N.M. Att'y. Gen. v. N.M. Pub. Regulation Comm'n
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The Public Regulation Commission (PRC) granted Southwestern Public Service Company’s (SPS) application to: (1) include a prepaid pension asset in its rate base in order for SPS to earn a return on this asset; and (2) obtain a renewable energy cost rider to recover approximately $22 million of renewable energy procurement costs from those customers who did not have a legislatively imposed limit on their renewable energy costs (non-capped customers). The Attorney General appealed the PRC’s final order granting SPS’s application, arguing that the approved rates were unjust and unreasonable because the inclusion of the entire prepaid asset in the rate base was not supported by substantial evidence, and the PRC acted contrary to law in allowing SPS to recover the aforementioned renewable energy costs from non-capped customers. After review, the Supreme Court affirmed the PRC because: (1) SPS was entitled to earn a reasonable rate of return on the investor-funded prepaid pension asset; and (2) SPS could recover its renewable energy costs in excess of the large customer cap from non-capped customers because such a recovery mechanism was the only viable method of cost recovery that was consistent with the purposes of the Renewable Energy Act.
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1 IN THE SUPREME COURT OF THE STATE OF NEW MEXICO 2 Opinion Number:______________ 3 Filing Date: September 28, 2015 4 No. S-1-SC-34768 5 NEW MEXICO ATTORNEY GENERAL, 6 Appellant, 7 v. 8 NEW MEXICO PUBLIC REGULATION COMMISSION, 9 Appellee, 10 and 11 SOUTHWESTERN PUBLIC SERVICE 12 COMPANY, OCCIDENTAL PERMIAN LTD., 13 and COALITION FOR CLEAN AFFORDABLE ENERGY, 14 Intervenors-Appellees. 15 APPEAL FROM THE NEW MEXICO PUBLIC REGULATION 16 COMMISSION 17 Hector H. Balderas, Attorney General 18 P. Cholla Khoury, Assistant Attorney General 19 Santa Fe, NM 20 for Appellant 1 New Mexico Public Regulation Commission 2 Margaret Caffey-Moquin 3 Santa Fe, NM 4 for Appellee 5 6 7 8 Hinkle Shanor, LLP Jeffrey L. Fornaciari Dana S. Hardy Santa Fe, NM 9 Xcel Energy Services, Inc. 10 Stephen Fogel 11 Austin, TX 12 for Intervenor Southwestern Public Service Company 13 14 15 16 Gallagher & Kennedy, P.A. Anthony J. Trujillo Germaine R. Chappelle Santa Fe, NM 17 Thompson & Knight, LLP 18 Phillip G. Oldham 19 Austin, TX 20 for Intervenor Occidental Permian, Ltd. 21 Charles F. Noble 22 Santa Fe, NM 23 for Intervenor Coalition for Clean Affordable Energy 1 Cuddy & McCarthy, LLP 2 Rebecca Dempsey 3 Santa Fe, NM 4 PNM Resources, Inc. 5 Benjamin Phillips 6 Albuquerque, NM 7 for Amicus Curiae Public Service Company of New Mexico 1 OPINION 2 CHÁVEZ, Justice. 3 {1} The Public Regulation Commission (PRC) granted Southwestern Public 4 Service Company’s (SPS) application to (1) include a prepaid pension asset in its rate 5 base in order for SPS to earn a return on this asset, and (2) obtain a renewable energy 6 cost rider to recover approximately $22 million of renewable energy procurement 7 costs from those customers who do not have a legislatively imposed limit on their 8 renewable energy costs (non-capped customers). The Attorney General appeals the 9 PRC’s final order granting SPS’s application, arguing that the approved rates are 10 unjust and unreasonable because the inclusion of the entire prepaid asset in the rate 11 base is not supported by substantial evidence, and the PRC acted contrary to law in 12 allowing SPS to recover the aforementioned renewable energy costs from non-capped 13 customers. We affirm the PRC because (1) SPS is entitled to earn a reasonable rate 14 of return on the investor-funded prepaid pension asset, and (2) SPS may recover its 15 renewable energy costs in excess of the large customer cap from non-capped 16 customers because such a recovery mechanism is the only viable method of cost 17 recovery that is consistent with the purposes of the Renewable Energy Act, NMSA 18 1978, §§ 62-16-1 to -10 (2004, as amended through 2011). 19 I. THE INCLUSION OF SPS’S PREPAID PENSION ASSET IN THE 1 2 RATE BASE {2} SPS applied to the PRC to include a prepaid pension asset in its rate base to 3 allow its shareholders, who funded the asset, to receive a corresponding return on 4 their investment. By including this prepaid pension asset in the rate base, the asset 5 is treated as a capital investment, allowing SPS to recover the asset as an expense, 6 thereby increasing SPS’s revenue requirement. See Joseph P. Tomain, Symposium 7 Article, “Steel in the Ground”: Greening the Grid with the iUtility, 39 Envtl. L. 931, 8 945-46 (2009) (providing and discussing the rate making formula, which sets the 9 amount of money utilities may receive for their investments and expenses). 10 Importantly, inclusion of an investment asset in the rate base does not enable 11 investors to recover the value of their investment, but instead only allows investors 12 to earn a return on the asset. See id. (noting that utilities generally recover the value 13 of an investment by treating the depreciation of the asset as an operating expense). 14 {3} The parties agree that a prepaid pension asset is the amount by which investor 15 contributions to a pension trust and earnings on these contributions exceed pension 16 expenses. S. Co. Servs., Inc., 122 FERC ¶ 61,218, at *62235, 2008 WL 630079, slip 17 copy at 5 (FERC 2008) (order on tariff filing), order clarified by 128 FERC ¶ 61,276, 18 2009 WL 3043950 (slip copy) (FERC 2009); In re Delmarva Power & Light Co., 2 1 2014 WL 3964914, slip copy at 18, 315 P.U.R. 4th 10 (Del. P.S.C. 2014) (“A prepaid 2 pension asset occurs when the accumulated contributions and growth in the pension 3 plan exceed the accumulated expenses associated with the pension obligations.”). For 4 example, SPS’s expert stated that if the annual pension contribution over a five-year 5 period is $100 and the annual pension expense over the same period is only $90, at 6 the end of the five-year period, the prepaid pension asset would be $50 ($100 x 5 7 $90 x 5), plus any return on the $50 prepaid pension asset. “Conversely, when 8 [accrued expenses] exceed[] contributions to [a] fund, a prepaid pension liability 9 accrues.” See In re Sw. Pub. Serv. Co., 2008 WL 4226018 n.256, slip copy at 114 10 (NMPRC) (final order partially adopting recommended decision), order clarifying 11 final order sub nom. 2008 WL 9888273 (slip copy) (NMPRC 2008). The SPS expert 12 also stated that the prepaid pension asset is an artifact of timing; over a long period, 13 pension contributions and pension expenses may even out, but over short and 14 intermediate periods there will surely be differences, which are recorded as either 15 prepaid pension assets or pension liabilities. 16 {4} SPS’s expert testified that pension contributions and expenses differ because 17 the federal Employee Retirement Income Security Act of 1974, 29 U.S.C. §§ 100118 1461 (2011), and the Internal Revenue Code, 26 U.S.C. §§ 1-59 (2012), dictate how 3 1 much the utility must contribute to its employee pension program, whereas the 2 Financial Accounting Standards Board promulgates codified accounting standards1 3 that govern how pension expenses are determined. The expert continued by testifying 4 that as a result of these differing federal and industry standards, pension contribution 5 and expense calculations utilize different assumptions, attribution methods, and 6 periods of time over which the costs are required to be recognized. SPS’s expert 7 stated that these dissimilarities often result in differing annual contribution and 8 expense amounts. When mandated contributions and income earned on the 9 contributions exceed expenses, a prepaid pension asset accrues. See S. Co. Servs., 10 Inc., 122 FERC ¶ 61,218, at *62235, 2008 WL 630079, slip copy at 5; see also In re 11 Delmarva Power & Light Co., 2014 WL 3964914, slip copy at 18. 12 {5} The expert witness also testified that utilities cannot legally withdraw any 13 funds from pension trusts except to pay pension benefits and expenses. See S. Co. 14 Servs., Inc., 122 FERC ¶ 61,218, at *62235, 2008 WL 630079, slip copy at 5. 15 However, SPS customers benefit from a prepaid pension asset because the earnings 16 on this asset are deemed to be income for SPS, which reduces the amount of revenue 1 17 Companies must follow Financial Accounting Standards Board codified 18 accounting standards to comply with generally accepted accounting principles. 4 1 it must collect from its customers. See Ind. Office of Util. Consumer Counselor v. 2 Ind. Mich. Power Co., 7 N.E.3d 1025, 2014 WL 934350, at *12 (Ind. Ct. App. 2014) 3 (memorandum decision) (non-precedential). The following hypothetical offered by 4 SPS’s testifying expert illustrates the indirect benefit SPS customers receive. 5 6 7 8 9 10 11 [S]uppose that in a given year the utility had a revenue requirement of $300, and that it expected to earn a 6% return on the pension fund. The $3.00 return on [a hypothetical] $50 prepaid pension asset (0.06 x $50) . . . would be credited against the revenue requirement, so that the utility could only collect $297 from its customers through [the] rates. Thus, the revenue requirement is reduced by $3.00 as a result of the prepaid pension asset. 12 SPS customers therefore would benefit from rate reductions generated by the prepaid 13 pension asset, but SPS would not earn a return on the prepaid pension asset if the 14 asset is not included in SPS’s rate base. 15 {6} In this case, the New Mexico jurisdictional share2 of SPS’s prepaid pension 16 asset is approximately $36.9 million. According to SPS, this asset resulted in $1.7 17 million in earnings that effectively reduced SPS’s pension expense by $1.7 million, 18 which reduced SPS’s revenue requirement by the same amount. SPS sought “to 2 19 SPS operates in other states besides New Mexico. For the relevant time 20 period, SPS’s total prepaid pension asset, on a total company basis, was 21 approximately $179.7 million. The amount of this asset attributable to New Mexico 22 is approximately $36.9 million. 5 1 include the net amount of its prepaid pension asset of approximately $22 million” in 2 the rate base to earn a return on its $22 million (the $36.9 million asset minus a $14.9 3 million tax deferred asset). 4 {7} In a recommended decision, the PRC hearing examiner concluded that because 5 the prepaid pension asset reduced the pension expense by $1.7 million, that $1.7 6 million should be included in the rate base for recovery. The PRC hearing examiner 7 did not recommend that the $22 million net prepaid pension asset amount be included 8 in the rate base. SPS disagreed with this recommendation, contending that the 9 examiner’s proposal would enable “SPS [to] earn a return only on the amount of the 10 reduction in the cost of service rather than on the amount of the asset that resulted in 11 the reduction.” 12 {8} The PRC also disagreed with the hearing examiner. In its final order, the PRC 13 authorized the inclusion of the net amount of the prepaid asset in SPS’s rate base 14 because doing so “recognizes that ratepayers benefit from the prepaid pension asset 15 and that the utility should earn a return on the prepaid pension asset in order for the 16 utility to recover its full cost of service.” The Attorney General appeals, arguing that 17 substantial evidence does not support the inclusion of the entire prepaid pension asset 18 within the rate base. 6 1 A. Standard of Review 2 In determining whether a PRC final order is supported by substantial evidence, {9} 3 we review the whole record, “view[ing] the evidence in the light most favorable to 4 the decision made by the [PRC].” PNM Gas Servs. v. N.M. Pub. Util. Comm’n (In re 5 PNM Gas Servs.), 2000-NMSC-012, ¶ 4, 129 N.M. 1, 1 P.3d 383 (internal quotation 6 marks and citation omitted). “ ‘Substantial evidence’ [is] such relevant evidence as 7 a reasonable mind might accept as adequate to support a conclusion.” Rinker v. State 8 Corp. Comm’n, 1973-NMSC-021, ¶ 5, 84 N.M. 626, 506 P.2d 783. “The supreme 9 court shall have no power to modify the action or order appealed from [(in this case, 10 a PRC final order)], but shall either affirm or annul and vacate the same.” NMSA 11 1978, § 62-11-5 (1982). “The [PRC] is vested with considerable discretion in 12 determining whether a rate to be received and charged is just and reasonable.” Hobbs 13 Gas Co. v. N.M. Pub. Serv. Comm’n, 1980-NMSC-005, ¶ 4, 94 N.M. 731, 616 P.2d 14 1116. A party challenging a PRC final order has the burden of establishing that the 15 order is “arbitrary and capricious, not supported by substantial evidence, outside the 16 scope of the agency’s authority, or otherwise inconsistent with law.” N.M. Indus. 17 Energy Consumers v. N.M. Pub. Regulation Comm’n, 2007-NMSC-053, ¶ 13, 142 18 N.M. 533, 168 P.3d 105 (internal quotation marks and citation omitted). 7 1 B. The Prepaid Pension Asset 2 The Attorney General contends that only the earnings generated by the prepaid {10} 3 pension asset should be included in the rate base because this is the amount by which 4 the ratepayers have benefitted, or the amount by which the utility’s revenue 5 requirement is reduced. The Attorney General argues that only $1.7 million should 6 be included in the rate base, whereas the PRC’s final order enables SPS to include 7 $22 million in the rate base, which is the net amount of its prepaid pension asset. In 8 resolving this issue, we explain the rationale for electric utility regulation. 9 {11} Electric utilities are regulated because their industry has natural monopoly 10 characteristics. Joseph P. Tomain, The Persistence of Natural Monopoly, 16 Nat. 11 Resources & Env’t. 242, 242 (2002). In natural monopoly settings, both the benefits 12 and the possibility of competition are limited. Omega Satellite Prods. Co. v. City of 13 Indianapolis, 694 F.2d 119, 126 (7th Cir. 1982). If the electric industry was a 14 competitive free-for-all, different companies would attempt to build separate electric 15 grids and sign up customers as quickly as possible to reduce their average costs of 16 business more rapidly than their rivals. See id. This competitive process would last 17 until a single company was left standing “because until a company serves the whole 18 market it will have an incentive to keep expanding in order to lower its average 8 1 costs.” Id. Thus, until a single company wins, competition within the electric 2 industry would produce wasteful duplicate grids that would needlessly raise average 3 costs for consumers. See id.; Tomain, The Persistence of Natural Monopoly, supra, 4 at 242 (“A specific service area needs only one set of electric . . . wires—the 5 investment in any other set of wires is wasteful.”). To avoid wasteful duplication, a 6 government may choose to give one firm a monopoly within a service area “in 7 exchange [for] a commitment to provide reasonable service at reasonable rates.” 8 Omega Satellite Prods. Co., 694 F.2d at 126. 9 {12} Electric utility regulation consequently reflects a compact between utilities and 10 the public. See Jersey Cent. Power & Light Co. v. Federal Energy Regulatory 11 Comm’n (FERC), 810 F.2d 1168, 1189 (D.C. Cir. 1987) (Starr, J., concurring). A 12 utility is given a monopoly over a service area, and in exchange accepts government 13 regulation of its business, including price regulation. Id. Under this arrangement, 14 utility investors obtain a stability in earnings that would likely be unattainable in less 15 regulated industries, while “ratepayers are afforded universal, non-discriminatory 16 service and protection from monopolistic profits.” Id. 17 {13} Regulators attempt to set prices that mimic market conditions and ensure that 18 utilities are “profitable enough to attract capital investment.” Tomain, “Steel in the 9 1 Ground,” supra, at 945. The following rate making formula traditionally determines 2 utility revenues to be received from ratepayers: R = O + (V - d)r, where R represents the utility’s revenue requirement—that is, the amount of money the utility needs to stay in business. O represents the utility’s prudently incurred expenses. In short, ratepayers reimburse the utility for its expenditures dollar for dollar. The utility’s rate base is represented by (V - d), which stands for the value of a utility’s capital investment minus depreciation, which is returned to the utility as expenses. Finally, r represents the rate of return on the rate base. 3 4 5 6 7 8 9 10 Id. at 945-46. 11 {14} The utility’s rate base—the total amount of investment made by a utility to 12 provide its service—is determined by adding the utility’s investment in physical 13 properties to its working capital. Cent. La. Elec. Co. v. La. Pub. Serv. Comm’n, 373 14 So. 2d 123, 129 (La. 1979). Thus, a utility can include physical properties such as a 15 power plant, see, e.g., Hobbs Gas Co., 1980-NMSC-005, ¶ 6, and working 16 capital—operating funds essential to pay for current obligations—in its rate base. 17 Gov’t of Guam v. Fed. Mar. Comm’n, 329 F.2d 251, 256 (D.C. Cir. 1964); Ariz. Pub. 18 Serv. Co., 5 FERC ¶ 63,038, at *65179, 1978 WL 16416, slip copy at 2 (FERC 1978) 19 (defining working capital as “the money which a utility puts up to finance the services 20 provided until it is compensated by customers”). 21 {15} In the context of utility regulation, working capital 10 1 2 3 4 5 6 does not include the total liquid funds with which the business is conducted. It is not the property which the business has; that is, it is not the excess of current assets over current liabilities. Working capital, rather, is an allowance for the sum which the company needs to supply from its own funds for the purpose of enabling it to meet its current obligations as they arise and to operate economically and efficiently. 7 Gov’t of Guam, 329 F.2d at 256 (internal quotation marks and citation omitted). As 8 a result, only utility contributions, not ratepayer contributions, can be properly 9 included in the rate base as working capital. For example, if a utility were to prepay 10 for natural gas with investor funds, the utility should expect to receive a reasonable 11 return on its investment. Zia Nat. Gas Co. v. N.M. Pub. Util. Comm’n (In re Zia Nat. 12 Gas Co.), 2000-NMSC-011, ¶ 22, 128 N.M. 728, 998 P.2d 564. Conversely, if 13 ratepayers have paid in advance for the natural gas, the utility would have no 14 expectation of a return because its capital was not used to buy the natural gas. Id. 15 {16} A utility can include prepayments for pension expenses in its rate base 16 “because the utility is out-of-pocket for such costs until they are recovered from 17 ratepayers and is therefore entitled to recover its cost of financing such prepaid 18 expenses.” S. Co. Servs., Inc., 122 FERC ¶ 61,218, at *62235, 2008 WL 630079, slip 19 copy at 5. For example, in the context of prepaid pension assets, income earned on 20 the pension fund is reported under generally accepted accounting principles as a 11 1 reduction to the utility’s pension expense. Id. “If that reduction in pension expense 2 is used in determining a utility’s rates, there will be a corresponding reduction in the 3 amounts collected from ratepayers.” Id. Under these circumstances, the utility must 4 finance the reduction because it cannot use the income from the pension trust to pay 5 other current obligations; as a result, the utility is allowed to recover the costs of 6 financing the reduction by including the pension income in the rate base. See id. The 7 Attorney General’s position is that the utility can only recover the costs of financing 8 the reduction of the utility’s revenue requirement, i.e., the utility can only earn a 9 return from the pension income generated by the prepaid pension asset. 10 {17} However, a utility may not only be out-of-pocket for reductions in its revenue 11 requirement resulting from pension fund earnings. A utility may also be out-of12 pocket for investor-funded contributions that are in excess of pension expenses. 13 Basically, when a utility supplies working capital to fund contributions in excess of 14 pension expenses to create an income-producing prepaid pension asset, the utility 15 finances the cost of the entire prepaid pension asset. See, e.g., In re Rocky Mountain 16 Power, 2014 WL 7526282, at *14 ¶¶ 52, 53, *36 (Wyo. P.S.C. 2014) (noting that a 17 “prepaid pension asset represents [a utility’s] contributions to its pension . . . plans 18 in excess of what is expensed to that time” and the utility “finances the asset with a 12 1 combination of debt and equity financing”). 2 {18} Other jurisdictions have allowed utilities to recover the financing costs of the 3 net prepaid pension asset by including the asset in the rate base as a component of 4 working capital. See, e.g., Ind. Office of Util. Consumer Counselor, 7 N.E.3d 1025, 5 2014 WL 934350, at *12 (upholding a regulatory determination that a prepaid 6 pension asset be included in the rate base because the “asset amounted to working 7 capital that benefited the ratepayers by reducing the total pension costs needed in [the 8 utility’s] revenue requirement”); In re Rocky Mountain Power, 2014 WL 7526282, 9 at *14, *36 (finding persuasive a utility’s argument that it should recover the 10 financing costs of its prepaid pension asset by including the asset in the rate base to 11 enable the utility to earn a return on that asset). But see In re Pub. Util. Comm’n of 12 Or., 2015 WL 4710466, at *7 (Or. P.U.C. 2015) (affirming a “long-standing policy 13 of allowing a utility to recover its pension contributions [only as an] expense and 14 reject[ing] the . . . Utilities’ proposal to include their current prepaid pension assets 15 in rate base”). 16 {19} On appeal, the Attorney General does not argue as a matter of law that the 17 prepaid pension asset cannot be included in the rate base. The Attorney General’s 18 only evidentiary challenge is that inclusion of the net prepaid pension asset will result 13 1 in ratepayers paying more to SPS than the benefit ratepayers have enjoyed from the 2 pension fund earnings. We interpret the Attorney General’s argument to be that SPS 3 did not prove how much of the net prepaid pension asset resulted in consumers 4 paying $1.7 million less to SPS. We disagree. We hold that some or all of a prepaid 5 pension asset should be included in the rate base to the extent that the evidence 6 evinces that the asset was investor-funded, as opposed to ratepayer-funded.3 See In 7 re Potomac Elec. Power Co., 2008 WL 516553, slip copy at 29, 263 P.U.R. 4th 1 8 (D.C. P.S.C.) (finding that “investor-supplied cash contributions have resulted in an 9 asset from which [utility] customers receive a tangible benefit in the form of reduced 10 pension expenses” and including the prepaid pension asset in the rate base), adhered 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Because utilities may only include in the rate base investor-funded, prepaid pension assets, we emphasize that “shareholder contributions do not solely drive prepaid pension asset balances.” In re Pub. Util. Comm’n of Or., 2015 WL 4710466, at *8 (Or. P.U.C. 2015) . For example, during “periods of high economic growth, a prepaid pension asset balance will increase even with no shareholder contributions,” id., presumably because, among other reasons, existing funds within a pension trust can earn unexpectedly high returns. See, e.g., In re Cent. Tel. Co. of Tex., 19 Tex. P.U.C. Bull. 929, 1993 WL 595464, slip copy at 13 (Tex. P.U.C. 1993) (noting that because a utility failed to “accurately predict that its pension fund would experience favorable investment results and that there would be reductions in benefit levels, the [utility’s] pension fund was subsequently overfunded” through rates collected earlier from ratepayers). In short, simply placing a prepaid pension asset in the rate base allows utilities to earn returns on amounts that are not shareholder contributions. See In re Pub. Util. Comm’n of Or., 2015 WL 4710466, at *8. 3 14 1 to on denial of reconsideration sub nom. 2008 WL 4831456 (slip copy) (D.C. P.S.C. 2 2008); In re N. Ill. Gas Co., 2005 WL 2445944, slip copy at 23 (Ill. C.C. 2005) 3 (noting that a prepaid pension asset “was created by ratepayer-supplied funds, not by 4 shareholder-supplied funds,” and finding that the “prepaid pension asset should be 5 eliminated from rate base”); In re Zia Nat. Gas Co., 2000-NMSC-011, ¶ 22 (noting 6 that only investor-supplied working capital may be included in the rate base); In re 7 Cent. Tel. Co. of Tex., 19 Tex. P.U.C. Bull. 929, 1993 WL 595464, slip copy at 13 8 (Tex. P.U.C. 1993) (concluding that conversely, when ratepayer-supplied money 9 overfunds a pension plan, investors are not entitled to “earn a return on the prepaid 10 pension asset because [this] . . . would have the effect of charging ratepayers again 11 for amounts they have already paid”). Similarly, while a prepaid pension asset may 12 be included in the rate base, prepaid pension liability must be subtracted from the rate 13 base. See, e.g., In re Ky.-Am. Water Co., 1997 WL 34863470, slip copy at 10 (Ky. 14 P.S.C. 1997) (noting that although pension liabilities can be utilized to reduce the rate 15 base, if “a pension asset is created, then the asset should be included as a rate base 16 addition”), opinion modified on denial of reh’g sub nom. In re Adjustment of the 17 Rates of Ky.-Am. Water Co., 1997 WL 34863471 (slip copy) (Ky. P.S.C. 1997). 18 {20} The evidence indicates that SPS has a net prepaid pension asset of 15 1 approximately $22 million. The evidence also indicates that including $22 million 2 of the net prepaid pension asset in the rate base would generate approximately $2.5 3 million in revenue for SPS, which exceeds the $1.7 million by which SPS asserts the 4 pension expense was reduced. SPS maintains that its actual annual pension expense 5 is $5.36 million, but the $1.7 million return on the prepaid pension asset reduced the 6 pension expense to $3.66 million. 7 {21} Although the Attorney General is correct to make an evidentiary contention, 8 the premise of its argument is incorrect. Utilities are able to recover the costs of 9 financing their business operations through the inclusion of investor-supplied 10 working capital in the rate base. See In re Zia Nat. Gas Co., 2000-NMSC-011, ¶ 22. 11 In his written testimony, Gene H. Wickes stated that “[t]he portion of the prepaid 12 pension asset due to these contributions has therefore come exclusively from 13 shareholder capital and should be included in rate base.” It is uncontested that SPS 14 investors made contributions to the pension fund that are required by law. These 15 contributions exceeded expenses and generated earnings that effectively reduced 16 SPS’s—and consequently the ratepayers’—pension expense. Had the ratepayers 17 advanced the contributions to the pension fund, their contributions would not have 18 been included in the rate base. See In re N. Ill. Gas Co., 2005 WL 2445944, slip copy 16 1 at 14. However, because the ratepayers did not make the contributions, the investors, 2 not the ratepayers, absorbed the cost of funding the pension program, and therefore 3 the net prepaid pension asset was properly included in the rate base. See, e.g., In re 4 Pub. Serv. Co. of Colo., 1993 WL 494141, slip copy at 17, 148 P.U.R. 4th 1 (Colo. 5 P.U.C. 1993) (“In order to compensate investors for the additional funds they supply 6 to meet the higher contribution levels, the resulting prepaid assets are an appropriate 7 addition to rate base.”); In re Potomac Elec. Power Co., 2008 WL 4831456, slip copy 8 at 3 (concluding that inclusion of an investor-supplied prepaid pension asset in the 9 rate base is supported by substantial evidence because “the earnings on the prepaid 10 pension asset will reduce the annual [utility] expense, thus benefiting customers by 11 reducing the revenue requirement”); Ind. Office of Util. Consumer Counselor, 7 12 N.E.3d 1025, 2014 WL 934350, at *12 (upholding a regulatory determination that a 13 prepaid pension asset amounted to working capital that should be included in the rate 14 base). 15 {22} We note, however, that contributions to pension funds should be scrutinized 16 to ensure that utility investments are “used and useful” so as to inure to the benefit 17 of consumers. See N.M. Indus. Energy Consumers v. N.M. Pub. Serv. Comm’n, 18 1986-NMSC-059, ¶ 29, 104 N.M. 565, 725 P.2d 244 (internal quotation marks 17 1 omitted) (noting that the “ ‘used and useful’ concept is but one factor among many 2 to be considered by the [PRC] in its rate base analysis”). Utilities should not 3 voluntarily overfund their pension funds simply to earn a favored rate of return. In 4 re Appalachian Power Co., 2011 WL 2150661, slip op. at 27, 288 P.U.R. 4th 185 (W. 5 Va. P.S.C. 2011) (“Prepayments should be subject to the same review as any other 6 investment or expense of a utility. Inclusion of prepayments in rate base should not 7 be used for a utility to find a convenient place to deposit funds and then expect to 8 earn a return on those funds.”). On the other hand, mandatory contributions to 9 pension funds are useful. Such contributions may benefit customers by generating 10 an income-earning prepaid pension asset to reduce pension expenses, see, e.g., In re 11 Potomac Elec. Power Co., 2008 WL 516553, slip copy at 29, and also fund the 12 pension programs that make it possible for the utility to attract and retain 13 highly-skilled workers. See, e.g., In re Advice Letter No. 830 - Gas of Pub. Serv. Co. 14 of Colo., 2013 WL 5799983, at *46-47 (Colo. P.U.C.). 15 {23} We conclude that the Attorney General has failed to meet its burden of showing 16 that the PRC’s inclusion of the entire prepaid pension asset was unreasonable or 17 unlawful for lack of substantial evidence. 18 2000-NMSC-012, ¶ 4. 18 See In re PNM Gas Servs., 1 II. 2 THE LAWFULNESS STANDARDS RIDER 3 A. 4 SPS’s Recovery of Renewable Energy Procurement Costs from NonCapped Customers 5 The Attorney General also contends that the PRC acted contrary to law when {24} OF THE RENEWABLE PORTFOLIO 6 it approved SPS’s renewable energy cost rider because the rider sought to recover 7 renewable energy costs from non-capped customers, customers who are not subject 8 to a legislatively imposed limit on their renewable energy costs. We review issues 9 of law de novo. N.M. Attorney Gen. v. N.M. Pub. Regulation Comm’n, 10 2013-NMSC-042, ¶ 10, 309 P.3d 89. However, “[w]hen an agency that is governed 11 by a particular statute construes or applies that statute, [we] will [accord] some 12 deference to the agency’s interpretation.” Id. ¶ 12 (internal quotation marks and 13 citations omitted). We will reverse the agency’s interpretation of a statute if it is 14 unreasonable or unlawful. Id. 15 {25} The resolution of this issue necessitates a discussion of the Renewable Energy 16 Act, §§ 62-16-1 to -10. As a preface to our discussion of this issue, some background 17 on renewable energy promotion is warranted. 18 {26} Under the traditional rate formula, utilities receive a reasonable rate of return 19 for capital project investments such as power plants. See Tomain, “Steel in the 19 1 Ground,” supra, at 946. Utilities consequently have an incentive to invest in capital 2 projects, see id., and “prefer low-risk, conventional technologies that can be built 3 quickly instead of long-term, innovative technologies that would be riskier.” Virginia 4 R. Hildreth, Comment, Renewable Energy Subsidies and the GATT, 14 Chi. J. Int’l 5 L. 702, 707 (2014). As a result, “government assistance is often key to encourage 6 investment in industries like renewable energy.” Id. Such encouragement is 7 desirable because there are numerous benefits to renewable energy such as “lessened 8 dependence on foreign fossil fuel supplies, heightened national security, overall 9 cleaner air, and local and rural job creation.” Shelley Welton, From the States Up: 10 Building a National Renewable Energy Policy, 17 N.Y.U. Envtl. L.J. 987, 995 11 (2008); see also Brent M. Haddad & Paul Jefferiss, Forging Consensus on National 12 Renewables Policy: The Renewables Portfolio Standard and the National Public 13 Benefits Trust Fund, 12 The Elec. J. 68, 69 (Mar. 1999) (listing benefits of renewable 14 energy). 15 {27} Renewable portfolio standards are among the most popular methods of 16 encouraging renewable energy development. See Lincoln L. Davies, State Renewable 17 Portfolio Standards: Is There A “Race” and Is It “To the Top”?, 3 San Diego J. 18 Climate & Energy L. 3, 10 (2011-2012). These standards mandate that utilities 20 1 incorporate renewable energy sources into their electric generation portfolios, id. at 2 13, and frequently enable utilities to purchase renewable energy credits4 to satisfy the 3 mandates of renewable portfolio standards. Id. at 11. A renewable portfolio standard 4 therefore combines “both a potentially inflexible regulatory directive and the 5 malleable tool of economic trading,” id. at 10, to “inject an element of economic 6 efficiency into [renewable portfolio standard] schemes.” Id. at 11. 7 {28} Under the Renewable Energy Act, New Mexico has a renewable portfolio 8 standard that both mandates the incorporation of renewable energy sources into 9 electric generation portfolios and allows for the purchase of renewable energy 10 certificates (credits) to satisfy the mandates. Sections 62-16-4 to -5. Pursuant to this 11 renewable portfolio standard, before the proceedings in this case, the evidence 12 indicates that SPS received PRC approval to (1) purchase the outputs of two New 13 Mexico wind farms, (2) pay incentives encouraging customers to install solar and 14 biomass generation systems, (3) obtain renewable energy credits from various 15 sources, and (4) purchase solar photovoltaic systems. 16 {29} The controversy over the permissibility of SPS’s proposed rider arises from a 4 17 Renewable energy credits “typically represent the production of one megawatt 18 hour (‘MWh’) of renewables-fueled electricity.” Davies, supra, at 11. 21 1 disagreement as to how renewable energy costs are allocated between different rate 2 classes. In utility regulation, customers are often divided into different classes that 3 are charged different rates. II Leonard Saul Goodman, The Process of Ratemaking 4 964-65 (1998). The creation of rate classes involves the consideration of various 5 factors such as alternate fuel capability and types of customer, which can be classified 6 as residential, commercial, or industrial. Id. at 965. Differential rates can be utilized 7 to implement various policies. Tomain, “Steel in the Ground,” supra, at 946-47. 8 {30} In this case, cost allocation has been utilized to address a problem that is 9 incidental to the promotion of renewable energy generation. The use of renewable 10 energy tends to raise energy costs relative to the consumption of fossil fuels. See 11 Hildreth, supra, at 716 (“The technology needed for renewable energy tends to be 12 more expensive than traditional fuel sources.”); Trevor D. Stiles, Renewable 13 Resources and the Dormant Commerce Clause, 4 Envtl. & Energy L. & Pol’y J. 34, 14 43-44, 45 (2009) (numerically illustrating how there is a “vast price discrepancy 15 between renewable energy sources and fossil fuel sources for energy generation”). 16 The prospect of “overly high renewable implementation costs” has prompted concern 17 that commercial and large industrial customers may leave the utility system or exit 18 states that implement prohibitively expensive renewable energy promotion plans. 22 1 California Commissioner Seeks Consideration of Shale Gas, 4054 PUR Util. Reg. 2 News 1, 1 (Jan. 20, 2012). These large customers may have the capacity to self3 generate their energy needs or simply close their plants in areas where energy costs 4 are high. See Charles G. Stalon & Reinier H.J.H. Lock, State-Federal Relations in 5 the Economic Regulation of Energy, 7 Yale J. on Reg. 427, 449 (1990). When these 6 large customers are driven from the utility system, utility rates have to be raised even 7 further for remaining customers, which exacerbates the potential for other customer 8 exits. See id. In light of the potential for large customers to exit the grid, the 9 Legislature enacted Section 62-16-4(A)(2), which limits the annual amount large 10 customers can be charged for renewable energy procurement. The PRC calls this 11 limit the “large customer cap.” Accordingly, costs that exceed the large customer cap 12 may be called “large customer cap costs.” 13 {31} In earlier proceedings, the evidence indicates that the PRC had already 14 approved SPS’s “requested procurements without any reduction to SPS’s overall 15 [renewable portfolio standards] to account for large customer cap costs.” When the 16 PRC learned that SPS’s costs exceeded the large customer cap, the PRC specifically 17 approved treatment of that amount as a deferred cost. “A ‘deferred cost’ is one that 18 has been paid by the [utility] but is postponed for inclusion in rates until a future 23 1 period.” I Leonard Saul Goodman, The Process of Ratemaking 321 (1998). This may 2 occur, for example, when a utility “has a major future liability, and before collecting 3 anything through rates, its management decides that the books should reflect the 4 liability.” Id. Under these circumstances, a utility “may apply for [regulator] 5 approval to fund an account, and to reflect on its books a deferred debit or ‘regulatory 6 asset,’ . . . which later can be charged to ratepayers and amortized over a future 7 period.” Id. Regulatory assets are often created to spread out the recovery of 8 nonrecurring costs over a period of years so as to avoid substantial rate increases, 9 which may occur if full recovery was allowed as soon as the utility made an 10 expenditure. City of Corpus Christi v. Pub. Util. Comm’n of Tex., 51 S.W.3d 231, 11 244-45 (Tex. 2001). 12 {32} SPS filed an application seeking to obtain a rider to recover approximately $22 13 million of renewable energy procurement costs. Riders are surcharges applied to 14 directly recover specific costs. See Chesapeake Utils. Corp. v. Del. Pub. Serv. 15 Comm’n, 705 A.2d 1059, 1063 (Del. Super. Ct. 1997) (referring to a rider as a 16 surcharge); Citizens Util. Bd. v. Ill. Commerce Comm’n, 651 N.E.2d 1089, 1102 (Ill. 17 1995) (“[A] rider mechanism . . . facilitates direct recovery of a particular cost.”). 18 These surcharges give regulators more flexibility in spreading out costs charged to 24 1 ratepayers over a period of time. See Chesapeake Utils. Corp., 705 A.2d at 1063 n.3. 2 {33} Section 62-16-4(A)(1)(a)-(d) mandates that a certain percentage of a “public 3 utility’s total retail sales to New Mexico customers” be comprised of renewable 4 energy. The required percentage escalates over time. See id. However, under the 5 large customer cap provision of Section 62-16-4(A)(2), the renewable portfolio 6 standards mandated in Section 62-16-4(A)(1) 7 8 9 10 11 12 13 14 15 16 shall be reduced, as necessary, to provide for the following specific procurement requirements for nongovernmental customers at a single location or facility, regardless of the number of meters at that location or facility, with consumption exceeding ten million kilowatt-hours per year [(capped customers)]. On and after January 1, 2006, the kilowatt-hours of renewable energy procured for these customers shall be limited so that the additional cost of the renewable portfolio standard to each customer does not exceed the lower of one percent of that customer’s annual electric charges or forty-nine thousand dollars ($49,000) [(large customer cap)]. 17 Section 62-16-4(A)(2). The large customer cap in Section 62-16-4(A)(2) also 18 escalates over time such that capped customers can continue to be charged increasing 19 amounts for renewable energy. 20 {34} The evidence indicates that SPS sought to recover the renewable energy 21 procurement costs that exceeded the large customer cap from non-capped customers. 22 The Attorney General opposed SPS’s application, arguing that SPS could only 25 1 recover its costs from large customers. The Attorney General argues that recovery 2 of large customer cap costs from non-capped customers is contrary to both Section 3 62-16-4(A)(2) and 17.9.572.15 NMAC, a regulation concerning renewable energy 4 cost recovery. The Attorney General contends that Section 62-16-4(A)(2) mandates 5 the reduction of renewable energy procurements if such procurements would generate 6 costs in excess of the large customer cap. Under the Attorney General’s reasoning, 7 because large customer cap costs should not have arisen as a matter of law, they 8 cannot be allocated to non-capped customers. 9 {35} In a supplemental recommended decision, the hearing examiner recommended 10 that SPS be allowed to recover large customer cap costs from non-capped customers 11 because given the cost limits on large customers, SPS’s ability to collect excess costs 12 from large customers in the future would be speculative and uncertain. In a final 13 order partially adopting the recommended decision (the final order), the PRC agreed 14 with the hearing examiner. We affirm the PRC on this issue because its actions are 15 consistent with Section 62-16-4(A)(2) and the Renewable Energy Act as a whole. 16 B. Discretion to Reduce Renewable Energy Procurements 17 Section 62-16-4(A)(2) states that the New Mexico renewable portfolio {36} 18 standards mandate “shall be reduced, as necessary” to accommodate the large 26 1 customer cap. According to the Attorney General, the word “shall” indicates that 2 renewable energy procurement reductions are mandated whenever renewable energy 3 procurement costs would otherwise exceed the large customer cap. One opposing 4 interpretation of Section 62-16-4(A)(2) is that the phrase “as necessary” modifies the 5 phrase “shall be reduced” to indicate that the PRC has discretion to reduce renewable 6 energy procurements, even if large customer cap costs would result from such 7 procurements. The Attorney General argues that when large customer cap costs arise, 8 the PRC has discretion regarding the amount by which renewable energy procurement 9 should be reduced, but not whether the renewable portfolio standards should be 10 reduced. We hold that (1) Section 62-16-4(A)(2) does not mandate a reduction in 11 renewable energy procurement whenever large customer cap costs arise, and (2) the 12 PRC has discretion to reduce renewable energy procurement when large customer cap 13 costs arise. 14 {37} Our analysis begins with the plain text of the statute. Garcia v. Gutierrez, 15 2009-NMSC-044, ¶ 53, 147 N.M. 105, 217 P.3d 591. In analyzing the phrase “shall 16 be reduced, as necessary,” we knowledge that “shall” is a word of mandate. See 17 Black’s Law Dictionary 1375 (6th ed. 1990). However, the phrase “as necessary” 18 indicates discretion. Norris v. Emanuel Cty., 561 S.E.2d 240, 244 (Ga. Ct. App. 27 1 2002). Because “as necessary” modifies the word “shall” in Section 62-16-4(A)(2) 2 (internal quotation marks omitted), the statute’s plain text indicates that when large 3 customer cap costs arise, the PRC has discretion to determine whether renewable 4 energy procurement reductions are necessary. 5 {38} The next sentence in Section 62-16-4(A)(2) provides that “the kilowatt-hours 6 of renewable energy procured for these customers shall be limited so that the 7 additional cost of the renewable portfolio standard to each customer does not exceed” 8 the large customer cap. The word “shall” in this sentence is not modified by any 9 words of discretion. The Attorney General apparently relies upon this lack of 10 discretionary language to argue that Section 62-16-4(A)(2) mandates renewable 11 energy procurement reductions whenever large customer cap costs arise. We 12 disagree. This sentence merely precludes capped customers from being charged costs 13 in excess of the statutory cap. Logically, should large customer cap costs arise, the 14 PRC can ensure compliance with the statutory cap in two ways: the PRC can either 15 reduce renewable energy procurement or adjust what is actually charged to capped 16 customers. In adjusting what is actually charged to capped customers, the PRC “may 17 authorize deferred recovery of the costs of complying with the renewable portfolio 18 standard.” Section 62-16-4(A)(2). In other words, the PRC can choose not to reduce 28 1 procurements, even when large customer cap costs arise, by deferring the excess costs 2 for later recovery, so as not to charge capped customers with statutorily prohibited 3 costs. See id. 4 {39} A plain reading of Section 62-16-4(A)(2) indicates that the PRC has the 5 authority not to reduce renewable energy procurements, even when large customer 6 cap costs increase. This interpretation is strongly supported by a reading of the 7 Renewable Energy Act in its entirety, and it should therefore be adopted. See Arnold 8 v. State, 1980-NMSC-030, ¶ 10, 94 N.M. 381, 610 P.2d 1210 (“Legislative intent is 9 to be determined primarily from the language used in the Act or statute as a whole.”). 10 Moreover, this reading acknowledges the difficulty of avoiding large customer cap 11 costs. 12 {40} First, the renewable portfolio standard promulgated by the Renewable Energy 13 Act provides a minimum standard. See § 62-16-4(A)(1) (“[R]enewable energy shall 14 comprise no less than [a given] percent of each public utility’s total retail sales to 15 New Mexico customers.” (emphasis added)). The Attorney General’s reading of 16 Section 62-16-4(A)(2) would have us treat the large customer cap as providing a 17 maximum standard. This is problematic because mandating renewable energy 18 procurement reductions whenever large customer cap costs arise would be 29 1 inconsistent with Section 62-16-2(A)(5), which plainly states that “a public utility 2 should have incentives to go beyond the minimum requirements of the renewable 3 portfolio standard.” 4 {41} Second, Section 62-16-4(A) clearly evinces a legislative intent to 5 systematically increase renewable energy use in New Mexico. Section 62-16-4(A)(1) 6 escalates renewable energy procurement requirements over time, while Section 627 16-4(A)(2) increases the large customer cap over time. Mandating renewable energy 8 procurement reductions whenever large customer cap costs arise would undermine 9 New Mexico’s ability to systematically increase renewable energy usage. 10 {42} Third, the Attorney General’s argument is erroneously premised on the idea 11 that Section 62-16-4(A)(2) was meant to protect non-capped customers from high 12 renewable energy costs by banning costs in excess of the large customer cap to 13 prevent large customer cap costs from being allocated to non-capped customers. We 14 need not adopt the Attorney General’s interpretation of Section 62-16-4(A)(2) to 15 protect non-capped customers from high renewable energy costs because another 16 statutory provision already performs this function: Section 62-16-4(B) mandates 17 setting an overall reasonable cost threshold for renewable energy procurement. 18 {43} Fourth, the Attorney General’s argument appears to assume that large customer 30 1 cap costs can be forecast on an accurate and consistent basis so that in approving 2 renewable energy procurements, the PRC can systematically avoid large customer cap 3 costs. The record proper indicates otherwise. PRC approvals of renewable energy 4 procurement are “based on the best information available at the time the resources 5 were being reviewed.” SPS notes that how much large customer cap costs will 6 increase depends on future occurrences such as the fluctuation of natural gas prices. 7 Accordingly, the evidence indicates that we cannot reasonably expect that large 8 customer cap costs can be predictably eliminated. 9 {44} Reading the language of the Renewable Energy Act as a whole, we conclude 10 that the PRC has discretion to decline to reduce renewable energy procurement, even 11 when large customer cap costs arise. This authority is congruent with the statutory 12 policy of increasing renewable energy use in New Mexico. Moreover, we cannot 13 reasonably expect that either the PRC or utilities will be able to avoid large customer 14 cap costs. Thus, adopting the Attorney General’s position that large customer cap 15 costs have to be avoided as a matter of law also would be contrary to practical 16 experience. 17 C. 18 Section 62-16-4(A)(2) Does Not Preclude the Recovery of Large Customer Cap Costs from Non-Capped Customers 31 1 {45} The PRC exercised its discretion not to reduce renewable energy procurement 2 when large customer cap costs arose, which is consistent with our interpretation of 3 Section 62-16-4(A)(2). It then authorized the deferral of large customer cap costs for 4 future recovery. The PRC’s final order provides for the collection of large customer 5 cap costs from non-capped customers. We therefore determine the permissibility of 6 collecting large customer cap costs from non-capped customers. 7 {46} The Attorney General does not oppose SPS’s ability to recover deferred large 8 customer cap costs. It merely contends that such costs should not be recovered from 9 non-capped customers, asserting that (1) enabling recovery of large customer cap 10 costs from non-capped customers “violate[s] the basic ratemaking principle of cost[ ] 11 causation,” and (2) Section 62-16-4(A)(2) protects non-capped customers from 12 paying for large customer cap costs. We reject the Attorney General’s position as 13 contrary to law and hold that large customer cap costs can be allocated to non-capped 14 customers. 15 {47} The Attorney General’s contention that allocating large customer cap costs to 16 non-capped customers violates the principle of cost causation is without merit. The 17 plain language of Section 62-16-4(A)(2) does not mandate that renewable energy 18 procurement costs be recovered only against those customers who caused large 32 1 customer cap costs. Moreover, renewable energy procurement costs arise as a result 2 of statutory mandate, see § 62-16-4(A)(1), such that neither capped nor non-capped 3 customers can be said to cause any specific procurement costs. 4 {48} Similarly, the Attorney General’s assertion that Section 62-16-4(A)(2) protects 5 non-capped customers from large customer cap costs is unsupported by law. Its 6 argument assumes that Section 62-16-4(A)(2) mandates reductions in renewable 7 energy procurement whenever large customer cap costs arise to protect both capped 8 and non-capped customers from high renewable energy costs. Under the Attorney 9 General’s reasoning, rates for non-capped customers cannot be increased by large 10 customer cap costs because such increases would deprive non-capped customers of 11 the protections provided by Section 62-16-4(A)(2). We reject this reasoning because 12 Section 62-16-4(A)(2) does not evince a legislative intent to protect non-capped 13 customers. We have already held that Section 62-16-4(A)(2) does not mandate 14 renewable energy procurement reductions when large customer cap costs arise. The 15 Attorney General’s contention that Section 62-16-4(A)(2) precludes large customer 16 cap costs to protect non-capped customers is also incorrect because nothing in 17 Section 62-16-4(A)(2) addresses the interests of non-capped customers. See State v. 18 Diamond, 1921-NMSC-099, ¶ 5, 27 N.M. 477, 202 P. 988 (We will not insert words 33 1 that are absent in a statute.). We conclude that Section 62-16-4(A)(2) does not 2 preclude the allocation of large customer cap costs to non-capped customers. 3 {49} The PRC had previously approved of SPS’s procurement plans. Under Section 4 62-16-6(A), “[c]osts that are consistent with commission approval of procurement 5 plans . . . shall be deemed to be reasonable.” Thus, the renewable procurement costs 6 in this case are reasonable as a matter of law. Because these procurement costs are 7 reasonable, SPS is entitled under Section 62-16-6(A) to recover large customer cap 8 costs. Id. (“A public utility that procures or generates renewable energy shall recover, 9 through the rate-making process, the reasonable costs of complying with the 10 renewable portfolio standard.”). The evidence indicates that if large customer cap 11 costs only can be collected from capped customers, 20 years or more could elapse 12 “before SPS even has the opportunity to collect” these procurement costs. Thus, as 13 the PRC determined, the Attorney General’s proposed cost recovery mechanism “is 14 speculative and uncertain, and would not provide a reasonable opportunity for SPS 15 to recover [large customer cap] costs.” Forcing SPS to collect large customer cap 16 costs only from capped customers would effectively disallow recovery of these 17 procurement costs, contrary to the Renewable Energy Act’s guarantee that utilities 18 can recover the reasonable costs of renewable energy procurement. Sections 34 1 62-16-4(A)(2) & -6(A).5 2 D. 3 17.9.572.15 NMAC Does Not Preclude the Recovery of Large Customer Cap Costs from Non-Capped Customers 4 The Attorney General contends that the “plain language” of 17.9.572.15 {50} 5 NMAC “make[s] clear that costs associated with large [capped] customers should be 6 borne by large customers alone.” 17.9.572.15 NMAC is a regulatory provision 7 concerning renewable energy cost recovery that references Section 62-16-4(A)(2). 8 Our interpretation of Section 62-16-4(A)(2) therefore informs our construction of 9 17.9.572.15 NMAC. We have previously held in this opinion that Section 62-1610 4(A)(2) provides the PRC with discretion, not a mandate, to reduce renewable energy 11 procurement when large customer cap costs arise, and does not bar the allocation of 12 large customer cap costs to non-capped customers. Consistent with our interpretation 13 of Section 62-16-4(A)(2), we hold that 17.9.572.15 NMAC also does not bar the 14 allocation of large customer cap costs to non-capped customers. 15 16 17 18 19 20 21 5 We also note that although the Attorney General relies on Section 62-16-4(A)(2) to argue for a cost recovery mechanism which SPS argues would effectively disallow its ability to recover large customer cap costs, such a mechanism would be contrary to the plain language of Section 62-16-4(A)(2), which provides that “[n]othing contained in this paragraph [concerning the large customer cap] shall be construed as affecting a public utility’s right to recover all reasonable costs of complying with the renewable portfolio standard.” 35 1 {51} 17.9.572.15 NMAC provides that: 2 3 4 5 6 A. A public utility shall recover the reasonable costs of complying with this rule through the rate making process, including its reasonable interconnection and transmission costs and other costs attributable to acquisition and delivery of renewable energy to retail New Mexico customers. 7 8 B. Costs that are consistent with commission-approved annual Renewable Energy Act plans are deemed to be reasonable. 9 10 11 12 13 14 C. A public utility that is permitted to defer the recovery of renewable energy costs pursuant to commission order may, through the ratemaking process, recover from customers that are not subject to the rate impact limitations of Sections 62-16-4A(2) and 62-16-4A(3) NMSA 1978 the cumulative sum of those deferred amounts, plus a carrying charge on those amounts. 15 16 17 18 19 D. For customers that are subject to the rate impact limitations of Section 62-16-4A(2) NMSA 1978, a public utility may, through the ratemaking process, recover from those customers the cumulative sum of those Section 62-16-4A(2) NMSA 1978 limited deferred amounts, plus carrying charges on those amounts. 20 21 22 23 E. Any renewable energy procurement costs recovered through the utility’s fuel clause shall be separately identified in its monthly and annual fuel and purchased power clause adjustment filings and its continuation filings. 24 {52} The Attorney General’s argument relies on 17.9.572.15(D) NMAC to support 25 its contention that large customer cap costs can only be recovered from large 26 customers. The Attorney General seems to share our understanding that large 36 1 customer cap costs, which arise pursuant to Section 62-16-4A(2), may be deferred. 2 Based on this understanding, the Attorney General assumes that the term “Section 623 16-4A(2) NMSA 1978 limited deferred amounts” in Subsection D is a synonym for 4 deferred large customer cap costs. Armed with this assumption, the Attorney General 5 contends that because Subsection D concerns recovery of costs from capped 6 customers and only Subsection D expressly refers to recovery of “Section 62-167 4A(2) NMSA 1978 limited deferred amounts,” large customer cap costs can only be 8 recovered from capped customers. 9 {53} We reject the Attorney General’s contention. 17.9.572.15(C) NMAC states 10 that whenever “[a] public utility . . . is permitted to defer the recovery of renewable 11 energy costs pursuant to commission order,” the utility may recover the deferred 12 amounts from non-capped customers. Subsection C therefore authorizes public 13 utilities to recover deferred costs, in general, from non-capped customers. By 14 contrast, 17.9.572.15(D) NMAC explicitly authorizes only the recovery of “Section 15 62-16-4A(2) NMSA 1978 limited deferred amounts” from capped customers. Thus, 16 although 17.9.572.15(D) NMAC arguably provides that only “Section 62-16-4A(2) 17 NMSA 1978 limited deferred amounts” may be recovered from capped customers, 18 17.9.572.15(C) NMAC provides that any deferred amounts may be recovered from 37 1 non-capped customers. 2 {54} We conclude that a plain reading of 17.9.572.15 NMAC indicates that deferred 3 costs arising from Section 62-16-4A(2) can be recovered from both capped and non4 capped customers. There is simply no language explicitly banning the collection of 5 deferred large customer cap costs from non-capped customers. The Attorney General 6 errs in conflating the issue of whether capped customers may be charged only for 7 Section 62-16-4A(2) deferred amounts with whether only capped customers may be 8 charged the aforesaid deferred amounts. 9 III. 10 {55} CONCLUSION We affirm the PRC’s final order. We will not disturb the PRC’s finding that 11 SPS’s entire prepaid pension asset was properly included in the rate base. We also 12 hold that the PRC properly allocated large customer cap costs to non-capped 13 customers to enable SPS to recover its reasonable renewable energy procurement 14 costs. 15 {56} IT IS SO ORDERED. 16 17 ______________________________ EDWARD L. CHÁVEZ, Justice 38 1 WE CONCUR: 2 ___________________________________ 3 BARBARA J. VIGIL, Chief Justice 4 ___________________________________ 5 PETRA JIMENEZ MAES, Justice 6 ___________________________________ 7 CHARLES W. DANIELS, Justice 8 ___________________________________ 9 TIMOTHY L. GARCIA, Judge 10 Sitting by designation 39
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