Washington Gas Light Co. v. Public Service Commission

450 A.2d 1187, 1982 D.C. App. LEXIS 433

• Court: District of Columbia Court of Appeals
• Decided: September 10, 1982
• Docket: 79-587, 79-740, 79-745 and 79-746
• Status: Published

Opinions

PER CURIAM:

In these consolidated petitions of appeal, the various petitioners have raised numerous objections to a ratemaking decision of the Public Service Commission (the Commission or PSC) granting Washington Gas Company (WGL or the Company) an increase in operating revenues of $7.1 million (of which $3.9 million was included to cover added income taxes).

The proceeding commenced in July, 1977 when WGL filed with the Commission an application to increase its rates and charges for gas service within the District of Columbia. The Company originally sought to increase its annual gross operating revenues by $8.6 million, so as to produce a 9.85% overall return on investment and a return of 14.5% on common equity. That request was based upon a calendar 1976 test year. On December 1,1977, the Company filed an amended application based on a test year ending June 30, 1977. The amended application sought a $10.9 million revenue increase in order to produce the same overall rate of return (9.85%) and the same return on equity (14.5%) as were originally requested.

On October 19, 1977, the Commission granted intervention to the Apartment and Office Building Association of Metropolitan Washington, Inc. (AOBA), Columbia Realty Venture (CRV), the General Services Administration (GSA) (representing the consumer interests of the executive agencies of the United States Government), People’s Counsel¹ (PC), the Staff of the PSC (Staff), and other parties not pertinent to these appeals. Following lengthy hearings, briefing, and considerable decisional delay, the Commission issued its Proposed Opinion and Order No. 6051 on February 13,1979 (Order No. 6051). After the parties noted their exceptions to the proposed order, the Commission issued its Final Opinion and Order No. 6060 on March 16, 1979 (Order No. 6060)². The final order, which adopted the proposed order with minor modifications, granted WGL a revenue increase of $7.1 million and authorized rates of return of 9.25% overall (on rate base) and 13.0% on common equity. The Commission also instituted a new rate design which had the effect of increasing the disparities in rates of return among WGL’s various customer classes.

Timely Applications for Reconsideration of the Commission’s final order were lodged with the PSC by all pertinent parties. See D.C.Code 1981, § 43-904. The Commission thereafter denied those applications in Order No. 6069, issued April 26, 1979, and Order No. 6082, issued May 11,1979. These petitions of appeal followed.

On appeal, the Company raises eleven separate issues. It challenges as unlawful, unreasonable, or confiscatory the Commission’s decisions regarding the rate design, rate of return, attrition, and the treatment of miscellaneous gains, losses, and operating expenses. It also contests the Commission’s consideration of federal wage and price guidelines in setting the new rates. The GSA, AOBA, and CRV join the Company in challenging the rate design. People’s Counsel supports the Commission on each of the issues raised by WGL, but, together with the GSA, urges that it was error for the Commission to compute WGL’s revenue requirements using a tax allowance based on a 48% federal corporate tax rate, when that rate had been replaced by a 46% tax rate prior to the issuance of the Commission’s decision.

We conclude that, with respect to all issues, as the decision of the Commission was not unreasonable, arbitrary, or capricious, and as the Commission adequately explained the reasons for its decision, the Commission’s order must be affirmed.

I. Scope of Review

Our review of the Commission Order is governed in the first instance by D.C.Code 1973, § 43-706, which narrowly circumscribes the scope of our review “to questions of law, including .constitutional questions; and the findings of fact by the Commission shall be conclusive unless it shall appear that such findings of the Commission are unreasonable, arbitrary, or capricious.” See, e.g., Metropolitan Washington Board of Trade v. Public Service Commission, D.C.App., 432 A.2d 343, 350 (1981); Potomac Electric Power Co. v. Public Service Commission, D.C.App., 402 A.2d 14, 17 (en banc), cert. denied, 444 U.S. 926, 100 S.Ct. 265, 62 L.Ed.2d 182 (1979); People’s Counsel v. Public Service Commission, D.C.App., 399 A.2d 43, 45 (1979); Washington Public Interest Organization v. Public Service Commission, D.C.App., 393 A.2d 71, 75 (1978), cert. denied, 444 U.S. 926, 100 S.Ct. 265, 62 L.Ed.2d 182 (1979). To facilitate our review, the Commission must indicate “fully and carefully the methods by which, and the purposes for which, it has chosen to act, as well as its assessment of the consequences of its orders for the character and future development of the industry.” In re Permian Basin Area Rate Cases, 390 U.S. 747, 792, 88 S.Ct. 1344, 1373, 20 L.Ed.2d 312 (1968); see Metropolitan Washington Board of Trade v. Public Service Commission, supra at 351-52. We are obliged to examine the record to determine whether the Commission has acted arbitrarily, and whether each component of the Commission order is supported by substantial evidence. In re Permian Basin Area Rate Cases, supra, 390 U.S. at 792, 88 S.Ct. at 1373; People's Counsel v. Public Service Commission, supra at 45. We must further ascertain that, in striking a balance between the competing consumer and investor interests, “the Commission has given reasoned consideration to each of the pertinent factors.” Id. at 45-46 (quoting In re Permian Basin Area Rate Cases, supra, 390 U.S. at 792, 88 S.Ct. at 1373).

At the same time, in recognition of the authority delegated to the Commission by Congress, and of the expertise of the commissioners- in the complex and esoteric area of utility'regulation, we accord great respect to the decisions of the commissioners. See Goodman v. Public Service Commission, 162 U.S.App.D.C. 74, 78-79, 497 F.2d 661, 665-66 (1974). We have stated that, “Our review of a utility commission order is the narrowest judicial review in the field of administrative law.” Potomac Electric Power Co. v. Public Service Commission, supra at 17; accord, Metropolitan Washington Board of Trade v. Public Service Commission, supra at 351.

Theories of ratemaking in particular fall within the special province of the Commission. Although “[a] theory of rate-making must be reasonable, explained, and supported, [it] is not subject to the same substantiation principle as the substantial evidence test applicable to fact-finding.” Continental Air Lines, Inc. v. Civil Aeronautics Board, 179 U.S.App.D.C. 334, 342, 551 F.2d 1293, 1301 (1977). A reviewing court may not supplant valid theories employed by the Commission with those “more nearly to its liking.” Metropolitan Washington Board of Trade v. Public Service Commission, supra at 352. Accord, In re Permian Basin Area Rate Cases, supra 390 U.S. at 792, 88 S.Ct. at 1373; Potomac Electric Power Co. v. Public Service Commission, supra at 18. Nor may we “reassess the weights given by a rate-making agency to different factors, absent a legislative direction as to precisely what gravity each factor bears. All that the [reviewing] court may properly do is to consider whether the agency did take into account all the relevant factors and no others.” Association of American Publishers, Inc. v. Governors of the United States Postal Service, 157 U.S. App.D.C. 397, 403-04, 485 F.2d 768, 774-75 (1973).

Indeed, the Supreme Court has established that it is the “total effect” of a rate order, rather than the theory employed, that determines its validity.

Under the statutory standard of “just and reasonable” it is the result reached not the method employed which is controlling. ... It is not theory but the impact of the rate order which counts. If the total effect of the rate order cannot be said to be unjust and unreasonable, judicial inquiry ... is at an end. The fact that the method employed to reach that result may contain infirmities is not then important. [Federal Power Commission v. Hope Natural Gas Co., 320 U.S. 591, 602 [, 64 S.Ct. 281, 287, 88 L.Ed. 333] (1944) (citations omitted).]

This standard was held applicable to the District of Columbia Public Service Commission in Washington Public Interest Organization v. Public Service Commission, supra at 75:

These statutory criteria [D.C.Code 1981, §§ 43-501, -601, -611, -905, -906] are akin to those governing the Federal Power Commission and its oversight by the federal courts. In that context, the Supreme Court has held that unless the overall effect of a rate is “unjust and unreasonable,” the Commission’s order should be approved, irrespective of “infirmities” in the methodology used to calculate it.

Accord, Metropolitan Washington Board of Trade v. Public Service Commission, supra at 351.³

In Washington Public Interest Organization v. Public Service Commission, supra, we clarified our role as a reviewing court in light of the broad authority allotted the Commission under Federal Power Commission v. Hope Natural Gas Co. and its progeny:

While it is true that a regulatory commission cannot be faulted for its methodology if the “total effect of the rate order cannot be said to be unjust and unreasonable,” Federal Power Comm’n v. Hope Natural Gas Co., [supra, 320 U.S. at 602, 64 S.Ct. at 287], it is also true that the methodology must be disclosed for the bearing it may have on that overall judgment. Absent precise explanation of methodology as applied to the facts of the case, there is no way for a court to tell whether the Commission, however expert, has been arbitrary or unreasonable. [Washington Public Interest Organization v. Public Service Commission, supra at 76-77.]

This requirement is intended to assist the reviewing court:

[B]ecause ratemaking is complicated and understandably prone to technical, often shorthand terminology, there is a substantial risk that agency action will be too conclusional — not elaborate enough— for a non-expert court confidently to review. A court, without insisting on more precise explanation, could simply be fooled into accepting arbitrary agency action by the mesmerizing influence of the confidently expressed language of experts.

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While our own authority is . . . limited, our authority — and responsibility — to find out why an agency acts as it does is considerable. [Id. at 78-79.]

We therefore imposed an independent burden on the Commission to explain its actions fully and clearly, by (1) announcing the criteria governing its determination, and (2) explaining how the particular order reflects application of these criteria to the facts of the case. Id. at 75.

Ratemaking orders, as the product of expert judgment, are presumptively valid; the petitioner challenging an order carries the heavy burden of demonstrating clearly and convincingly a fatal flaw in the action taken. Federal Power Commission v. Hope Natural Gas Co., supra 320 U.S. at 602, 64 S.Ct. at 287; Metropolitan Washington Board of Trade v. Public Service Commission, supra at 351-52; Potomac Electric Power Co. v. Public Service Commission, at 18; Goodman v. Public Service Commission, D.C.App., 309 A.2d 97, 101 (1973). The additional requirements imposed on the Commission by Washington Public Interest Organization v. Public Service Commission do not detract from the presumptive validity of Commission rate orders. Even if the court disagrees with the Commission, if the Commission has fully and clearly explained what it does and why it does it, and the agency decision is supported by substantial evidence, the court, upon a finding that the Commission order is reasonable in its overall effect, should sustain the order.

With these considerations in mind, we turn to the individual assertions of error raised by the parties.

II. Rate Structure

AOBA, CRV, GSA, and the Company contend that the rate design prescribed by the Commission unjustifiably discriminates in favor of certain residential utility customers at the expense of other commercial and industrial customers. We find that the rate design established by the Commission was based upon sound ratemaking principles and ample consideration of the evidence, and that class-based differences in the approved rates are adequately supported in the record by both cost and non-cost factors.

A. Background

Rate design, or rate structure, is the mechanism whereby a utility realizes its revenue requirements. See Order 6051, at 80. Costs that are thus recovered include “customer costs,” “demand costs,” and “commodity costs.” Customer costs are the fixed costs incurred in the maintenance of facilities and in providing service to customers.⁴ These costs are unrelated to the quantity of gas consumption, and are virtually identical for all utility customers. Demand costs include equipment and storage costs that are incurred in serving customers collectively.⁵ Equipment must be capable of meeting peak load requirements; in non-peak periods storage costs are incurred in maintaining a state of preparedness for peak period demands. Certain WGL customers, especially those who use gas for heating and cooling, are largely responsible for the occurrence of peak periods, and thus bear greater responsibility than others for demand costs. Commodity costs cover the cost of the gas itself, and, in the immediate sense, vary directly with the volume of gas consumed.⁶ See generally Order 6051, at 81 & n.l; WGL Exh. J, at 12,17 (testimony of Edmund W. Smallwood).

Prior to 1976 WGL employed a Commission-sanctioned “declining block” rate structure. Under this system initial units of gas purchased were most expensive, in order for the Company to recoup fixed demand and customer costs. Successive purchases were incrementally less expensive, so that average commodity costs varied inversely with consumption. In times when commodity costs were relatively low, the declining block structure, which was inherently promotional, and which reflected economies of scale realized on fixed costs in sales to large scale commodity consumers, was justified on economic grounds, as closely mirroring cost causation. See In re Washington Gas Light Co., 16 P.U.R.4th 261, 278 (D.C.P.S.C. 1976).

In 1976 the Commission, in consideration of escalating gas replacement costs and declining gas availability, reevaluated and rejected the traditional promotional rate structure:

Complicating the cost picture are several factors. One is that existing and new supplies of gas are becoming more and more costly. To the extent that the company must replace gas sold on a promotional basis with higher priced gas, its average costs will escalate. Another factor is that the company’s service is limited by gas supply, as well as by pipeline capacity. In these circumstances, traditional allocation techniques must be reevaluated; customers’ responsibility for fixed costs must be related more closely to their gas usage. [Id. at 278-79.]

Equally important, the Commission recognized the need to “stress conservation of a wasting resource, natural gas,” and concluded that “[promotional rate structures tend to foster a misallocation of scarce resources.” Id. at 279.

In lieu of the traditional rate structure the Commission in 1976 approved a two-part rate, comprised of a uniform commodity charge of twenty-one cents per therm, and a “system” or “customer” charge.⁷ A uniform commodity charge, it was reasoned, would encourage conservation and eliminate the misallocation problem inherent in the declining block structure. The system charge was designed both to insure that the Company would recoup fixed costs, and also to ease the transition from the declining block structure to a two-part rate structure. The Commission stated, “Our decision rests upon pragmatic as well as theoretical considerations. When a commission ushers in a drastically new rate structure, it has the responsibility — or at least the discretion — to temper radical changes in the historical rate patterns.” Id. at 280.

Even upon issuance of the 1976 decision the Commission anticipated periodic review and modification of the system charge levels.

Moreover, in a future general rate case, the commission will consider rate structure again. This case is only the first step in a periodic review of system charge levels. Once customers have had a fair opportunity to adjust to the new rate structure, the company can consider system charges which include more cost ingredients. [Id]⁸

B. The Commission’s Action in the Case Before Us

The Commission maintained the two-part rate structure in the instant case, keeping intact the commodity charge, and merely renaming the “system charge,” which is now the “customer charge.” Order 6051, at 81. Rate schedules, however, were reevaluated and revised. The commodity charge was increased from 21 cents per therm to 32.55 cents per therm. Order 6060, at 5. Customer charges for different classes of customers were modified as follows:

CUSTOMER CLASS FORMAL CASE 647 FORMAL CASE 686

(1976) (1979)

Residential heating $72/year ($8/month; 9 months/year $45/year ($5/month; 9 months/year)

Residential non-heating $45/year ($3.75/ month; 12 months/ year) $30/year ($2.50/ month; 12 months/ year)

Small commercial & industrial heating (under 3,000 Ccf) (Ccf = 100 cubic feet) $148.50/year ($16.50/ month; 9 months/ year) $58.50/year ($6.50/ month; 9 months/ year)

Large commercial & industrial heating (3,000 Ccf and up) $148.50/year ($16.50/ month; 9 months/ year) $148.50/year ($16.50/ month; 9 months/

Non-heating commercial & industrial $84/year ($7/month; 12 months/year) $84/year ($7/month; 12 months/year)

Watergate & Interruptible $.19/therm $.30/therm

See Order 6060, Charts A and B; In re Washington Gas Light Co., supra at 287; Order 6051, at 90-100.

1. Residential Customers9

a. Heating and Cooling Customers

The Commission explicitly adopted the recommendation of WGL that the monthly charge to residential heating and cooling customers be reduced from $8 to $5, to “soften the adverse impact that a fixed charge each month has on small volume customers.” Order 6051, at 95 (quoting WGL Exh. J, at 19-20 (testimony of Edmund W. Smallwood)). Whereas the WGL proposal sought a reduction only for customers who consumed below 100 Ccf per year, however, the Commission remarked that “WGL concedes that there is no real difference in the customer costs based on annual consumption [between customers who consume above and below 100 Ccf per year],” Order 6051, at 96, and therefore applied the $5 charge uniformly to all residential heating and cooling customers.

b. Non-Heating and Non-Cooling Customers

Residential non-heating and non-cooling customers use gas solely for cooking and/or heating water. The Commission remarked upon the low revenues WGL receives from this class, but also noted that under the two-part rate this class of customers pays the highest unit price for service of any class. Id. WGL, the Commission found, had in the past promoted gas usage among these low-volume gas users “who are in no position to respond to more cost-based rates.” Id. at 97. The Commission, in the face of this conflict between cost causation and “historic rate patterns and social considerations,” id., reduced the customer charge for the residential non-heating, non-cooling customer class by approximately the same proportion as it reduced the residential heating and cooling class, from $8.75 per month to $2.50 per month.

2. Commercial and Industrial Customers¹⁰

a. The WGL Proposal

When two-part rates were first employed, all commercial and industrial heating and cooling customers were treated alike. In this case WGL proposed segregating these customers into three categories according to their levels of usage, and varying customer charges accordingly. Customers consuming less than 1,000 Ccf per year (the “store front commercial customer”) would pay a $5 monthly customer charge; those consuming 1,000 to 3,000 Ccf per year would pay an $8 monthly charge; and those using in excess of 3,000 Ccf yearly would, under the WGL plan, pay a $25 monthly customer charge. WGL Exh. J, at 22.

b. The Commission's Order

The Commission accepted WGL’s dichotomy between those commercial and industrial heating and cooling customers who consume more than 3,000 Ccf per year and those who consume less than this amount, but the Commission found no basis for distinguishing between small usage customers (less than 1,000 Ccf yearly) and medium usage customers (1,000 to 3,000 Ccf yearly). A $6.50 monthly customer charge was imposed on all customers who use less than 3,000 Ccf per year.

The Commission also rejected WGL’s proposal that large commercial heating and cooling customers pay a $25 monthly customer charge. First, the Commission found the previous customer charge of $16.50 for this group effectively comprehended the greater costs accompanying these customers’ comparatively greater sizes. Second, the Commission stated that “[cjustomer costs for all customer classes exceed the respective customer charges, but we can find no reason for increasing the charge for only one sub-class, large volume commercial.” Id. at 98-99.

Rates for non-heating, non-cooling industrial and commercial customers were left unchanged at $7 per month.

3. Interruptible Customers¹¹

In Formal Case 647 the rate for interrup-tible customers was set at nineteen cents per therm, two cents below the flat firm commodity charge. The Commission concluded that that rate covered fixed and commodity costs, was fair to consumers, and was competitive with other sources of supply. In re Washington Gas Light Co., supra at 282.

In the instant case the Commission adopted the WGL proposal that the interruptible rate be increased to thirty cents per therm, to reflect increases in commodity, fixed, and capital costs; the Commission found too that the thirty cents per therm rate was still competitive with other fuel sources. Order 6051, at 99 — 100.

C. Analysis

1. Two-Part Rate Structure

Only People's Counsel argued to the Commission in favor of a single volumetric rate rather than a two-part rate structure.¹² A single volumetric rate would embrace both the fixed costs of serving customers (described as “customer” and “demand” costs, see pp. 1194-1195 and notes 4-5 supra), and commodity costs. Dr. Wilson, the witness for People’s Counsel, testified that gas supply, rather than delivery capacity, is the limiting factor in the Company’s natural gas service area. PC Exh. D, at 13-14. The optimally efficient economic pricing solution, he concluded, would therefore be to attribute a zero weight to the sunk costs of the overbuilt transmission capacity, “and to recoup total revenue requirements largely on a volumetric basis.” Id. at 13. The effect of the proposed volumetric prices would be to maximize conservation of the scarce resource, gas. Id. at 14.

The Commission agreed with People’s Counsel that conservation was a major objective, Order 6051, at 85, but noted that gas supply prospects were improving, at least for the near-term future. Id. at 84-85. The Commission questioned Dr. Wilson’s assertion that the Company had excess storage capacity, id. at 84, and his testimony concerning marginal cost pricing principles. Id. at 87.

Further, the Commission found that the imposition of a volumetric rate structure would aggravate the risk to the Company of under-collection of fixed costs. Fixed costs are incurred independently of the level of gas sales. Id. at 82-83. The fixed cost component of a volumetric rate would be determined on the basis of projected temperatures and fuel usage. The danger of under-collection of fixed costs as a result of unexpectedly warm temperatures and low fuel usage would be aggravated where all fixed costs were recouped through the commodity charge, as they would be under a single volumetric rate structure.¹³ The Commission found rather that maintenance of a two-part rate structure, and utilization of a warmer “normal weather standard,”¹⁴ were desirable to reduce the risk to WGL of under-collection of fixed costs. Id. at 83-84.

The Commission also remarked upon the inconsistency of People’s Counsel’s proposal with modern utility practice. Whereas under the proposal offered by People’s Counsel fixed costs would have been recovered entirely through the commodity charge, the Commission noted that the Federal Power Commission “has never designed pipeline rates which recover more than 75 percent of fixed costs through the commodity charge.” Id. at 84. The Commission agreed, though, that, consistent with modern public utility practice, the majority of WGL’s fixed costs would continue to be recovered through the commodity charge. Id.

2. Differentiation Among Customer Classes

The petitioners ground their opposition to the rate design established by the Commission, first, on the Commission’s substantial reliance on factors other than cost causation in formulation of the rate design, and second, on the closely related problem of the alleged disparity among the rates of return the Company will receive from different classes of customers under the order. The disparity, it is asserted, renders the rate design unconstitutionally confiscatory in that, as a concomitant of that disparity, certain groups are compelled to subsidize others’ gas usage, instead of merely paying for their own purchases.

a. Legitimacy of Cost-Related and Non-cost factors

By now, the permissibility of relying on non-cost factors in rate design is beyond serious dispute. Inasmuch as the differences in customer charges among the various consumer classes, and the alleged differences in “class rates of return” derive from reasonable consideration of such factors, they do not render the rates invalid.¹⁵

Preliminarily, we note that the use of non-cost factors in addition to cost causation does not amount to a rejection of the latter. Contrary to petitioners’ contention, the Commission did not repudiate the significance of the principles of cost causation for utility ratemaking. The Commission’s specific denial that it was rejecting cost-causation principles, Order 6060, at 16; Order 6051, at 90, attains credence from its discussion of the lack of cost justification for discriminating between residential heating and cooling customers who consume above and below 100 Ccf of gas per year, as was proposed by WGL, id. at 96, and from its discussion of the conflict between the principles of cost causation and counterven-ing considerations of the value of service, historic rate patterns, and equity, in setting rates for residential non-heating and non-cooling customers, id. at 97.

Furthermore, relevant cost considerations are not limited to historic costs (the cost already paid for existing fuel stocks), but include replacement costs (the cost of purchasing new fuel stocks to replace those currently being consumed). The Commission has expressed concern with escalating gas replacement costs. In Formal Case 647, the basic facts and rationales of which were reaffirmed in the instant case, Order 6051, at 89-90,¹⁶ a two-part rate structure was first substituted for the traditional declining block rate structure. The Commission, commenting upon the increasing complexity of the economic equation for utility rate designs, which impelled this transition, stated:

Complicating the cost picture are several factors. One is that existing and new supplies of gas are becoming more and more costly. To the extent that the company must replace gas sold on a promotional basis with higher priced gas, its average costs will escalate. Another factor is that the company’s service is limited by gas supply, as well as by pipeline capacity. In these circumstances, traditional allocation techniques must be reevaluated; customers’ responsibility for fixed costs must be related more closely to their gas usage. [In re Washington Gas Light Co., supra at 278-79 (citing Consolidated Gas Supply Corp. v. Federal Power Commission, 172 U.S.App.D.C. 162, 520 F.2d 1176 (1975)).]

Accord, Midwest Gas Users Association v. State Corporation Commission, 3 Kan. App.2d 376, 382-83, 393, 595 P.2d 735, 740, 747 (1979); United States Steel Corp. v. Pennsylvania, 37 Pa.Commw.Ct. 195, 207-10, 390 A.2d 849, 856-57 (1978); In re Laclede Gas Co., 25 P.U.R.4th 51, 58 (Mo.P.U.C. 1978). Although the Commission projected increasing gas supplies in the near-term future, Order 6051, at 84-85, it noted too the rising cost of the commodity. Id. at 99. It is anticipated that as local supplies of gas are depleted, the Company will eventually have to replenish its commodity supplies from more exotic and expensive sources. See Order 6051, at 88. Because gas is a limited and wasting resource, see In re Washington Gas Light Co., supra at 279, it is foreseeable too that rising recovery costs will contribute to increased commodity replacement costs, regardless of the economic climate — for we note also the effect of inflation on replacement costs.

[T]he cost of recovering natural gas can no longer be treated as just another cost of doing business. Although there is considerable controversy over the amount of natural gas which can be ultimately recovered domestically, there is little difference of opinion that the amount of natural gas ultimately recovered will cost considerably more per Mcf than gas recovered in the past. This is a reasonable assumption because not only are the factors of production (land, labor, and capital) involved in gas exploration and development increasing in cost, but the process itself is becoming more costly. Where gas could once be recovered onshore in porous wells at shallow depths and in great quantities, the depletion of these resources has forced the natural gas industry to drill deeper in tighter formations, drill offshore, or look to supplies beyond the continental limits of this country. Hence, even if the traditional costs of production level off or decrease, the cost of recovering natural gas will continue to increase or, in other words, putting an end to inflation will not put an end to increases in the price of gas. [In re Laclede Gas Co., supra at 88.]

[II] Under this analysis, the inclusion of substantial fixed costs in the commodity charge is cost-justified.¹⁷ The high usage customers contribute disproportionately to the exhaustion of relatively inexpensive commodity sources, and thus accelerate future increases in commodity prices for all utility customers. See id. A higher commodity price would tend to decrease consumption, thereby reducing the upward pressure on gas prices. Petitioners allege that due to the inclusion of fixed costs in the commodity charge, customers who consume greater quantities of gas are compelled to subsidize lesser consumers. The high usage customer, however, if charged solely on the basis of current commodity prices at any given time, never covers the gas replacement costs for which he is responsible. The price system is thus distorted, with the smaller consumer absorbing higher costs caused by the greater consumer, or, in effect, subsidizing the greater gas consumer. The Commission’s inclusion of substantial fixed costs in the commodity charge tends to mitigate the distortions in cost allocations caused by rising replacement costs.

By attributing to each customer the expenses for which he is responsible, the consumer has before him the correct price indicators upon which to base his purchase and resource consumption decision. The Commission expressed concern in Formal Case 647 that “[promotional rate structures tend to foster a misallocation of scarce resources.” In re Washington Gas Light Company, supra at 279. See In re Laclede Gas Co., supra at 88-89.

If every customer on [the] company’s system must pay at least the cost of replacing any gas he consumes, then those customers have the proper price information to decide whether the benefits of conserving that gas are equal to the price. If any customer on [the] company’s system does not have to pay at least the cost of replacing the gas that customer consumes, then that customer is permanently insulated from the cost impact his consumption has upon [the] company’s entire system.

By recovering more than historic cost in the commodity charge, the Commission’s order moves toward long-term cost-reflective pricing, which contributes to a more efficient allocation of resources.¹⁸

We would be compelled to reject the petitioners’ contention that a utility rate order depends for its validity upon a predominantly cost-based foundation, even if that concept is expanded to encompass replacement cost. On the contrary, historic and replacement costs are not the only criteria in the establishment of a rate structure, see Apartment House Council of Metropolitan Washington, Inc. v. Public Service Commission, supra at 57, and it is a function of the Commission to determine the relative weight to accord the various factors that it considers in the ratemaking process, see Association of American Publishers, Inc. v. Governors of the United States Postal Service, supra, 157 U.S.App.D.C. at 403-04, 485 F.2d at 774-75.

The value of service to the consumer is one of the valid non-cost factors. The Commission’s reliance upon value of service as a relevant factor¹⁹ in the determination of whether there has been unlawful discrimination is supported by precedent, see, e.g., In re Washington Gas Light Co., 99 P.U.R.3d 139,144 (D.C.P.S.C.1973); and this court has previously endorsed consideration by the Commission of “whether customers have paid different amounts for the same service under the same circumstances.... So long as the classifications are reasonable, a difference in rates may exist between different classes of customers.” Atlantic Telephone Co. v. Public Service Commission, D.C.App., 390 A.2d 439, 444 (1978). See also Florida Retail Federation, Inc. v. Mayo, 331 So.2d 308, 312 (Fla.1976); Midwest Gas Users Association v. State Corporation Commission, supra, 3 Kan.App.2d at 381-91, 595 P.2d at 739-46; New England Telephone and Telegraph Co. v. Public Utilities Commission, 390 A.2d 8, 59 (Me.1978); In re Arkansas Louisiana Gas Co., 558 P.2d 376 (Okl.1976); United States Steel Corp. v. Pennsylvania, supra 37 Pa.Cmwlth. at 207-09, 390 A.2d at 856. “[E]ach unit of natural gas has the same energy value and the same economic value no matter how many units of gas a customer may purchase.” In re Arkansas Louisiana Gas Co., supra at 378. The intrinsic value of service to the customer may conflict with the cost of service to the utility, but is, we conclude, a valid equitable consideration, which the Commission not unreasonably included in the utility rate equation.

The Commission’s consideration of historical rate patterns in fashioning the order was likewise not inappropriate. See

Apartment House Council of Metropolitan Washington, Inc. v. Public Service Commission, supra at 58. While structuring utility rates solely on the basis of the ability of different groups of customers to pay would comprise a manner of social legislation and subsidy best left to the legislative branch of government, see United States Steel Corp. v. Pennsylvania, supra 37 Pa.Cmwlth. at 173, 390 A.2d at 871; In re Rate Design for Electric Corporations, 26 P.U.R.4th 280 (N.Y.P.S.C.1978), in the instant ease we find no abuse of discretion in the Commission’s refusal to impose high gas rates on residential customers where the Company, through past advertising and favorable rate structures, promoted dependence by these customers on gas usage. Moreover, consideration of an equitable factor such as this is not invalidated simply because the same rationale might apply to certain members of other customer classes. See Metropolitan Washington Board of Trade v. Public Service Commission, supra at 358-59. Such imperfections are inherent in any system employing broad classifications, and the Commission may exercise its discretion to provide relief to those classes which, as a whole, have the greatest claim to it.²⁰

The Commission also permissibly relied upon the need for resource conservation. Order 6051, at 89. We have previously affirmed the Commission’s obligation to aid in the energy crisis. Apartment House Council of Metropolitan Washington, Inc. v. Public Service Commission, supra at 57; see Metropolitan Washington Board of Trade v. Public Service Commission, supra at 358. Although the Commission anticipates a ready supply of gas in the near future, Order 6051, at 84-85, recognizing that gas is a scarce, finite, and wasting resource, and that conservation is in the public interest, see, e.g., In re Washington Gas Light Co., 16 P.U.R.4th at 279, we find reasonable and within the scope of its allowed discretion the Commission’s incorporation of a conservation goal into the ratemaking equation. See Central Hudson Gas and Electric Corp. v. Public Service Commission, 447 U.S. 557, 571, 100 S.Ct. 2343, 2354, 65 L.Ed.2d 341 (1980) (“We accept without reservation the argument that conservation ... is an imperative national goal. Administrative bodies empowered to regulate electric utilities have the authority — and indeed the duty— to take appropriate action to further this goal.”); California Manufacturers Association v. Public Utilities Commission, 24 Cal.3d 251 at 260, 155 Cal.Rptr. 664 at 669, 595 P.2d 98 at 103 (Public Utility Commission “may properly consider prospective shortages of natural gas and the need to conserve that commodity”); Boston Edison Co. v. Department of Public Utilities, 375 Mass. 1, 47, 375 N.E.2d 305, 333, appeal dismissed, 439 U.S. 921, 99 S.Ct. 301, 58 L.Ed.2d 314 (1978) (it was reasonable to conclude that the exemption of the first 384 kilowatt hours of electricity use “would encourage energy conservation in the public interest”).

b. Differences in Customer Charge Among the Various Customer Classes

It is unnecessary to reiterate in detail the Commission’s rationale for its setting of customer charges, which are outlined in section B, supra. Inasmuch as these differences are reasonably based on legitimate cost and non-cost factors already discussed, they do not render the rates invalid. Two areas of contention merit a brief further mention, however: the charges applied to residential non-heating and non-cooling customers, and those applied to interruptible customers.

One factor influencing the Commission was the tension inherent between the cost to the Company of providing service, and the value of service to WGL customers. Discussing residential non-heating and non-cooling customers, the Commission commented:

Because of the very low volume of gas which this sub-class takes relative to its customer costs, a two-part rate yields an anomaly; this sub-class pays the highest unit price for service at the same time as WGL earns the least return from this service.

In designating rates for the residential non-heating/non-eooling sub-class, the Commission faces a direct conflict between the principle of cost causation, on one hand, and historic rate patterns and social considerations on the other hand. [Order 6051, at 96-97 (emphasis in original).]

We cannot say that the charge arrived at was based on illegitimate factors or embodies a capricious application of them. On the contrary, the record reflects a reasoned consideration and resolution of an issue as to which reasonable people can differ. It is not for us to substitute our preferences for the judgment confided by law to the Commission.

While in the case of residential non-heating and non-cooling customers these cost considerations led the Commission to reduce the customer charge, id., it was drawn by other factors to approve WGL’s proposed increase to a thirty cents per therm rate for interruptible customers. Id. at 99-100. These included rising fuel costs, the amount of investment fairly allocable to interrupti-ble service customers,²¹ the value of the service provided to these customers, and the closely related factor of the competitiveness of the rate charged interruptible customers for gas with the price of other forms of fuel. Order 6051, at 99-100. “Utility companies operating under public franchises and having monopolistic characteristics are subject to special regulation.” Public Utilities Commission v. Capital Transit Co., 94 U.S.App.D.C. 140, 145, 214 F.2d 242, 247 (1954). Although such regulation protects utility companies to a degree from ordinary market pressures, realities of the marketplace, including the company’s competitive position and, in this context, the price of alternative fuels, may be considered in establishing or assessing the reasonableness of a rate structure. See United States Steel Corp. v. Pennsylvania, supra, 37 Pa. Cmwlth. at 207-09, 390 A.2d at 856. We find that the Commission acted reasonably in predicting the interruptible rate upon the above enumerated facts, and that the rate works no unfair discrimination. As it is neither unreasonable, arbitrary, nor capricious, and is supported by substantial evidence, the rate must be sustained.

c. Alleged Differences in Class Rates of Return

The objections raised by petitioners and in dissent relating to class rates of return are based entirely on a data analysis prepared by Washington Gas Light itself that is seriously flawed, was never adopted by the Commission, and which the Commission was under no obligation to adopt. Even if the PSC had adopted it as an aid in rate design, it does not follow that those rate of return estimates would become the legal benchmark for judicial assessment of whether the rates are imper-missibly discriminatory under the D.C. Code or the Constitution. While the choice of a rate design — within wide bounds — is for the Commission to make, the standards for judging where the bounds lie, i.e., what is “discriminatory”, are for the court to establish. Finally, even if one hypothesizes the impossible — a single, objective, agreed upon method for allocating costs — differences in the resulting class rate of return estimates would not satisfy petitioners’ burden of proving illegally discriminatory rates. If, as here, the asserted differences flow from a reasonable application of legitimate cost and non-cost policies, they are permissible. Indeed, if the non-cost factors are given weight at all, differences in class rates of return are virtually inevitable.

The record contains no decisive projection of the several rates of return reasonably to be expected under the instant rate order. During the hearings, Mr. Smallwood, vice-president of WGL, presented evidence indicating a range of rates of return from firm service customers varying from a negative 8.42% from residential non-heating customers to 26.11% from commercial and inter-ruptible fuel users. On cross-examination, however, Mr. Smallwood renounced the figures he had earlier espoused, due to the erroneous methodology — the misallocation of mains to individually metered apartments ²² — that he had relied upon in calculating those figures.²³ WGL Exh. N, at 26. He testified further that he had not, since learning of the error, recomputed the rates of return, and could not state with certainty whether the resulting rate would be negative. The Commission, acting within the scope of its allowed discretion, accordingly disregarded WGL’s erroneous projection of class rates of return in fashioning the rate order.²⁴

Since the Company’s cost causation analysis failed to pass muster, and despite the extensive consideration the Commission gave to cost allocations and cost causation during the rate hearings, no specific cost data clearly underlie the rate order. This lack of specificity does not alone imperil the validity of the order. We have previously held that

[i]t is not necessary that differences in rate of return be specifically and quantitatively supported by customer class-cost considerations. The Supreme Court has stated that “[ajllocation of costs is not a matter for the slide-rule. It involves judgment on a myriad of facts. It has no claim to an exact science.” [Apartment House Council of Metropolitan Washington, Inc. v. Public Service Commission, supra at 57 (1975) (quoting Colorado Interstate Gas Co. v. Federal Power Commission, 324 U.S. 581, 589, 65 S.Ct. 829, 833, 89 L.Ed. 1206 (1945)).]

Accord, Midwest Gas Users Association v. State Corporation Commission, supra, 3 Kan.App.2d at 391, 393, 595 P.2d at 746, 747.

Apart from the problems of accounting for individually-metered vs. group-metered apartments, the Washington Gas Light analysis is based on more fundamental assumptions that the Commission is not compelled to accept as a guide to rate design. Neither is this court compelled to accept those assumptions as the foundation for determining what is impermissibly discriminatory under the Constitution or D.C. Code.²⁵ In particular, petitioner’s approach assumes that fixed costs must be allocated on a per-consumer basis, without regard to how much each consumer used the system. Even if one corrects the error of failing to account for the fact that individually-metered homes should not pay the same share as an entire building of group-metered apartments, see note 10 supra, it is not obvious that a per-unit allocation would be the only permissible one. For example, one might rationally allocate fixed costs, other than those directly attributable to particular customers or groups of customers,²⁶ in proportion to consumption. Indeed, this is the cost recovery method that overwhelmingly predominates in the sale of consumer goods and services generally. In the typical business, there is no “customer charge” and therefore one hundred percent of fixed costs are covered by the “commodity charge” — the price of the good or service in question. Most observers would not consider it unfairly discriminatory that a customer who buys one dollar’s worth of goods contributes less to the overhead costs of the store than the customer who buys $100’s worth of goods. Indeed, it might be considered unfairly discriminatory if the two were required to pay a separate and equal fee for overhead.

If the Commission or this court adopted the principle of cost allocation in proportion to consumption, then the current set of rates would result in higher estimated rates of return for the classes of smaller consumers than for the other categories. Under the utilities’ terminology, this would reflect a suspiciously unjust “cross-subsidy” of the large by the small user. It would be eliminated by recovery of all fixed costs through the commodity charge. We do not raise this possibility for the purpose of suggesting that it be adopted by the Commission as a guide to rate design. Nor do we adopt it as the standard for finding unconstitutional discrimination. If we did, we would have to reject the proposed rates and require the elimination of the customer charge, thus moving further from the result sought by the utility. Rather, we raise it to refute the suggestion that the “imprecision” in cost allocation is only a matter of technical differences in methodology. It is also a question of fundamental choices among alternate basic assumptions, no one of which can “objectively” be identified as the “correct” one. Under these circumstances, the dissent’s unexamined presumption that we are compelled to rely on the petitioner’s preferred choice, after correction of certain acknowledged errors, is specious.

Even if one hypothesizes an objective, agreed-upon standard for estimating class rates of return, substantial disparities among the resulting estimates would not satisfy petitioners’ burden of making a convincing showing of unlawful discrimination. “Discriminatory rates” cannot simply be equated with differences in estimated rates of return from subparts of the utility’s business.²⁷ We have never imposed a requirement of uniformity among the rates of return from different customer classes; differences have indeed traditionally been tolerated. Our scrutiny of the legality of allegedly discriminatory differences in charges imposed upon utility customers focuses rather upon the reasonableness of the customer classifications. Metropolitan Washington Board of Trade v. Public Service Commission, supra at 360-61; Atlantic Telephone Co. v. Public Service Commission, supra at 444; Apartment House Council of Metropolitan Washington, Inc. v. Public Service Commission, supra at 57.²⁸ Indeed, insofar as the Commission may permissibly consider factors other than cost causation in structuring the rate design, it is inevitable that differences among rates of return will exist.

Because the utility’s revenue requirement is based on cost (expenses plus capital return) and because customer rates are designed to provide the revenue requirement, it is apparent that consideration by the commission of any factor other than cost will result in some customers paying less while others necessarily pay more than cost. Having discretion to consider factors other than cost, the commission must necessarily create some disparity among users.. .. [California Manufacturers Association v. Public Utilities Commission, 24 Cal.3d 251, 261, 595 P.2d 98, 103, 155 Cal.Rptr. 664, 669 (1979) (en banc).]

Only a minor part of the differences in class rates of return, as calculated by petitioners, is due to the differences in the customer charges applied to various classes. The differences are predominately due to the fact that a substantial part of fixed costs is recovered through the commodity charge. As a result, a larger absolute amount of fixed costs is borne by large users. However, they bear a smaller proportion of such costs in relation to their consumption, since part of fixed costs are borne through flat customer charges. Thus, if there are permissible grounds for recovering a portion of fixed costs in the commodity charge, notwithstanding a cost causation theory that allocates fixed costs on a flat per-customer basis, the rates must be upheld.

The discussion in subsection a, supra, shows that there are indeed adequate bases for the Commission decision to recover a substantial portion of fixed costs through the commodity charge. It will suffice simply to summarize them here. One reason is conservation of energy resources. The higher the marginal cost of gas to the consumer (the commodity charge), the greater the incentive to reduce energy waste or to shift to lower cost energy sources. Concern that commodity prices cover replacement costs is another permissible consideration. As existing sources of gas are exhausted, finding and exploiting new ones becomes increasingly expensive. If the commodity charge is not higher than the historic cost, it will fail to cover the higher replacement cost, leading to an undesirable allocation of resources. Moreover, high demand is a contributing factor to higher resource prices. It is therefore not unjust that those who consume more and therefore are more responsible for overall consumer demand bear a proportionately higher burden of replacement costs. Value to the consumer, ability to pay, and historical rate patterns are additional reasons for not recovering fixed costs exclusively through the customer charge.²⁹

Finally, at each juncture the Commission has balanced countervailing criteria, and in so doing has satisfied the independent burden imposed on it by Washington Public Interest Organization v. Public Service Commission, supra at 75-77, to announce the criteria governing the rate determination and to explain how the order reflects application of these criteria to the facts before it. The Commission acted within the scope of its discretion in balancing the various criteria upon which it relied. Mathematical formulae are not required. “Allocation of costs is not a matter for the slide-rule. It involves judgment on a myriad of facts. It has no claim to an exact science.” Colorado Interstate Gas Co. v. Federal Power Commission, 324 U.S. 581, 589, 65 S.Ct. 829, 833, 89 L.Ed. 1206 (1945). As petitioners have failed to demonstrate that the order is unjust and unreasonable in its total effect, the rate design must be sustained.

III. Rate of Return

By determining and weighting the cost of each portion of WGL’s capital structure, the Commission found that the Company is entitled to the opportunity to earn a maximum overall return of 9.25% on its rate base.³⁰ Only the Company disputes this finding, contending that this allowance is unreasonable and confiscatory. It traces the alleged error to two facets of the “cost of capital” analysis used by the Commission to establish the authorized overall return: (1) the Commission’s determination that WGL should be allowed a 13% return on common equity; and (2) the Commission’s reduction of the test-year cost of debt by means of amortizing gains which had been realized in past years upon WGL’s redemption of certain long-term debentures.³¹

The statutory authority of the Commission to design “reasonable, just, and nondiscriminatory” rates, D.C.Code 1981, § 43-501, is, we have stated, “deliberately broad.” Metropolitan Washington Board of Trade v. Public Service Commission, supra at 350.

[T]he Commission [is given] authority to formulate its own standards and to exercise its ratemaking function free from judicial interference, provided the rates fall within a zone of reasonableness which assures that the Commission is safeguarding the public interest — that is, the interests of both investors and consumers. ... From the investor standpoint, courts have defined the lower boundary of this zone of reasonableness as “one which is not confiscatory in the constitutional sense.” Federal Power Commission v. Natural Gas Pipeline Co., 315 U.S. 575, 585 [62 S.Ct. 736, 742, 86 L.Ed. 1037] (1942); Washington Public Interest Organization v. Public Service Commission, [supra at 76]. From the consumer standpoint, the upper boundary cannot be so high that the rate would be classified as “exorbitant.” [Metropolitan Washington Board of Trade v. Public Service Commission, supra at 350 (emphasis in original).]

If the overall effect of a rate order is found to be reasonable, judicial inquiry must stop; any infirmities in the method employed to determine those rates becomes immaterial. Federal Power Commission v. Hope Natural Gas Co., supra 320 U.S. at 602, 64 S.Ct. at 287; People’s Counsel v. Public Service Commission, supra at 46. As the return on equity authorized in this case lies within the “zone of reasonableness,” we find no error with respect to either aspect of the rate of return determination.

A. Return on Common Equity

Three witnesses presented evidence on the cost of WGL’s common equity. Each relied primarily upon a “discounted cash flow” (DCF) analysis to arrive at a proposed return on common equity.

The DCF method takes into account current and anticipated income to the investor from dividends and the eventual sale price of the stock. The method of determining the cost of equity under the DCF approach can be stated by a rather simple formula, i.e., market capitalization rate (cost of equity) equals the current dividend yield plus anticipated growth. This constitutes the marginal cost of equity and is commonly referred to as the “bare-bones” cost of capital. Rate analysts usually adjust this figure to allow for market pressure upon the issuance of additional shares of common stock and for the costs of issuing the stock. [Order 6051, at 17 (emphasis added).]

See also In re Washington Gas Light Co., 16 P.U.R.4th at 274 n.8; Staff Exh. 14, Sch. 5.

The Company's witness, Patrick J. Maher, first determined the “yield” component in his DCF analysis. He assumed that utility common stocks are interest-rate sensitive: i.e., that their dividend/price ratios tend to follow the general level of interest rates for long-term bonds. WGL Exh. C, at 13. Using data on newly-issued Aa-rated long-term utility bonds and stock yields for selected companies in Moody’s and Standard & Poor’s indices of gas distributors and electric utilities, id. at 13-15, Maher concluded that investors in gas distribution companies over the preceding two years had been requiring stock yields (dividends) at a level of approximately 90% of the corresponding bond yields. He further stated that long-term utility bonds had recently been selling with yields of 8 to 9%. Id. at 22. Assuming average future bond yields of 8.5%, he projected that the stock dividend/price ratio of his comparison companies would be about 7.5% to 7.75%. Id. at 23.

To derive the “growth” component of his DCF analysis,³² Maher calculated the growth in retained earnings for the Standard & Poor’s and Moody’s groups of natural gas distributors during the period 1974-76. Those companies showed an average growth of 4.72% in 1974, 5.02% in 1975, and 5.97% in 1976. WGL Exh. 3. Sch. 19. Based on these figures, Maher estimated that investors reasonably could expect growth in the neighborhood of 5.5% to 6.0% when investing in the gas distribution industry. WGL Exh. C. at 21. Adding that projection to the dividend yield component, he concluded that the “investors’ capitalization rate” or “marginal cost of equity” in the industry was approximately 13% to 13.75%. Id. at 23.

Maher further stated his belief that the return on equity should be higher than the marginal cost of equity. If the Company realized only the marginal cost of equity capital on sales of common stock, he claimed, its stock would sell at book value. Due to the cost of floating additional common shares, however, he argued that the utility would actually receive less than the book value of its present stock from new investors. Thus he concluded that sales at book value would dilute existing equity and reduce the value of outstanding shares. Id. at 23. Maher recommended a return on common equity of 14.0% to 14.5%, which he believed would promote the sale of WGL’s stock at a market-to-book premium of approximately 11.5%. Id. at 24-25.³³

The Staff’s witness, Gerald J. Glassman, like Maher based his DCF analysis on historical yield and growth data for a representative group of gas distributors. Glass-man selected from Standard & Poor’s data file on 155 utility companies, twelve comparison companies with characteristics approximating those of WGL; these characteristics included 1976 sales between $65 million and $500 million, with gas sales providing at least 90% of total revenues, and equity ratios between 25% and 45%. (WGL during 1976 had operating revenues of $270 million, entirely from gas sales; its equity ratio was approximately 35%.) Staff Exh. 14, at 28-29 & Sch. 6. Using data on WGL and the comparison companies for the years from 1967 to 1976, see id., Sch. 6, he estimated that WGL’s dividend yield should be approximately 8.25%. Id. at 36. He further concluded that a reasonable expectation of growth in common stock value would be “no more than 4%.” Id. at 34. Adding these two components together, he determined that the market capitalization rate or marginal cost of WGL’s common equity was approximately 12.25%. Id. at 36. To this figure Glassman recommended adding a 7.5% allowance to compensate for the effect of flotation costs and market pressure.³⁴ His resultant proposed return on equity was 13.24%. Id. at 39-40.

People’s Counsel’s witness, Dr. Caroline M. Smith, used a DCF methodology similar to the one employed by Glassman. She selected as comparison companies fifteen gas distribution companies that were listed in the Value Line Investment Survey and that derived 85% or more of their gross revenues in 1976 from residential, commercial, and industrial gas sales. PC Exh. B, at 10 & Sch. 3. Smith calculated the “current dividend yield” for each company, (the dividend/price ratio based on average prices for June through November, 1977), and then used the average of those yields — 8.22%—as the dividend yield component of her DCF analysis. Id. at 11. To derive the' growth component, she studied trends in her comparison companies’ earnings per share, dividends per share, and book value per share. Results for several time periods were used. From those data she concluded that investors’ expectations for growth in the value of gas utility common stocks were approximately 3.5% to 4%. Id. at 12 & Sch. 4. Combining the yield and growth factors, she estimated that the market capitalization rate for the comparison companies' common equity was approximately 11.75% to 12.25%. Id. at 15 & Sch. 6. Smith then conducted a regression analysis, which indicated that the ratio of common equity in a utility’s capital structure is the single most important factor influencing investor assessments of relative risk among gas distributors. The lower the common equity ratio, she found, the higher the risk. She further found that WGL’s common equity ratio was significantly lower than the average for her fifteen comparison companies, thus increasing the cost of WGL’s common equity by more than a quarter of a percentage point above the fifteen companies’ average. She concluded that the “bare-bones” cost of common equity for WGL is in the range of 12.05% to 12.55%. Id. at 17-22 & Schs. 7-8.

Unlike Maher and Glassman, Smith disputed the need for any adjustment to cover flotation costs or market pressure. Based upon studies of the effect on securities markets of new stock and bond issuances by utilities, she concluded that market pressure has been an insignificant or nonexistent phenomenon in recent years. Id. at 30-33. She recommended that a market pressure adjustment, if made, should not exceed 3% of the price of the stock to be issued. Id. at 34. Smith also testified that WGL was not likely to issue any additional common stock within the next five years, as, she surmised, its capital needs during that period would be financed largely by debt, retained earnings, depreciation, deferred taxes, and investment tax credits. Id. at 29. This testimony was uncontradicted. See Order 6060, at 46 (Stratton, C., dissenting). Smith therefore concluded that no flotation cost adjustment was warranted, but added that if the Commission did allow such an adjustment, it should not exceed .06%. PC Exh. B, at 34-36.

The Commission, acting within the scope of its discretion, decided that the cost-of-equity evidence submitted by the Staff and People’s Counsel was more reliable than that supplied by WGL. It explained:

The Company repeats one of the same errors which caused us to place little reliance on its return-on-equity evidence in the last case. The companies which Mr. Maher used in his analysis simply are not comparable to Washington Gas Light Company. For his long-term study, 1960-1976, he used Standard & Poor’s natural gas distributors indices. When focusing on more recent industry experience, 1974-1976, Mr. Maher expanded his analysis to include the Moody’s group. Unfortunately, these indices include companies which are not only in the gas distribution business, but which also have transmission facilities and produce significant quantities of gas. One company is even engaged in oil production, the sale of chemicals and chemical products, and engineering and construction services. Each of these companies had returns on equity and retained earnings growth which were greater than the average from 1974-1976. And their common stock has consistently sold at a market-to-book premium, whereas the group as a whole sold at an average discount from 1974 — 1976. In light of this lack of comparability, we again cannot place principal reliance on the Company’s evidence.

The return-on-equity evidence of the Staff and People’s Counsel avoids this deficiency. Mr. Glassman studied the growth and dividend yield of Washington Gas Light Company and a group of 12 gas distribution companies which were selected as being representative of the gas distribution industry and similar to Washington Gas Light Company from the standpoint of investment uncertainty. Similarly, Dr. Smith studied 15 gas distribution utilities, each of which received 85 percent or more of gross revenues from gas sales in 1976. [Order 6051, at 18-19.]

In accordance with the Glassman and Smith studies, the Commission determined that WGL’s marginal (or “bare-bones”) cost of common equity was 12.25%. Order 6051, at 18-19. This ruling cannot be said to be arbitrary, unreasonable, or unsupported by reliable and probative evidence. The Commission properly may give more credence to certain evidence than it does to other evidence which it deems less reliable. See Goodman v. Public Service Commission, 162 U.S.App.D.C. at 78, 497 F.2d at 665; Washington, Marlboro & Annapolis Motor Lines, Inc. v. Public Utilities Commission, 114 F.Supp. 328, 333 (D.D.C.1952), aff’d, 93 U.S. App.D.C. 63, 206 F.2d 490 (1953). The Commission had a reasoned basis for rejecting the Company’s studies.

The Commission also adopted the recommendation of People’s Counsel that no allowance be made for market pressure and flotation costs because “it does not appear that the Company is planning to issue new equity in the foreseeable future.” Id. at 20. The Commission did, however, add seventy-five “basis points” to WGL’s bare cost of equity, thereby raising the Company’s authorized return on equity to 13%, because the Commission did not believe that a 12.25% return on equity would provide an adequate spread between the bare cost of equity and current high yields on government and utility bonds. Id. at 21-22. The Commission was influenced too: (1) by the substantial market-to-book discounts on the sale of WGL stock from 1974 to 1977, id. at 23; see note 33 supra; (2) by the fact that the average rate of return on equity for the comparison companies selected by the Staff had been consistently higher than WGL’s, Order 6051, at 23; and (3) by “the continuing uncertainty surrounding the gas supply picture.” Id. at 24.

The Company contends that the authorized return and the resultant level of rates are unreasonable and confiscatory. In the Company’s view, it was illogical for the Commission to lower WGL’s authorized return on equity from 13.4%, (as established in WGL’s last rate proceeding, in 1976, In re Washington Gas Light Co., 16 P.U.R. 4th at 277), to 13%, in the face of “spiralling” interest rates, particularly after the Commission had acknowledged WGL’s recent poor performance with regard to market-to-book ratios, growth rates, and actual return on equity. People’s Counsel and the Commission, on the other hand, urge that the rate levels established in this case are ample. They take issue with the Company’s assertion that costs of capital “spiral” in the long run; on the contrary, they argue, capital costs fluctuate over time. Therefore, a reduction in the allowed rate of return on common equity is not per se unreasonable merely because interest rates have risen since the last rate order. Moreover, they argue, the 13% return compares favorably with the common equity earnings of those gas distributors that Staff witness Glass-man found comparable to WGL.³⁵

In assessing the rate of return authorized by the Commission, we are guided by two landmark decisions of the Supreme Court. In Bluefield Water Works & Improvement Co. v. Public Service Commission, 262 U.S. 679, 692-93, 43 S.Ct. 675, 678-79, 67 L.Ed. 1176 (1923), the Court stated:

A public utility is entitled to such rates as will permit it to earn a return on the value of the property which it employs for the convenience of the public equal to that generally being made at the same time and in the same general part of the country on investments in other business undertakings which are attended by corresponding risks and uncertainties; but it has no constitutional right to profits such as are realized or anticipated in highly profitable enterprises or speculative ventures. The return should be reasonably sufficient to assure confidence in the financial soundness of the utility and should be adequate, under efficient and economical management, to maintain and support its credit and enable it to raise the money necessary for the proper discharge of its public duties. A rate of return may be reasonable at one time and become too high or too low by changes affecting opportunities for investment, the money market and business conditions generally.

In Federal Power Commission v. Hope Natural Gas Co., supra 320 U.S. at 603, 64 S.Ct. at 288, the Court elaborated upon the Blue-field criteria:

The rate-making process under the Act, i.e., the fixing of “just and reasonable” rates, involves a balancing of the investor and the consumer interests.... From the investor or company point of view it is important that there be enough revenue not only for operating expenses but also for the capital costs of the business. These include service on the debt and dividends on the stock.... By that standard the return to the equity owner should be commensurate with returns on investments in other enterprises having corresponding risks. That return, moreover, should be sufficient to assure confidence in the financial integrity of the enterprise, so as to maintain its credit and to attract capital. [Citation omitted.]

The Bluefield and Hope cases continue to provide the basic framework for analyzing the fairness or reasonableness of allowed rates of return.

On the record before us, it is apparent that the 13% authorized return on common equity compares favorably with the actual returns on equity realized by those gas distributors that were found similar to WGL. See note 35 supra. Only once during the ten-year period from 1967-76 was the comparison companies’ average return on equity over 13%. In the most recent year for which data was available, 1976, those companies averaged only an 11.45% return on equity.

This comparison may be somewhat misleading, because it compares WGL’s authorized return on equity with other companies' actual returns. In his dissenting opinion, Commissioner Stratton matched WGL’s authorized return in this case against the common equity returns authorized by respective state commissions in each of the comparison companies’ most recent rate proceedings.³⁶ All but two of the eleven gas distributors in the Staff’s comparison group had been authorized nominal equity returns in excess of the 13% allowed in this case. Nevertheless, we are unable to conclude that WGL’s authorized rate of return falls outside the “zone of reasonableness.” See In re Permian Basin Area Rate Cases, supra 390 U.S. at 767, 88 S.Ct. at 1360 (quoting Federal Power Commission v. Natural Gas Pipeline Co., 315 U.S. 575, 585, 62 , 86 L.Ed. 1037 (1942)); Metropolitan Washington Board of Trade v. Public Service Commission, supra at 350. WGL’s authorized rate of return is in the same general range as that of comparable utilities. The Commission’s cost-of-equity determination is supported by the evidence, and its upward adjustment of that figure by seventy-five basis points, although not supported by specifically quantifiable evidence in the record, appears to be a rational attempt to bring the Company’s equity return up to a competitive level.

Moreover, an inadequate authorized rate of return has not been primarily responsible for WGL’s financial plight in recent years: The Company has been unable to earn its allowed return. This, appears to be a common experience. Compare the table of authorized earnings for comparable companies, note 23 supra, with the table of actual earnings for comparable companies, note 22 supra. A utility’s inability to realize its authorized return is usually caused by inflationary forces (in the form of attrition in the rate base and increased operating expenses), inefficient management, or both. There is no evidence (nor has any party alleged) that WGL has been improvidently managed; there is, however, no doubt that inflation has affected, and continues significantly to affect, regulated utilities. We later discuss separately the question of whether the Commission has taken legally adequate steps to account for attrition and inflation. At this juncture, we conclude that the Commission’s determination of a 13% rate of return on equity is supported by the record and is not confiscatory or unreasonable as a matter of law.³⁷

B. Treatment of Gains Realized on Reacquisition of Long-Term Debt

As part of a predetermined sinking fund obligation, WGL periodically repurchases some of its outstanding long-term debt. The Company is able to reacquire these obligations at less than their par value when their coupon rate is lower than the coupon rate in the current bond market. When a bond is repurchased at less than par, the company realizes a gain. From 1955 through 1977, WGL realized from such purchases gains totaling $3,747,000.

Prior to the ratemaking proceeding in issue here, it was WGL’s practice to account for these gains as “below-the-line” profits— that is, net earnings accruing to the benefit of the company’s stockholders, rather than its ratepayers — in the year the applicable debt was retired. Thus, whenever WGL repurchased one of its debentures at less than face value, the resultant gain was treated as part of the Company’s retained earnings and, presumably, was taken into account when the Company declared shareholder dividends.³⁸

Until the ratemaking proceeding presently before us, this accounting practice apparently was not challenged by the Commission. In the instant proceeding, however, the Commission ruled that this treatment of gains is unrealistic and inequitable, at least for ratemaking purposes. The Commission instead determined that the gain realized from each repurchase should be amortized over the remaining life of the particular debt retired, and that each year during that remaining life, the amounts so amortized should be used to offset the Company’s overall cost of debt. The effect of this policy is to shift the benefits of these gains from the Company’s shareholders to its ratepayers, since a utility’s cost of debt is a factor considered by the Commission in setting the authorized overall rate of return.³⁹ The rationale behind this policy shift was described by the Commission as follows:

Any reduction in or savings associated with the cost of debt should be passed on to the customers. This is the corollary of the principle that all legitimate costs incurred in financing or refinancing debt are part of the cost of debt and should be passed on to the consumer. [Order 6051, at 12.]

The policy thus prescribed by the Commission is not a novel one. Rather, the Commission followed the decision of the Federal Power Commission (FPC) in Manufacturers Light and Heat Co., 44 F.P.C. 314, 319-26, 84 P.U.R.3d 511, 516-22 (1970), in which the FPC announced a policy virtually identical to that adopted in this proceeding. The FPC has reaffirmed its Manufacturers Light & Heat Co. ruling on several occasions. See, e.g., Columbia Gulf Transmission Co., 53 F.P.C. 2016, 2024-25, 10 P.U. R.4th 116, 122-23 (1975); Kansas-Nebraska Natural Gas Co., 53 F.P.C. 1691, 1708, 9 P.U.R.4th 481, 496-97 (1975), aff’d sub nom. Kansas-Nebraska Natural Gas Co. v. Federal Power Commission, 534 F.2d 227 (10th Cir. 1976); Consolidated Gas Supply Corp., 52 F.P.C. 454, 465, 5 P.U.R.4th 418, 427-28 (1974). See also Accounting for Premium, Discount and Expense of Issue, Gains and Losses on Refunding and Reacquisition of Long-Term Debt, and Interperiod Allocation of Income Taxes, Order No. 505, 51 F.P.C. 714, 39 Fed.Reg. 6,093 (1974), rehearing denied, 51 F.P.C. 1746 (1974), clarified & aff’d, 59 F.P.C. 591 (1977), aff’d mem. sub nom. Texas Eastern Transmission Corp. v. Federal Energy Regulatory Commission, 187 U.S.App.D.C. 426, 574 F.2d 637, cert. denied, 439 U.S. 836, 99 S.Ct. 119, 58 L.Ed.2d 132 (1978). In addition, a nearly unanimous consensus of state regulatory bodies agree that gains as well as losses resulting from the repurchase of debentures should be passed on to ratepayers.⁴⁰

WGL does not contest the Commission’s decision to implement such a policy. The Company contends, however, that the Commission properly could consider only those gains realized on purchases in the test year and thereafter. Instead, the Commission adopted the approach followed by the Federal Power Commission in Manufacturers Light and Heat Co., supra:

[T]he amount of gains to be used as an offset to interest costs should be the pro forma amount that would have been amortized during the test year had such gains been amortized over the remaining life of the debt from the date of realization to the daté of maturity of the issues involved. [Order 6051, at 14-15 (citing Manufacturers Light and Heat Co., supra at 324-26, 84 P.U.R.3d at 520-21).]

Put in simpler terms, the Commission announced that for ratemaking purposes it would look to all gains realized since the repurchasing scheme began in 1955; that it would treat those gains as if they had been amortized from the time of repurchase over the remaining lives of the bonds involved; and that it would offset the cost of long-term debt in the test year (1977) by the sum of the portions of these gains which would have been amortized in that year under such a system of accounting. WGL argues that by dipping back into gains realized prior to the test year, which were recorded by the Company as “below-the-line” earnings under the then-acceptable method of accounting, the Commission has engaged in a type of retroactive ratemaking proscribed in Board of Public Utility Commissioners v. New York Telephone Co., 271 U.S. 23, 46 S.Ct. 363, 70 L.Ed. 808 (1926). In that case, the Supreme Court struck down an order that the telephone company make up future earnings deficiencies out of excessive depreciation reserves accumulated in the past. The Court stated:

The revenue paid by the customers for service belongs to the company. The amount, if any, remaining after paying taxes and operating expenses, including the expense of depreciation, is the company’s compensation for the use of its property. If there is no return, or if the amount is less than a reasonable return, the company must bear the loss. Past losses cannot be used to enhance the value of the property or to support a claim that rates for the future are confiscatory.... And the law does not require the company to give up for the benefit of future subscribers any part of its accumulations from past operations. Profits of the past cannot be used to sustain confiscatory rates for the future. [Id. at 31-32, 46 S.Ct. at 366 (citations omitted).]

In the proceedings below, the Commission acknowledged that “past excessive earnings belong to the regulated utility just as past losses must be borne by it. A course of action which would violate this doctrine is commonly referred to as retroactive rate-making.” Order 6060, at 7. The Commission, however, went on to rule:

We were very careful not to indulge in retroactive ratemaking. The Commission’s decision does not deprive stockholders of any past gains to which they were entitled prior to our decision in this case. They are permitted to keep all those gains which would have been amortized prior to the test year had the Commission instituted a policy of passing on the gains to the customers at the time the gains were realized. The customers get only the remaining pro forma unamortized gains which fall within the test period and in successive years. Under these circumstances, we do not think that it can be fairly said that we have engaged in retroactive ratemaking. [Id]

WGL contends on appeal that the Commission did not go far enough to avoid retroactivity. The Company argues, in effect, that because the Commission until now has tolerated the utility’s practice of accounting for these gains as below-the-line earnings, its stockholders acquired a vested entitlement to the entire amounts of all gains realized prior to the 1977 test year. The Commission and People’s Counsel urge, on the other hand, that since it is the ratepayers who ultimately bear the cost of the utility’s debt, any gains arising from reac-quisitions of long-term debt should inure to the ratepayers’ benefit in the form of a reduction in current debt cost. People’s Counsel contends that it is no more an act of retroactivity to use these past gains as offsets to present debt cost than it is to permit WGL to charge present ratepayers for the current cost of debt securities issued in years past.

We agree with the Commission and People’s Counsel that the Company’s argument denies the realities — as well as the equities — of long-term debt financing. When a utility repurchases a debenture in the open market at a discount, the effect of such a transaction is to reduce the company’s embedded cost of debt. This is true regardless of whether the discount is treated for accounting purposes as a reduction in debt expense or, as has been WGL’s practice, as retained earnings. In other words, gains on reacquired debt reduce the company’s embedded cost of debt, irrespective of the utility’s accounting practices. As the Federal Power Commission noted in Manufacturers Light and Heat Co., supra at 323-24, 84 P.U.R.3d at 519-20:

[T]he discounts on repurchased debt under consideration here represent a savings which is virtually automatic. [The utility] is required to repurchase its debentures for sinking fund purposes. So long as interest rates continue above the levels of the early 1950’s, such repurchases will continue to be made at discounts each year. Unless amortization of these amounts is required, the cumulative effect will be to add large sums to retained earnings, with no benefit to consumers. Yet consumers will continue to pay the cost of debt, including new debt issued at higher rates to replace that retired.

* * * * * *

Patently, all legitimate costs incurred in financing or refinancing debt are part of the cost of debt, and should be passed on to the consumer. Conversely, any reduction in or savings associated with cost of debt also should be passed on to the consumer.

Since management is required ... to incur both premiums and discounts associated with prudent retirement of debt, it is neither accurate nor equitable to describe such charges and credits as fortuitous. Instead, sound principle requires that they be treated as a normal and recurring part of utility financing and given appropriate recognition in determining the true cost of debt.

The question of retroactive ratemaking was not discussed as such in Manufacturers Light and Heat Co. In that case, however, the FPC amortized gains over the remaining lives of debentures retired from 1956 through the test year, 1969, even though it apparently had never before announced such a ratemaking policy. Later, in Columbia Gulf Transmission Co., 53 F.P.C. 2016, 2024-25, 10 P.U.R.4th 116, 122-23 (1975), the FPC rejected a utility’s argument that the agency properly could amortize only those gains realized since the date the utility began amortizing such gains for accounting purposes. Cf. Washington Public Interest Organization v. Public Service Commission, supra at 82-85 (PSC is not bound to conform ratemaking policies with accounting method used by utility even where system of accounting was prescribed by the Commission).

We think that the ratemaking policy announced in the federal precedents and adopted by the Commission here is soundly supported by the realities of long-term debt financing. As the FPC noted in Manufacturers Light and Heat Co., the savings in debt cost associated with the repurchase of debentures at a discount are “virtually automatic.” 44 F.P.C. at 323, 84 P.U.R.4th at 519. Furthermore, it is the ratepayers, rather than the stockholders, who are burdened with payment of income taxes on the gains realized, as well as with the cost of financing new debt issued by the Company to replace the retired debt.⁴¹ Accordingly, we find that the Commission’s amortization of all gains realized since 1955 did not constitute illegal retroactive ratemaking. The fact that the Commission until now has acquiesced in the Company’s use of a method of accounting that did not reflect the actualities or the equities of debt financing provides an insufficient basis to hold that WGL’s stockholders acquired an immediate “vested” interest in all gains realized prior to the 1977 test year. We therefore affirm the Commission’s treatment of gains realized on the reacquisition of long-term debt.

IV. PROPOSED Adjustments to Account for Post-Test-Period Changes in Operating Expenses and Rate Base

A. Attrition

The Company challenges the Commission’s denial of its request for an additional 0.5% authorized return on rate base above and beyond the return indicated by the cost-of-capital computation in order to offset the effects of attrition.⁴² The Company’s request for an incremental attrition allowance was in addition to its plea for more conventional attrition remedies such as a year-end rate base and pro forma adjustments to its test-period operating expenses. The 0.5% figure represented approximately one-half of the projected effect upon the Company’s earnings of two specific factors that WGL anticipated would cause attrition: expanding rate base and increased direct labor costs. See WGL Exh. C, at 29-31. The Company’s witness, Maher, estimated that WGL’s year-end rate base for the District would be $87 million for 1977 and $92.4 million for 1978, representing an annual growth rate of 6.21%. He further projected that when the Company’s then-current labor agreement expired on May 31,1978, a new settlement would be reached at a five or six percent increase. Id. at 29-30.

The Commission Staff also recommended that a specific attrition allowance be granted. Its witness, Glassman, estimated WGL’s 1978 rate base growth at about three percent, to $89.6 million by year-end. He suggested that the attrition allowance should be based solely on expected rate base expansion, and not on anticipated increases in operating costs (such as wages and pensions). Accordingly, he proposed an incremental allowance of 0.27% on the year-end 1977 rate base. Staff Exh. 14, at 46-58; see id., Schs. 14 — 15.

People’s Counsel opposed any lump-sum attrition allowance. Its witness, Daniel Sack, testified that attrition would be mitigated adequately by the use of a year-end rate base and by allowing the Company to make pro forma adjustments to reflect known increases during 1977 and 1978 in the costs of labor, pensions, insurance, taxes, peak-shaving gas, and other expense items. PC Exh. C. at 30-31. See also WGL Exh. D, at 6-9; WGL Exh. 4, at 4-21, 23, 25-26 (testimony and exhibits prepared by Lewis G. Unkle). People’s Counsel suggested also that the effects of attrition would be offset further by increased operational efficiencies, which a WGL witness had predicted would be forthcoming. See WGL Exh. A, at 5-7 (testimony of Paul E. Rei-chardt). Finally, People’s Counsel referred to testimony by Staff witness Glassman to the effect that customer contributions to capital in the form of deferred income tax accumulations would continue to rise each year and would not be reflected in the Company’s cost of service until the next rate proceeding is instituted.

The Commission essentially adopted the position urged by People’s Counsel. It stated in part:

The Commission is sympathetic to the attrition problem which the Company has been experiencing throughout the 1970’s. It is a matter of great financial importance to the Company as well as to District customers. Nevertheless, on the basis of this record we are hesitant to adopt the proposed solution of a lump-sum adjustment; we are not convinced that a lump-sum adjustment to the revenue requirement is a reasonable approach to the attrition problem in this case.

For purposes of this case, we will continue to rely on the corrective measures adopted in past cases. The year-end rate base which this Commission uses has long been recognized as a device to compensate for attrition resulting from a growth in investment which outstrips growth in revenues. Although this device does not alleviate attrition stemming from expenses growing faster than sales, the Commission does adjust test-year expenses for “known changes” which occur during, or within a reasonable period subsequent to, the test year.

In an effort to formulate policy for future cases, the Commission has decided to undertake a thorough reevaluation of the problem. We recognize that year-end rate base and pro forma adjustments may not be adequate in the years to come. Much depends on the future trends in the underlying factors which affect the Company’s attrition rate. [Order 6051, at 27-28.]

The Commission suggested that alternative remedies, such as a projected test year, might be preferable to a lump-sum attrition allowance, and stated its intention to institute a separate proceeding “in the near future” to reevaluate the problem.⁴³ Id. at 28-29.

In its Application for Reconsideration of the Commission’s final order (submitted April 16, 1979), the Company renewed its request for attrition relief. It proffered new data tending to demonstrate that the newly-approved rates were already insufficient to allow WGL its authorized return.⁴⁴ It asked that the Commission recompute WGL’s revenue requirement using a pro forma test year ending December 31, 1978.

On April 26, 1979, the Commission issued its First Order on Reconsideration (Order No. 6069), in which it denied the Company’s plea that updated figures be substituted for the “stale” test-year data. The Commission found that WGL’s request to supplement the record came much too late. It noted that if it decided to incorporate the Company’s post-1977 test-year evidence into the case at that time, it would be compelled to reopen the record in order to allow other parties to confront WGL’s witnesses and test their 1978 and 1979 calculations. Such an endeavor, it found, would be tantamount to initiating a new rate proceeding. Order 6069, at 2-3.

We agree with the Commission that it was under no obligation to consider extra-record evidence that was offered for

the first time after the Commission’s final order had been issued. While it may be an abuse of discretion for an agency to ignore the most recent data on the record of a proceeding, see West Ohio Gas Co. v. Public Utilities Commission (No. 2), 294 U.S. 79, 81-82, 55 S.Ct. 324, 325, 79 L.Ed. 773 (1935); Potomac Electric Power Co. v. Public Service Commission, supra at 18-19; Telephone Users Association v. Public Service Commission, D.C.App., 304 A.2d 293, 298 (1973), cert. denied, 415 U.S. 933-34, 94 S.Ct. 1448, 1449, 39 L.Ed.2d 492 (1974), the same cannot be said as easily for evidence submitted after the record has been closed and a final opinion issued. See Bowman Transportation, Inc. v. Arkansas-Best Freight System, Inc., 419 U.S. 281, 294-96, 95 S.Ct. 438, 446-47, 42 L.Ed.2d 447 (1974) (“we have always been loath to require that factfinding begin anew merely because of delay in proceedings of such magnitude and complexity”); Illinois Commerce Commission v. United States, 292 U.S. 474, 480-81, 54 S.Ct. 783, 785, 78 L.Ed. 1371 (1934); cf. Potomac Electric Power Co. v. Public Service Commission, supra at 19 (“[A] request to use more recent data submitted in a last minute filing ... is not necessarily a fair or reasonable request. It is to be resolved in the reasonable exercise of the Commission’s discretion.”) (footnote omitted). Only in exceptional circumstances is it appropriate for a reviewing court to remand a final ratemaking decision in order to update a “stale” record. See Atchison, Topeka & Santa Fe Railway Co. v. United States, 284 U.S. 248, 52 S.Ct. 146, 76 L.Ed. 273 (1932) (Commission’s refusal to reopen record in light of the economic metamorphosis brought on by the Great Depression was an abuse of discretion). Although the PSC consumed a considerable amount of time before rendering a decision after the record in this case was closed — perhaps due to the number of novel and complex issues raised — we do not find any “exceptional” circumstances justifying a reopening of the record. On appeal, WGL contends that the Commission failed to state adequate findings of fact in support of its decision, and argues, in effect, that, in light of the continuing erosion to its rate of return caused by inflation, the failure to provide an attrition allowance was per se unreasonable.

No party disputes the fact that WGL’s earnings have suffered from attrition in recent years, or that inflation is likely to remain an economic reality in the near future. The Commission recognized the Company’s earnings erosion and took several steps that it considered sufficient to combat attrition in this case. Besides routinely allowing WGL to amend its original application (based on a calendar 1976 test year) to incorporate a test year ending June 30, 1977, the Commission also (1) adjusted the mid-1977 test period to reflect known changes in operating costs occurring shortly thereafter, and (2) used a year-end rate base (as of December 31, 1977) in establishing WGL’s revenue requirements. WGL’s argument, that the Commission was required to grant further relief in the form of an attrition allowance to compensate for expected growth in the rate base and anticipated increases in labor costs, is, we find, without merit.

Although other jurisdictions have accepted separate attrition allowances as a valid means of hedging against inflation, see, e.g., Legislative Utility Consumers' Council v. Granite State Electric Co., 119 N.H. 359, 362-63, 402 A.2d 644, 646-47 (1979) (attrition allowance of 0.5% of rate base upheld); In re Georgia Power Co., 30 P.U.R. 4th 409, 420-21 (Ga.P.S.C.1979) (authorized return on equity increased by 0.7% to account for attrition), a majority of state regulatory commissions adhere to the view that, absent extraordinary conditions, using a year-end rate base and making adjustments for known and measurable changes occurring within a reasonable time after the test period are sufficient steps to offset attrition. See, e.g., In re General Telephone Co., 19 P.U.R. 4th 227, 232-35 (Fla.P.S.C.1977); In re Kansas Power and Light Co., 13 P.U.R.4th 213, 223 (Kan.St.Corp.Comm’n 1975); In re East Ohio Gas Co., 16 P.U.R.4th 137, 153-54 (Ohio P.U.C. 1976); In re Chesapeake and Potomac Telephone Co., 19 P.U.R.4th 349, 363-64 (Va.St.Corp.Comm’n 1977). General allegations of as-yet-unquantified future cost increases and rate base expansion do not provide an automatic entitlement to incremental attrition relief.

Effective ratemaking requires “an honest and intelligent forecast as to probable price and wage levels” in the near future. McCardle v. Indianapolis Water Co., 272 U.S. 400, 408, 47 S.Ct. 144, 147, 71 L.Ed. 316 (1926). See also Telephone Users Association v. Public Service Commission, supra at 300-03. To be sure, WGL made a bona fide attempt to quantify the expected growth in its rate base during the year 1978 and the estimated increase in labor costs that would be engendered by the new labor agreement (to be negotiated following the expiration of the then-existing contract on May 31,

1978). However, there were a number of countervailing factors in the record that support the Commission’s refusal to grant a supplemental allowance based on those estimated increases. First, there was a significant lack of unanimity as to the expected growth in WGL’s rate base. The Company’s prediction was more than 100% greater than that of the Staff, and People’s Counsel challenged the methodology used by both. Second, the Company’s projection with respect to future wage levels not only was speculative, but also related to a labor settlement that was yet to be negotiated and, in any event, would not take effect until June 1, 1978. The Commission did not act unreasonably in refusing to grant rate relief on the basis of conjectural costs so far removed from the test period. Third, there was evidence that the size of WGL’s labor force had declined steadily in recent years, due in part to productivity efficiencies. There also was evidence that the Company expected to cut costs in some areas through improved technologies in the near future. In addition, a Company witness pointed out that customer contributions in the form of deferred income taxes should continue to rise each year. Evidence was adduced that the gas supply picture for the near future had improved since WGL’s last rate proceeding. The Company recently had been authorized to expand its service obligation by up to 5,000,000 therms per year to a maximum of 3,000 new customers. See note 49 infra. And finally, we observe that the Commission computed WGL’s operating expenses using a 48% federal corporate income tax rate, whereas Congress had recently lowered the actual rate to 46%, effective January 1, 1979. Since we today affirm the Commission’s use of the 48% tax rate (see Part IV (B) infra), the savings that the Company realizes on the difference between the two rates will serve also to mitigate attrition.⁴⁵

In sum, although it is generally desirable for the Commission to account for changes in costs or in the rate base occurring within a reasonable period after the test year— even when this entails making educated forecasts — there were sufficient offsetting factors in this case to justify the Commission’s refusal to grant the Company separate relief based on projected pos West-year rate base expansion and labor expense increases. On the basis of the record before us, we cannot conclude that the Commission committed reversible error in finding that the Company had failed to justify its request for a separate attrition allowance.

B. Federal Income Tax Rate

The Commission computed WGL’s revenue requirements using the 48% federal corporate income tax rate, which was in effect until December 31, 1978.⁴⁶ Order 6060, at 9-10. People’s Counsel and the GSA contend here, as they did before the Commission, that since the rates in issue here went into effect on March 16, 1979, upon the issuance of Order 6060, the Commission should have used instead the newly-enacted 46% tax rate, which became effective on January 1, 1979. The Commission and the Company respond that the 46% rate was properly rejected because of its remoteness from the test year.⁴⁷ If it were to be utilized, they argue, equity then would require that a number of post-test-period cost increases (which were not reflected in WGL’s pro forma test-period expenses) also be incorporated. WGL additionally contends that People’s Counsel’s espousal of the 46% tax rate is inconsistent with its position opposing an attrition allowance. The Commission stated:

Were we to consider the new 46 percent corporate income tax rate, fairness and consistency would dictate that we likewise consider other offsetting changes in the tax laws, together with changes in other expenses, such as higher wage rates for labor. And in fact, the reduction in the income tax rate effective in 1979 is not the only change in the tax laws. Both the taxable wage base and the percentage rate for the social security tax (FICA) have been increased for 1979. There could well be other changes which, in the aggregate, might more than offset any rate reduction occasioned by using the 46 percent tax rate. But People’s Counsel has failed to address this question of offsetting post-test year increases in expenses. For the reasons stated, we cannot grant People’s Counsel’s exception on this point. [Order 6060, at 10 (footnote omitted).]

The Commission’s interest in using income and expense data from a discrete time period, the test year, and its reluctance continually to extend that period until the issuance of its Final Order, are, we conclude, not unreasonable limitations on the ratemaking process. See Potomac Electric Power Co. v. Public Service Commission, supra at 18-19. The Commission’s use of the 48% tax rate must therefore be affirmed.

V. Treatment Of Expenses Incurred For Advertising, Trade Association Membership, Community Affairs Programs, And Business And Civic Organization Support

The Commission, over the dissent of Commissioner Stratton, found that certain expenses, including $95,000 for general advertising, $56,000 for trade association dues, $130,000 incurred in providing information to schools and community groups, and $35,-000 for membership dues and support payments to civic and business organizations, did not inure to the benefit of WGL’s customers. The Commission therefore concluded that these expenses should be borne by the Company’s shareholders, rather than its ratepayers. Order 6051, at 68-74. The Commission concurrently announced its intention to initiate rulemaking hearings on the treatment of advertising expenses in the near future. Id. at 69.

On appeal the Company argues that the Commission’s change of policy was arbitrary and unreasonable. The Commission and People’s Counsel respond that the Commission acted within the scope of its allowed discretion and that, as the Company failed to prove that these expenditures directly benefited the ratepayers, the Commission’s action must be sustained. Finding no error, we affirm the Commission’s treatment of these expenses.

A. Advertising expenses

In the proceedings before the Commission, People’s Counsel proposed that WGL’s general and administrative expenses be reduced by $95,000, the amount expended by WGL on general advertising during the test year. First, People’s Counsel contended that WGL had for accounting purposes treated the advertising expenses as being “of a good will or institutional nature which is . . . designed to improve the image of the utility or the industry,” rather than as “informational.”⁴⁸ Second, Daniel Sack, the witness for People’s Counsel, stated in prepared testimony that, in light of restrictions on the Company’s authorization to expand service to new customers,⁴⁹ he considered it inappropriate to charge advertising expenses to the ratepayers.⁵⁰

WGL’s witness, Unkle, responded that, despite the “technical wording” of the Uniform System of Accounts, over half the expenses in the account represented the Company’s contribution to the American Gas Association’s media advertising program, which informs customers about gas safety, gas supply, fuel characteristics, and the rising cost of gas. Unkle acknowledged that the Company had in the test year kept another, separate account, which covered informational advertising to customers.

The Commission accepted People’s Counsel’s proposed adjustment to the Company accounts, stating:

Whenever WGL wants to charge its advertising to the ratepayers, it must

carry the burden of proof. In this instance, People’s Counsel alleged that WGL’s advertising program was strictly for “image” building. Faced with this challenge, WGL should have come forward with a detailed presentation. Instead, although WGL presented a rebuttal witness, he contented himself with a three-sentence response. The witness’ statement that the advertising was “informational” is phrased in generalized and conclusory language. It defies analysis or verification. In these circumstances, the Commission will not require the ratepayers to underwrite these advertising costs. [Order 6051, at 69 (emphasis added).]

On appeal, the Company contends that the Commission erred in its allocation of the burden of proof. The Commission charged the Company with the burden of responding to the challenge by People’s Counsel to WGL’s accounting practice. The Company argues instead that “the Commission bears the burden of explaining the reasonableness of any departure from a long-standing practice, and any facts underlying its explanation must be supported by substantial evidence.” Columbia Gas Transmission Corp. v. Federal Energy Regulatory Commission, 202 U.S.App.D.C. 219, 299 n.31, 628 F.2d 578, 586 n.31 (1979). See also Atchison, Topeka & Santa Fe Railway Co. v. Wichita Board of Trade, 412 U.S. 800, 808, 93 S.Ct. 2367, 2375, 37 L.Ed.2d 350 (1973).

The case before us differs materially from Columbia Gas Transmission Corp. v. Federal Energy Regulatory Commission, supra, upon which petitioner relies. In Columbia Gas, the Commission itself, and its predecessor, the Federal Power Commission, for nearly twenty-five years had used one method of accounting (the Seaboard formula) for purposes of both cost allocation and rate design. 202 U.S.App.D.C. at 295 & n.12, 628 F.2d at 582 & n.12. In rate proceedings one party had suggested substitution of another accounting method (the United formula) for purposes of rate design. Several parties presented substantial evidence in opposition to such a substitution, while its proponent simply contended without evidentiary support that the substitution would distribute certain costs more equitably. The Commission staff also supported the United proposal. An administrative law judge found the United proposal inapplicable, but was overruled by the Commission which in conclusory fashion adopted the United proposal. Id. 202 U.S.App.D.C. at 296-98, 628 F.2d at 583-85. The court reviewed the record and found no evidence that adoption of the United proposal would serve any purpose. Under these circumstances, the court stated that, although the Commission was empowered to reconsider its policy and change its approach, in case of such a change the Commission was at least required fully to articulate the basis for its decision. Id. 202 U.S.App.D.C. at 305-06, 628 F.2d at 592-93. See also West. Ohio Gas Co. v. Public Utilities Commission (No. 1), 294 U.S. 63, 72, 55 S.Ct. 316, 321, 79 L.Ed. 761 (1935) (commission’s disallowance of certain advertising expenses as business expenses chargeable to ratepayers was wrong where the commission’s action had no basis in evidence, either direct or circumstantial ).

In this case, unlike Columbia Gas, the Commission had never before ruled on the accounting treatment of advertising expenses.⁵¹ We are thus not confronted with a departure from a long-standing Commission practice. Under these circumstances, the Commission did not bear the burden of explaining the reasonableness of its ruling.

The Commission’s ruling on the burden of proof issue, that it was incumbent upon the Company to demonstrate that the advertising benefited its ratepayers in order to charge its ratepayers for these expenses, was consistent with modern utility practice. See, e.g., In re General Telephone Co., 37 P.U.R.4th 127, 155 (Cal.P.U.C.1980); In re Mountain States Telephone and Telegraph Co., 22 P.U.R.4th 516, 541 (Colo.P.U.C.1977); In re Hawaiian Telephone Co., 23 P.U.R.4th 385, 404 (Hawaii P.U.C.1978); In re Central Illinois Public Service Co., 34 P.U.R.4th 267, 280-81 (Ill. Commerce Comm’n 1979); In re South Carolina Electric and Gas Co., 37 P.U.R.4th 441, 480 (S.C.P.S.C.1980). Courts too have ruled that institutional advertising expenses should not be charged to ratepayers “unless the utility establishes [that] such expenditures benefit all ratepayers.” State v. Oklahoma Gas and Electric Co., 536 P.2d 887, 894 (Okl.1975); accord, e.g., State ex rel. Laclede Gas Co. v. Public Service Commission, 600 S.W.2d 222, 228-29 (Mo.App. 1980), appeal dismissed, 449 U.S. 1072, 101 S.Ct. 848, 66 L.Ed.2d 795 (1981); City of Cleveland v. Public Utilities Commission, 63 Ohio St.2d 62, 70-73,406 N.E.2d 1370,1377-79 (1980); cf. Washington Public Interest Organization v. Public Service Commission, supra at 85 (the question before us in determining the propriety of a Commission ruling on an accounting issue was whether the Company had made a “convincing showing” that the Commission's ruling was unreasonable, unjust, or discriminatory.) But see note 55 infra.

The Commission fairly described the Company’s evidence as a “generalized and conclusory” refutation of People’s Counsel’s proposal. Order 6051, at 69.⁵² The evidence presented by People’s Counsel, although weak, was at least as substantial as the Company’s. Circumstantial evidence was presented — the recording of the disputed expenses in Account 930.1, and the existence of a second separate account for informational advertising, as testified to by the Company’s witness Unkle on cross-examination — indicative that the Company had made an internal judgment that the expenses were image-building in nature.⁵³ Also, Sacks’s argument, that since WGL would in the near future be permitted to expand only minimally promotional advertising was unnecessary, buttressed the position of People’s Counsel.⁵⁴ Under these circumstances, we cannot conclude that the Company has made a convincing showing that the Commission’s determination, that the Company failed to prove that the advertising was other than image-building in nature, was factually unreasonable.

Nor did the Commission err as a matter of law in concluding that such expenses must be charged to the Company’s shareholders rather than its ratepayers. The principle underlying public utility accounting systems is that gains and losses on assets which are “used and useful” in serving the public are allocated to the ratepayers, while expenses for and profits from nonutility assets are allocated to the company’s shareholders. Washington Public Interest Organization v. Public Service Commission, supra at 82. “A regulated utility may not impose unnecessary costs upon its consumers.” Cities Service Gas Co. v. Federal Power Commission, 424 F.2d 411, 417 (10th Cir. 1969), cert. dismissed, 400 U.S. 801, 91 S.Ct. 9, 27 L.Ed.2d 33 (1970). A large number of public utility commissions have in recent years concluded that “institutional” advertising, which is “designed to enhance or preserve the corporate image of the utility, and to present it in a favorable light,” City of Cleveland v. Public Utilities Commission, supra 63 Ohio St.2d at 70, 406 N.E.2d at 1377 (quoting In re Promotional Practices of Public Utilities and Cooperative Utility Associations, 97 P.U.R.3d 1, 4 (Okla.Corp.Comm’n 1972)), benefits company shareholders, rather than ratepayers, and should be disallowed as an operating expense upon which to base utility rates. See, e.g., In re Southwestern Bell Telephone Co., 27 P.U.R.4th 493, 509-11 (Ark.P.S.C. 1979); In re Mountain States Telephone and Telegraph Co., supra at 541 (Colo.); In re Southern Bell Telephone and Telegraph Co., 21 P.U.R.4th 451, 471-72 (Fla.P.S.C. 1977); In re Hawaiian Telephone Co., supra at 403-04; In re Idaho Power Co., 29 P.U. R.4th 183, 204 (Idaho P.U.C.1979); In re Interstate Power Co., 32 P.U.R.4th 494, 509 (Minn.P.S.C.1979); In re Empire District Electric Co., 30 P.U.R.4th 1, 3-4 (Mo.P.S.C. 1979); In re Gas Co., 35 P.U.R.4th 106, 127-28 (N.M.P.S.C.1980); In re South Carolina Electric and Gas Co., 34 P.U.R.4th 458, 489 (S.C.P.S.C.1979); In re Otter Tail Power Co., 30 P.U.R.4th 26, 34-36 (S.D.P.U.C. 1979); In re Monongahela Power Co., 25 P.U.R.4th 449, 455 (W.Va.P.S.C.1978); In re Madison Gas and Electric Co., 34 P.U.R.4th 569, 575 (Wis.P.S.C.1980). Courts have sustained such determinations as being reasonable and within the scope of the commissions’ authority. E.g., State ex rel. Laclede Gas Co., supra at 226-29; City of Cleveland v. Public Utilities Commission, supra 63 Ohio St.2d at 72-73, 406 N.E.2d at 1378-79; State v. Oklahoma Gas and Electric Co., supra at 894; Pacific Northwest Bell Telephone Co. v. Davis, 43 Or.App. 999, 1015, 608 P.2d 547, 556 (1979); cf. Consolidated Edison Company of New York, Inc. v. Public Service Commission, 47 N.Y.2d 94, 417 N.Y.S.2d 30, 34, 103, 390 N.E.2d 749, 752-53 (1979), rev’d on other grounds, 447 U.S. 530, 544, 100 S.Ct. 2326, 2337, 65 L.Ed.2d 319

(1980) (sustaining the Commission’s ruling disallowing the company’s accounting method under which promotional advertising expenses were considered above-the-line expenses chargeable to ratepayers).⁵⁵

We conclude that the Commission’s ruling, that the Company bears the burden of demonstrating why ratepayers should cover the cost of institutional advertising expenses, and that the Company had failed to meet this burden, was not unjust, unreasonable, or discriminatory. The ruling of the Commission must therefore be sustained.⁵⁶

B. Trade Association Dues

People’s Counsel’s witness Sack proposed that $56,000 expended by WGL for trade association dues be excluded from the company’s operating expenses. Sack suggested that “[t]he ratepayer gets no benefit” from these dues, and that such expenses are “not a necessary part of providing gas service to the consumer.” PC Exh. C, at 23-24. On cross-examination, Sack conceded that he had made no attempt to discover what the Company’s trade association membership entailed.

In his rebuttal testimony, WGL’s witness Unkle stated:

Of the $56,000 of association dues included in the rate case, ... $55,400 represents annual dues paid by the Company for its membership in the American Gas Association [AGA].

As a member of the American Gas Association, the Company has available to it resources for prompt, competent analysis of significant issues affecting the short and long term viability of the gas industry. The American Gas Association also acts as an industry clearinghouse for information on new techniques in coping with industry problems related to gas operations. [WGL Exh. L, at 6.]

The Commission adopted People’s Counsel’s proposal and eliminated $56,000 from WGL’s operating expenses. In so doing, the Commission remarked:

[Trade associations] represent their members in matters affecting them, such as proposed legislation, activities of relevant regulatory agencies, litigation, information dissemination, and image-building advertising.

m * % * * *

Although AGA’s general activities are undoubtedly valuable to investors, the record does not demonstrate that they improve customer service. Accordingly, it is more appropriate for WGL’s stockholders to fund the gas industry’s legislation and public relations programs.

To illustrate our rationale for excluding AGA dues from cost of service, we contrast these dues to WGL’s payments to AGA regarding a coal gasification project. In Case No. 647 [16 P.U.R.4th at 267], we allowed WGL to recover those payments to AGA through rates. We viewed the coal gasification project as related to future customer service, in the sense that it enhanced gas supplies. On the other hand, the general activities of the AGA, as funded by the dues in question, are far less tied to improving service to the customer. [Order 6051, at 69-71 (emphasis added).]

Review of the accounting treatment of expenditures such as trade association dues is typically and appropriately entrusted to the Public Service Commission. The purpose of Commission oversight is to protect the consuming public against monopolistic exploitation, see State ex rel. Laclede Gas Co. v. Public Service Commission, supra at 226, in part by assuring that utility customers are compelled to pay only for expenses that accrue to their benefit. The Commission’s allocation of the burden to the Company to demonstrate that the payment of trade association dues benefits customers comports with modern utility commission regulatory practice. See Colorado Ute Electric Association, Inc. v. Public Utilities Commission, 198 Colo. 534, 541, 602 P.2d 861, 865-66 (1979) (en banc); In re Florida Gas Co., 13 P.U.R.4th 255, 259 (Fla.P.S.C. 1975); In re Idaho Power Co., 23 P.U.R. 299, 319-20 (Idaho P.U.C.1977); In re Rules and Regulations Covering Rate Case Treatment of Certain Expenses, 30 P.U.R.4th 338, 343 (N.M.P.S.C.1979). Likewise, the Commission’s disallowance of trade association dues as operating expenses for rate-making purposes, in the absence of evidence that the expenses directly benefit the ratepayer, parallels the practice of many other utility commissions. See, e.g., In re Idaho Power Co., supra at 319-20; In re Kansas City Power and Light Co., 28 P.U.R.4th 398, 437-38 (Mo.P.S.C.1979); In re Rules and Regulations Covering Rate Case Treatment of Certain Expenses, 30 P.U.R.4th at 343; In re Minnesota Gas Co., 32 P.U.R.4th 1, 27-28 (S.D.P.U.C.1979); Washington Utilities and Transportation Commission v. Washington Natural Gas Co., 32 P.U.R.4th 530, 542-43 (Wash.Utils. & Transp.Comm’n 1979); In re Pennzoil Co., 6 P.U.R.4th 189, 194 (W.Va.P.S.C.1974). Contra, In re Southwestern Bell Telephone Co., 28 P.U. R.4th 519, 537 (Kan.St.Corp.Comm’n 1979); In re Columbus and Southern Ohio Electric Co., 24 P.U.R.4th 261, 287 (Ohio P.U.C. 1978).

We conclude that here, in the absence of evidence that AGA activities benefited customers, the Commission acted reasonably and within the scope of its allowed discretion in concluding that ratepayers should not be compelled, by inclusion of those expenditures in the Company’s operating expenses, to pay the AGA dues.⁵⁷

C. Community Affairs Expenses

The Company’s witness, Unkle, testified that, at the invitation of schools and community groups, WGL sends out speakers to talk about matters relating to gas service, including fuel conservation, safety considerations, the two-part billing system, estimated billing, the gas supply situation, and the rising cost of gas. WGL Exh. L, at 6. During the test year, WGL incurred expenses of $130,000 on this speakers program. People’s Counsel’s witness, Sack, recommended that the entire amount be disallowed as an operating expense. He testified:

The amount of $130,000 described as community activities is clearly to enhance the public image of the Company and, as such, should be borne by the stockholder. The Company is free to make these expenditures and may even consider that it is under a certain amount of community pressure to do so. These activities are probably not equally available to all ratepayers and may, in fact, not even be desired by many of the ratepayers. I believe that this expense, being one of enhancing the public image of the Company, should be borne by the stockholders. [PC Exh. C, at 24.]

On cross-examination, Sack admitted that his characterization of the Company’s speakers program as “one enhancing the public image of the Company” was based on speculation concerning the implications of the descriptive title of the program.

In rebuttal, Unkle denied that WGL’s community activities were undertaken to enhance the Company image. Rather, he stated,

Talking about such subjects to community groups is one important way our Company can provide information about subjects of vital concern both to us and our customers.

... The purpose is to communicate with customers on those subjects about which they want more information. In fact, the Company is under a certain amount of community pressure to engage in such activities. Such expenses are not only proper, but they are vital. [WGL Exh. L. at 6-7.]

The Commission adopted People’s Counsel’s proposal, explaining its reasoning as follows:

[T]he Commission believes that WGL’s shareholders should pay these community affairs expenses. We take this action for two reasons. In the first place, notwithstanding WGL’s protestations to the contrary, many of these community affairs activities are image-building in effect. These presentations enhance WGL’s appearance in the community without any direct link to providing utility service. Secondly, we analogize these community affairs expenses to the charitable discounts for telephone service which we discontinued in a prior C&P rate proceeding, Case No. 631. There, we viewed those telephone discounts as a “forced contribution by telephone users to ‘individuals and organizations to which [the ratepayers] might not otherwise contribute.’ ” (Order No. 5790, p. 78). In the same way, if ratepayers must underwrite WGL’s community affairs expenses, they will be forced to make a contribution to the beneficiaries of WGL’s program. That would be unfair, particularly since only a limited number of community organizations are receiving speakers from WGL.

In taking this action, we do not find that WGL has acted imprudently. Nevertheless, the nature of the community affairs program is more akin to the interest of WGL’s stockholders than to [that of] the ratepayers. We shall, however, reserve the right to reevaluate in the future this issue and the question of support to civic organizations. [Order 6051, at 73-74.]

On appeal, the Company likens the expenditures in issue to informational advertising. Utility commissions generally find informational advertising, relating, for example, to safety and conservation, to be chargeable as an above-the-line expense to ratepayers. See, e.g., In re Peoples Gas Light and Coke Co., 34 P.U.R.4th 292, 317-18 (Ill. Commerce Comm’n 1979) (75% of informational advertising expenses allowed above-the-line); In re Gas Co., supra at 128 (N.M.); In re South Carolina Electric and Gas Co., 37 P.U.R.4th 441, 480 (S.C.P.S.C. 1980); In re Madison Gas and Electric Co., 34 P.U.R.4th 569, 575 (Wis.P.S.C.1980). The Company contends that the Commission’s ruling, that these expenditures must be charged below the line to WGL’s shareholders, rather than above the line to the ratepayers, was arbitrary and unreasonable. The Commission responds that, as in the case of the challenged advertising expenses and trade association dues discussed above, the Company failed to meet its burden of demonstrating that the expenses in question directly benefited the utility’s ratepayers.

As in the case of the other challenged expenses, we also accept the Commission’s allocation of the burden of proof with respect to community affairs expenses. As the Company has primary control of its own records, there is no injustice in allotting to the Company the initial responsibility for demonstrating the reasonableness of above-the-line charges to its ratepayers.

The sparse record with respect to the challenged community affairs expenses consists merely of cross-allegations as to the nature and purpose of the speakers programs, unsubstantiated by documentary evidence on either side. The Commission did not act arbitrarily in refusing to accept WGL’s conclusory assertions here; the burden of proof imposed in this case is consistent with the Commission's usual practice. See, e.g., In re Potomac Electric Power Co., 36 P.U.R.4th 139, 186-87 (D.C.P.S.C.1980):

While we readily appreciate that an applicant for a rate increase cannot be expected in its initial filing to offer detailed support for each and every aspect of its cost of service, we do expect substantially more than this conclusory and bare bones effort to deal with a concrete, specified issue such as this one. Without more, Pepco’s skeletal affirmative case falls far short of showing, even at a pri-ma facie level, the appropriateness of its advertising expenditures .... [Id. at 186.]

Nor is the Commission’s disallowance of these community affairs expenses inconsistent with the treatment accorded such items by utility commissions in other jurisdictions. See, e.g., In re Northwestern Bell Telephone Co., 37 P.U.R.4th 1, 23 (Minn.P.S.C. 1980) (expenditures for open house community events, multisubject films, town talkers, displays and exhibits on multisubjects excluded from above-the-line operating expenses). On this record the Commission could reasonably conclude, as it did, that the Company failed to demonstrate a direct link between the speakers program and the provision of utility service, and thus that the Company did not justify above-the-line treatment for the community affairs expenses.⁵⁸

D. Business and Civic Support Payments

The Commission further disallowed as operating expenses for ratemaking purposes WGL’s contributions to various business and civic organizations.⁵⁹ Although it recognized that all of these organizations appeared to be meritorious and deserving of the business community’s support, the Commission concluded:

WGL’s management decision to contribute to these organizations is not the ratepayers’ concern. However worthwhile these organizations may be, the ratepayers may not be required to make forced contributions to them. Since the ratepayers do not directly benefit from WGL’s payments in terms of gas service, they should not bear this cost. [Order 6051, at 72.]

We cannot conclude that the Commission’s decision on this point was arbitrary or unreasonable. The Company’s contributions to these organizations are tantamount to charitable donations. Reviewing courts have generally held that it is a proper exercise of agency discretion for a regulatory commission to exclude such donations from a utility’s cost of service. See, e.g., Alabama Power Co. v. Alabama Public Service Commission, supra at 779-80; New England Telephone and Telegraph Co. v. Public Utilities Commission, supra at 55-56 (Me.); State ex rel. Utilities Commission v. Southern Bell Telephone and Telegraph Co., 24 N.C.App. 327, 335, 210 S.E.2d 543, 549 (1975), vacated on other grounds, 289 N.C. 286, 221 S.E.2d 322 (1976). Indeed, a growing number of courts have held that charitable contributions may not be recovered from the ratepayers, and have reversed utility commission orders that allowed such contributions as operating expenses. See, e.g., Alabama Power Co. v. Alabama Public Service Commission, 390 So.2d 1017, 1027 (Ala.1980); City of Cleveland v. Public Utilities Commission, supra 63 Ohio St.2d at 73-74, 406 N.E.2d at 1379-80 (and cases cited therein). Contra, New England Telephone and Telegraph Co. v. Department of Public Utilities, 360 Mass. 443, 480-84, 275 N.E.2d 493, 518-21 (1971). We note too that the Uniform System of Accounts treats charitable contributions as a below-the-line deduction from income, chargeable to the shareholders rather than the ratepayers. 18 C.F.R. Pt. 201, Account 426.1 (1980). But see note 53 supra.

We accordingly find no error in the Commission’s conclusion that “the ratepayers may not be required to make forced contributions” to business and civic organizations, Order 6051, at 72, and we therefore affirm the Commission’s below-the-line treatment of these expenses.

VI. Tax Normalization op Construction Overheads

In an attempt to create a source of interest-free capital, WGL requested that the Commission “normalize” (i.e., defer) the tax effect of certain construction overhead expenses for ratemaking purposes. The Internal Revenue Code allows utilities to deduct the full amount of certain indirect expenses related to construction work in the year in which they were incurred. I.R.C. § 167(1). In the test year, WGL took full tax deductions for the amounts expended on these eligible overheads, which included pensions, group insurance premiums, and social security and unemployment compensation taxes for construction workers, as well as interest on debt in the Allowance for Funds Used During Construction (AFUDC). On a separate set of books, however, the Company capitalized these expenses over the useful life of the plant for rate purposes. By capitalizing the overheads for rate purposes, while deducting these expenses in full during the test year for tax purposes, the Company hoped to improve its cash flow situation since it would be obtaining, in effect, an interest-free loan of capital from the ratepayers.⁶⁰

Normalization is a recognized method of providing capital for companies that otherwise are having difficulty securing working or construction funds. “The proper test for determining whether or not normalization of book-tax timing differences should be authorized is whether or not the utility company has experienced, or will experience in the following year, severe cash-flow problems and internally generated fund reductions of significance.” In re Laclede Gas Co., 27 P.U.R.4th 241, 261 (Mo. P.S.C.1978).

In this case, the Commission denied the Company’s request for normalization, finding that “WGL does not appear to have cash flow difficulties sufficient to warrant the ratepayers paying for income taxes WGL is not in fact paying.” Order 6051, at 61. The Commission also was skeptical of WGL’s suggestion that tax normalization would result only in a tax deferral, rather than a permanent tax savings. It stated:

From the narrow perspective of each individual item of plant, one might argue that there will only be a tax deferral because each plant component will eventually go into service and start to generate tax benefits for the ratepayers. But looking at the broader perspective of income taxes paid, the Commission finds that the answer is less than clear. WGL has an expanding rate base, a phenomenon which should continue for some time. WGL’s expanding plant will deprive not only present but also future ratepayers of rates reduced by these normalized construction overhead deductions. Under normalization with expanding plant, there will always be more deferred deductions which will offset the previously deferred deduction from which the ratepayers are now supposed to benefit. The net effect is that WGL’s rates might never be reduced to account for construction overhead deductions. The result could be a permanent tax saving — at the ratepayer’s expense. [Id. at 62.]

Accord, e.g., Federal Power Commission v. Memphis Light, Gas & Water Division, 411 U.S. 458, 460, 93 S.Ct. 1723, 1725, 36 L.Ed.2d 426 (1973); Public Systems v. Federal Energy Regulatory Commission, 196 U.S.App. D.C. 66, 69, 606 F.2d 973, 976 (1979); Alabama-Tennessee Natural Gas Co. v. Federal Power Commission, 359 F.2d 318, 328 (5th Cir.), cert. denied, 385 U.S. 847, 87 S.Ct. 69, 17 L.Ed.2d 78 (1966); City of Los Angeles v. Public Utilities Commission, 15 Cal.3d 680, 685-86, 125 Cal.Rptr. 779, 782, 542 P.2d 1371, 1374 (1975) (en banc). But see Regulations Implementing Tax Normalization for Certain Items Refíecting Timing Differences in the Recognition of Expenses or Revenues for Ratemaking and Income Tax Purposes, 46 Fed.Reg. 26,613 (1981) (to be codified in 18 C.F.R. Pt. 2) (requiring certain public utilities to use tax normalization to compute the income tax component of their cost of service and concluding that normalization, as set forth in the Federal Energy Regulatory Commission’s final order, will not cause utilities or their investors to realize a permanent tax savings). Notwithstanding these concerns, the Commission stated that room for doubt still exists.” It declined to permit WGL to normalize the construction overheads, but announced that, “In the future, if the Company can present a more persuasive case, this Commission will consider it with an open mind.” Order No. 6051, at 62.

Until this proceeding, WGL routinely had flowed through any benefits from tax deductions directly to its customers; this case is the first in which WGL has sought to defer the tax effect of construction overheads for rate purposes. Although utility regulatory commissions are divided on the question of whether or not to permit companies to defer the flow-through of tax benefits to ratepayers, courts appear to be unanimous in concluding that the question is one which is entrusted to the sound discretion of regulatory commissions. See, e.g., Federal Power Commission v. Memphis Light, Gas & Water Division, supra 411 U.S. at 467, 93 S.Ct. at 1729; Midwestern Gas Transmission Co. v. Federal Power Commission, 388 F.2d 444, 448 (7th Cir.), cert. denied, 392 U.S. 928, 88 S.Ct. 2286, 20 L.Ed.2d 1387 (1968); Alabama-Tennessee Natural Gas Co. v. Federal Power Commission, 359 F.2d at 332-33, 339; Office of the Public Counsellor v. Indiana & Michigan Electric Co., Ind.App., 416 N.E.2d 161, 171 (1981); Central Maine Power Co. v. Public Utilities Commission, 382 A.2d 302, 321-22 (Me. 1978). We cannot conclude that the Commission acted unreasonably or otherwise abused its discretion in denying the Company’s normalization proposal. We therefore affirm the Commission’s ruling on this issue.

VII. Treatment op the Tax Benefit Resulting From WGL’s Filing op a Consolidated Tax Return

WGL and its subsidiaries take advantage of an Internal Revenue Code provision that permits affiliated companies to file a consolidated income tax return. I.R.C. § 1501. By so doing, losses sustained by unprofitable affiliates can be used to offset the taxable income of the profitable companies during a given year. The net result is that the group incurs a lower tax liability for the year than it would have if each affiliate had filed an individual tax return.

For the test year, WGL filed a consolidated return with three of its subsidiaries, none of which is directly regulated by the Commission. One of these companies is the Crab Run Gas Company (Crab Run), a gas exploration and production subsidiary, which is wholly owned by WGL. Crab Run is a recent addition to WGL’s corporate family, and, like most gas exploration outfits, it has operated at a net loss during the first few years of its existence. In an earlier proceeding, the Commission decreed that the costs of keeping Crab Run afloat should be borne entirely by WGL’s stockholders; thus, for ratemaking purposes the Company’s investment in Crab Run was not to be reflected in WGL’s rate base, nor were subsequent operating losses incurred by Crab Run to be included in WGL’s cost of service. See Formal Case No. 610, Order No. 5685, Jan. 23, 1975, at 15. This would be fair to WGL’s stockholders, the Commission said, because if Crab Run eventually were successful, its profits from the sale of gas would inure to the direct benefit of the parent company’s stockholders, rather than its ratepayers. Id.

By including the operating losses of Crab Run in its consolidated tax return, WGL’s District of Columbia operations realized a test-year income tax savings of $96,000 (compared with the amount of tax the Company would have paid had it filed an individual return). Order 6060, at 5. The Commission stated, “The new rates do include a component [$3.9 million] for Federal Income Taxes. This is the factual basis needed for implementing our approval of the principle that ratepayers should share in consolidated tax savings.” Id. The Commission determined that the shareholders and ratepayers of WGL should share equally in this consolidated tax savings; accordingly, the Company’s cost of service was reduced by one-half of the tax savings, or $48,000. WGL contends that because the stockholders have been required to bear all of the risk associated with Crab Run’s operations, it was arbitrary and unreasonable for the Commission to allow the ratepayers to share in the consolidated tax savings. Not only was this unfair, WGL argues, but it also was contrary to the Commission’s promise in Order No. 5685, supra, to assign all future profits from Crab Run to the benefit of the investors.

Initially, we note that there is a difference between profits from the sale of Crab Run gas (as discussed by the Commission in Order No. 5685), and profits realized from tax savings generated by consolidating Crab Run’s and WGL’s tax returns. Therefore, WGL’s allegation that the Commission has purloined the benefits that it promised to the stockholders in Order No. 5685 is not wholly valid.

Moreover, the Supreme Court has explicitly sanctioned the ratemaking principle at issue here. In Federal Power Commission v. United Gas Pipe Line Co., 386 U.S. 237, 87 S.Ct. 1003, 18 L.Ed.2d 18 (1967), the Court held that it was neither unreasonable nor unlawful for the FPC to reduce a utility’s revenue requirements by the full amount of a consolidated tax savings.⁶¹ In United, as here, it was fairly clear that the ratepayers receiving the consolidated tax benefits had not funded the nonjurisdictional affiliate whose losses had made the savings possible. Nevertheless, the Court found that it was reasonable for the FPC to adjust the regulated utility’s cost of service to reflect that company’s pro rata share of taxes actually paid, rather than allow the company’s shareholders to receive a permanent windfall tax savings based on a hypothetical tax expense. See id. 386 U.S. at 243-45, 87 S.Ct. at 1007-08. Accord, e.g., Florida Gas Transmission Co. v. Federal Power Commission, 391 F.2d 114 (5th Cir. 1968); Mechanic Falls Water Co. v. Public Utilities Commission, 381 A.2d 1080, 1091-95 (Me.1977); Michaelson v. New England Telephone and Telegraph Co., 404 A.2d 799, 809-10 (R.I.1979); In re The Chesapeake and Potomac Telephone Co., 4 P.U.R.4th 1, 36-39 (D.C.P.S.C.1974).⁶²

The Commission acted within the scope of its authority and in accordance with accepted principles of utility ratemak-ing in allocating to the ratepayers a portion of the tax savings realized by the Company from the filing of consolidated tax returns. We affirm the Commission’s ruling on this issue.

VIII. Treatment of Map Computerization Expenses

During the test year, WGL entered into a contract for the computerization of its distribution maps and records system. Under this program, aerial photographs will be used to produce “digitized” maps of the Company’s service area, showing the location of mains, services, and other aspects of its distribution plant. The contract is to be completed within four years at a total price of $2,075,000. WGL spent $132,000 for the first phases of this project during the final three months of the test year.

The Company, which books the conversion program as an expense item rather than a capital asset, proposed that the project’s total cost be amortized evenly over the four-year contract term (at $519,000 annually), beginning with the test year. Instead, the Commission ruled that only the $132,000 actually incurred during the test year should be included in the Company’s cost of service; remaining amounts expended on the contract after the test year were to be placed in a deferred expense account, and to be amortized (over an as-yet-undetermined period) once the project is completed. Order 6051, at 66-68. The Commission explained:

In adopting this hybrid treatment, the Commission first rejects WGL’s proposal for an immediate four-year amortization. WGL’s computerized data base will benefit customers well beyond the term of the four-year contract. Accordingly, recovery of the full contract price in four years is unreasonable. Of course, present ratepayers have received some improvement in service from the partial performance to date. Nonetheless, WGL has made no attempt to match those benefits to its $519,000 expense proposal. Nor has WGL taken account of any offsets, such as improved labor efficiency and reduced costs attributable to the program. In sum, to adopt WGL’s proposal would distort the test period match-up of costs and cost reductions.

On the other hand, the Commission cannot totally ignore the program’s costs, as People’s Counsel’s witness originally recommended. The computerization program is currently being used in the daily operations of the Company with resulting benefits. All of the District of Columbia has been photographed, and many of the aerial photographs have been digitized. Although additional benefits will result as the work progresses, parts of the program are in use now. No reason exists, therefore, for deferring the entire expense until the complete program is in operation. Indeed, even People’s Counsel appears to accept that test-year expenses can properly include the $132,000 paid during that period.

Under its decision, the Commission anticipates that a substantial portion of the total contract price will remain in the deferred expense account upon completion. It is clear to the Commission that the fully computerized data base will be useful to WGL in providing gas service after contract completion. The deferred expense accounting we have chosen recognizes that fact. Yet we are constrained by the state of the record not to establish how or over what period of time the deferred expenses will be recovered after contract completion. In a future rate filing, we anticipate that WGL will address how the computerized data base affects existing operations. It should also present evidence showing how the deferred expenditures should be treated for ratemaking purposes. [Id. at 67-68.]

The Company contends that the Commission’s treatment of these expenses is unlawfully confiscatory. However, WGL’s unhappiness seems to stem not so much from the allowance of only $132,000 during the test year, but rather from the Commission’s suggestion that future expenditures on this project should be deferred for rate purposes until the conversion is completed. In its brief, WGL argues:

[O]ver the remaining life of the contract, WGL is precluded from recovering anything at all for the heavy investments made. The Company is not even permitted a return on the expended amounts placed in the deferred expense account. For example, in WGL’s current application for a permanent rate increase [Formal Case No. 722], pursuant to the Commission’s mandate, map computerization expenses expended during the applicable test period are wholly excluded.

* * * * * *

The Commission’s treatment of map computerization expense is novel. A superficial analogy might be drawn to the treatment of expenditures for construction work in progress. A minority of the regulatory commissions, including the Commission for the District of Columbia, do not permit construction expenditures to be included in the rate base until after the plant is completed and in service (see Potomac Electric Power Co., Application for Rate Increase Formal Case No. 685, Order No. 7000, July 18, 1979). In that instance, however, the assumed return on the funds expended in construction is accumulated. Upon placing of the plant in service, the utility begins to recover the accumulated return during construction, plus the return on the plant added to the rate base; also, depreciation on the plant is an allowable expense item in connection with this capital asset. The Commission made no provision for accumulating returns on amounts placed in the deferred expense account for map computerization for eventual recovery after the project is completed. But this is only the start of the injustice.

In the instance of a capital asset, such as a constructed plant, to spread out recovery of investment in the form of depreciation allowances over the entire estimated period during which ratepayers will benefit from such asset is not unreasonable, inasmuch as throughout that period the Company is permitted to earn a reasonable return on that capital expenditure. On the other hand, to tie the recovery period of an expense item, such as for map computerization, to the period during which ratepayers may reap the full benefit of that expenditure is grossly unreasonable. [Brief for WGL at 26-27 (emphasis in original).]

The Commission and People's Counsel urge, on the other hand, that the PSC’s action is consistent with the general rate-making precept that the recovery of costs should be synchronized with the realization of affiliated benefits. Furthermore, they argue, the company’s complaint about how post-test year expenses will be recovered is premature; this issue will be ripe for review only when, in a subsequent rate proceeding, the Commission issues a more definitive ruling on what treatment should be accorded these expenditures.

We agree with the Commission and People’s Counsel that only the $132,000 test year allowance is ripe for review. Because the opinion leaves open the question of precisely what rate treatment should be accorded post-test-year map computerization expenditures, we address only the reasonableness of the amount actually allowed in the case before us.

As the Company acknowledges, it is not uncommon for regulatory commissions to defer the inclusion of construction costs in a utility’s rate base until after the plant is completed and in service. See, e.g., Providence Gas Co. v. Burman, supra at 692-93; South Dakota Public Utilities Commission v. Otter Tail Power Co., 291 N.W.2d 291, 295 (S.D.1980); Re Southwestern Electric Power Co., 26 P.U.R.4th 381, 382-83 (F.E.R. C.1978); In re Southwestern Bell Telephone Co., 36 P.U.R.4th 283, 294 (Mo.P.S.C.1980); Pennsylvania Public Utilities Commission v. Pennsylvania Electric Co., 1 P.U.R.4th 272, 278 (Pa.P.U.C.1973). Analogously, when particular test year operating expenditures are deemed to be “extraordinary” (i.e., infrequently recurring), commissions often amortize the recovery of these expenses over an appropriate number of years. See, e.g., In re Central Illinois Public Service Co., 34 P.U.R.4th 267, 280 (III. Commerce Comm’n 1979) (cost of study to improve efficiency and performance amortized over five years); In re Monmouth Consolidated Water Co., 24 P.U.R.4th 464, 470 (N.J.Bd. of Pub.Util.Comm’rs 1978) (expenses relating to extraordinarily cold winter amortized over ten years); In re Columbus and Southern Ohio Electric Co., supra at 285-86 (expenses of installing sulfur dioxide scrubber amortized over twenty years). These types of rate treatment are corollaries of the “more basic principle of economics and regulation [that] costs which benefit future ratepayers should be capitalized and ex-pensed in the future.” South Central Bell Telephone Co. v. Louisiana Public Service Commission, 352 So.2d 964, 980 (La.1977), cert. denied, 437 U.S. 911, 98 S.Ct. 3103, 57 L.Ed.2d 1142 (1978).

Along these lines, we cannot conclude that the Commission erred in rejecting WGL’s four-year amortization schedule for map computerization costs. So far as the record reveals, the map conversion project is essentially a non-recurring item which should benefit future ratepayers in terms of cost efficiencies “well beyond the term of the four-year contract.” Order 6051, at 67. In response to testimony by WGL’s witness, Smallwood, indicating that a number of interim benefits were being experienced as a result of work already completed, the Commission allowed WGL to recover the $132,000 already expended on the program. In the absence of a more detailed presentation by WGL matching future expenditures with resultant interim benefits, we do not think that the allowance of only $132,000 was unreasonable. Accordingly, we affirm on this issue.

IX. Treatment of Gains Realized on WGL’s Sale of Propane Reserves

WGL uses propane to provide gas when demand exceeds the available pipeline supply. Several years prior to the commencement of this rate proceeding, the Company purchased a sizeable quantity of propane, which is stored in Conway, Kansas. Subsequently, pipeline supplies became more plentiful and it was no longer necessary to maintain such large reserves of propane. Accordingly, during the period ending June 30, 1977, WGL sold the final eleven million gallons of propane that had been stockpiled in Kansas. The Company realized a net aftertax gain of $855,200 on these sales, $192,000 of which was allocable to the District of Columbia. Order 6051, Appendix A, Sch. 2.

WGL recorded the entire gain in a below-the-line account, and proposed that the Commission likewise allow the Company’s shareholders to have the profits from the sales. The Staff and People’s Counsel objected, urging that the ratepayers were entitled to the entire gain. The Commission ultimately adopted the Staff’s proposal to amortize the gain over three years for the ratepayers’ benefit; WGL’s test-year operating revenues accordingly were increased by one-third of the total net after-tax gain ($64,000). Id. The Company contends that the Commission’s action in this regard was unlawfully confiscatory.

The appropriate allocation of gains and losses realized upon the transfer of utility property is an issue that has received surprisingly little attention in reviewing courts. Those few courts that have addressed the subject have provided only general guiding principles by which to judge the propriety of a commission’s action in such matters. It is evident, however, that each case must rest upon its own factual situation; the validity of each allocation of profits or losses depends upon the nature of the property transferred and a balancing of the equities involved. See generally Democratic Central Committee v. Washington Metropolitan Area Transit Commission, 158 U.S.App.D.C. 7, 26-32, 485 F.2d 786, 805-11 (1973), cert. denied, 415 U.S. 935, 94 S.Ct. 1451, 39 L.Ed.2d 493 (1974).

The propane that WGL sold during the test period had been recorded by the Company in Account 151.109 of the Uniform System of Accounts, see 18 C.F.R. Pt. 201 (1980). PC Exh. C, at 13. That account is labelled “Propane Stock” and is a subeate-gory of Account 151, “Fuel Stock.” The Uniform System of Accounts prescribes methods for allocating gains and losses on the transfer of certain categories of utility property.⁶³ However, such guidelines do not materially aid our review function in this case for two reasons. First, the Uniform System’s allocation scheme relies largely upon certain classifications of the property transferred, e.g., whether the property is “depreciable” or “non-deprecia-ble,” whether it is “operating” or “non-operating”, and whether the property is in current use or “held for future use.” See Washington Public Interest Organization v. Public Service Commission, supra at 82-84. The record in this case does not disclose the nature of the propane stock in question with precision from an accounting standpoint.⁶⁴ Moreover, even if the proper treatment under the Uniform System were plain, it would not be dispositive for rate-making purposes. See note 41 supra. The more important inquiry in determining who should receive the gains from the propane sales is the question of who has borne the risks and burdens associated with its maintenance. See Democratic Central Committee v. Washington Metropolitan Area Transit Commission, supra 158 U.S.App.D.C. at 27-32, 40—43, 485 F.2d at.806-11, 819-22. See also Washington Public Interest Organization v. Public Service Commission, supra at 87-88; City of Lexington v. Lexington Water Co., 458 S.W.2d 778 (Ky.1970); New York Water Service Corp. v. Public Service Commission, 12 A.D.2d 122, 129, 208 N.Y. S.2d 857, 863-64 (1960), appeal denied, 10 N.Y.2d 705, 219 N.Y.S.2d 1025 (1961).

The Commission found that the equities favored a complete allocation of gains to the ratepayers.⁶⁵ It stated:

To begin, WGL procured this propane for the benefit of ratepayers and to provide more system reliability during peaking periods. As a result, this propane inventory was included in WGL’s rate base. And ratepayers paid all WGL’s costs for storing the propane in Kansas. In addition, if WGL lost the propane, as through some catastrophe, it would be likely to ask that ratepayers help bear the loss. Since the ratepayers face the risk of loss, they should likewise realize the gain when this propane is sold off-system. [Order 6051, at 48.]

The Company does not dispute that the propane stock was included in WGL’s rate base or that the ratepayers paid all costs associated with maintaining the reserves in Kansas. It argues, however, that because WGL’s investors furnished the capital to purchase the propane, any profits realized on its disposal must go to the investors. This result is mandated, the Company argues, by the Supreme Court’s opinion in Board of Public Utility Commissioners v. New York Telephone Co., supra 271 U.S. at 32, 46 S.Ct. at 366, wherein the Court stated:

Customers pay for service, not for the property used to render it. Their payments are not contributions to depreciation or other operating expenses, or to capital of the company. By paying bills for service they do not acquire any interest, legal or equitable, in the property used for their convenience or in the funds of the company. Property paid for out of moneys received for service belongs to the company, just as does that purchased out of proceeds of its bonds and stock.

While the above language is appealing on its face, the Commission and People’s Counsel correctly note that the case from which it was quoted is distinguishable from the one at hand. The issue in New York Telephone was whether past excess depreciation accruals could be used to reduce present depreciation accruals. The Court found that such a policy constituted unlawful retroactive ratemaking. Not only is that issue factually distinct from the one before us, but its applicability to the type of question presented here was implicitly rejected by the circuit court for the District of Columbia in Democratic Central Committee v. Washington Metropolitan Area Transit Commission, supra. See note 65 supra.

As we have noted with respect to this case, the ratepayers paid all costs associated with maintaining the propane in Kansas, including storage and transportation costs (and personal property taxes, if any). They also paid WGL a return on the original cost of the propane, since the fuel was included in the rate base. See PC Exh. C, at 14. We further note that the propane stock was maintained pursuant to WGL’s obligation to hedge against fuel shortages during peak usage periods: propane is unique as the “property” of a gas distribution company, since in periods of need it becomes gas to be supplied to consumers. Therefore, the Company’s assertion that it is “not in the business of selling” propane is essentially unrealistic.

We hold that the treatment of gains realized on the sale of propane reserves was not so unreasonable as to constitute an unlawful confiscation of the Company’s property. We therefore affirm the Commission’s ruling on this point.

X. Proceeds From the ARCO Litigation

In 1973, WGL and the Atlantic Richfield Company (ARCO) entered into a contract whereby ARCO would supply naphtha feedstock to WGL for use in the production of synthetic natural gas.⁶⁶ In 1975, WGL filed a lawsuit against ARCO alleging an anticipatory breach of that contract; ARCO then lodged a counterclaim. At about the same time, WGL abandoned the synthetic gas project for economic reasons. In November, 1976, the two companies reached a settlement under which ARCO paid WGL $2,750,000.

WGL recorded this amount in Account 434, “Extraordinary Income,” on the ground that the settlement was a “nontypical, noncustomary, infrequently recurring gain[].” 18 C.F.R. Pt. 201, Account 434 (1980); see WGL Exh. H, at 1-2. The Commission, however, assigned all proceeds that were allocable to the District of Columbia to the ratepayers, amortizing that amount over a three-year period.⁶⁷ Order 6051, at 49-52 & Appendix A, Sch. 2. WGL contends that the Commission’s action was unreasonable and unlawfully confiscatory since, in the Company’s view, the investors had borne the risks of the litigation. We disagree.

The precise issue presented here is apparently a novel one in this jurisdiction. Nevertheless, we are of the opinion that the governing law on review should be the same here as it was with respect to the gains realized on WGL's disposal of propane reserves, discussed in Part IX supra: the benefits of a particular utility endeavor should inure to those who have borne the risks and burdens associated with that undertaking. See Democratic Central Committee v. Washington Metropolitan Area Transit Commission, supra 158 U.S.App. D.C. at 27-32, 485 F.2d at 806-11. None of the parties disputes that this is the applicable legal principle; their disagreement stems from differing perceptions on the part of WGL, on the other hand, and People’s Counsel and the Commission, on the other, as to who actually bore the risks and burdens in the ARCO litigation.

We again find no basis on which to reverse the Commission’s decision. In analyzing the equities, it is instructive initially to note just what the settlement proceeds involved represent. Theoretically, the sum of $2.75 million represents the increased costs suffered by WGL as a result of ARCO’s failure to perform the contract. These costs, had the synthetic gas project achieved fruition, eventually would have been passed on to the ratepayers. The project originally was embarked upon for the benefit of the ratepayers. The ratepayers funded the design stages of the project and inevitably would have borne the burden of financing the least costly alternative to the ARCO contract in the event that WGL had not abandoned the project. It appears, then, that the ratepayers bore the primary burdens associated with the underlying synthetic gas project.

The Company makes much of the fact that it eliminated all expenses associated with the ARCO litigation from its cost of service in this proceeding. WGL’s witness Heim testified that the Company made a conscious decision “long before settlement negotiations were undertaken with ARCO” that the stockholders would bear all costs and risks in the lawsuit. Therefore, WGL urges, it was the stockholders who carried the burdens and risks of the litigation. The Commission found this argument unpersuasive, as do we. On cross-examination, Heim acknowledged that WGL routinely records legal judgments against the Company above the line. As for the litigation expenses (attorneys’ fees, etc.), the Commission expressed skepticism that the Company actually decided early in the litigation to exclude these fees from its costs of service.⁶⁸ Regardless of whether the Commission’s skepticism was warranted, we do not think that the issue of who paid the legal fees is a particularly relevant one in allocating the settlement proceeds in this case. Under the Commission’s decision, the settlement award is to be reduced by the amount of litigation expenses before it is allocated to the ratepayers; in other words, the shareholders will be reimbursed for these fees before the proceeds are moved above the line. Thus, there is no chance that the shareholders will have financed the ratepayers’ gain.

Two additional factors favor af-firmance of the Commission’s decision on this point. First, the decision is consistent with the Commission’s treatment of losses on another attempted but abandoned supplemental gas supply project. In Order No. 5522 in Formal Case No. 567, the Commission charged WGL’s ratepayers with the unrecovered costs of the Company’s abandoned Brandywine storage project. See Order 6051, at 51 n.l. The situation here is sufficiently analogous to support a similar above-the-line treatment of the settlement proceeds. Second, the Maryland Public Service Commission has found that ratepayers should receive the Maryland-allocable portion of the ARCO litigation proceeds. Washington Gas Light Co., Order No. 62783 (Md.P.S.C., Dec. 15,1977), at 10. The Maryland PSC reasoned that such treatment was consistent with the handling of the Company’s loss on the Brandywine project. We think that the District of Columbia Commission was justified in following the same approach in this case.

Therefore, the Commission’s ruling with respect to the ARCO litigation proceeds is affirmed.

XI. Application op the President’s 1978 Voluntary Wage and Price Guidelines

In December, 1978, the Council on Wage and Price Stability published voluntary wage and price guidelines implementing the President’s anti-inflation program. See 43 Fed.Reg. 60,772 (Dec. 28,1978) (codified in 6 C.F.R. Pt. 705). The Council specifically indicated that the guidelines should apply to rates charged by natural gas utilities, and it urged that federal and state regulatory commissions “assure compliance to the fullest extent possible.” 43 Fed.Reg. at 60,777-78.⁶⁹

In the proceedings below, the Commission reviewed its proposed rate schedule in light of the applicable guidelines, and determined that the new rates were in full compliance with the program’s price deceleration standard. Order 6051, at 101-04. The Company contends that it was error for the Commission to rely on the guidelines in setting the Company’s rates. The gravamen of its argument is that neither the guidelines nor even the Council’s congressionally-enacted organic statute can limit the Commission’s duty to set rates that will enable the Company to earn a fair rate of return. The Commission and People’s Counsel treat this question as a non-issue, however, because the guidelines ultimately had no effect on the rates adopted by the Commission.

We agree with the Commission and People’s Counsel that no ease or controversy is presented by the Commission’s merely having checked the new rates against the Administration’s wage and price standards. The Commission’s deference to the standards cannot be reviewed in a vacuum; we may consider only the overall reasonableness of the rates adopted by the Commission. See Federal Power Commission v. Hope Natural Gas Co., supra 320 U.S. at 602, 64 S.Ct. at 287. Thus, before we may assess the propriety of applying the guidelines in cases such as this one, we first must find, at a minimum, that the guidelines affected the level of rates established for the utility. Even then, it probably would be inappropriate for us to judge the validity of the guidelines as applied absent a further determination that the rates established by the Commission would deprive the utility’s shareholders of a fair return on their investment. In this case, the Commission simply observed that its proposed rates passed muster under the guidelines. The guidelines played no affirmative role in the Commission’s formulation of the rate schedule. WGL suffered no prejudice by virtue of the Commission’s reference to the guidelines; therefore, there is no genuine issue presented for review on this point.

Affirmed.

1 . The Office of People’s Counsel was established by Congress in 1975 to represent the interests of utility consumers in the District of Columbia. See D.C.Code 1981, § 43-106.

2 . The new rates went into effect on that date.

3 . Having discussed the principles governing our substantive review, and the case law establishing them, one is at a loss to comprehend the dissent’s accusation that our conclusion amounts to an “unsupported assertion.” Post at 1263. We are content to leave it to the reader to assess whose assertion is unsupported.

4 . Customer costs include the costs of, for example, maintenance of the regulator, service line, and meter, as well as the service costs of reading meters and billing customer accounts.

5 . Demand costs include the costs of the transmission and distribution systems, the storage facilities, and peak-shaving plants.

6 .Although in the immediate sense commodity costs do vary directly with the quantity of gas consumed, due to continuing increases in commodity replacement costs, those who currently consume larger quantities of gas cause higher future commodity costs for all gas consumers. Thus perceived, higher commodity costs can rationally be attributed to customers who consume larger quantities of gas. .

7 . The two-part rate structure further departed from traditional rate schedules in that separate rates were established for different varieties of customers, whereas previously rate schedules had varied by type of use. See In re Washington Gas- Light Co., supra at 279.

8 . In the present case, the Commission was perfectly entitled to rely on those findings and principles made in Case 647 which were not peculiar to that individual case, and it specifically found that the basic facts had not changed. Accordingly, we must take those principles into account on judicial review of Orders 6051 and 6060. This conclusion embodies the same policy as provides a major underpinning of the familiar doctrines of res judicata, collateral estoppel, and adherence to precedent. It would be pointless and wasteful to require the PSC to reinvent the wheel in this and every subsequent proceeding. To do so would turn an already protracted and complex process into an intractable morass, without any corresponding benefit. Therefore, the PSC may rely on principles established in one case, adapting them in light of subsequent experience, until it decides to abandon them.

9 . The residential customer class includes individually-metered apartment customers, but no group-metered apartment buildings. See note 10 infra.

The Cooperative Housing Association (CHA) argued to the Commission that because WGL’s fixed costs for mains, services, and regulators are lower for individually-metered apartment customers than for customers living in houses, customers living in individually-metered apartments should pay lower customer charges than customers in houses. Specifically, CHA sought a customer charge of $2.50 monthly for individually-metered apartments, in contrast to the previous rate of $3.75 per month.

The Commission agreed with the merits of the CHA argument but considered CHA’s request temporarily moot since charges for all residential customers were lowered. WGL was directed to study whether it would be appropriate to establish a separate sub-class for individually-metered apartment customers in the future. Order 6051, at 90-91.

10 . Group-metered apartments are included in the category of commercial and industrial customers. In Formal Case 647 the Commission rejected a Company proposal under which apartment houses would have been charged by unit. Under the Company proposal apartment units would have paid a $3.50 monthly charge each, whereas industrial buildings would have paid a unitary $25 per meter monthly charge. Thus the Company would reap $350 monthly from a 100-unit apartment building, and potentially as little as $25 from a 100-unit office building. The Commission found that no cost justification had been provided for treating office and apartment buildings so differently, and therefore rejected the Company proposal. In re Washington Gas Light Co., supra at 280-81.

In the instant case the Commission found that the Company had merely resurrected its earlier proposal, again without providing cost justifications for it. The Commission agreed with the Company that “certain components of customer costs would appear to increase with the size of the customer.” Order 6051, at 93. The Commission added, however, first, that the Company had ignored “the self-evident economies of scale which cause customer costs for any apartment building to increase less rapidly than the increase in the number of apartment dwelling units,” id, and second, that since customer charges for commercial and industrial customers like apartment houses would be computed on a per meter basis, and that since a large apartment house typically has more meters than a small one, customer charges would in fact be higher for large apartment houses than for small ones. Id at 95.

11 . Whereas “firm” customers purchase gas on a requirements basis, “interruptible” customers purchase gas in bulk. Interruptible customers characteristically have the capacity to use alternate fuels, and are thus in a position to take advantage of competitive market conditions. See Pa. Pub. Util. Comm’n v. Philadelphia Elec. Co., 33 P.U.R.4th 319, 360 (Pa.P.U.C.1980).

The Company’s primary obligation is to its firm customers; interruptible customers purchase only “excess” gas supplies. So the Company can use interruptible service as a gas supply management tool: by selling excess gas, the Company avoids the necessity of investing in additional excess storage capacity. See id.

12 . The appropriateness of a two-part rather than a single volumetric rate structure is not contested on appeal. Discussion of the rationale for imposition of a volumetric rate structure is nevertheless material to consideration of the overall reasonableness of the rate order. The Commission, although it refused in this case to adopt so unusual and extreme a solution as a single volumetric rate structure, agreed in principle with a number of the considerations that would support such a structure, and incorporated these to some extent in the rate design it finally ordered.

13 . Under the two-part rate structure fixed costs are recovered in large part through the commodity charge, though a portion of the Company’s fixed costs is recovered through the flat customer charge. The amount of fixed costs collected through the commodity charge necessarily varies directly with the level of fuel sales. To assure that the company will realize its revenue requirements, the Commission establishes the fixed cost component of the commodity charge in accordance with a projected level of fuel sales.

14 . Fuel sales are substantially weather sensitive. In order realistically to project fuel sales, the Commission does not predicate its estimate upon actual sales in a given test year, but rather adjusts test year revenues to reflect sales under assumed “normal weather conditions”. These “normal weather conditions” are determined by using average temperatures and temperature trends over a thirty-year period and making future projections therefrom.

Yearly temperatures are then calculated and stated in terms of “degree day deficiencies”: the extent to which daily mean temperatures fall below 65 degrees Fahrenheit. Order 6051, at 38 n.l. Prior to the instant case WGL fuel sales were calculated on the basis of 4,211 degree day deficiencies. In this case the Commission noted a warming trend in the area, and adopted the “normal weather year” proposed by WGL of 3,987 degree day deficiencies. Id. at 39-41. This modification inured to the benefit of the Company, since the Commission, having projected higher temperatures and lower fuel usage, considered the lower anticipated consumption in calculating the fixed cost component of the commodity charge. See id. at 83.

15 . The dissent is able to reach its conclusions only by ignoring or severely discounting several of these factors, on the theory that they either were not invoked by the Commission or were not considered important by it. However, the considerations discussed in our opinion were in fact invoked by the Commission in the orders under review. Those which apply with particular force to particular classes, or whose relevance had not already been adequately elaborated in earlier decisions were discussed in some detail. Those factors whose significance in justifying unequal class rates of return was already established in Case 647 (which included energy conservation, rising gas costs, and other factors) were explicitly invoked by reference to that case. Order 6051 at 89-90. See In re Washington Gas Light Co., supra at 278-84. The Commission is not required to rehash its reasons for adopting basic policies in every rate case, at the risk of having relied-upon factors of recurring importance disregarded or discounted by courts on review. See note 8 supra.

16 . See note 15 supra.

17 . As will become apparent in subsection c, infra, these considerations strongly undercut petitioners’ assertions that current inequality among alleged rates of return realized from various customer classes constitutes irrational discrimination or unconstitutionally confiscatory cross-subsidization.

18 . The dissent insists that this court must blind itself to the fact that rising replacement cost militates against a commodity charge limited to historic commodity cost, relying on the authority of Securities and Exchange Commission v. Chenery Corp., 318 U.S. 80, 87-88, 94, 63 S.Ct. 454, 459, 462, 87 L.Ed. 626 (1943). The very treatise cited in dissent observes that the “ideal” stated in Chenery does not constitute an enforceable rule, a fact that the dissent conveniently omits.

One might wish that not only agencies but also courts could and would live up to the Supreme Court’s statement of the ideal. No one will quarrel with the ideal. But as a practical rule for practical enforcement, the statement goes beyond what may be expected either from agencies or from courts. [2 K. Davis, Administrative Law Treatise § 16.12 (1958).]

The dissent ignores the fact that our discussion of replacement cost arises by way of exposing a fallacy in petitioner’s assumption that all the relevant cost-causation factors are subsumed in its analysis, which is based on historic cost. Chenery does not require a court to ignore a fallacy in a petitioner’s argument as to a proposition that he bears the burden of establishing, simply on the ground that it was not among those explicitly cited by the agency. In Chenery, the Supreme Court placed upon the agency the burden of showing that the fiduciary rule used to single out certain shareholders for lesser rights upon reorganization was authorized by the agency statute. It had to show that the rule was derived from the SEC’s mandate to separate “fair and equitable” terms from those “detrimental to ... the interest of investors,” and not “merely” by nonbinding common law principles.

In contrast, the rate design does not fall if the Commission fails to establish that replacement costs must be recovered in the commodity charge. Rate design orders are presumptively valid, and it is the petitioners’ burden to establish discrimination. See part I supra. The Company’s failure to account for replacement cost in its estimates undermines its case, whether or not the Commission explicitly refers to that fact.

Even if Chenery required us to consider only those objections to petitioners’ proof raised by the Commission, that criterion is satisfied here. The replacement cost consideration relates to the legality of recovering part of fixed costs in the commodity charge. That issue was addressed by the PSC in Case 647, see In re Washington Gas Light Co., 16 P.U.R.4th at 279-80, whose continuing validity on this issue was reaffirmed on Order 6051, see note 15 supra. In that case, the Commission explicitly cited the fact that the cost of replacement (new) gas is greater than the cost of old fuel as a reason for increasing the proportion of total costs recovered through the commodity charge, including part of fixed costs. The Commission legitimately invoked the authority of that decision and its supporting reasoning by reference in the present case. Id. Accordingly, we are not required to ignore replacement costs on appellate review.

The dissent further attempts to disqualify replacement cost as a legitimate factor by suggesting that it was not the Commission’s “real” reason for its action. Post at 1244. It does this by quoting from another part of Order 6051, which has nothing to do with the principle at hand. When quoted in context, the intended meaning is abundantly clear.

In designing rates for the residential non-heating/non-cooling sub-class, the commission faces a direct conflict between the principle of cost causation, on the one hand, and historic rate patterns and social considerations on the other hand.... We shall accordingly reduce the customer charge for this sub-class from $3.75 to $2.50 per month....

We take this action essentially for equitable reasons.... At least at this time, we feel compelled to provide some degree of relief for existing customers who are in no position to respond to more cost-based rates. Equally important is the Commission’s desire to lessen the extent to which the low-volume gas user pays a higher per unit price for service. [Order No. 6051, at 97 (emphasis added).]

The first two quoted sentences are omitted from the dissent. The “action [taken] essentially for equitable reasons” was the decision to reduce the customer charge for non-heating residential customers, without making a comparable reduction for some other classes. This decision has only a minor effect on the disparities in class rates of return estimated by the Company. It has no significant relevance to the replacement cost issue, which concerns the size of the commodity charge, not the relative sizes of the various customer charges. Thus, contrary to the impression given by the dissent, the language it quotes does not refer to the issue as to which replacement cost is relevant and as to which it is therefore involved by the PSC and this court. That issue is the decision to recover fixed costs through the commodity charge, which is applied equally to all classes.

19 . The PSC explicitly stated that this factor, along with the others dealt with in Case 647, justified disparate rates of return among all customer classes. Order 6051 at 89-90. See In re Washington Gas Light Co., 16 P.U.R.4th at 283 (value of service cited as supporting refusal to equalize class rates of return). The policy of preventing unit energy prices from departing too radically from the value of service to the customer was also explicitly raised in the present case with respect to the customer charge for the residential non-heating/non-cooling sub-class. Order 6051 at 97.

20 . The dissent would apparently impose on the Commission a burden of conducting costly comparative studies of the income of utility consumers, or of the effect of past promotional rates and advertising on them, before taking note of such equitable factors. See post at 1252. That is not its burden. The Commission is entitled to make reasonable inferences as to the effect of its orders on the various consumer classes. It is then for petitioners to make a convincing showing of unfairness or discrimination. , They are free to present whatever empirical studies they like in order to meet that burden.

21 . In Formal Case 647, the Commission commented upon the deceptiveness of the rate of return from interruptible customers:

Rate of return is a function of investment. In fact, under any formula, proportionately less rate base is allocated to interruptible customers than to any major category of firm customers. Thus, although interruptible customers consumed 5 per cent of the company’s test-year gas supply, they were allocated only 1.5 per cent of its fixed costs. As a result, the interruptible customers’ rate of return will always appear to be on the high side, and considered alone, will be meaningless. All this, of course illustrates the truth of our observation that “[a]n attempt to determine rate of return for a single class of service, rather than for the company’s entire utility service, is a fruitless undertaking.” [In re Washington Gas Light Co., 16 P.U. R.4th at 282 (quoting In re Washington Gas Light Co., 99 P.U.R.3d at 146).]

The Commission readopted this reasoning in the instant case. Order 6051, at 99-100.

22 . The Company allocated the cost of mains on a per-meter basis, failing to eliminate the unfairness that results from alloting the same share of costs to a single apartment as to an entire building containing numerous group-metered units.

The Company employs a “cost of capital” method to determine the rate of return. As discussed in notes 17-18 supra, the rate of return for a particular class of customers is calculated first by determining the cost of capital assets the use of which on a pro rata basis is fairly attributable to that class. The allocation of capital assets such as mains to customer classes is thus highly material to the determination of the rate of return realized or realized from the several classes, and a misallocation of capital assets is likely to distort the results.

23 . Commissioner Stratton in his dissent to the instant order relied upon the same methodology as had Mr. Smallwood. Commissioner Stratton anticipated that under the customer charges established in Orders 6051 and 6060 the rates of return would be as follows:

CLASS RATE OF RETURN

Firm Sales_

Residential heating 4.91 %

Residential non-heating (8.42%)

Commercial heating 15.13%

Commercial non-heating 26.11%

Watergate & Interruptible 58.05%

See Order 6060, Chart D.

24 .Recognizing that the WGL’s expert analysis in the record is inadequate, the dissenter goes on to perform his own. Post at 1248. However, this is a task confided, for very good reasons, to the Commission, as aided by the parties before it. Unlike courts, the PSC has an expert technical staff. Its analysis will be of help to the appellate court as well as the Commission itself. Perhaps more importantly, by introducing new calculations for the first time in an appellate opinion, the dissent effectively cuts off the right of the parties to respond to them and analyze the shortcomings they may have. Accordingly, we decline to engage in such an endeavor and confine our review to the rate analyses presented to the Commission below.

25 . If the PSC had accepted the utility analysis, that analysis would, however, be relevant to the narrower question of whether the Commission had applied it in an arbitrary or capricious manner.

26 . There are a few cost items that can be directly associated with a particular customer in the sense that, if the customer were not served by the system, the costs would not be incurred. These include, for example, the cost of the customer’s meter and of sending his monthly bill. Together they represent the marginal cost to the system of extending service to an additional customer in the service area. This is to be contrasted with the bulk of fixed costs, such as gas mains, for which there is no single “correct” or “objective” means of allocation.

27 . The dissent in its preoccupation with the concept of class rates of return as a basis for invalidating a rate design that it finds too favorable to residential consumers and not favorable enough to commercial and industrial customers, virtually equates disparate class rates of return (as defined by the utility itself) with “discriminatory rates.” See, e.g., post at 1242 & n.l. Of course the “discriminatory charges” rendered illegal by D.C.Code 1981, § 43-501 are the rates charged customers, not the rate of return on shareholders’ equity. Although shareholders have a due process right to an opportunity to earn a certain level of return on their investment, see part III infra, their earnings are unaffected by the manner in which the overall rate is attributed to particular classes of customers; there are no “residential non-heating shares”, only shares in the utility as a whole.

It appears that the dissent would rule that an adequate showing of discrimination is made out simply by a showing of disparate class rates of return, as defined by the utility itself. The burden would then shift to the Commission to rebut the claim by showing that the “discrimination” is justified. This has never been the law in this jurisdiction and we decline to adopt it now. The burden rests where it always has — on the party alleging illegal rate discrimination. See part I supra.

28 . We find the dissent’s attempt to distinguish such cases as Apartment House Council and Metropolitan Washington Board of Trade to be unpersuasive. Those and other cases indicate most clearly that non-cost factors are permissible and that it is the function of the Commission, not this court, to weigh them and exercise discretion to arrive at a reasonable accommodation.

29 . In view of the multiple reasons supporting the result reached by the Commission, the dissent’s preoccupation with a single factor (the concerns over replacement costs evidenced in Case 647, which was reaffirmed in this case) is puzzling. Even if replacement costs are ignored, there are more than adequate reasons specifically invoked in Orders 6051 & 6060 for permitting a therm charge in excess of historic gas cost. The fact that these factors, already the subject of discussion in other cases, could have been discussed at greater length is not an excuse to exclude them as bases for reviewing the present orders, as the dissent does. Neither is it significant that these factors are cited in the text of the Commission opinions, and are not the subject of separate formal findings.

30 . The Company’s authorized overall rate of return is determined by the “cost of capital” method. That method seeks to determine what return the Company must offer its investors in order to attract the capital investment in its stocks and bonds necessary to finance its construction and operations. Order 6051, at 16; see In re Potomac Elec. Power Co., 29 P.U. R.4th 517, 521 (D.C.P.S.C.1979). See also Sun City Water Co. v. Arizona Corp. Comm’n, 26 Ariz.App. 304, 309 -10, 547 P.2d 1104, 1109-10, vacated on other grounds, 113 Ariz. 464, 556 P.2d 1126 (1976) (en banc); City of Evansville v. Southern Ind. Gas & Elec. Co., 167 Ind.App. 472, 479 81, 339 N.E.2d 562, 569-70 (1975); In re Southwestern Bell Tel. Co., 10 P.U.R.4th 323, 328 29 (Ark.P.S.C.1975); In re Southern Conn. Gas Co., 24 P.U.R.4th 162, 194 (Conn.Pub.Util. Control Auth. 1978).

The rate of return is an expression, in terms of percentage of rate base, of: “... the amount of money a utility earns, over and above operating expenses, depreciation expense, and taxes, expressed as a percentage of the legally established net valuation of utility property, the rate base. Included in the ‘return’ are interest on ... debt, dividends on preferred stock, and earnings on common stock equity. In other words, the return is that money earned from operations which is available for distribution among the various classes of contributors of money capital .... ” [In re Potomac Elec. Power Co., 29 P.U.R.4th at 521-22 (quoting P. Garfield & W. Lovejoy, Public Utility Economics 116 (1964)).]

It is assumed that the cost of capital, when competently computed, is essentially and practically the equivalent of a fair rate of return. See New England Tel. & Tel. Co. v. Public Utils. Comm'n, supra at 32.

The overall cost of a utility’s capital is calculated by determining the cost of each component in the company’s capital structure. A weighted cost for each component is derived by multiplying its cost by its ratio to total capital. The sum of these weighted costs then becomes the utility’s overall rate of return, which is multiplied by the company’s rate base to determine the company’s revenue requirement. See id.

In this case, the Commission found WGL’s capital structure (as of December 31, 1977) and capital costs to be as follows:

Type of Proportion Cost Weighted Capital_of Capital_Rate Cost

Debt 48.391 7.04% 3.40%

Preferred Customer 12.5 6.59 .82

Deposits 0.9 6.0 .05

Equity 38.3 13.0 4.98

Overall 100.0 9.25

Order 6051, at 25.

31 . Under the Commission’s “cost of capital” method of establishing an overall rate of return, each component of the Company’s capital structure is independently significant, and the overall return is a direct function of the weighted costs of each type of utility capital. See note 30 supra. Furthermore, some types of capital are riskier than others: for example, equity is generally considered a more risky investment than debt capital. Thus the overall rate of return cannot, theoretically, be assessed in isolation. Nor, for the same reasons, is WGL’s authorized overall return subject to meaningful comparison with the returns earned by other gas distributors in the absence of an in-depth analysis of those utilities’ capital structures.

The record in this case does not contain sufficient data for us to perform this type of complex inquiry, nor do we think such an endeavor would be as meaningful as a review of the Commission’s treatment of each of the two primary components of WGL’s capital structure: common equity and long-term debt. We note that all interested parties — WGL, People’s Counsel, and the Commission — focus their rate of return arguments on these two individual components rather than on the overall 9.25% allowance.

32 . Although the “growth” component of the DCF analysis is intended to represent the “expected future growth in the value of the equity investor’s investment,” New England Tel. & Tel. Co. v. Public Utils. Comm’n, supra at 36, there is a lack of unanimity as to the best indicator of expected growth. Factors which are widely considered relevant in predicting growth (and which were relied upon in various combinations by the three witnesses on rate of return in this case) include the historical growth patterns of dividends, book value, and retained earnings of representative utilities. See, e.g., WGL Exh. C, at 20-21; Staff Exh. 14, at 27; PC Exh. B, at 11-12.

33 . From 1974 to 1976, WGL’s common stock sold on the open market at an average discount of more than 40% below book value. This figure was well below the average market-to-book ratio for comparable gas distributors during the same period. See Staff Exh. 14, Sch. 11; WGL Exh. 3, Sch. 16.

34 . Glassman’s estimate of 7.5% was based upon studies of selling costs and market price movements in recent years. Selling costs for new issues by gas companies ranged from 3% to 7% in 1976 and 1977. During the same two years, there were both positive and negative market pressures in the gas industry. Staff Exh. 14, at 40 — 41 & Sch. 12. “Market pressure” is the impact of a new stock issuance on the price of the stock. It is measured by projecting the difference between the offering price of the new issue, and the price that would have prevailed in the absence of the new offering, after allowing for upward or downward movements of the market as a whole during the period between announcement of the new issue and the pricing date. See PC Exh. B. at 30, 33; Staff Exh. 14, at 40. For example, an increase in the supply of a particular class of stock may have the effect of depressing the market price per share. Glassman testified that in the gas industry in 1976-1977, positive market pressures averaged 2.7%, while negative market pressures averaged 3.7%. Id at 41 & Sch. 12.

35 . Rate Earned on Average Book Equity of Comparable Gas Distributors

1967 12.99%

1968 12.96

1969 12.56

1970 12.27

1971 13.08

1972 12.38

1973 13.03

1974 11.52

1975 12.77

1976 11.45

[Staff Exh. 14, Schs. 8 & 11.]

36 . Commissioner Stratton set forth data showing the following authorized rates:

Date of Equity

Company Order Return

Alabama Gas 12/28/76 12.8 %

Atlanta Gas Light 12/9/76 13.25%

Brooklyn Union Gas 11/28/78 13.75%

Indiana Gas 11/23/77 15.9 %*

Laclede Gas 7/1/77 13.4 %

Michigan Gas 1/4/78 13.5 %

Minnesota Gas 10/2/78 12.47%

N.J. Natural Gas 12/8/77 13.5 %

Company Date of Equity' Order Return

Northwest National 1/5/79 13.4 %

Piedmont 8/7/78 13.06%

Southwest Gas 8/8/77 14.2 %

Order 6060, at 48-dissenting). & n.39 (Stratton, C.,

* The equity return figure for Indiana Gas is an estimate based on a fair value rate base, while the other equity return figures were calculated according to an original cost rate base.

37 . Since we find the 13% allowed return on equity to be lawful on its face, we need not discuss whether the Commission was justified in declining to factor into its determination an adjustment for market pressure and flotation costs. Any infirmities in the method employed by the Commission are immaterial as long as the net result or overall effect of the Commission’s order is reasonable. Federal Power Comm’n v. Hope Natural Gas Co., supra 320 U.S. at 602, 64 S.Ct. at 287; People’s Counsel v. Public Serv. Comm’n, supra at 46. We note at any rate that the Commission took alternative steps to adjust upward the bare cost of equity, and WGL does not specifically contest the Commission’s findings in this respect.

38 . In Washington Pub. Interest Org. v. Public Serv. Comm’n, supra at 82, we outlined the basic principles of public utility accounting:

A regulated company’s balance sheet segregates the “utility plant” assets (including land), which are “used and useful” in serving the public, from the company’s other assets — called “nonutility property” — which are carried on the books, most commonly, as investments. [J. Suelflow, Public Utility Accounting: Theory and Application 25-31 (1973).] Similarly, the company’s income statement carefully separates “utility operating income” and related expenses from its “other income” arising out of activities beyond the Commission’s jurisdiction. Id. at 20-25. Gains and losses on “utility” operations generally are allocated “above the line” to the ratepayers, whereas “nonutility” gains and losses are allocated “below the line” to the investors. Id. at 23-24. In a sense, therefore, each public utility is at least two companies: one serving and accountable to the public (through the good offices of the Commission) and the other accountable solely to its investors.

These allocations either to ratepayers or to investors are implemented on the company’s books through use of accounts established under the Uniform System [of Accounts] to reflect transactions with specified consequences above or below the line. Fundamentally, therefore, a utility’s accounting system is designed to channel entries into accounting categories intended to have a prescribed impact on periodic ratemaking. Id. at 24. [Footnote omitted.]

39 . In numerical terms, the effect of the PSC’s decision is to reduce the cost of long-term debt in the test year by $275,000, to a cost rate of 7.04%. Long-term debt represents 48.3% of WGL’s total test-year capital. Order 6051, at 25 & n.l. For a description of how the various components of capital structure figure in the determination of the authorized rate of return, see notes 30 & 31 supra.

40 . Some state commissions amortize the gains realized from these acquisitions over the remaining lives of the retired bonds, as did the FPC in Manufacturers Light & Heat Co., supra, and the PSC in the case before us. See, e.g., In re Southern Cal. Gas Co., 27 P.U.R.4th 63, 73 (Cal.P.U.C.1978); In re Montana-Dakota Util’s Co., 21 P.U.R.4th 1, 24 (S.D.P.U.C.1977); In re Sierra Pac. Power Co., 15 P.U.R.4th 560 (Nev.P. S.C.1976) (abstract). Other states, however, utilize different methods for computing the amount by which the cost of debt will be offset by these gains. Rather than amortizing the gains over the remaining lives of the debentures, some state agencies, for example, reduce the cost of debt in the test year by the average gain over the preceding five-year period. See In re Consumers Power Co., 3 P.U.R.4th 321, 331-32 (Mich.P.S.C.1974). Others simply use actual or estimated test year gains to reduce the cost of debt in that test year. See, e.g., In re Elizabethtown Gas Co., 3 P.U.R.4th 182, 190-91 (N.J.Bd.Pub.Util.Comm’rs 1973); In re National Fuel Gas Distrib. Corp., 17 P.U.R.4th 138, 154 (N.Y.P.S.C.1976). While all of these methods are designed to pass on to consumers the benefits of the gains on reacquired debt, the latter approach has been criticized because it “would permit the timing of reacquisitions to occur prior to the test year thereby benefiting the shareholders while burdening the ratepayer with the refinancing cost.” In re Kansas-Neb. Natural Gas Co., supra at 1708, 9 P.U.R.4th at 497.

41 . It should be noted that the same rising interest market which allows the Company to repurchase debt at a discount also makes the new financing more costly.

42 . “Attrition” is the tendency of a utility’s rate of return to diminish over time as a result of high construction costs, an expanding rate base, and increasing operating costs. Factors exacerbating attrition are inflation and regulatory lag: construction and operating expenses rise while the utility’s tariffs remain fixed. See Potomac Elec. Power Co. v. Public Serv. Comm’n, supra at 23; Telephone Users Ass’n v. Public Serv. Comm’n, D.C.App., 304 A.2d 293, 298 (1973), cert. denied, 415 U.S. 933-34, 94 S.Ct. 1448, 1449, 39 L.Ed.2d 492 (1974).

43 . We note that the Commission has since begun rulemaking proceedings to address the problem of attrition. See 27 D.C.Reg. 2,794 (June 27, 1980); Zinder Companies, Inc., Policy Options for the Ratemaking Treatment of Attrition (report and recommendations prepared for the Public Service Commission). Though the Commission has issued its final Rules of Practice and Procedure, (which were first proposed together with the Zinder report), see 28 D.C. Reg. 2,984 (July 3, 1981), as amended id. at 3,343 (July 24, 1981), the Commission has not yet taken any final action on the attrition issue.

44 . In prepared testimony, Mr. Maher testified that if the new rates had been in effect during 1978, WGL’s District of Columbia operations would have produced a return on average rate base of 8.61% and a return on equity of 11.38%. (This is compared with the authorized returns of 9.25% and 13%, respectively; the comparability of the returns on rate base is dubious, however, since the Company used an average, rather than year-end, rate base to arrive at the 8.61% figure.) He also testified that at the “going level” of expenses as of March 16, 1979, the Company’s returns under the new rates would be 6.73% on rate base and 6.42% on equity. Finally, Maher projected the Company’s pro forma returns for calendar year 1978 at 5.86% on rate base and 4.15% on equity.

45 . Another possible factor weighing against a separate attrition allowance was suggested by the Virginia State Corporation Commission, which postulated that when attrition is found to exist, capital markets will reflect the expectation of the erosion of earnings in the cost of equity capital, (which in turn will be reflected in the utility’s authorized rate of return). It stated:

A threshold question in evaluating the concept of attrition, as proposed, is whether the so-called attrition phenomenon is already taken into account in determining the cost of capital.... If the cost of capital already includes an implicit attrition allowance by way of a risk premium, no further allowance or adjustment is needed. [In re Chesapeake & Potomac Tel. Co., supra at 364.]

46 . [W]hen setting new gas rates, the Commission accounts for income taxes in two ways. The test year cost of service includes an allowance for income taxes paid on test year taxable income. From this cost of service, the Commission determines any deficiency in the revenues generated from the existing rates, when compared to the revenues needed to permit the Company to earn the allowed rate of return. The second tax component relates to this revenue deficiency. When the Commission increases rates to eliminate the revenue deficiency, the increase granted includes an additional allowance so that the Company can pay the taxes on the increased revenues and still net the amount needed to remove the revenue deficiency. This is the so-called “tax multiplier.” [Order 6060, at 9.]

47 . The test year ended on June 30, 1977. Thus, People’s Counsel and GSA would have the Commission utilize a tax rate which did not become effective until 18 months after the end of the test period.

48 . The Company’s witness, Unkle, acknowledged that the disputed advertising expenses had been recorded in Account 930.1 of the Uniform System of Accounts, and that Note A to Account 930.1 limits expenses in that account to image-building advertising costs. See 18 C.F.R. Pt. 201, Account 930.1 (1980).

49 . There was no evidence of record to this effect. Sack’s statement, however, was unchallenged. We note that in In re Washington Gas Light Co., Formal Case No. 687, Order No. 5998 (May 16, 1978), the Commission authorized WGL to expand its annual firm service to a maximum of 3,000 new customers. Id at 17.

50 .For a general discussion of public utility accounting practices, see note 38 supra.

51 . Although there was no evidence of record respecting the Company’s past practice, the Company’s allegation that it had previously charged advertising costs above the line to the ratepayers was undisputed.

52 . We note too that the Company denied only in part the allegations of People’s Counsel that the advertising was image-building in nature. The Company’s witness, Unkle, asserted that “over half” of the expenses in question had been applied to informational advertising, and failed even to address the allocation of the remainder of the expenses.

53 . Petitioner’s treatment of the disputed expenses under the Uniform System of Accounts was not dispositive of the purpose of these expenditures. “[T]he existence of any particular accounting system does not automatically dictate the treatment of expense items for rate-making purposes.” Providence Gas Co. v. Burman, 376 A.2d 687, 699 (R.I.1977). See also Washington Pub. Interest Org. v. Public Serv. Comm’n, supra at 85; New Eng. Tel. & Tel. Co. v. Public Utils. Comm’n, supra at 23. However, “a utility’s accounting system is designed to channel entries into accounting categories intended to have a prescribed impact on periodic ratemaking.” Washington Pub. Interest Org. v. Public Serv. Comm’n, supra at 82. “[The Uniform System of Accounting,] which is designed to assist in ratemaking, reflects years of fine tuning premised on expert views about balancing investor and consumer interests.” Id. at 85. Although petitioner’s accounting treatment of the disputed expenses did not automatically dictate their treatment for ratemak-ing purposes, it was circumstantial evidence upon which the Commission might reasonably rely unless the Company effectively refuted it.

54 . In West Ohio Gas Co. v. Public Utils. Comm’n'(No. 1), supra 294 U.S. at 72, 55 S.Ct. at 321, the Supreme Court stated,

We take judicial notice of the fact that gas is in competition with other forms of fuel .... A business never stands still. It either grows' or decays. Within the limits of reason, advertising or development expenses to foster normal growth are legitimate charges upon income for rate purposes as for others.

The impact of competition, and thus the relevance of West Ohio Gas to this case, was much diminished by the limitation on WGL’s authorization to expand. See note 49 supra.

55 . Some courts, like the dissent in this case, have concluded that West Ohio Gas Co. v. Public Utils. Comm’n (No. 1), supra, makes a utility’s judgment that an advertising or public relations expenditure is chargeable to the ratepayers conclusive, or at least shifts the burden of proof to the regulatory body. Alabama Power Co. v. Alabama Pub. Serv. Comm’n, 359 So.2d 776, 780 (Ala. 1978); New Eng. Tel. & Tel. Co. v. Department of Pub. Utils., 360 Mass. 443, 482 84, 275 N.E.2d 493, 517-18 (1971); Central Me. Power Co. v. Public Utils. Comm’n, 153 Me. 228, 243-46, 136 A.2d 726, 736-37 (1957). We think that such a reading is far too broad. In that case, the advertising was for what was in 1935 a concededly appropriate purpose — increasing the consumption of gas. Furthermore, due to declining marginal costs, this purpose was deemed to be of particular benefit to ratepayers. Id. The only objection to the advertising item was that it was excessive in amount or wastefully spent. The Commission had made an arbitrary reduction of the allowance, without supporting evidence for its allegations of waste. Perhaps the presumption of validity accorded in that case is adequately supported on the ground that utility managers have no incentive to make ineffective or otherwise wasteful expenditures. However, that reasoning is simply inapplicable where, as here, a utility is charged with making advertising expenditures for illegitimate purposes, or for valid purposes that accrue to the benefit of shareholders rather than ratepayers. Apart from the oversight imposed through the PSC, utility management is accountable to shareholders, not ratepayers. If allowed to do so, management may succumb to the temptation of undertaking public relations projects for the benefit of the former, while charging their cost to the latter. Thus there is no justification for extending West Ohio Gas to cover the situation where an advertising expenditure is alleged to be in a non-allowable category and not merely excessive, as the dissent would have us do. Accordingly, the burden of proof remains in its customary place — on the utility.

The modern trend is in accord with this view. See Note, Public Utilities: The Allowance of Advertising Expenses for Rate-Making Purposes — Is This Trip Really Necessary?, 29 Okla. L.Rev. 202, 213 (1976), and decisions cited therein. Courts have balanced against the West Ohio Gas presumption of utility managers’ good faith the need for protection of the consuming public by regulation against public utilities’ functioning as natural monopolies. E.g., State ex rel. Laclede Gas Co. v. Public Serv. Comm’n, supra at 226. That court stated:

By adoption of ... a rule [permitting the Public Service Commission to disallow institutional advertising expenditures from operating expenses for ratemaking purposes unless the utility demonstrates that such expenditures benefit ratepayers], the managerial prerogatives of Laclede are maintained, and the right of Laclede to continue to exercise its right of free speech is preserved, while at the same time the P.S.C. can perform its regulatory role of balancing the integrity of regulated utilities against the protection of the ratepayer. [Id. at 228-29.]

Accord, State v. Oklahoma Gas and Electric Co., supra at 894. This, we think, is clearly the better rule.

56 . We note that there is nothing in the Commission Order on the issue, which was based on the Company’s failure to meet its burden of proof, that would prevent the Company from attempting to show that these expenses should be borne by the ratepayers in a future rate proceeding.

57 . The dissent’s theory that a utility should be allowed to charge trade association fees to ratepayers because unregulated businesses pass on those costs to consumers, post at 1260, is based on a faulty premise. Since trade association dues are not a cost of providing the service (i.e., a company could provide the service without being a member of the association) one would not expect them to be passed on to consumers in a competitive market. Rather, the dues would be in the nature of reinvested profits. A company choosing to join and pay dues would thus forego a small part of present profits in the hope of reaping future benefits, such as favorable legislation which an association promotes by lobbying and public relations. Thus the dissent’s invocation of a market analysis cuts against its conclusion.

58 . See note 56, supra. The Commission Order made explicit reference to reevaluating this issue at a later time. [Order 6051, at 73-74.]

The Company also challenges the analogy drawn by the Commission between charitable discounts and the speakers program, arguing that, whereas a charitable discount helps the recipient organization achieve its goals, which may or may not be shared by utility ratepayers, the Company speakers program, by providing consumer information, fosters Company goals and the overall goals of the community. Under the speakers program, the Company sends out speakers to schools and community organizations at the request of those groups. Were above-the-line treatment allowed for the speakers program, individual ratepayers would, as in the case of charitable discounts charged above the line, be compelled without choice to subsidize a program the benefits of which they would not necessarily experience. Utility commissions commonly consider such expenditures more properly charged to company shareholders than to their ratepayers. See Part V(D) infra.

59 . WGL’s witness, Unkle, explained the nature of these payments:

Business support payments represent amounts paid to various civic and business groups which are concerned with preserving and improving the Washington community. Of the $35,000 of such payments included in the test year, $12,600 was paid to the Washington Board of Trade, $6,480 to the National Capital Downtown Committee and $5,000 to the District of Columbia Municipal Research Bureau, Inc. [WGL Exh. L, at 6.]

60 . Tax normalization can be viewed as an interest-free loan from the ratepayers because, under such a scheme, the tax benefits of the deductions claimed by the Company during the test year are not directly flowed through to the ratepayers in the same year. In the absence of normalization, tax deductions claimed during the test year serve to lower the utility’s cost of service (since income taxes are part of the cost of service), thus reducing the overall rates to consumers (since cost of service is chargeable to ratepayers). When construction overheads are normalized, however, they effectively are treated as capital expenditures for ratemaking purposes. The ratepayers receive tax benefits from these overheads only as they are depreciated over the useful life of the related plant, even though the utility has claimed the full benefit of the overheads on its test-year tax return. See generally Federal Power Comm’n v. Memphis Light, Gas & Water Div., 411 U.S. 458, 459-60, 93 S.Ct. 1723, 1725, 36 L.Ed.2d 426 (1973); Public Systems v. Federal Energy Reg. Comm’n, 196 U.S.App.D.C. 66, 68-69, 606 F.2d 973, 975-76 (1979); Alabama-Tenn. Nat. Gas Co. v. Federal Power Comm’n, 359 F.2d 318, 326-28 (5th Cir.), cert. denied, 385 U.S. 847, 87 S.Ct. 69, 17 L.Ed.2d 78 (1966).

61 . Although the Court in United was interpreting the Federal Power Act, the principles that were involved there (i.e., whether the FPC had impermissibly intermingled the profits and losses of nonjurisdictional utilities with those of the regulated utility, and whether the resultant rates were “just and reasonable”) are relevant to our review under the District’s statutes.

62 . But see Florida Gas Transmission Co., 47 F.P.C. 341, 93 P.U.R.3d 477 (1972), modified, 49 F.P.C. 261, 98 P.U.R.3d 221 (1973), aff’d mem. sub nom. Sun Oil Co. v. Federal Power Comm’n, 505 F.2d 476 (D.C.Cir.1974). In that case the Federal Power Commission reverted to determining regulated utilities’ costs of service on the basis of individual tax liability, even where it is “hypothetical,” rather than by accounting for consolidated tax savings. The Commission stated:

At the present time, we seek to avoid a determination that will tend to defeat efforts to acquire additional gas supplies or constitute a disincentive to exploration and development. Since 1968, all major industry data indicate that gas is being consumed at a greater rate than it is being discovered, and a number of pipelines have had to file plans for curtailment of service to their customers under our Order No. 431, 45 FPC 570. Therefore, if a case were before us where an affiliated, regulated or nonregulated, producer of oil or gas showed a tax loss, and this loss company were joined in a consolidated return with a pipeline, the United or Cities Service case, in our opinion, would no longer be persuasive authority, for to reduce the rates of a regulated pipeline because of such affiliated exploration and development activities would be discouraging to the very enterprise we now want to encourage. [Supra at 362, 93 P.U.R.3d at 495.1

63 . For a discussion of the Uniform System’s allocation scheme, see Washington Pub. Interest Org. v. Public Serv. Comm’n, supra at 82-85; note 38 supra.

64 . The Company recorded the gain realized upon the sale of the propane in Account 495.3, “Other Gas Revenues,” a below-the-line account. See PC Exh. C, at 13.

65 . Treatment of gains and losses on the sale of utility property has been inconsistent in the District as well as at the federal level. In 1973, the Federal Power Commission (now Federal Energy Regulatory Commission), relying upon Board of Pub. Util. Comm’rs v. New York Tel. Co., 271 U.S. 23, 46 S.Ct. 363, 70 L.Ed. 808 (1925), promulgated an amendment to the Uniform System of Accounts, which provided that such gains and losses should be allocated to shareholders. See Accounting Treatment to Account for Gains and Losses on the Disposition of Utility Property That Had Been Classified in Utility Service and Consolidation of Certain Depreciation Accounts, Order No. 473, 49 F.P.C. 390, 38 Fed.Reg. 4,947 (1973) [hereinafter cited as Order No. 473], The same year, however, the District of Columbia Circuit decided Democratic Central Comm. v. Washington Metro. Area Transit Comm’n, supra, in which the court found “no impediment, constitutional or otherwise, to recognition of a rate-making principle enabling ratepayers to benefit from appreciations in value of utility properties accruing while in service.” Id., 158 U.S.App. D.C. at 21, 485 F.2d at 800. The Federal Energy Regulatory Commission, apparently satisfied that the circuit court’s decision had adequately refuted any impediment posed by New York Telephone, then reversed directions and provided that ratepayers should be benefitted by a gain on the sale of an excess pipeline system. See Re El Paso Natural Gas Co., 23 P.U.R.4th 66, 92 (F.E.R.C.1977). In so ruling, the FERC relied upon Democratic Central Committee and ignored the FPC’s 1973 accounting order. Meanwhile, however, the District of Columbia PSC, in WGL’s most recent rate proceeding prior to this one, had characterized the holding in Democratic Central Committee as “peculiar to the utility there involved,” and instead had relied upon the 1973 FPC order [Order No. 473, supra] in assigning to shareholders gains from the sale of certain WGL real estate in Georgetown. See In re Washington Gas Light Co., 16 P.U.R.4th at 286, remanded sub nom. Washington Pub. Interest Org. v. Public Serv. Comm’n, supra. Thus, in WGL’s 1976 rate proceeding, the PSC relied upon an accounting rule that the FERC was soon to repudiate. In the case before us, the PSC now follows the same Democratic Central Committee ruling that it had apparently shunned in 1976.

66 . Naphtha is a petroleum derivative.

67 . The Commission implemented its ruling by reducing WGL’s operating expenses by $86,-299. This figure represented a reduction of the original $2.75 million settlement by taxes and expenses to $1,079,316, of which $258,898 was allocated to the District, with the three-year amortization yielding the final $86,299 expense adjustment. Order 6051, Appendix A, Sch. 2.

68 . The Commission evidently theorized that it would be very easy and tempting for a utility to make a pro forma adjustment to eliminate legal fees from its test-year operating expenses once the utility had a sizeable settlement safely in hand. Its skepticism was supported by the fact that WGL, in its 1976 rate proceeding (Formal Case No. 647), had not excluded litigation costs connected with the ARCO case from its cost of service. In justification of WGL’s practice in Formal Case 647, the Company’s witness Unkle testified that no adjustment had been made at that time because the expenses for that test year were so small that their elimination would have had ncfeffect on rates. WGL Exh. H, at 2-4. He also testified that the Company did exclude ARCO-related legal fees from its operating expenses in Maryland and Virginia rate proceedings in 1976.

69 . The Council recently amended its guidelines to delineate specific standards for electric, gas, and water utilities. See 6 C.F.R. § 705.45 (1980).