two producing zones, in their area of responsibility.

With the adoption of Statewide Rule 8, amended by Order No. 20-56, 841, by the Texas Railroad Commission, salt water disposal in the State of Texas will become essentially 100% subsurfaced by 1969. Although such a method is not without hazard in regard to pollution, when such a system is properly designed, installed, and operated, it provides greatest possible assurance of eliminating pollution of surface and subsurface domestic water supplies.

This paper describes the industry's efforts to overcome these obstacles which bar the industry from disposing of salt water without contaminating fresh water. This paper also points out that operators have disposed of vast quantities of salt water with statistically negligible contamination and suggests methods to continue progress in eliminating pollution hazards.

The prudent design of good salt water disposal systems requires consideration of all reservoir conditions and economic factors.

A discussion pertaining to the design, construction and operation of salt water disposal systems from supervisory and record maintenance viewpoints.

This patented system consists of a typical chemical pump, chemical chamber fitted atop a modified lubricator cap, all on the surface and a modified plunger available in any configuration currently on the market. The entire system has only 4 moving parts, not including the plunger. This system is capable of transporting liquid chemicals each plunger cycle. The entire system can be installed with common tools typically, during the shut-in segment of the well cycle. Field trials in two different wells in So.

This paper provides five examples of pumping well buildups and the pressure transient analysis of the buildup data. The bottomhole pressure data is also included for each test. All of the buildup data was collected through the use of automatic acoustical fluid level machines. When the examples were picked an attempt was made to show typical buildup responses from Permian basin wells. Some of the buildups selected are from wells that are tight and have three phase flow. The tight wells have been stimulated, and do not fit the standard reservoir response models.

After many years of producing a lower zone in the Conger FMT Chevron recompleted existing wells in an upper zone. The lower zone was closed off with a cast iron bridge plug. Severe problems with sand production were encountered and various methods were used to produce the well and deal with the sand. This paper will review the problems and solutions encountered when these changes were made. It will also review the different pump designs that were used and which were successful.

The presence of clay minerals within a sandstone reservoir is a major factor in the sensitivity of that reservoir to treatment fluids. The exact type of fluid sensitivity (acid, fresh water, etc.) depends on the exact type of clay mineral present in the reservoir. In recent years, X-ray diffraction analysis has been extensively used to determine the type and amount of clay minerals present in reservoir sandstones.

This paper describes savings which are realized by the use of lower temperatures in oil treating.

A new promising CO2 cocktail enhanced oil recovery technology has developed. The technology involves in-situ generation of carbon dioxide to recover trapped residual oil from reservoirs. This technology has two at least unique features that set it apart from existing technologies. First, CO2 is injected as part of a dense liquid phase (not simply compressed CO2). Because the injected fluid is a dense liquid at ambient conditions, there is no need for the expensive compression costs that are associated with convention CO2 injection processes.

The purpose of this paper is to share the authors" experiences in applying SCADA technology to the oilfield. This paper discusses some currently available SCADA technologies, how SCADA technology is typically applied to onshore oil and gas production, and the practical considerations of implementing oilfield SCADA. This is based on the authors" experiences as control system engineers in oil and gas producing operations. The intended audience is people familiar with onshore oil and gas production operations.

This paper deals with a dual subject concerning scale and paraffin problems encountered in the production of petroleum. Scale formation is caused by an upset in equilibrium conditions within a given system and this is explained in detail. Several methods of control are discussed and optimum conditions of control outlined. Chemical treatment for scale control is discussed at length since this is the most practical method of control in the production of oil. Paraffin or wax formation in oil production equipment is explained as to types and different areas of these occurring types.

For years, all oilfield scales were called gyp, and gyp meant trouble. Times and methods may have changed, but gyp, or scale, still means trouble. Scale can be anything that precipitates from water. We have seen scale deposits that were pure rock salt and others that were much more exotic, such as zinc phosphates, sodium carbonate, and occasionally minute traces of gold and silver, but these are unusual. Everyday oilfield scales are calcium carbonate, calcium sulfate or gypsum, and barium sulfate. Strontium sulfate is occasionally found, usually in conjunction with barium sulfate.

Calcium sulfate scale deposition in oil producing wells in West Texas is a serious and expensive production problem. A great deal of time and money has been devoted to this problem but, as yet, no completely satisfactory solution has been found. Mechanical removal of the scale followed by fracture treatments or acidizing have been partially effective in restoring production capacity. Squeeze treatments using scale inhibitors have considerable promise, but will require refinements in the placement techniques.

Downhole scales commonly encountered in producing operations are often calcium carbonate and calcium sulfate, less frequently barium sulfate and strontium sulfate. The problems vary in severity, the deposits sometimes being sufficient to cause pump failures and

Scale is a term commonly used in the petroleum industry to define insoluble, inorganic salt deposition in water or water-containing systems. Normally this deposition is composed of the salts of calcium, magnesium, iron and barium. Oil field brine water contains many and varied inorganic salts are increased or the solubility of the salts is decreased, the equilibrium is upset and precipitation takes place. This precipitation is commonly called scale. The physical factors which may cause precipitation are temperature, pressure, evaporation and condensation.

The anticipation of scaling conditions before they have commenced or before the deposits have become excessive is a vital prerequisite to the preventative maintenance of any oil field equipment handling water. The author's current procedures and means of using water analyses for the prediction of scaling are reviewed. Other methods that are also available, and some of which have been proposed, are also briefly reviewed. In view of their appearing more prevalent in the oil field, the attention is focused on calcium sulfate, calcium carbonate, and barium sulfate.

Scaling of oil wells, injection wells, equipment and flow lines is a serious production problem. The scales, which are formed from the produced brine, may be one of many chemical compounds or a mixture of several. The effect of scale deposits can be noticed in many ways, but all are factors which will show up in the economics of production.

Wellbore flow barriers, such as scale deposits, can be pulverized by a new technique that utilizes high-intensity sonic shock waves of microsecond duration. Improvements in well productivity have been realized in field tests at costs substantially below those of conventional remedial services. The Sonic Shock Tool is lowered in the well on a wireline. It is powered by a high-voltage arc whose shock waves in well fluids hammer the casing walls and openings with a high-intensity impact of microsecond duration.