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Recently, AI-K decided to update the technology in use to collect and analyze sucker rod load data. Data was being collected with Leuterts, Amerada Hess Corp. Portable Well Analyzer I (AHC PWA I) or AHC PWA II systems. Even though the Leuterts were easy to install, the data was difficult to analyze. The AHC PWA I is an older and obsolete digital dynamometer developed ten years ago. The AHC PWA II utilized load cells, but the electronics did not hold up. AI-K approached Echometer Co. to develop a portable well analyzer system, utilizing modified Leutert heads.

Analysis of conventional and pressure cores taken with stable foam from the San Andres formation within the Bennett Ranch Unit of the Wasson Field provides a better means of formation evaluation. The pressure core data were used to correct conventional core oil saturations to in situ conditions. This oil saturation adjustment method corroborates similar procedures cited in the literature. The pressure at the bit was controlled during the coring operation to minimize the possibility of core fluid saturation alteration.

Hydraulic fracturing as a well stimulation technique has been in widespread usage since its introduction to the oil industry in 1948. Lease oil was used predominantly as the fracturing fluid for the first decade. Technical advancement in developing surfactants, friction reducers, and effective gelling agents stimulated greater interest in water frac as early as 1958 and increased its popularity. Today approximately 60% of all fracturing jobs are performed with water-base fracturing fluids.

The purpose of this paper is to explain what load factor is, show how it will affect the power bill, and provide a few ideas on how to improve the load factor. Also, rates will be discussed briefly. The rates used here are Southwestern Public Service Company's rates; however, the principles will apply to most other power companies. Available rates and a basis for selecting the most favorable rate will be provided.

One of the problems encountered in stimulating low pressure and/or low permeability sandstone reservoirs is recovery of the treatment fluid. Some wells have low bottomhole pressures and in many cases these pressures are so low as to give little or no aid in treatment load recovery. Reservoir permeability is determined by the relative number and size of pores as well as by the size and continuity of the pore intersections. Permeability is unique to a particular reservoir and cannot be altered by stimulation.

Beam pumping units have been the principal means of artificial lift in the oil field for many years. In recent times, stimulation in secondary recovery projects and encroaching water in water-drive reservoirs have made it necessary to lift more fluid than ever before. There have been several improvements in beam pumping equipment, causing it to remain the best method of artificial lift in most of our wells. A few of these improvements are unique pumping unit geometry, high-slip motors, rolled sucker-rod threads, and sprayed metal couplings.

Most of the improved, or enhanced, oil recovery methods in use today are described in this paper. It is designed to provide definitions of the terminology used in the literature for describing various types of recovery processes and to provide an overview of each process. The general areas covered are thermal methods, chemical flooding, miscible gas drives, and improved water flooding using polymers.

This paper describes experiences with a new water-base drilling mud system that has been utilized in diverse geographic locations, formation lithologies, and environments such as temperature, density, salinity and total hardness. In addition to providing versatility in wide-ranging conditions, the original goals of the development were to create an easy-to-engineer mud system that would produce good hole stability and improve rates of penetration with the use of either conventional or polycrystalline diamond composition (PDC) bits.

There are many ways that sucker-rod systems can be improved. Performance and utilization of available equipment can be increased without the installation of larger units at greater costs. The use of rod guides is an inexpensive method for optimizing machinery already on the lease. This method keeps capital expenditures to a minimum and also reduces pulling costs up to 50 percent. Rod guides were originally designed to combat crooked-hole wear, but operators have been quick to find other money-saving uses for them.

This presentation is directed toward providing application guidelines for hydraulic pumping systems, in an effort to improve the performance of the system which in turn should make the system more acceptable to the operator. In the last 20 years the manufactures of down well hydraulic pumps have invested a great deal of time and money in research and development programs to improve both reciprocating and jet type products that they offer to the industry.

The North Concho Bluff Field produces from the upper Guadalupian tidal-flat sandstone play of the Queen Formation. Recently, the waterflood production from the field had decreased to a point where it was barely generating a positive cash flow. A reservoir simulation model was constructed in an attempt to improve earnings by identifying areas of potential oil bypassed during waterflooding. However, the spatial coverage of modem well log and core data within the field was inadequate in describing the reservoir for the simulator study.

This paper presents an improved sucker rod pumping design method similar to the API RP 11L but provides more accurate answers. The design is based on developing look-up tables or graphs for the desired unit geometry and pumping conditions by using a wave equation program. The wave equation and simulation techniques are used to mimic pumping conditions and calculate the loads and displacements. Such an approach makes it possible to compare, on a general basis, the different pumping geometries.

A solution now exists for problems attributable to gas interference in down-hole rod-pump assemblies. With the patented Solution Valve (SV), designed and manufactured by Eagle Advanced Oil Field Technologies, gas entering the pump chamber as either free gas or initially as dissolved gas, can be effectively displaced. Positioned on bottom of the conventional plunger, the SV performs in conjunction with conventional standing and travel valves such that the pump chamber is charged with fresh well bore fluids during each pump cycle.

Field results of limited entry treatment through pin point perforating and controlled injection rate in 201 wells are presented. A comparison with conventional treatments is made.

It is becoming more important, due to greater depths, higher temperatures, and increased volumes, that the most dependable and economical pumping equipment be installed to produce oil wells at this time. It is important that the operator be fully aware of the advantages of the electrical submergible pumping equipment and make efficient use of it. This paper will bring out these more important advantages. When these advantages and operating techniques are understood and utilized by the operator, one of the most economical methods of well production can be achieved.

Polyacrylamides hydrated in hydrochloric acid and crosslinked with iron-based ions have been utilized for a number of years as in-situ divertors in the stimulation of extended-length carbonate zones. A significant improvement to this process has been developed, field-tested, and placed into general use. Crosslinking the polyacrylamide with a zirconium-based metallic ion has proven to be an alternative with a number of advantages over existing systems.

It has been documented in field test results that in many cases a production increase can be obtained by replacing a steel sucker rod string with a fiber-glass and steel sucker rod string. (2) While these tests have demonstrated the value of fiberglass sucker rods, the beam pumping systems were still fairly inefficient because the pumping units that were being used were originally designed for use with steel sucker rods.

A high quality cement bond between casing and wellbore is an environmental and economic imperative for the duration of a well. A strong cement bond provides zonal isolation and prevents gas migration, gas entrapment and excessive water production. The growing public concern about possible gas migration to fresh water or to the atmosphere has further highlighted the importance of achieving the best possible cement bond. A chemical preflush prior to primary cementing is an inexpensive and effective method to help ensure a quality primary cement job.

Separating water produced in conjunction with crude oil has been an ever increasing problem since Drake's first well. As refinery capabilities grew more complex and pipeline companies became more aware of the problems associated with water, their demands to lower the water content of oil expanded to those we know today. The process equipment arm of the petroleum industry has always reacted to these needs with ever growing efficiency.

The industry has developed methods to improve the sweep efficiency during EOR processes. These methods include the use of certain patterns, as well as horizontal or deviated wells. The goal of these processes is to create an even movement of injection fluid across the reservoir. Special chemicals have been used to divert the injected fluid to eliminate channeling and to improve sweep efficiency. This paper will present a new methodology to modify sweep patterns to positively impact recovery.

The Spraberry trend of west Texas is a low-porosity naturally fractured reservoir, traditionally completed in the Upper Wolfcamp carbonate, Dean sand, Lower Spraberry sand, and Upper Spraberry sand zones. The overall interval is from 1200 to 1500 ft. thick, with completions encompassing from two to four stages. In all cases the wells require large hydraulic fracture treatments to produce economic quantities of oil and gas. The most common method of perforation selection involves correlating from well to well using cased hole gamma ray/neutron logs and drilling time.

Multilateral horizontal wells have been used as an approach to further improve production and injection volumes. As a result, very often the steep hyperbolic decline seen in a single lateral well is reduced. The first approach used was with a milled casing section in which several laterals are drilled off a cement plug. Subsequent laterals are then sidetracked off the main laterals drilled. These laterals are 4 314 inch openhole with no liners. Reentering these laterals is costly when doing initial stimulation work for completion.

The Permian basin of west Texas is known for its low permeability reservoirs, earning it the reputation of "hard rock country." wells completed here require A significant percentage of the hydraulic fracture treatments in order to produce economic quantities of oil and gas. The hydraulic fracture treatment can represent a significant portion of the total well cost. In addition, the effectiveness of the treatment can be critical to the economics of the well. Too small a treatment can leave valuable hydrocarbons in the ground.

For maximum profits in rod pumping operations the efficiency of the pumping system must be maximized, this can only be achieved by finding the optimum pumping mode for the required liquid production rate. These principles are used in the paper by presenting a case study on improving rod pumping operations. The project reported was conducted in a mature onshore field with 70-plus rod pumped wells. An extensive measurement program involving more than 50% of the wells was set up and pumping parameters were measured with a portable computerized system.

Carbonate formations are often stimulated by hydraulically fracturing the zone of interest with reactive fluids, most commonly hydrochloric acid. The productivity increase of the oil and gas wells where this stimulation approach is utilized, is often much less than predicted by the pretreatment design. This paper will address the problems and difficulties of properly designing an acid fracturing stimulation treatment, and will offer new techniques and alternative fluid systems that allow better designs for this type of stimulation.