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When an oil operator becomes a party to a proration agreement he may wonder, with good cause, whether production prorated today is merely deferred untiltomorrow or whether oil might be lost. Various types of evidence obtained fromproduction records when studied quantitatively are of great assistance inarriving at definite conclusions. A study of individual examples cited in thispaper leads towards some solution of the problem, particularly when they areconsidered in the aggregate. Many production curves on various pay horizons were studied. A disappointinglylarge number of these were of contributory value, but inconclusive. However, there were enough curves of similar type from the Wilcox sand at Earlsboro, Bowlegs, Seminole City, the Cromwell horizon at Little River, and the Simpsondolomite at Valley Center, Kansas, from which reasonably definite conclusionswere drawn. Assuming that deferred production is later made up with no increase in ultimaterecovery, a curve (Fig. 1) shows the normal flowing and pumping life of acomposite well, constructed by the family curve method. The initial productionof the well shown is 1700 bb1. daily and the allowed production is 25 per cent.On this basis the average daily allowed rate for the first month is 425 bbl., or the area BCDE, which is equivalent to the area AFDG under the normal declinecurve. The potential production for the second month is 1500 bb1. and theallowed production 375 bb1. daily By this procedure a potential curve for eachsucceeding month is obtained (points A, H, I, J and K). If the well is openedit should produce somewhere near its potential curve for a short period andthen decline at a more rapid rate than the potential curve. This theoreticalanalysis is basic. Actual examples exhibiting all points raised by the idealcurve are rare.
Introduction Oil wells usually reach their maximum daily output shortly after they arecompleted. From that time they decline in production; the rapidity of declinedepending on the output of the wells and on other factors governing theirproductivity. The production curve of a well shows the amount of oil producedper unit of time for several consecutive periods; if the conditions affectingthe rate of production are not changed by outside influences, the curve will befairly regular, and, if projected, will furnish useful knowledge as to thefuture production of the well. By the aid of this knowledge the value of aproperty may be judged, and proper depletion and depreciation charges may bemade on the books of the operating company. Certain difficulties peculiar tooil production are encountered when estimating the future production of oilwells, and the oil producer has been more uncertain regarding the futureproduction of his property than the producer of almost any other mineral. In recent years much attention has been devoted to this problem, andconsiderable progress has been made in the development of methods forestimating future production. As valuable as these methods are, to the producerwho knows how to use them, they still leave much to be desired in accuracy andease of application. Methods are needed that are more dependable, that willfurnish closer estimates from data obtainable early in the life of theproperty, that show the limitation of the estimates, and that may be quicklyand easily applied. The present paper discusses some new methods which meetsome of these requirements. So far as we know, the information given is new. The methods outlined havegreatly assisted us in evaluating oil properties in certain fields during thelast 2 years, and if confirmed by data now being gathered in other fields, their value will be still greater. Although the deductions here presented havebeen derived from enough data to warrant the belief that further investigationswill confirm them, some of them are advanced only tentatively. AIME 059โ48
- South America > Brazil > Parnaiba Basin > Block PN-T-68 > California Field (0.99)
- North America > United States > Oklahoma > Anadarko Basin (0.89)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)
Abstract Only 5 โ 10% of the oil in Lloydminster heavy oil reservoirs is recovered during cold production with sand (CHOPS). Cyclic solvent injection (CSI) is the most promising post-CHOPS follow-up process. In CSI, a solvent mixture (e.g. methane-propane) is injected and allowed to soak into the reservoir before production begins (Figure 1). CSI has been focused on heavy oil recovery from post-CHOPS reservoirs that are too thin for an economic steam-based process. It has been piloted by NEXEN and by Husky and was a fundamental part of the $40 million Joint Implementation of Vapour Extraction (JIVE) solvent pilot program that ran from 2006โ2010. This paper describes field scale simulations of CSI performed with a comprehensive numerical model that uses "mass transfer" rate equations to represent non-equilibrium solvent solubility behaviour i.e. there is a delay before the solvent reaches its equilibrium solubility in oil. The model contains mechanisms to consider foaming or to ignore it depending on the field behaviour. It has been used to match laboratory experiments, design CSI operating strategies, and to interpret CSI field pilot results. The paper summarizes the impact on simulation predictions of post-CHOPS reservoir characterizations where the wormhole region was represented by one of the following five configurations: (1) an effective high permeability zone, (2) a dual permeability zone, (3) a dilated zone around the well, (4) wormholes (20 cm diameter spokes) extending from the well without branching, (5) wormholes extending from the well with branching from the main wormholes,. The different post-CHOPS configurations lead to dramatically different reservoir access for solvent and to different predictions of CSI performance. The impacts of grid size, upscaling, well inflow parameter, solvent dissolution and exsolution rate constants, and injection strategy were examined. The assumption of instant equilibrium solubility resulted in a 23% reduction in oil production compared to when a delay in solvent dissolution and exsolution was allowed for. Increasing the grid block size by a factor of 9 reduced the predicted oil production five-fold. Assuming isothermal behaviour in the simulations decreased predicted oil production by 17%.
- North America > Canada > Alberta (0.28)
- Europe > United Kingdom > North Sea > Central North Sea (0.24)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Introduction During the past 98 years the United States has produced annually more crude oil than any other country, except during one three-year period and another period of four years. Needless to say this nation has surpassed all others in cumulative production. The United States for many years has produced a greater percentage of its proved reserves annually than has any other country with large reserves. The high annual withdrawal from reserves by this nation in the past may lead in the future to the loss of its status as center of crude oil production. Center of Annual Production Rumania, birthplace of the oil industry, was the center of crude oil production during the three-year period, 1857 to 1859 (Fig. 1 and Table 1). Actually, it had the only recorded output in 1857 and 1858 and 67 per cent of world production in 1859. Before continuing the citation of honors as center of world's production, it should be mentioned that there may have been small production from some spot before records were kept. The United States was largest producer from 1860 through 1897. U.S.S.R. took the lead from this nation in 1898 and held it through 1901. However, the United States regained the front position in 1902 and has not been overtaken since then. Since the first year of its supremacy, 1860, the United States has produced 50 per cent or more of world's production every year with these exceptions: 1898 to 1902, inclusive, 1953 and 1954. During the period 1907 through 1947 thenation's output was over 60 per cent of world's production each year, and in six of the years it produced 70 per cent or more of world's total. There are several countries that should not be ignored despite the fact that they have not led the world as yet in production any year. A comparison of the maximum annual production of each of nine countries and the same year's production of the other eight countries is shown in Table 2. (See Fig. 2 also.) Six of the cited countries registered their maximum annual production in 1954. Probably all of these could produce more than they did in 1954. The percentage of the world's 1954 production credited to Iraq, Kuwait, and Saudi Arabia - and the known potentialities of these countries and Iran - suggest the direction in which the center of production is moving.
- Asia > Middle East (1.00)
- North America > United States > California (0.48)
- South America > Brazil > Parnaiba Basin > Block PN-T-68 > California Field (0.97)
- North America > United States > Texas (0.89)
- North America > United States > Oklahoma (0.89)