Power Commission Research Articles

Redevelopment of Alabama Power Company's Lay Dam

Many electric utilities which operate combined steam and hydroelectric generating systems are becoming increasingly aware, as a result of recent system split-ups, of the value of hydro plants, not only to supply costly peaking power requirements but as spinning reserve for protection during such major system disturbances. These utilities are also becoming increasingly concerned about the future availability of such older hydro plants as the time approaches when the initial licenses issued by the Federal Power Commission under the Federal Power Act of 1920 will begin to expire.

Pipeline Failures Guide Highway Crossing Practice

A Federal Power Commission survey and report on failures of natural gas transmission pipelines, and their causes is discussed. Its findings on safety regulations of the States and proposed Federal minimum standards is analyzed for its impact on good practice for highway-pipeline crossings. Conclusions support recommended guides for depth of bury, encasement, and markers for pipelines at highway crossings, and warn of jurisdictional gaps in enactment and enforcement of safety regulations.

Dam Safety—An Objective of Federal Licensing

The safety of dams is a subject of both national and worldwide interest. An important area of such interest in the United States concerns the hydroelectric power dams constructed and operated by non-federal entities under licenses issued by the Federal Power Commission. The Commission’s regulations require the licensee to submit detailed drawings for projects, accompanied by adequate information relating to controlling factors, such as data on foundations and construction materials, stability and stress analyses for important structures, and spillway design criteria. Regional office staff engineers usually inspect projects under construction at not less than monthly intervals and those in operation about once a year. In December, 1965, the Commission established a new Part 12 of its regulations. The new regulations provide for a program of inspections by independent consultants at regular five-year intervals, to supplement the inspections by the Commission’s staff.

Developments in Western Canada in 1966

Overall exploration costs of about $415 million in Western Canada during 1966 were at an all-time high, up $21 million from 1965. Expenditure increases in wildcat drilling (up $20 million) and geophysical work (up $21 million) were partly offset by a decrease in land purchases (down $31 million). Surface mapping continued to decline sharply. Most of the exploratory interest and significant discoveries were in dolomite of the Middle Devonian Muskeg and Keg River Formations of northwestern Alberta. Other highlights of 1966 were: (1) a sharp rise in land acquisitions, particularly in the Territories and Arctic Islands; (2) a continuing production increase--up 6-9% in all sectors (liquids, gas, and sulfur) of the industry; (3) authorization by the Federal Power Commission of additional gas imports into northern California and Montana. Alberta and Southern was granted export permits of 100 MMcf. per day commencing November 1, 1966, and an equal additional amount to commence November 1, 1967. At that time, total average deliveries will be 615 MMcf. per day. West coast Transmission was granted a temporary export permit of 100 MMcf. per day commencing November 1, 1966, and the National Energy Board was considering Westcoast's application for a permanent amount of 200 MMcf. per day (ov r a 25-year period), which would increase total deliveries to El Paso in 1967 to 500 MMcf. per day. Pending at year end was Federal Power Commission approval of the Trans-Canada Great Lakes pipeline project, which essentially involves transportation of Canadian gas through the United States for re-delivery into Eastern Canada. Comparisons below are with 1965: Table

Federal Gas Regulation and the Producing Segment of the Gas Industry

Abstract The history of the regulation of the natural gas industry is traced from the passage of the Natural Gas Act of 1938. The original Federal Power Commission proceeding which started in 1948, the United States Supreme Court decision in 1954, the change in regulation techniques from company to area basis, the area guideline prices, the "in line" price basis, the Permian Basin hearing and Opinion 468 and the subsequent three area hearings are some of/he details reviewed. The long-term characteristics of the producing industry presented on figures show its rapid acceleration during the post-war period and the decline since about 1956. Data show that demand continues to increase, that potential reserves are available to be discovered and suggest that present downward trends in industry activity will eventually change. History of Gas Regulation In 1936 a commission investigated the gas utility industry and recommended federal laws to regulate transmission charges and wholesale city-gate rates of interstate lines. In 1938 Congress passed the Natural Gas Act giving the Federal Power Commission authority to regulate interstate lines. In 1940 the FPC ruled that it had no jurisdiction over field sales of gas by an independent producer and gatherer not affiliated with the purchasing pipeline. The FPC decided in 1946 that it had jurisdiction over field price of gas produced directly by Interstate Natural Gas Co. for its own interstate line. In 1947 the Supreme Court affirmed findings in the Interstate Natural case, but in less sweeping language than the circuit court. Also, the FPC issued Order No. 139 asserting that it would not attempt to regulate sales to interstate pipelines by producers and gatherers independent of transmission companies. In 1948 the FPC instituted an investigation into prices charged by Phillips Petroleum Co. for gathered and processed gas delivered to several interstate lines, chiefly at instigation of Wisconsin and Michigan cities served by Michigan-Wisconsin Pipe Line Co. for which Phillips was a big supplier and gatherer. Congress passed the Kerr bill in 1950 specifically exempting production and gathering from FPC jurisdiction. FPC did not oppose this amendment to the Natural Gas Act. President Truman vetoed the bill and FPC rescinded Order No. 139. In 1951, in a 4-t0-1 decision, the FPC ruled it had no jurisdiction over gas sales of Phillips and the case was taken to the U. S. Court of Appeals for District of Columbia. The FPC opposed this action, as did Phillips and the states of New Mexico, Oklahoma and Texas. On May 22, 1953, the court of appeals reversed the FPC in a 2-to-l decision and said that Phillips' sales were not made during the course of production and gathering so that Phillips was subject to FPC rate-making powers. On June 7, 1954, the Supreme Court's Phillips decision held that the commission had jurisdiction over the regulation of wellhead gas prices. Producers thereafter complied by making public filings to the FPC for all interstate contracts giving data such as rates, volumes and prices. Faced with the new problem of regulating thousands of gas producers, the commssion's first attempts at producer regulation were on an individual company basis. A few of the first rate increase filings were approved on the basis of cost evidence. In 1956 President Eisenhower in effect said that he was forced to veto HR 6645 (Harris-Fullbright bill) which amended the Natural Gas Act, but that he regretted this action because he was in accord with the act's basic objectives. He also sent a message to Congress urging repeal of the regulation of independent producers of natural gas. The years 1956 to 1960 were a period of evolution in gas regulation. The courts indicated that the commission need not require conventional rate base evidence if other cost evidence were available to insure that consumers were not paying more than a just and reasonable price, including cost of capital investment. The courts also ruled that the FPC need not fix separate rates for each producer if it found a uniform rate desirable.

Water Resources Site Preservation on Federal Lands

The Bureau of Reclamation, Federal Power Commission, and Geological Survey preserve water resources sites. Through cooperative procedures of these agencies and the land management agencies, Federal lands designated as being valuable for water power or reservoir sites are managed to forestall undesirable encumbrances, yet allow many interim uses without destroying site values. These designated sites are acquired for water development either through Congressional approval of projects to occupy them or through operation of public land laws. Site preservation procedures serve to protect a limited resource and to retain control of advantages derived; and such operations are beneficial to all organizations developing water resources, whether Federal or not.

The Northeast power failureߞa blanket of darkness

The massive blackout of November 9-10 has triggered some prompt and expeditious action, spearheaded by the Federal Power Commission's list of 19 affirmative recommendations that should be implemented by the utilities to preclude the possibility of a recurrence. These proposals include the need for fully coordinated power pools, more extensive stability studies for the operation of interconnected systems, the need for mixed generation facilities for quicker response to power swings, and a review of the adequacy of existing automated equipment.

The Review Function in Water Resources Development

Water resources projects reviewed for the investment of public funds must pass tests against criteria that have been virtually unchanged since 1802. Selected projects show continuity of criteria, common features likely to produce controversy, and proved evaluation procedures. The Corps of Engineers projects reviewed by the Board of Engineers for Rivers and Harbors prior to authorization by the Congress serve as the basis for much of the paper. Attention is given to adequate presentation of all information needed for a reliable decision by a body concerned with professional integrity, the full significance of reasonable alternatives, and sound project formulation. The application of announced policy to specific projects frequently shows inadequacies or inconsistencies not recognized previously and best resolved with the aid of collective judgment by an experienced review organization. Projects must meet tests for feasibility, adequate value, and an assured market. They must show economic efficiency by comparing favorably with other alternatives. The review integrates political factors in the decision process at Secretary level or higher. Roles of the Federal Power Commission and the Bureau of the Budget receive special attention.

Federal Power Commission Control over River Basin Development

Federal Power Commission Control over River Basin Development

The Cost of Natural Gas

Abstract Three principal methods of cost determination have been proposed to the Federal Power Commission as a basis for pricing natural gas at the wellhead: the cost of service; the expenditure approach; and the inventory cost approach. Each of these approaches has severe limitations, partly due to the approach itself and partly, due to the presence of joint costs, which renders the resulting unit cost of gas subject to the vagaries of inherently arbitrary methods of allocation. Although some progress has been made in narrowing the gap between proponents of different allocation methods, the cost of gas can only be determined within relatively wide ranges, which do not furnish a sufficient degree of reliability to serve as a basis for pricing. Introduction The purpose of this paper is to review and appraise the principal methods of cost determination which have been proposed to the Federal Power Commission as the basis for pricing natural gas at the wellhead. I must caution that there is no such thing as "the" cost of natural gas; there may be "a" cost of natural gas, but even it cannot be determined with the degree of reliability and accuracy characteristic of scientific inquiry. In some degree, all cost determinations of gas are a fiction. There are several reasons for this inaccuracy and unreliability. A first obstacle arises from the difficulty of relating costs to the quantity of reserves found or produced. Thus, there is uncertainty over whether the supplies reported as found in a particular period were found as the result of expenditures in that period. The reported reserve additions consist of (1) discoveries and (2) extensions and revisions. Even if we assume that the reported discoveries of a particular period are the result of expenditures during that period - an assumption of questionable validity due to the time lags involved in the various phases of exploration-the extensions and revisions are to a considerable, though unknown, extent the result of exploratory expenditures in a prior period. A second obstacle stems from the elusive nature of hydrocarbons, which makes an accurate measurement of reserves impossible until after the reservoirs have been depleted. This obstacle is not only encountered when costs are related to reserves added, but also when costs are related to production, because costs include capital recovery charges which in turn are typically based on the relation between annual production and ultimate reserves. A third difficulty is the virtual impossibility of determining the cost for a gas supply other than for existing reserves. This difficulty stems both from the variability in productivity as well as the fact that an extractive industry tends to be an increasing-cost industry. These problems are particularly serious in determining cost for pricing, since the purpose of such a determination is partly to determine the expenditures necessary to discover supplies adequate to meet future demand, and the necessary supplies may exceed those that happen to have been found. An estimate of dollar expenditures required for an additional supply is difficult and uncertain, because it hinges on an estimate of the future productivity of drilling. A fourth obstacle stems from the fact that over 90 per cent of all gas is found and produced in conjunction with either oil or condensate liquids. The costs of finding and developing gas are therefore joint costs, subject to methods of allocation which are inherently discretionary and arbitrary. Hence, allocated costs are never in fact costs, but merely a reflection of individual judgments, which vary to such an extent that the results frequently vary 100 per cent between the low and the high. The fact that the cost of finding gas cannot be accurately determined does not mean that all cost studies are equally fictitious. Some fictions have more basis in reality than others. The extent to which cost determinations are fictitious is directly related to the degree to which the results are dependent upon allocation. This leads us to the important distinction between the cost of nonassociated and the cost of associated gas. Costing Nonassociated Gas In determining the cost of nonassociated gas, it is possible to directly identify the cost of drilling and equipping successful wells, as well as the cost of producing the gas. These items account for approximately half of total costs. This leaves the cost of dry holes, lease acquisitions, geological and geophysical as joint costs, which require allocations between oil reservoirs and gas reservoirs. During the last two years, considerable progress has been made in this area. Most experts who have presented costs of nonassociated gas at FPC proceedings agree that these joint costs should be allocated in proportion to either the cost of successful wells or the number of successful feet drilled. JPT P. 133ˆ

The Federal Power Commission Does Not Have Jurisdiction over the Sale of a Developed Leasehold Interest of Gas in Formation: Marr v. FPC

The Federal Power Commission Does Not Have Jurisdiction over the Sale of a Developed Leasehold Interest of Gas in Formation: Marr v. FPC

Due Process of Law. In General. Fair Housing Act Is Constitutional but Commission's Power to Issue "Appropriate" Orders Is Too Broad. Colorado Anti-Discrimination Comm'n v. Case (Colo. 1962)

Due Process of Law. In General. Fair Housing Act Is Constitutional but Commission's Power to Issue "Appropriate" Orders Is Too Broad. Colorado Anti-Discrimination Comm'n v. Case (Colo. 1962)

Utilities. Ratemaking. Federal Power Commission May Restrict Return on Investment Made Possible by Income Tax Fast Writeoff Provisions to That Necessary to Assure Their Use. Panhandle E. Pipe Line Co. v. FPC (D. C. Cir. 1963)

Utilities. Ratemaking. Federal Power Commission May Restrict Return on Investment Made Possible by Income Tax Fast Writeoff Provisions to That Necessary to Assure Their Use. Panhandle E. Pipe Line Co. v. FPC (D. C. Cir. 1963)

An International comparison of voltage-transformer calibrations to 350 kv

IN JUNE 1960, the Hydro-Electric Power Commission of Ontario inquired whether the United States National Bureau of Standards (NBS) in Washington could measure for them the ratio and phase-angle errors of a 350-kv voltage transformer then being built to their order. This request was also made at about the same time of the National Research Council of Canada (NRC) in Ottawa. Neither laboratory had, at that time, made calibration measurements on instrument transformers at this voltage level, but both had given the problem considerable thought; and it appeared that the request by Ontario Hydro afforded a unique opportunity not only to examine some of the problems involved in voltage-ratio measurements at 350 kv, but also to compare measurement results between the two national laboratories.

FPC Jurisdiction over Nonnavigable Waters: United States: Federal Power Commission. Water and Watercourses. Electricity

FPC Jurisdiction over Nonnavigable Waters: United States: Federal Power Commission. Water and Watercourses. Electricity

Aspects of Gas Deliverability

Abstract Three aspects of gas deliverability are presented in this paper. The first treats with the gas deliverability or availability of a normal depletion-type dry gas field. Such encompasses not only the period of stabilized constant rate, but in ore so, the "tailings" when a fixed abandonment pressure is reached and the rate by necessity must decline. A comprehensive work plot is offered, developed from mathematics herein included, that removes the trial-and-error computations that attended such undertakings in the past. The second part treats with the discount factor of the open flow potential constant from what is observed initially in testing a gas well to what is evidenced when stabilization is reached. This prevails in tight formations, such as the Kansas Hugoton field which is offered as the example. The means of establishing this factor are pressure build-up curves which, as sustained by analytical deductions, reproduce this entire period of transient flow under conditions of a constant rate influx. Finally, what is offered in this paper is the deliverability performance of an exceedingly rich gas condensate field producing from a tight formation. The example shown is the Knox Bromide field in Oklahoma, producing from the Bromide formations. The results are ominous, showing early reduction in permeability to gas flow, due to the retrograde condensate forming in the pore space, with the attending early logging-up of these wells. The analytics of lowered permeability are incorporated in the gas deliverability formula along with the PVT data that gives the increased condensate liquid saturation as the gas flows to the wellbore. This paper would not be complete without a critique offered at the end. With the many gas wells now in production and those that have completed their life, there has been no factual information collected by any source as to what constitutes that permeability range where a gas well would be unimpaired in its gas deliverability by the presence of rich condensate content, and the lowered range where such would be harmful. This question confronts all producers. Introduction Various aspects of gas deliverability are presented in this paper that includes depletion-type reservoirs, deterioration factor of the gas deliverability constant, and the performance of a rich gas condensate reservoir producing from a tight sand. With respect to the presentation of gas deliverability and its tailings for depletion-type gas reservoirs, one notes that this is essentially the information offered by every gas transmission company and producer appearing before the Federal Power Commission for Letters Of Conveyance in the dedication of reserves. In the ordinary procedure, as many engage upon this study, trial-and-error calculations are included, particularly as apply to the tailings. For many years one of the writers has employed mathematical analyses to perform this step and avoid the complexities so associated. In the preparation of this paper these analyses have been amplified to include any slope n for the open flow potential relationship for which the tailings can be determined from Fig. 1.With reference to the deterioration or discount factor of the open flow potential constant as such occurs in the gas deliverability formula, this for the most part has been an unexplored subject. Although the issue first appeared in the Kansas Hugoton field, where such was surmised but only recently resolved, this situation of a deterioration of the gas deliverability constant can occur wherever dry gas production from a tight sand is encountered. The first concerted attacks upon this problem were the presentations of Hurst and Goodson before the Kansas Corporation Commission to show that transient fluid flow and unsteady-state flow formulas prevailed. This was amplified later before the Federal Power Commission to show that this deterioration factor could be identified from pressure build-up curves. This has been reported by McMahon. Its importance to the industry merits the review of these essential features in completing the program on the aspects of gas deliverability. Finally, as illustrated here, for a low permeability formation such as the Knox Bromide field where the gas is rich, representing some 165 bbl of condensate per MMcf of effluent gas, the gas deliverability can be of limited extent in the life of the field, leaving substantial amounts of condensate and gas unrecovered. In cases such as this, gas cycling is mandatory. This is particularly revealed by the fluid mechanics introduced here, employing factual field as well as laboratory data, to show this restriction upon gas deliverability. JPT P. 668^

The NPD Nuclear Power Station Electrical System and the Statistical Approach to Its Design

This paper describes the electrical system designed for the Nuclear Power Demonstration (NPD) Generating Station and the statistical approach used to make decisions as the design progressed. NPD is a 22-mw (megawatt) nulcear power station designed by Canadian General Electric Company in co-operation with Atomic Energy of Canada, Ltd., and The Hydro Electric Power Commission of Ontario (HEPC). The reactor is heavy-water-moderated and heavy-water-cooled and uses natural uranium as the fuel. The plant is located on the Ottawa River about 1 mile downstream from the Ontario Hydro's Des Joachims generating station. An electrical system was designed for NPD which is quite similar to that which would be found in a conventional generating station of the same rating. However, because of the critical nature of some of the processes during all phases of operation including shutdown, a great deal of emphasis was placed on reliability. Throughout the design, circuit configuration and equipment selection stressed reliability as well as cost.

Natural Gas Regulation in the Future: ABSTRACT

The pipeline transmission companies and producers may expect more liberal treatment in the future from the courts and the Federal Power Commission because this will be essential in the public interest. The Supreme Court, in the now famous CATCO case, directed the Commission to their responsibility under the Natural Gas Act to fix rates consistent with maintaining a supply of natural gas to the consumers. We must assume that the courts and the Commission will not lose sight of this responsibility, but recent decisions disclose that this regulatory agency is not aware of the fact that they are faced at this time with maintaining a supply of natural gas to consumers. The transmission companies must build and finance additional pipelines to meet increasing demands of consumers, but they have the problem today of obtaining the necessary funds at reasonable costs with the bloom being off pipeline investments. Consideration must be given to the depreciating rate base, rate of return, and other factors which determine the attractiveness of pipeline investments. The Commission has recently followed the practice of not only using area pricing for the purpose of placing a lid on producers' prices, but also for rolling back existing area prices. The failure of many companies to bid on offshore acreage offered recently by the Federal Government and the State of Louisiana in areas known to contain proven or potential natural gas-producing acreage should be a warning that producers are losing their incentive to take the costly capital risks to drill for natural gas. This will have its effect on the supply of gas in 5 or 10 years. However, it is not believed that producers can hope for more liberal treatment until the Commission is convinced that there will be a shortage of natural gas in the near future. End_of_Article - Last_Page 370------------

Producer Rate Regulation in Natural Gas Certification Proceedings: "Catco" in Context

The Supreme Court’s 1959 Catco opinion held that the Federal Power Commission should give more consideration to proposed prices when awarding certificates authorizing the sale of natural gas. This article addresses the contribution of this decision to producer price regulation, in the historical context in which it finds significance, and its impact on the FPC and court of appeals decisions that followed.

Floating-point arithmetic in COBOL

article Free AccessFloating-point arithmetic in COBOL Author: O. Kesner Hydro-Electric Power Commission of Ontario, Toronto, Ont., Canada Hydro-Electric Power Commission of Ontario, Toronto, Ont., CanadaView Profile Authors Info & Claims Communications of the ACMVolume 5Issue 5May 1962 pp 269–271https://doi.org/10.1145/367710.367739Published:01 May 1962Publication History 1citation354DownloadsMetricsTotal Citations1Total Downloads354Last 12 Months19Last 6 weeks4 Get Citation AlertsNew Citation Alert added!This alert has been successfully added and will be sent to:You will be notified whenever a record that you have chosen has been cited.To manage your alert preferences, click on the button below.Manage my AlertsNew Citation Alert!Please log in to your account Save to BinderSave to BinderCreate a New BinderNameCancelCreateExport CitationPublisher SiteeReaderPDF