The State of Texas, separately from the Commission, intervened in this case and is 1

represented by the consumer protection and public health division of the Office of the Attorney

General. Hon. Elizabeth Ames Jones is successor in office to Hon. Charles R. Matthews, originally

a party to this suit in his official capacity as a commissioner of the railroad commission. We have

substituted Jones for Matthews as a party to this suit. See Tex. R. App. P. 7.2(a). 

TEXAS COURT OF APPEALS, THIRD DISTRICT, AT AUSTIN

444444444444444444444444444

ON MOTION FOR REHEARING

444444444444444444444444444

NO. 03-04-00731-CV

CenterPoint Energy Entex, Appellant 

v.

Railroad Commission of Texas, Victor Carrillo, Elizabeth A. Jones,

Michael Williams, City of Tyler and State of Texas, Appellees 1

FROM THE DISTRICT COURT OF TRAVIS COUNTY, 353RD JUDICIAL DISTRICT

NO. GN402169, HONORABLE DARLENE BYRNE, JUDGE PRESIDING

O P I N I O N

We withdraw our opinion and judgment issued on February 24, 2006, and substitute

this one in its place. We overrule the motions for rehearing filed by CenterPoint Energy Entex and

by the City of Tyler.

This appeal presents a question of first impression: whether the Texas Railroad

Commission (the Commission) may conduct a retroactive prudence review of charges flowed
We refer to this entity as Entex, as it was known during the relevant eventsfrom which this 2

appeal arose. 

Cities have exclusive original jurisdiction over natural gas rates in areas within the 3

municipality while the Commission has the same over rates in areas outside of municipalities. See

Tex. Util. Code Ann. §§ 102.001(a)(1)(A) & 103.001 (West Supp. 2005). A municipality can

surrender its authority to the Commission. Id. §§ 102.001(a)(1)(B), 103.001, 103.003. 

We have reproduced an example of one of the City-approved rate schedules at Appendix

A.

2

through a purchased gas adjustment clause (PGA clause) and order refunds of charges that the

Commission finds the utility imprudently incurred. We must also consider whether such a review

is a “ratemaking proceeding” in which a participating municipality is entitled to expense

reimbursement. See Tex. Util. Code Ann. § 103.022 (West 1998). The Commission and the district

court answered both questions in the affirmative. Because we find that the Commission has

authority to conduct the review and order refunds but that such a review is not a “ratemaking

proceeding,” we affirm the order of the district court in part but reverse and render in part. 

BACKGROUND

Appellant CenterPoint Energy Entex is a gas utility subject to the Gas Utility 2

Regulatory Act. See Tex. Util. Code Ann. § 101.003(7) (West Supp. 2005); see generally id.

§§ 101.001-105.051 (West 1998 & Supp. 2005) (GURA). For more than twenty-five years, Entex

purchased gas on behalf of customers served by the Tyler Integrated Distribution System (TIDS) and

charged customers under tariffs approved by the City of Tyler (the City), termed “rate schedules.”3

Since 1985, each of Entex’s approved rate schedules included a “Purchased Gas Adjustment

Provision” (PGA clause), an automatic escalator mechanism devised by utility regulators to deal with

rapid fluctuations in the cost of natural gas. See Railroad Comm’n of Tex. v. High Plains Natural
 We will discuss the nature of PGA clauses in more detail when we consider Entex’s 4

appellate issues.

3

Gas Co., 613 S.W.2d 46, 48 (Tex. Civ. App.—Austin 1981), writ ref’d n.r.e., 628 S.W.2d 753 (Tex.

1981) (per curiam). Such a clause operates to increase or decrease the revenue of the gas company

by exactly the amount of its increased or decreased costs of gas charged the gas company by its

suppliers. Id. (citing City of Norfolk v. Virginia Elec. & Power Co., 90 S.E.2d 140 (Va. 1955)).

Although Texas has never expressly addressed the use of PGA clauses in a statute, our courts have

long approved of their use by regulators. See San Antonio Indep. Sch. Dist. v. City of San Antonio,

550 S.W.2d 262, 266-67 & n.2 (Tex. 1976); High Plains Natural Gas Co., 613 S.W.2d at 48 (citing

City of Chicago v. Illinois Commerce Comm’n, 150 N.E.2d 776 (Ill. 1958)); Railroad Comm’n of

Tex. v. City of Fort Worth, 576 S.W.2d 899, 902 (Tex. Civ. App.—Austin 1979, writ ref’d n.r.e.);

see also Tex. Util. Code Ann. §§ 101.001-105.051 (no express recognition of PGAs).4

Since at least November 1992, Entex notified the City on a monthly basis regarding

any gas cost changes that it would flow to its customers through the PGA clause. In some months,

Entex reported no changes. In others, it informed the City of a change, either an increase or a

decrease, and generally provided supporting information in the form of two Entex-generated

documents stating the cost of gas purchased from several gas distributors and the effect those costs

would have on the amounts charged to customers. 

In 2002, the City began reviewing Entex’s past customer gas charges, after which it

informed Entex of “concerns” it had about the manner by which Entex purchased gas for resale to

its customers. In particular, Entex had been acquiring its gas through two gas contracts, one with

Texas GasMark, Inc. (TGM contract) and one with TXO Gas Marketing Corporation (TXO
 On January 8, 2003, the City, by ordinance, surrendered to the Commission its claimed 5

jurisdiction over the matter. See Tex. Util. Code Ann. § 103.003 (West Supp. 2005). 

4

contract). Both of the gas supplies purchased under each contract were “firm” (as opposed to

interruptible), but the TGM contract price was significantly lower than the TXO contract price. It

was alleged that Entex acted wrongfully by charging the higher priced gas to residential and small

commercial customers while reserving the lower-priced gas for large commercial customers. The

City believed that this procedure resulted in “overcharges” of about $39,000,000 to residential and

small commercial customers because Entex had passed the higher-priced gas charges to those

customers through the PGA clauses in Entex’s filed rates. The City made further charges alleging

that Entex had filed misleading tariffs, failed to request annual price redeterminations, and failed to

charge non-Tyler customers for their proportionate share of Entex’s capital costs. The City set the

matter for consideration at a city council meeting. 

Entex filed suit in Travis County district court seeking a declaration that the City

lacked authority to order refunds and an injunction to prevent consideration of the issue at the city

council meeting. Entex asserted that ordering refunds for gas distribution was within the exclusive

jurisdiction of the Commission. See Tex. Util. Code Ann. § 104.005(c) (West 1998). Entex and the

City agreed that Entex would dismiss its district court proceedings and that the parties would instead

submit the issues directly to the Commission. In their “Joint Petition for Review of Charges for Gas

Sales,” the parties requested that 5

the Commission initiate a proceeding to determine whether Entex has properly and

lawfully charged and collected for gas sales to residential and commercial customers

served from the TIDS during the period from November 1, 1992 to October 31, 2002,
 The Commission’s hearing examiners characterized the parties’ positions thus: “Generally, 6

the City of Tyler, on the one hand, argues that the proceeding includes a ‘prudence review’ of past

purchases. On the other hand, Entex argues that the Commission lacks the authority to conduct a

retroactive prudence review and that this case is limited to an audit of its gas costs flow through.”

(Footnotes omitted.). 

5

to consider any appropriate remedies, including but not limited to, refunds, with

interest, and to enter such orders as may be appropriate.

But the parties disputed what the Commission’s review should entail. Entex urged

that the Commission had power only to determine whether Entex “properly and lawfully charged and

collected for gas sales to residential and commercial customers in Tyler as authorized under its tariffs

and rate schedules” but that the Commission could not consider the prudence of Entex’s gas

purchases because that would constitute retroactive ratemaking. See id. § 104.151. Entex also

maintained that the Commission should first consider the scope of its review authority before

reaching the merits of the City’s allegations. The City argued that the Commission could conduct

a retroactive prudence review of Entex’s gas purchases and that the Commission should address in

6

a single proceeding both the scope of its authority to review Entex’s charges and to order refunds

and the merits of the City’s allegations. The City also requested that the Commission order Entex

to reimburse the City for its expenses because it considered the proceeding to be a “rate case” as

defined in the utilities code. See id. § 103.022 (West 1998). Entex responded that the case was not

a “ratemaking proceeding” and, thus, the City was not entitled to recover its expenses. See id.

§ 103.022. 

The Commission set the matter before two hearing examiners, who decided that

“issues related to a consideration of the reasonableness and necessity of Entex’s gas costs and gas
Commissioner Michael Williams dissented. 7

After filing its petition in district court, Entex filed a petition for writ of mandamus 8

requesting that this Court stay the Commission from engaging in its prudence review of Entex’s gas

purchases during the pendency of this appeal. We denied the petition. The parties report that the

Commission has conducted its review, found that no refund was due, and severed from that

proceeding the issue of the City’s claim for rate case expense reimbursement. The Commission later

denied the City reimbursement in the severed cause. Because this appeal continues to present live

issues affecting matters still pending before the Commission, we proceed to consider them. 

6

purchase practices will be considered in this proceeding.” The Commission denied Entex’s appeal

of this decision. After a hearing on the merits, the hearing examiners rejected the City’s argument

that any proceeding that affects the compensation of a utility is a ratemaking proceeding. Instead,

they decided that “ratemaking proceedings” are only those that are exclusively devoted to rates such

that they may result in changed rates. Thus, the examiners found that the City could not be entitled

to reimbursement for its expenses. On appeal, the Commission reversed that holding and awarded

the City 90 percent of its expenses.7

Entex then filed suit in Travis County district court seeking a declaration that the

Commission lacks authority to conduct a retroactive prudence review of gas purchases and,

alternatively, that such an action by the Commission is not a “ratemaking proceeding” in which the

City could obtain expense reimbursement. It also asked the district court to enjoin enforcement of

the Commission’s order requiring Entex to reimburse the City 90 percent of its expenses. The

district court rendered judgment declaring that the Commission has authority to conduct a retroactive

prudence review of gas purchases and that such a proceeding is a ratemaking proceeding in which

the City could recover expenses. This appeal followed.8
7

DISCUSSION

Entex brings two issues on appeal that mirror its issues before the district

court—whether the Commission has authority to conduct a retroactive prudence review of gas

purchases that Entex flowed through the PGA clauses and whethersuch a proceeding is a ratemaking

proceeding for which the City can seek expense reimbursement.

Standard of review

Our consideration of Entex’s appellate issues ultimately turns upon statutory

construction. Statutory construction is a matter of law, which we review de novo. City of San

Antonio v. City of Boerne, 111 S.W.3d 22, 25 (Tex. 2003). The goal of statutory construction is to

give effect to the intent of the legislature. Fleming Foods of Tex., Inc. v. Rylander, 6 S.W.3d 278,

284 (Tex. 1999); Union Bankers Ins. Co. v. Shelton, 889 S.W.2d 278, 280 (Tex. 1994). We

consider, among other factors, the language of the statute, legislative history, the nature and object

the legislature intended to be obtained, and the consequences that would follow from alternative

constructions, even when a statute is not ambiguous on its face. Tex. Gov’t Code Ann. § 311.023

(West 1998); Helena Chem. Co. v. Wilkins, 47 S.W.3d 486, 493 (Tex. 2001); United Servs. Auto.

Ass’n v. Strayhorn, 124 S.W.3d 722, 728 (Tex. App.—Austin 2003, pet. denied). We consider

disputed provisions in context, not in isolation. Texas Workers’ Comp. Comm’n v. Continental Cas.

Co., 83 S.W.3d 901, 905 (Tex. App.—Austin 2002, no pet.); see Fitzgerald v. Advanced Spine

Fixation Sys., 996 S.W.2d 864, 866 (Tex. 1999). 

The legislature has instructed us that GURA is to “be construed liberally to promote

the effectiveness and efficiency ofregulation of gas utilities.” Tex. Util. Code Ann. § 101.007 (West
8

1998). However, as an administrative agency, the Commission may exercise only those powers that

the legislature confers upon it in clear and express language and cannot create and exercise what

really amounts to a new or additional power for the purpose of administrative expediency. Texas

Natural Res. Conservation Comm’n v. Lakeshore Util. Co., 164 S.W.3d 368, 377 (Tex. 2005);

Public Util. Comm’n v. City Pub. Serv. Bd. of San Antonio, 53 S.W.3d 310, 316 (Tex. 2001). This

is because as an administrative agency the Commission is a creature of the legislature with no

inherent authority of its own. Lakeshore Util. Co., 164 S.W.3d at 377. “When the Legislature

expressly confers a power on an agency, it also impliedly intends that the agency have whatever

powers are reasonably necessary to fulfill its express functions or duties.” Id. at 378. And, an

agency created to centralize expertise in a certain regulatory area is ordinarily “given a large degree

of latitude in the methods it uses to accomplish its regulatory function.” Texas Mun. Power Agency

v. Public Util. Comm’n, 150 S.W.3d 579, 586 (Tex. App.—Austin 2004, pet. granted). However,

an agency may not, in the guise of implied powers, exercise what is effectively a new power, or a

power contrary to a statute, on the theory that such exercise is expedient for the agency’s purpose,

City of Austin v. Southwestern Bell Tel. Co., 92 S.W.3d 434, 441 (Tex. 2002), nor may it contravene

specific statutory language, run counter to the general objectives of the statute, or impose additional

burdens, conditions, or restrictions in excess of or inconsistent with the relevant statutory provisions.

State v. Public Util. Comm’n of Tex., 131 S.W.3d 314, 321 (Tex. App.—Austin 2004, pet. denied).

Retroactive prudence review of gas purchases

In its first issue, Entex argues that the Commission lacks authority to conduct

retroactive prudence reviews of gas purchase charges flowed through a PGA clause or to order
9

refunds. It also asserts that such a review that might result in a refund order violates the filed rate

doctrine and is a form of prohibited retroactive ratemaking.

Regulatory and policy context

We begin by recognizing that the legislature to date has continued to impose a

comprehensive regime of traditional rate regulation on gas utilities. Gas utilities are monopolies in

the areas they serve. Tex. Util. Code Ann. § 101.002(b) (West 1998). As a result, “the normal

forces of competition that regulate prices in a free enterprise society do not operate.” Id. Instead,

the legislature sought through GURA “to establish a comprehensive and adequate regulatory system

for gas utilities to assure rates, operations, and services that are just and reasonable to the consumers

and to the utilities,” with the overarching goal of protecting “the public interest inherent in the rates

and services of gas utilities.” Id. § 101.002(a). To this end, the legislature charged the Commission

with the task of ensuring “compliance with the obligations of gas utilities” in GURA and granted the

Commission broad powers to regulate “utility rates, operations, and services as a substitute for

competition.” Id. § 104.001 (emphasis added). The legislature emphasized that the Commission

“shall ensure that each rate a gas utility or two or more gas utilities jointly make, demand, or receive

is just and reasonable” in a manner that will “permit the utility a reasonable opportunity to earn a

reasonable return on the utility’s invested capital used and useful in providing service to the public

in excess of its reasonable and necessary operating expenses.” Id. § 104.003. These policy goals

inform our analysis of the Commission’s powers here. See id. § 101.007; compare with TXU

Generation Co., L.P. v. Public Util. Comm’n of Tex., 165 S.W.3d 821, 851-52 (Tex. App.—Austin

2005, pet. filed) (Pemberton, J., dissenting) (arguing that PURA’s competition statutory objectives
 We do so while mindful of the admonition that a “lawyer who attempts to chop his way 9

around in the jungle of legal opinion on the subject of these [PGA] clauses is apt to find himself

wandering in circles with hisintellectual machete so dulled he is soon brought to a standstill.” Philip

P. Ardery, Should There Be Rules about Escalator Clauses?, 53:1 Pub. Util. Fort. 35, 39 (1954).

10

should inform our view of the Commission’s general powers to ensure both “safe, reliable, and

reasonably priced electricity” in retail market and that ancillary services are available at “reasonable

prices”).

PGA clauses

We next note the nature and function of PGA clauses. Fuel adjustment clauses for 9

utilities, such as the PGA clauses at issue in this case, originated as part of utility rate schedules in

response to the rapid changes in coal prices during World War I. Richard J. Pierce, Reconsidering

the Roles of Regulation and Competition in the Natural Gas Industry, 97 Harv. L. Rev. 345, 373

(1983). They allow a utility to adjust charges automatically, either up or down, on an ongoing basis

in response to fluctuating fuel costs. Dennis Schiffel, Electric Utility Regulation: An Overview of

Fuel Adjustment Clauses, 95:13 Pub. Util. Fort. 23, 23-24 (1975); R.S. Trigg, Escalator Clauses in

Public Utility Rate Schedules, 106 U. Pa. L. Rev. 964, 964 (1958). In other words, an automatic fuel

adjustment clause is “a fixed rule under which future rates to be charged the public are determined.

It is simply an addition of a mathematical formula to the filed schedules of the Company under

which the rates and charges fluctuate as the wholesale cost of gas to the Company fluctuates.” City

of Norfolk, 90 S.E.2d at 148; see also Louisiana Pub. Serv. Comm’n v. Federal Energy Regulatory

Comm’n, 688 F.2d 357, 360-61 (5th Cir. 1982). 
 In the sample rate schedule reproduced as Appendix A, fixed-cost and variable-cost

10

portions of the schedule are reported together under the heading “Net Monthly Rate.” Some courts

have termed these numbers as the “base rate,” which fluctuates based on changes in the gas-cost

variable as described in the PGA clause. See, e.g., Southern Cal. Edison Co. v. Public Util. Comm’n,

576 P.2d 945, 954-55 (Cal. 1978). 

 Pierce has asserted that escalator clauses, such as the PGA clauses in this case, “are 11

essential to the financial viability of many pipelines and other utilities.” Richard J. Pierce,

Reconsidering the Roles of Regulation and Competition in the Natural Gas Industry, 97 Harv. L.

Rev. 345, 373 (1983). Nonetheless, criticism has been voiced against the use of such clauses

because of their automatic nature. See G. William Fowler, Purchased Gas Adjustment Clauses: An

Adjuster’s Viewpoint, 6 St. Mary’s L.J. 567, 578-81 (1974) (reviewing major areas of criticism of

fuel adjustment clauses, including incentive issues and parent-subsidiary self-dealing

considerations). 

 “Regulatory lag” is the loss of earnings between the time a utility files a petition for a rate 12

increase and when the rate relief actually becomes effective. Pierce, 97 Harv. L. Rev. at 360; see

R.S. Trigg, Escalator Clauses in Public Utility Rate Schedules, 106 U. Pa. L. Rev. 964, 964 (1958);

see also Elizabeth Warren, Regulated Industries’ Automatic Cost of Service Adjustment Clauses: Do

They Increase or Decrease Cost to the Consumer?, 55 Notre Dame L. Rev. 333, 348 (1980)

(“Regulatory lag simply operates as a squeeze on the utility.”). 

11

Other cost components of rate schedules are generated from historically based

projections of future costs and so are reflected in fixed components of the rate schedule. See 10

Pierce, 97 Harv. L. Rev. at 373. Although sometimes criticized, this bifurcated regulatory treatment

is generally deemed satisfactory because most costs tend to increase gradually and predictably while

fuel costs are particularly subject to dramatic and unforeseeable changes. Id. at 373 n.152. In 11

addition, fuel costs constitute such a large proportion of a utility’s total costs that any substantial

regulatory lag in approving rate increases to reflect fuel cost increases can cause the rapid financial 12
 Four pragmatic justifications have generally been identified for using such clauses: 13

(1) to reduce the number of rate proceedings and the expenses attended thereon,

(2) a series of smaller increases to the consumer, (3) improved financial

stability for the utility by reducing the variations in earnings caused by such

increase in expenses, and as a result (4) a somewhat reduced cost of capital

which ultimately would accrue to the benefit of the consumer.

Patricia Gabel, et al., Utility Rates, Consumers, and theNew York State Public Service Commission,

39 Alb. L. Rev. 707, 754 (1975); see Daily Advertiser v. Trans-La, Div. of Atmos Energy Corp., 612

So. 2d 7, 22 n.23 (La. 1993); see also Railroad Comm’n of Tex. v. City of Fort Worth, 576 S.W.2d

899, 902 (Tex. Civ. App.—Austin 1979, writ ref’d n.r.e.) (citing Montana Consumer Counsel v.

Public Serv. Comm’n, 541 P.2d 770 (Mont. 1975)); Fowler, 6 St. Mary’s L.J. at 578.

12

ruin of an otherwise healthy utility. Id. PGA clauses permit fluctuations in the utility’s costs to

13

be passed through directly to its customers as cost adjustments in subsequent utility bills. Elizabeth

Warren, Regulated Industries’ Automatic Cost of Service Adjustment Clauses: Do They Increase or

Decrease Cost to the Consumer?, 55 Notre Dame L. Rev. 333, 336 (1980). Through a PGA clause,

then, a utility can track its customer charges more closely to its current cost of fuel without

continually having to file for rate increases (or decreases) and ameliorate the regulatory lag problem.

See Public Serv. Co. of N. H. v. Federal Energy Regulatory Comm’n, 600 F.2d 944, 947 (D.C. Cir.

1979); Gulf Power Co. v. Florida Public Serv. Comm’n, 487 So. 2d 1036, 1037 (Fla. 1986).

Generally, implementation of PGA clauses is an exercise bya regulatory commission

of its ratemaking, as opposed to rulemaking, power, and PGA clauses are generally adopted in a

ratemaking proceeding as an integral part of a utility’s overall rate structure. See Public Serv. Co.

of N. H., 600 F.2d at 947 (describing such clauses as part of “utility’s filed rate”); Scates v. Arizona
13

Corp. Comm’n, 578 P.2d 612, 616 (Ariz. 1978); In re Petition of Allied Power & Light Co., 321

A.2d 7, 10-11 (Vt. 1974); Trigg, 106 U. Pa. L. Rev. at 996. In some jurisdictions, regulatory

commissions are statutorily authorized to implement such clauses; in others, the regulatory

commission implements such clauses pursuant to its plenary ratemaking authority. See Daily

Advertiser v. Trans-La, Div. of Atmos Energy Corp., 612 So. 2d 7, 23 (La. 1993). As already noted,

such clauses have been judicially recognized and approved in Texas, and we have also described the

adoption of a PGA as being part of a ratemaking proceeding. San Antonio Indep. Sch. Dist., 550

S.W.2d at 266-67 & n.2; High Plains Natural Gas Co., 613 S.W.2d at 48; City of Fort Worth, 576

S.W.2d at 902. 

Entex’s approved rate and its PGA clause

We next consider the relationship between the PGA clause here and Entex’s approved

rate. GURA defines a “rate” as 

(A) any compensation, tariff, charge, fare, toll, rental, or classification that is directly

or indirectly demanded, observed, charged, or collected by a gas utility for a

service, product, or commodity described in the definition of gas utility in this

section; and

(B) a rule, regulation, practice, or contract affecting the compensation, tariff, charge,

fare, toll, rental, or classification.

Tex. Util. Code Ann. § 101.003(12) (West Supp. 2005). Through this language, the legislature has

recognized that a rate may consist not merely of a fixed dollar amount but may instead be a rule

“affecting” the charge, a term contemplating the use of variables. See id. § 101.003(12)(B). 
For the sake of simplicity, we refer only to the terms and numbers used in the sample rate 14

schedule reproduced at Appendix A. 

The price of gas is divided into four brackets: for the first 400 cubic feet of gas, the 15

customer is charged a set price of $9.19 (the minimum monthly bill); the next 2,600 cubic feet cost

$.6536 per 100 cubic feet; the next 7,000 cubic feet cost $.5412 per 100 cubic feet; and, finally, any

amount of gas more than the initial 10,000 cubic feet will cost the customer $.5208 per 100 cubic

feet. 

The PGA clause also includes a provision for the amount charged to vary according to 16

changes in gross receipts taxes, a practice that has been common in jurisdictions that permit the use

of PGA clauses. See Trigg, 106 U. Pa. L. Rev. at 982-87.

14

The approved rate schedules in this case amount to a rule providing a three-step

process for computing a customer’s monthly gas charge. See id.; see also Appendix A. First, the 14

rate schedule sets each customer a minimum monthly bill, $9.19. Second, the rate schedule defines

the price of gas per 100 cubic feet of gas. Collectively, these prices may be termed the “base rate” 15

because they set the base from which the actual customer charge will vary according to the terms of

the third part of the rate schedule, the PGA clause. The third component, the PGA clause, states that

the “net monthly rate per unit sold is predicated upon a price of natural gas purchased for resale” at

$4.5705 per Mcf. As a result, the actual customer charge for gas would be the amount set by the 16

base rate, adjusted for the deviation of the cost of gas to Entex from the assumed purchase price of

$4.5705 per Mcf. 

This “rule” fits squarely within the statutory definition of “rate.” See Tex. Util. Code

Ann. § 101.003(12)(B). We thus conclude that an Entex gas rate consists of its entire rate schedule,

which may result in differing customer charges month-to-month. See 16 Tex. Admin. Code

§ 7.315(a), (c)(8) (2005) (formula may constitute rate; rate adjustment provision must be part of rate

filing); cf. ChevronTexaco Exploration & Prod. Co. v. Federal Energy Regulatory Comm’n, 387
15

F.3d 892, 895 (D.C. Cir. 2004) (quoting Transwestern Pipeline Co. v. Federal Energy Regulatory

Comm’n, 897 F.2d 570, 578 (D.C. Cir. 1990)) (under Federal Natural Gas Act, FERC may approve

“a tariff containing a rate ‘formula’ or a rate ‘rule’” instead of a specific number); Pierce, 97 Harv.

L. Rev. at 349 n.29 (rates generally may consist of fixed values and variable components). 

The Commission’s authority over the rate

The regulatory authority, whether the Commission or a municipality, “shall ensure

that each rate a gas utility or two or more gas utilities jointly make, demand, or receive is just and

reasonable.” Tex. Util. Code Ann. § 104.003 (West 1998). Rates must be established so as to

permit the utility “a reasonable opportunity to earn a reasonable return on the utility’s invested

capital used and useful in providing service to the public in excess of its reasonable and necessary

operating expenses.” Id. §§ 104.051, .053. “A gas utility may not directly or indirectly charge,

demand, collect, or receive from a person a greater or lesser compensation for a service provided or

to be provided by the utility than the compensation prescribed by the applicable schedule of rates

filed.” Id. § 104.005. Finally, the Commission “may require the examination and audit of the

accounts of a gas or municipally owned utility” and may inspect “the papers, books, accounts,

documents, and other business records of a gas utility within its jurisdiction.” Id. §§ 102.202, .203.

The utilities code does not define “examination” or “audit,” so we may rely on

definitions listed in commonly used dictionaries to discern the plain meaning of terms in the statute.

See Powell v. Stover, 165 S.W.3d 322, 326 (Tex. 2005); Texas Dep’t of Protective & Regulatory

Servs. v. Mega Child Care, Inc., 145 S.W.3d 170, 196 (Tex. 2004); Sheshunoff v. Sheshunoff, 172

S.W.3d 686, 695 n.8 (Tex. App.—Austin 2005, pet. filed). An “examination” is “an inspection” or
16

“analysis.” American Heritage Dictionary 456 (1973). An audit is a “formal examination of an

individual’s or organization’s accounting records, financial situation, or compliance with some other

set of standards.” Black’s Law Dictionary 126 (7th ed. 1999). It may involve “an adjustment or

correction of accounts.” American Heritage Dictionary 86.

The legislature has charged the Commission to ensure “compliance with the

obligations of gas utilities” in GURA and to regulate “utility rates, operations, and services as a

substitute for competition,” Tex. Util. Code Ann. § 104.001, and has specifically enumerated its

power to conduct examinations and audit the utilities. Id. §§ 102.202, .203. The PGA clause, as part

of the rate, is an important and varying factor in the charge to the utilities’ customers, and the amount

charged to customers ultimately depends, under the terms of the PGA clause, on the price of gas

purchased. PGA clauses are merely recoupment devices designed to permit utilities a

dollar-for-dollar recovery of fluctuations in fuel costs. The customer is harmed by the

implementation of such clauses only if such clauses aremanipulated or abused, thus encouraging the

promulgation of rate charges that are neither just nor reasonable to the ratepayer. See Fowler, 6 St.

Mary’s L.J. at 578-81; see also In re Niagara Mohawk Power Corp., 507 N.E.2d 287, 291 (N.Y.

1987). These criticisms are met, however, when the regulatory body reviews charges recouped by

a utility through a PGA clause and determines that such charges were “just and reasonable.” A

necessary corollary to such review is the power to take corrective action when the utility has

misapplied the terms of its rates. In other words, an allegation that a utility has manipulated its

purchases to artificially raise the cost of fuel differs in no substantial way from the claim that a utility

charged customers a price greater than an approved fixed rate. As the Ohio Supreme Court
17

observed, “the requirement of fairness which compels adjustment in rates to compensate utilities for

escalating fuel costs also compels retrospective reconciliation to exclude charges identifiably

resulting from unreasonable computations or inclusions.” Ohio Power Co. v. Public Utils. Comm’n,

376 N.E.2d 1337, 1338-39 (Ohio 1978). 

In response, Entex points out that although GURA and PURA share a common

legislative history, the legislature gave the Commission express authority in PURA to review and

reconcile the prudence of the fuel costs of electric utilities, see Tex. Util. Code Ann. § 36.203 (West

1998), yet included no such provision in GURA regarding gas utilities. Entex would have us infer

that the legislature did not intend to empower the Commission to review and reconcile gas utilities’

fuel costs. However, the legislature enacted the provision granting the Commission authority to

review and reconcile the prudence of fuel costs at a time when it had prohibited the PUC from

allowing electric utilities to use automatic fuel cost adjustment clauses like PGAs. Id. § 36.201

(West 1998); see also Entergy Gulf States, Inc. v. Public Util. Comm’n of Tex., 173 S.W.3d 199, 206

(Tex. App.—Austin 2005, pet. filed). By contrast, Texas courts by that time had approved the use

of PGA clauses by gas utilities. See High Plains Natural Gas Co., 613 S.W.2d at 48. Against this

legal backdrop, the legislature understandably provided a method for timely review and adjustment

of an electric utility’s fuel costs as an alternative for fuel factor adjustment clauses while including

no such provision regarding gas utilities. See Tex. Util. Code Ann. § 36.203(d). Thus, we find

uninstructive Entex’s comparison with the express powers given to the PUC.

As we have discussed, when a PGA clause is approved, the power to review past

purchases and order refunds is necessary to ensure compliance with the approved rate. We find it
18

reasonably necessary for the Commission to have the power to review past gas purchases and order

refunds as part of its express audit power to ensure compliance with the approved rate and its implied

power to approve PGA clauses. See id. §§ 104.005(a), (c) (Commission may order refund with

interest if it finds that utility violated terms of its filed rate);see also City Pub. Serv. Bd., 53 S.W.3d

at 316 (Tex. 2001); Lakeshore Util. Co., 164 S.W.3d at 378. Otherwise, the Commission’s authority

would be reduced to the ministerial task of verifying the utility’s arithmetic, and having the general

powers to regulate rates and ensure compliance together with the jurisdiction to examine and audit

the utilities would “be hollow and meaningless.” See Texas Bldg. Owners & Managers Ass’n v.

Public Util. Comm’n of Tex., 110 S.W.3d 524, 532 (Tex. App.—Austin 2003, pet. denied); Public

Util. Comm’n of Tex. v. City of Austin, 728 S.W.2d 907, 915 (Tex. App.—Austin 1987, writ ref’d

n.r.e.); see also In re Redi-Flo Corp., 384 A.2d 1086, 1097 (N.J. 1978) (court could not be satisfied

that PGA clause itself was “just and reasonable” if clause operated free from regulatory board’s

supervision and without periodic systematic review more comprehensive than “monitoring”). 

Filed rate doctrine

Entex next argues that the power to conduct a retroactive prudence review violates

the filed rate doctrine. We disagree.

The “filed rate doctrine” applies when state law creates a state agency and a statutory

scheme under which the agency determines reasonable rates for the service provided. Arkansas La.

Gas Co. v. Hall, 453 U.S. 571, 579 (1981); Keogh v. Chicago & Northwestern Ry., 260 U.S. 156,

163 (1922);see also Tex. Util. Code Ann. § 104.005(a) (codifying filed rate doctrine). The doctrine

holds that a tariff filed with and approved by an administrative agency under a statutory scheme is
19

presumed reasonable unless a litigant proves otherwise. Southwestern Elec. Power Co. v. Grant, 73

S.W.3d 211, 216 (Tex. 2002). It concomitantly prohibits regulated utilities from “charging rates for

their services other than those properly filed with the appropriate regulatory authority.” Entex v.

Railroad Comm’n of Tex., 18 S.W.3d 858, 862-63 (Tex. App.—Austin 2000, pet. denied) (quoting

Southwestern Bell Tel. Co. v. Metro-Link Telecom, Inc., 919 S.W.2d 687, 692 (Tex. App.—Houston

[14th Dist.] 1996, writ denied)). A tariff filed with and approved by an administrative agency under

a statutory scheme is presumed reasonable unless a litigant proves otherwise. Grant, 73 S.W.3d at

216; see Western Union Tel. Co. v. Esteve Bros. & Co., 256 U.S. 566, 572 (1921); Wegoland, Ltd.

v. NYNEX Corp., 27 F.3d 17, 18 (2d Cir. 1994); Metro-Link Telecom, 919 S.W.2d at 691. Thus,

under the doctrine filed tariffs govern a utility’s relationship with its customers and have the force

and effect of law until suspended or set aside. Grant, 73 S.W.3d at 217; see Keogh, 260 U.S. at

162-63; Carter v. AT&T Co., 365 F.2d 486, 496 (5th Cir. 1966); Metro-Link Telecom, 919 S.W.2d

at 692. Additionally, regulated utilities cannot vary a tariff’s terms with individual customers,

discriminate in providing services, or charge rates other than those properly filed with the appropriate

regulatory authority. Maislin Indus. v. Primary Steel, Inc., 497 U.S. 116, 126 (1990); Arkansas La.

Gas, 453 U.S. at 577; Metro-Link Telecom, 919 S.W.2d at 692. A utility’s obligations to its

customers cannot exceed its duties under the filed tariff. See Texaco, Inc. v. Central Power & Light

Co., 955 S.W.2d 373, 377 (Tex. App.—San Antonio 1997, pet. denied); Central Power & Light Co.

v. Romero, 948 S.W.2d 764, 767 (Tex. App.—San Antonio 1996, writ denied); see also Arkansas

La. Gas, 453 U.S. at 577-78. 
In East Tennessee, the gas supplier had tariffs that included a fixed demand charge 17

(entitling the purchaser to minimum amounts each day) and a “commodity charge” (an amount based

on the actual amount received). East Tenn. Natural Gas Co. v. Federal Energy Regulatory Comm’n,

631 F.2d 794, 797 (D.C. Cir. 1980). Due to shortages, the supplier began to curtail delivery of gas

and was unable to meet its minimum amount obligations (as promised under the demand charge

provision). Id. The supplier thus gave its customers, as termed by the D.C. Circuit, “demand charge

credits.” Id. To recover this loss, it also added a surcharge to its commodity charge, thereby

allowing the supplier to recoup all its revenue lost through the demand charge credit. Id. East

Tennessee invoked its PGA clause to pass through the surcharge to its customers but did not factor

in the demand charge credit. Id. FERC ordered the demand charge also passed though. Id. at 798.

However, the substance of the dispute before FERC was the nature of the credit. Id. at 797 n.6. East

Tennessee argued that they were “curtailment credits,” a position FERC rejected. Id. Thus, the

review at issue in the case was the proper characterization of the credit themselves. Only after

20

The considerations underlying the doctrine are the preservation of the regulatory

agency’s primary jurisdiction over reasonableness of rates and the need to insure that regulated

companies charge only those rates of which the regulatory agency has been made cognizant. See

Concord v. Federal Energy Regulatory Comm’n, 955 F.2d 67, 71 (D.C. Cir. 1992); City of Cleveland

v. Federal Power Comm’n, 525 F.2d 845, 854 (D.C. Cir. 1976). In addition, the doctrine serves to

provide predictability and certainty to enable customers to make decisions according to the rates as

approved and “the cost of what they are receiving.” Electrical Dist. No. 1 v. Federal Energy

Regulatory Comm’n, 774 F.2d 490, 493 (D.C. Cir. 1985); cf. Indiana & Michigan Elec. Co. v.

Federal Power Comm’n, 502 F.2d 336, 344 (D.C. Cir. 1974). A regulatory agency cannot

retroactively alter the cost-adjustment mechanism, nor can it reject calculations on the theory that

the method of calculation itself is not just or reasonable, because the rate rule is the filed rate. See,

e.g., ChevronTexaco, 387 F.3d at 896. However, the filed-rate doctrine does not preclude a review

based on the charge that a utility misapplied its rate. See East Tenn. Natural Gas Co. v. Federal

Energy Regulatory Comm’n, 631 F.2d 794, 800 n.10 (D.C. Cir. 1980).17
determining how to characterize the credits (as demand charge credits instead of as “curtailment

credits”) did FERC, and then the D.C. Circuit, consider whether the refund violated the filed rate

doctrine. In this way, FERC first conducted a review of the underlying transactions, to determine

the nature of the transactions and, after making that determination, only then engaged in the

application—calculating the correct charge.

Similarly, the central allegation in this case is the circumstances of Entex’s gas purchases

and sales—that it charged its residential and small commercial customers for the wrong gas. The

Commission is seeking to review which purchased gas was the correct one for delivery to the

residential and small commercial customers. Once it does that, it will engage in the ministerial task

of calculating the correct charge.

21

As we have explained above, the Commission’s authority to conduct a retroactive

review of gas purchases does not involve retroactively changing the terms of Entex’s approved rate

schedule. Instead, the Commission is attempting to review gas purchases that resulted in changes

to the amounts charged to Entex’s customers under the terms of its PGA clause. The City’s

underlying claim, the basis for the Commission’s action, amounts to one of abuse of the PGA clause,

a variable in Entex’s approved rate; the proceedings concern the alleged misapplication of Entex’s

rates rather than an attempt to change the terms of the rates. In other words, the Commission’s

review is not an attempt to order Entex to calculate its charges differently; rather, it would be

ordering Entex only to calculate its charges correctly. Thus, we conclude that the filed rate doctrine

does not prevent regulatory review of allegedly imprudent expenditures automatically passed through

to the ratepayers through a PGA clause. 

Rule against retroactive ratemaking

Finally, Entex argues that the authority to conduct a retroactive review of gas

purchases would violate the rule against retroactive ratemaking. We disagree. 
22

Fundamental in the utility ratemaking process is the principle, termed the rule against

retroactive ratemaking, that utility rates are set for the future and not the past. Railroad Comm’n of

Tex. v. Lone Star Gas Co., 656 S.W.2d 421, 425 (Tex. 1983). Utilities code sections 104.110 and

104.151 codify the rule against retroactive ratemaking for gas rates. Rates set by the Commission

“constitute the legal rates of the gas utility until changed” in the manner provided by GURA. Tex.

Util. Code Ann. § 104.151(b). If, after a hearing, the Commission finds a rate unreasonable, it shall

“enter an order establishing the rates the gas utility shall charge or apply for the service in question.”

Id. § 104.110(a)(1). The new rate “shall be observed thereafter until changed.” Id. § 104.110(b).

The rule against retroactive ratemaking is often misunderstood and misapplied. See

State v. Public Util. Comm’n of Tex., 883 S.W.2d 190, 199 (Tex. 1994) (citing Stefan Krieger, The

Ghost of Regulation Past: Current Applications of the Rule Against Retroactive Ratemaking in

Public Utility Proceedings, 1991 U. Ill. L. Rev. 983, 988 (1991)). It prohibits a public utility

commission from setting future rates to allow a utility to recoup past losses or to refund to consumers

excess utility profits. Id. “Restated, the rule prohibits a utility commission from making a

retrospective inquiry to determine whether a prior rate was reasonable and imposing a surcharge

when rates were too low or a refund when rates were too high.” Id. That is, the rule against

retroactive ratemaking only requires that natural gas companies, the Commission, and courts abide

by an administrative determination that a particular rate is just and reasonable. See East Tenn.

Natural Gas Co., 631 F.2d at 800. 

The Commission’s attempt to review Entex’s gas purchases, which directly affected

the amounts charged to Entex’s customers, and to order refunds to compensate for allegedly
 The rule against retroactive ratemaking generally protects the utility from being subject 18

to later decisions by a regulatory agency that the agency’s earlier decision in approving a rate was

“unsound.” See Public Util. Comm’n of Cal. v. Federal Energy Regulatory Comm’n, 894 F.2d 1372,

1383 (D.C. Cir. 1990). In the context of PGA clauses, this reasoning cannot apply—no regulatory

authority has ever considered the circumstances under which Entex made its gas purchases. 

23

imprudent purchases may well be retroactive in effect, but it is not retroactive ratemaking. As we

have already discussed, the Commission is not attempting to disturb the determination that Entex’s

rate schedules are just and reasonable. Rather, the Commission’s review will only concern its

application of the approved rates—having been given the benefit of including PGA clauses in its

rates, Entex will be subject to review of gas purchases to ensure that it did not misapply its filed rate

schedule. The Commission is not modifying the rate. 

The rule against retroactive ratemaking does not prohibit the Commission from

ordering a utility to honor its rate schedule when the rate schedule itself includes a variable term.

18

A customer charge determined by the application of a PGA clause cannot be declared reasonable or

just until after it has been implemented. Thus, a regulatory agency can identify overcharges only

through retrospective analysis. As the D.C. Circuit explained when considering a similar problem

under the Federal Natural Gas Act, “The allegedly retroactive changes here are not retroactive at all;

they simply implement an existing rate system that requires periodic adjustments.” East Tenn.

Natural Gas Co., 631 F.2d at 800 n.9; see also Concord, 955 F.2d at 75; Boston Edison Co. v.

Federal Energy Regulatory Comm’n, 856 F.2d 361, 370 (1st Cir. 1988). 

Entex offers two cases from other states to support its argument that the power to

order refunds after conducting retroactive review of gas purchases violates the rule against

retroactive ratemaking. See Matanuska Elec. Ass’n v. Chugach Elec. Ass’n, 53 P.3d 578 (Alaska
24

2002); Wisconsin Power & Light Co. v. Public Serv. Comm’n of Wis., 511 N.W.2d 291 (Wis. 1994).

Matanuska concerned a fuel surcharge included as an estimate in its rate, subject to quarterly true-up

proceedings. 53 P.3d at 581. Variances between the estimated and actual costs were taken into

account when calculating the next quarterly fuel surcharge filing. Id. Part of its fuel surcharge

estimate included a line-loss estimate to account for the amount of energy lost through the process

of generation and transmission. Id. Chugach had used a 5.219% line loss factor in its rate filings

with the regulatory agency, but later review revealed that its own internal documents showed the

actual line loss factor to be substantially lower. Id. at 582. Chugach corrected its error when filing

future tariffs but refused to issue refunds. Id. The Alaska Supreme Court held that, when initial

estimates are later shown to be inaccurate, previously set rates cannot be changed to correct for the

error. Id. at 585. It found confirmation in that approach because of the extensive review the

regulatory agency employed when setting the rate and accepting the line loss factor. Id. Chugach

does not aid our analysis here; we are not considering an estimate later found to be inaccurate, a

number that could have been verified before implementation, but the prudence of gas purchases,

which were not readily subject to review until after they occurred. 

In dicta, the Matanuska court relied on Wisconsin Power & Light, a case that

considered fuel adjustment clauses contained in wholesale electricity rates. Id. at 586 (reviewing

Wisconsin Power & Light, 511 N.W.2d at 295-97). The Wisconsin Supreme Court held that

ordering a refund for imprudent fuel purchases violated the rule against retroactive ratemaking.

Wisconsin Power & Light, 511 N.W.2d at 297. In part, the court found that the regulatory authority

actually had performed audits during the period subject to later review and so could not revisit its
 As the Rhode Island Supreme Court has observed, the “specter of retroactive ratemaking 19

must not be viewed as a talismanic inhibition against the application of principles based upon equity

and common sense.” Roberts v. Narragansett Elec. Co., 470 A.2d 215, 217 (R.I. 1984))

 See Fitchburg Gas &Elec. Light Co. v. Department of Telecomms. & Energy, 801 N.E.2d 20

220, 230-31 (Mass. 2004); Daily Advertiser v. Trans-La, Div. of Atmos Energy Corp., 612 So. 2d

7, 23 (La. 1993); MGTC Inc. v. Public Serv. Comm’n of Wyo., 735 P.2d 103, 107 (Wyo. 1987);

Equitable Gas Co. v. Pennsylvania Pub. Util. Comm’n, 526 A.2d 823, 830-31 (Pa. Commw. Ct.

1987); Gulf Power Co. v. Florida Pub. Serv. Comm’n, 487 So. 2d 1036, 1037 (Fla. 1986); Public

Serv. Comm’n of Md. v. Delmarva Power & Light Co., 400 A.2d 1147, 1153 (Md. Ct. Spec. App.

25

determination in later proceedings. Id. at 296. The agency had, in fact, often approved rates on

interim bases so that it could review fuel costs and order refunds after that review. Id. As a result,

the court held that, having “approved [the utility’s] rates, including the utility’s expected coal costs,

14 times, the [agency] cannot now claim that the [utility] must return this money.” Id. at 297. 

Wisconsin Power & Light differs significantly from this case. Entex’s PGA clause

was approved as part of its rate. As fuel costs changed, sometimes as frequently as every month,

there was no requirement to receive approval from a regulatory authority to alter the amount charged

to customers. Instead, the charges changed according to the terms of the filed rate. 

To the extent that Wisconsin Power & Light could be interpreted broadly as

prohibiting as retroactive ratemaking in Wisconsin any refund based on a review of fuel purchase

costs passed through to customers through fuel adjustment clauses, we decline to adopt that

reasoning here. Instead, we find persuasive the dissenting opinion to that case, arguing that, because

“rates calculated under the fuel adjustment clause go into effect without advance approval by the

[regulatory agency], the utility cannot validly expect that charges thus collected are insulated from

retroactive modification.” Id. at 299 (Abrahamson, J., dissenting). Many other courts have reached 19

similar conclusions. We have concluded that the proper characterization of the Commission’s 20
1979); Southern Cal. Edison Co. v. Public Util. Comm’n, 576 P.2d 945, 954-55 (Cal. 1978).

 Entex appears to make an additional argument—that the period to be subject to review is

21

not limited in a way that will pass constitutional muster concerning its vested rights in the approved

rates. See Tex. Const. art. I, § 16; Southwestern Bell Tel. Co. v. Public Util. Comm’n of Tex., 615

S.W.2d 947, 956-57 (Tex. App.—Austin 1981), writ ref’d n.r.e., 622 S.W.2d 82 (Tex. 1981). Thus,

Entex argues, the Commission’s review cannot function as an exception to the rule against

retroactive ratemaking. We emphasize that our holding here is that the rule does not apply to

retroactive review of gas purchase costs under a PGA clause. The Commission’s review is therefore

not an “exception” to the rule. In any event, Entex did not present this as-applied vested-rights

challenge to the Commission, and we will not consider it on appeal. See Texas Water Comm’n v.

Bushy Creek Mun. Util. Dist., 917 S.W.2d 19, 23-24 (Tex. 1996); Buddy Gregg Motor Homes, Inc.

v. Motor Vehicle Bd., 156 S.W.3d 91, 104 (Tex. App.—Austin 2004, pet. denied); AmaralWhittenberg v. Alanis, 123 S.W.3d 714, 719 n.4 (Tex. App.—Austin 2003, no pet.).

26

review recognizes that increased consumer charges resulting from gas purchases were not products

of ratemaking. We therefore hold that they cannot be rendered inviolable by the rule against

retroactive ratemaking.21

Conclusion concerning retroactive reviews of gas purchases

After careful review of Entex’s arguments, we have concluded that the Commission’s

claimed authority to conduct retroactive reviews of gas purchases and to order refunds has statutory

support and does not violate either the filed rate doctrine or the rule against retroactive ratemaking.

We overrule Entex’s first issue. 

Expense reimbursement

In its second issue, Entex argues that retroactive review of its gas purchases is not a

“ratemaking proceeding” in which theCommission could require it to reimburse the City for its costs

for participating in the review. See Tex. Util. Code Ann. § 103.022. We agree.
27

“The gas utilityin a ratemaking proceeding shall reimburse the governing body of the

municipality for the reasonable cost of the services of a person engaged under [the statute] to the

extent the applicable regulatory authority determines reasonable.” Id. § 103.022(b). As noted above,

the utilities code defines “rate” broadly:

(A) any compensation, tariff, charge, fare, toll, rental, or classification that is directly

or indirectly demanded, observed, charged, or collected by a gas utility for a

service, product, or commodity described in the definition of gas utility in this

section; and

(B) a rule, regulation, practice, or contract affecting the compensation, tariff, charge,

fare, toll, rental, or classification.

Id. § 101.003(12). A “proceeding” is a hearing, investigation, inquiry, or other procedure for finding

facts or making a decision under GURA. Id. § 101.003(11). The term includes a denial of relief or

dismissal of a complaint. Id.

Under GURA, a utility’s rates may be changed in only two ways—by petition of the

utility or by a rate-setting authority, such as the Commission or the City. See id. §§ 104.102, .151.

A proceeding that changes the amount charged customers may be a ratemaking proceeding in

circumstances where the proceeding is functionally equivalent of the procedures for notice and

hearing described in subchapters C and D of the utilities code. See Southwestern Pub. Serv. Co. v.

Public Util. Comm’n of Tex., 962 S.W.2d 207, 219-20 (Tex. App.—Austin 1998, pet. denied); see

also Tex. Util. Code Ann. §§ 104.103-.151. “[N]ot all matters that have a potential effect on rates

are ratemaking proceedings. Only matters directly resulting in changed rates constitute ratemaking

proceedings.” Southwestern Pub. Serv. Co., 962 S.W.2d at 220. The requirement that a ratemaking
The City’s petition to the Commission to engage in retroactive review of Entex’s gas 22

purchases reflects this distinction. The City did not cede its jurisdiction to set rates. Instead, it

alleged only that (1) Entex’s gas purchases were unreasonable; (2) Entex’s allocation of purchased

28

proceeding be the result of some sort of application to change the amount of money a utility can

charge its customers ensures “that the proceeding is one directly devoted to setting rates and is not

one peripherally related to rates.” Id. at 219.

The City argues that the proceedings at issue in Southwestern Public Service Co., 962

S.W.2d at 217-20, are substantially identical to those at issue in this case and should entitle it to

reimbursement of its expenses. In Southwestern Public Service Co., we considered the issue of

whether fuel reconciliation proceedings in the context of electricity regulation were “ratemaking

proceedings.” Id. The utility in that case sought review to reconcile its fuel expenses when its

“predetermined customer rates” resulted in over- or under-recovery of its fuel expenses. Id. at 210.

We held that those reconciliation proceedings were the functional equivalent of ratemaking

proceedings because the actual amount of the rate was fixed in an earlier proceeding. Id. at 219-20.

The purpose of the reconciliation proceeding, in other words, was to change the rates that had no

provision for allowing a pass-through for costs related to variations in the cost of fuel. See id. As

we have explained above, the PGA clauses in this case are an integral part of the approved rate. No

party is attempting to modify the clauses themselves, only to review compliance with the rate. Thus,

the proceedings at issue in Southwestern Public Service Co. are not similar to those we are

considering here.

We have already concluded that the issue presented here is one concerning alleged

misapplication of Entex’s approved rates, not the setting of Entex’s rates. The City is not seeking 22
gas discriminated against residential and small commercial customers; (3) its tariffs were false and

misleading (but did not request that new rates be set); and (4) the PGA clause included improper

charges. 

29

to adjust the formula contained in the PGA clause or to change Entex’s rates. It is merely requesting

a review of gas purchases to ensure that the customer charge complies with Entex’s approved rate.

As a result, these proceedings are not “ratemaking proceedings,” and the City is not entitled to

reimbursement for its costs for its participation in the review. We sustain Entex’s second issue. 

CONCLUSION

We have concluded that the Commission has the authority to review Entex’s past gas

purchases when the costs associated with those purchases were passed through to Entex’s customers

through the application of the PGA clauses in Entex’s filed rates and that the Commission has the

power to order refunds if it determines that Entex’s gas purchases were imprudent. We have also

determined that the Commission’s exercise of those powers do not violate the filed rate doctrine or

the rule against retroactive ratemaking, and we thus affirm the judgment of the district court

concerning those issues. We emphasize that Entex has only presented for our review facial

challenges to the Commission’s authority to conduct the prudence reviews. We express no opinion

regarding other issues, if any, that might be raised by the Commission’s application of this authority

in any particular circumstance.

We have also found that a prudence review is not a ratemaking proceeding for

purposes of utilities code section 103.022(b), and therefore the City is not entitled to recover its

expenses incurred while participating in those proceedings. Accordingly, we reverse the judgment
30

of the district court in part and render judgment that the City is not entitled to its expenses under

utilities code section 103.022(b).

 

Bob Pemberton, Justice

Before Chief Justice Law, Justices B. A. Smith and Pemberton

Affirmed in Part; Reversed and Rendered in Part

Filed: April 21, 2006
31

APPENDIX A

ENTEX

RATE SHEET

RESIDENTIAL SERVICE

RATE SCHEDULE NO. R-1446-2

APPLICATION OF SCHEDULE

This schedule is applicable to customers receiving gas for uses usual in a home

through a single meter serving a single family dwelling and its related structures. Natural gas

supplied hereunder is for the individual use of the customer at one point of delivery and shall not be

resold or shared with others.

NET MONTHLY RATE

First 400 cubic feet or less $9.19

Next 2,600 cubic feet .6536 per 100 cubic feet

Next 7,000 cubic feet .5412 per 100 cubic feet

Over 10,000 cubic feet .5208 per 100 cubic feet

MINIMUM MONTHLY BILL $9.19

PAYMENT

Bills shall be rendered on a monthly basis and are due and payable within ten (10)

days from the date of bill.

PURCHASED GAS ADJUSTMENT PROVISION

The above net monthly rate per unit sold is predicated upon a price of natural gas

purchased for resale hereunder of $4.5705 per Mcf. To the extent that ENTEX’s price of natural gas

to be purchased (adjusted to correct any prior variations from actual costs) for resale hereunder

increases or decreases, said net monthly rate shall be adjusted up or down to reflect (i) changes in

such cost of gas per unit sold and (ii) changes in gross receipts taxes resulting from such increases

or decreases in the net monthly rate. For purposes of calculating said adjustment, it shall be proper

for ENTEX to determine its cost of gas from its several suppliers and the gross receipts taxes to be

paid on the basis of a logical geographical area.

If ENTEX receives any refunds of any increased cost of purchased gas that have been

passed on under this provision, a refund shall be made to customers served by this rate schedule.